10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

☒    ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2021

or

☐    TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from            to            

Commission file number 001-37983

TechnipFMC plc

(Exact name of registrant as specified in its charter)

United Kingdom	98-1283037
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
Hadrian House, Wincomblee Road
Newcastle Upon Tyne
United Kingdom	NE6 3PL
(Address of principal executive offices)	(Zip Code)

+44 191-295-0303

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class	Trading Symbol	Name of Each Exchange on Which Registered
Ordinary shares, $1.00 par value per share	FTI	New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: None.

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ý    No  ¨ 

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes  ¨   No  ý

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes   ý    No  ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).     Yes  ý    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

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

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).  YES  ☐    NO  ý

The aggregate market value of the registrant’s ordinary shares held by non-affiliates of the registrant, determined by multiplying the outstanding shares on June 30, 2021, by the closing price on such day of $9.05 as reported on the New York Stock Exchange, was $3.3 billion.

Class	Outstanding at February 22, 2022
Ordinary shares, $1.00 par value per share	450,700,480

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s definitive Proxy Statement relating to its 2022 Annual General Meeting of Shareholders are incorporated by reference into Part III of this Annual Report on Form 10-K where indicated. The 2022 Proxy Statement will be filed with the U.S. Securities and Exchange Commission within 120 days after the end of the fiscal year to which this report relates.

TABLE OF CONTENTS

	Page
PART I
Item 1. Business	4
Item 1A. Risk Factors	20
Item 1B. Unresolved Staff Comments	37
Item 2. Properties	37
Item 3. Legal Proceedings	39
Item 4. Mine Safety Disclosures	39
PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	39
Item 6. [Reserved]	40
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations	41
Item 7A. Quantitative and Qualitative Disclosures About Market Risk	58
Item 8. Financial Statements and Supplementary Data	60
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	119
Item 9A. Controls and Procedures	119
Item 9B. Other Information	119
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections	119
PART III
Item 10. Directors, Executive Officers and Corporate Governance	120
Item 11. Executive Compensation	120
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	120
Item 13. Certain Relationships and Related Transactions, and Director Independence	121
Item 14. Principal Accountant Fees and Services	121
PART IV
Item 15. Exhibit and Financial Statement Schedules	121
Item 16. Form 10-K Summary	122
Signatures	124

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Annual Report on Form 10-K contains “forward-looking statements” as defined in Section 27A of the United States Securities Act of 1933, as amended, and Section 21E of the United States Securities Exchange Act of 1934, as amended (the “Exchange Act”). Forward-looking statements usually relate to future events, market growth and recovery, growth of our new energies business and anticipated revenues, earnings, cash flows or other aspects of our operations or operating results. Forward-looking statements are often identified by the words “believe,” “expect,” “anticipate,” “plan,” “intend,” “foresee,” “should,” “would,” “could,” “may,” “estimate,” “outlook” and similar expressions, including the negative thereof. The absence of these words, however, does not mean that the statements are not forward-looking. These forward-looking statements are based on our current expectations, beliefs and assumptions concerning future developments and business conditions and their potential effect on us. While management believes these forward-looking statements are reasonable as and when made, there can be no assurance that future developments affecting us will be those that we anticipate.

All of our forward-looking statements involve risks and uncertainties (some of which are significant or beyond our control) and assumptions that could cause actual results to differ materially from our historical experience and our present expectations or projections. Known material factors that could cause actual results to differ materially from those contemplated in the forward-looking statements include unpredictable trends in the demand for and price of crude oil and natural gas; competition and unanticipated changes relating to competitive factors in our industry, including ongoing industry consolidation; the COVID-19 pandemic, its impact on the demand for our products and services and global shipping and logistics challenges caused by it; our inability to develop, implement and protect new technologies and services, including new technologies and services for our New Energy Ventures; the cumulative loss of major contracts, customers or alliances and unfavorable credit and commercial terms of certain contracts; the refusal of DTC to act as depository agency for our shares; disruptions in the political, regulatory, economic and social conditions of the countries in which we conduct business; the United Kingdom’s withdrawal from the European Union; the impact of our existing and future indebtedness and the restrictions on our operations by terms of the agreements governing our existing indebtedness; the risks caused by our acquisition and divestiture activities; our inability to address increasing attention to ESG matters; certainties related to our investments in new energy industries; the risks caused by fixed-price contracts; any delays and cost overruns of new capital asset construction projects for vessels and manufacturing facilities; our failure to deliver our backlog; our reliance on subcontractors, suppliers and our joint venture partners; a failure or breach of our IT infrastructure or that of our subcontractors, suppliers or joint venture partners, including as a result of cyber-attacks; risks of pirates endangering our maritime employees and assets; potential liabilities inherent in the industries in which we operate or have operated; our failure to comply with numerous laws and regulations, including those related to environmental protection, climate change, health and safety, labor and employment, import/export controls, currency exchange, bribery and corruption, taxation, privacy, data protection and data security; the additional restrictions on dividend payouts or share repurchases as an English public limited company; uninsured claims and litigation against us, including intellectual property litigation; tax laws, treaties and regulations and any unfavorable findings by relevant tax authorities; potential departure of our key managers and employees; adverse seasonal and weather conditions and unfavorable currency exchange rates; and risk in connection with our defined benefit pension plan commitments, as well as those set forth in Part I, Item 1A, “Risk Factors” and elsewhere in this Annual Report on Form 10-K. We caution you not to place undue reliance on any forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any of our forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise, except to the extent required by law.

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PART I

ITEM 1. BUSINESS

Company Overview

TechnipFMC plc, a public limited company incorporated and organized under the laws of England and Wales, with registered number 09909709, and with registered office at Hadrian House, Wincomblee Road, Newcastle Upon Tyne, NE6 3PL, United Kingdom (“TechnipFMC,” the “Company,” “we,” or “our”) is a global leader in the energy industry, delivering projects, products, technologies, and services. With our proprietary technologies and production systems, integrated expertise, and comprehensive solutions, we are transforming our customers’ project economics. We have operational headquarters in Houston, Texas, United States, and in 2021 we principally operated across two business segments: Subsea and Surface Technologies.

We are uniquely positioned to deliver greater efficiency across project lifecycles, from concept to project delivery and beyond. Through innovative technologies and improved efficiencies, our offering unlocks new possibilities for our customers in developing their energy resources and in their positioning to meet the energy transition challenge.

Enhancing our performance and competitiveness is a key component of our strategy, which is achieved through technology and innovation differentiation, seamless execution, and reliance on simplification to drive costs down. We are targeting profitable and sustainable growth by seizing market growth opportunities and expanding our range of services. We are managing our assets efficiently to ensure we are well-prepared to drive and benefit from the opportunities in many of the markets we serve.

Each of our more than 20,000 employees is driven by a steady commitment to clients and a culture of project execution, purposeful innovation, challenging industry conventions, and rethinking how the best results are achieved. This leads to fresh thinking, streamlined decisions, and smarter results, enabling us to achieve our vision of enhancing the performance of the world’s energy industry.

History

In March 2015, FMC Technologies, Inc., a U.S. Delaware corporation (“FMC Technologies”), and Technip S.A., a French société anonyme (“Technip”), signed an agreement to form an exclusive alliance and to launch Forsys Subsea, a 50/50 joint venture, that would unite the subsea skills and capabilities of two industry leaders. This alliance, which became operational on June 1, 2015, was established to identify new and innovative approaches to the design, delivery, and maintenance of subsea fields.

Forsys Subsea brought the industry’s most-talented subsea professionals together early in operators’ project concept phase with the technical capabilities to design and integrate products, systems, and installation to significantly reduce the cost of subsea field development and enhance overall project economics.

Based on the success of the Forsys Subsea joint venture and its innovative approach to integrated solutions, in May 2016 Technip and FMC Technologies announced that the companies would combine through a merger of equals to create a global subsea leader, TechnipFMC, that would drive change by redefining the production of oil and gas. The business combination was completed on January 16, 2017 (the “Merger”), and on January 17, 2017, TechnipFMC began operating as a unified, combined company trading on the New York Stock Exchange (“NYSE”) and on the Euronext Paris Stock Exchange (“Euronext Paris”) under the symbol “FTI.”

In 2017, our first year as a merged company, TechnipFMC secured several project awards as many operators moved forward with final investment decisions for major onshore projects and subsea developments. Several of the subsea awards incorporated the use of our integrated approach to project delivery, validating our unique business model aimed at lowering project costs and accelerating the delivery of initial hydrocarbon production. This was made possible by bringing together the complementary subsea work scopes of the merged companies.

In 2018, TechnipFMC delivered the industry’s first three full-cycle, integrated projects and realized considerable growth in Subsea order inbound, driven in part by its unique integrated offering, iEPCI™ (“iEPCI”). For all of 2019, the value of integrated subsea awards to TechnipFMC more than doubled versus the prior year, representing more than 50% of all Subsea project order inbound. The increase was driven by a wider adoption of the integrated business model, particularly by those clients with whom we have unique alliances. With the industry’s most comprehensive and only truly integrated subsea market offering, we have continued to expand the deepwater opportunity set for our clients.

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On August 26, 2019, we announced our intention to separate into two diversified pure-play market leaders - TechnipFMC, focused on subsea and surface hydrocarbon production, and Technip Energies, focused on downstream engineering, procurement, and construction project execution.

On February 16, 2021, we completed the separation of the Technip Energies business segment. The transaction was structured as a spin-off (the “Spin-off”), which occurred by way of a pro rata dividend (the “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. Immediately following the completion of the Spin-off, we owned 49.9% of the outstanding shares of Technip Energies. During 2021, we sold approximately 75% of the original ownership stake for proceeds of $900.9 million. As of December 31, 2021, we retained 12.2% ownership of Technip Energies’ issued and outstanding share capital. In January 2022, we sold an additional 9.0 million Technip Energies shares for total proceeds of €118.4 million, or $135.1 million. As of February 25, 2022, we retain a direct stake of 12.9 million shares, representing 7.1% of Technip Energies’ issued and outstanding share capital and valued at $155.3 million.

On January 10, 2022, we announced that following a comprehensive review of the Company’s strategic objectives, we were proceeding with the voluntary delisting of our shares from Euronext Paris. The delisting was completed on February 18, 2022.

BUSINESS SEGMENTS

Subsea

We are transforming subsea energy production by safely providing innovative solutions that improve economics, enhance performance, and reduce emissions. As a fully-integrated technology and services provider, we continue to drive responsible energy development.

Our Subsea segment provides integrated design, engineering, procurement, manufacturing, fabrication, installation, and life of field services for subsea systems, subsea field infrastructure, and subsea pipe systems used in oil and gas production and transportation.

We are an industry leader in front-end engineering and design (“FEED”), subsea production systems (“SPS”), subsea flexible pipe, subsea umbilicals, risers, and flowlines (“SURF”) and subsea robotics. We also have the capability to install these products and related subsea infrastructure using our fleet of highly specialized vessels. By integrating the SPS and SURF work scopes, we are able to drive greater value to our clients through more efficient field layout and execution of the installation campaign. This capability, in conjunction with our strong commercial focus, has enabled the successful market introduction of an integrated subsea business model, iEPCI, which spans a project’s early phase design through life of field services.

Through integrated FEED studies, or iFEED™ (“iFEED”), we are uniquely positioned to influence project concept and design. Using innovative solutions for field architecture, including standardized configurable equipment, new technologies, digital services, and simplified installation, we can significantly reduce subsea development costs and accelerate time to first production.

iEPCI is our unique, fully integrated approach to designing, managing, and executing subsea projects. By combining complementary skills with innovative technologies, we boost efficiency, lower costs, and accelerate time to first oil and gas for our clients. As the first and only subsea provider to integrate SPS with SURF and a fleet of installation vessels, we successfully created a new market opportunity in 2016 through our iEPCI offering. iEPCI projects are partnerships based on knowledge sharing and mutual trust. Success is based on early engagement and a collaborative, cooperative approach, both internally and with our clients.

Our first-mover advantage and ability to convert iFEED studies into iEPCI contracts, often as direct awards, creates a unique set of opportunities for us that are not available to our peers. This allows us to deliver a fully integrated – and technologically differentiated – subsea system, and to better manage the complete work scope through a single contracting mechanism and a single interface, yielding meaningful improvements in project economics and time to first oil.

We continue to support our clients following project delivery by offering aftermarket and life of field services. Our wide range of capabilities and solutions, including integrated life of field, or iLOF™ (“iLOF”), allows us to help clients

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increase oil and gas recovery and equipment uptime while reducing overall cost. Our iLOF offering is designed to unlock the full potential of subsea infrastructures during operations by transforming the way subsea services are delivered and proactively addressing the challenges operators face over the life of subsea fields. We provide production optimization, asset life extension insight, proactive de-bottlenecking, and condition-based maintenance.

Our Subsea business depends on our ability to maintain a cost-effective and efficient production system, achieve planned equipment production targets, successfully develop new products, and meet or exceed stringent performance and reliability standards.

Subsea Segment Products and Services

Subsea Production Systems. Our systems are used in the offshore production of crude oil and natural gas. Subsea production systems are placed on the seafloor and are used to control the flow of crude oil and natural gas from the reservoir to a host processing facility, such as a floating production facility, a fixed platform, or an onshore facility.

Our subsea production systems and products include subsea trees, chokes and flow modules, manifold pipeline systems, controls and automation systems, well access systems, multiphase and wet-gas flow meters, and additional technologies. The design and manufacture of our subsea systems requires a high degree of technical expertise and innovation. Some of our systems are designed to withstand exposure to the extreme hydrostatic pressure of deepwater environments, as well as internal pressures of up to 20,000 pounds per square inch ("psi") and temperatures of up to 400º F. The development of our integrated subsea production systems includes initial engineering design studies and field development planning and considers all relevant aspects and project requirements, including optimization of drilling programs and subsea architecture.

Subsea Processing Systems. Our subsea processing systems, which include subsea boosting, subsea gas compression, and subsea separation, are designed to accelerate production, increase recovery, extend field life, lower greenhouse gas emissions, and/or lower operators’ production costs for greenfield, subsea tie-back and brownfield applications. To provide these products, systems, and services, we utilize our engineering, project management, procurement, manufacturing, and assembly and test capabilities.

Subsea Umbilicals, Risers and Flowlines. We are a leading provider of SURF infrastructure. We develop, engineer, manufacture and install umbilicals, rigid pipelines and flexible pipes, connections and tie-ins for subsea systems. Our rigid pipes are installed using our fleet of differentiated rigid pipelay vessels and are designed to optimize flow assurance through innovative insulation coatings, electric trace heating, plastic liners, and pipe-in-pipe systems.

Our vessels will typically perform the installation of the flexible pipes and umbilicals, but we also sell these products directly to energy companies or to other vessel operators. We offer a comprehensive range of umbilical systems including steel tube umbilicals, thermoplastic hose umbilicals, power and communication systems and hybrid umbilicals. We are also qualifying a hybrid flexible pipe system, which is highly resistant to corrosive compounds, and will extend the operating envelope of flexible systems while reducing cost and weight.

Vessels. We have a fleet of 17 vessels that are used for the installation and servicing of our products. We have sole ownership of nine vessels, ownership of six vessels as part of joint ventures, and two vessels operated under charter agreements.

Subsea Services. Subsea services provides a portfolio of well and asset services that drive value and efficiency throughout the life of our clients' subsea development cycle. Our vision is to deliver customer service excellence every day, with the purpose of maximizing the performance of our clients’ well and asset operations.

Well Services include all service offerings for the well:

•ROV Services: remotely operated vehicle ("ROV") drill support services, enabled by Schilling Robotics, TechnipFMC’s underwater robotics group;

•Drilling Services: exploration and production wellhead systems and services; and

•Installation Services: Installation of trees, tubing hangers and completion of the well.

Asset Services include all service offerings for the asset:

•Maintenance Services: test, modification, refurbishment and upgrade of subsea equipment and tooling;

•Asset Integrity Services: optimizing the performance of the subsea asset through product and field data, including inspection, maintenance and repair ("IMR"); and

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•Production Management Services: enhanced well and field production, including real-time virtual metering and flow assurance services.

Intervention and Plug and Abandonment Services:

• Rig and vessel-based well intervention services and subsea plug and abandonment.

Subsea Studio™ Digital Platform. Through Subsea Studio™, we connect data, technology, and expertise to optimize the development, execution, and operation of current and future subsea fields. Our open and connected ecosystem can exchange data efficiently with suppliers, partners, and clients, providing immediate access to relevant information, and improving efficiency and quality of decisions and planning. Subsea Studio™ establishes a data flow, or a “digital thread,” that connects applications using common data models throughout a project’s lifecycle. Each decision is data-driven and each piece of actionable data is made readily available. We utilize this data to create value for our clients through efficiency gains, optimized productivity, and increased reliability.

Our Subsea Studio™ portfolio of digital solutions is comprised of:

•Subsea Studio™ FD, which combines our subsea expertise and digital technologies to design, optimize, and select the best field development, thereby increasing quality and reliability and accelerating time to first oil;

•Subsea Studio™ EX, which increases execution efficiency and speed by using a data-centric approach, automation, collaboration, and seamless interfaces; and

•Subsea Studio™ LOF, which enhances performance and production targets through digitally enabled operations and services.

Research, Engineering, Manufacturing and Supply Chain (“REMS”). REMS is an organization formed in 2019 to support accelerated technology development and manufacturing innovation. We accomplish this by reducing the cycle-time of engineering and manufacturing our products, including working with our suppliers to reduce their costs, and optimizing our processes and workflow management. Through REMS, we are focused on challenging existing technologies and implementing world-class manufacturing practices, including LEAN and process automation, to improve reliability while reducing total product cost and lead time to delivery. Our REMS organization supports both our Subsea and Surface Technologies segments.

Product Management. In 2019, we established a Product Management function to expand our capabilities to assess, define, and deliver the technologies and products of the future. This helps our REMS organization and Subsea and Surface Technologies businesses to drive the understanding of customer requirements, the competitive landscape, and investment prioritization.

Dependence on Key Customers

Generally, our customers in the Subsea segment are major integrated oil companies, national oil companies, and independent exploration and production companies.

We actively pursue alliances with companies that are engaged in the subsea development of oil and natural gas to promote our integrated systems for subsea production. These alliances are typically related to the procurement of subsea production equipment, although some of them are related to EPCI services. Development of subsea fields, particularly in deepwater environments, involves substantial capital investments. Operators have also sought the security of alliances with us to ensure timely and cost-effective delivery of subsea and other energy-related systems that provide integrated solutions to meet their needs.

Our alliances establish important ongoing relationships with our customers. While these alliances do not contractually commit our customers to purchase our systems and services, they have historically led to, and we expect that they would continue to result in, such purchases.

The commitment to our customers goes beyond project delivery, and we nurture these alliances with transparency and collaboration to better understand their needs to ensure customer success.

No single Subsea customer accounted for 10% or more of our 2021 consolidated revenue.

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Competition

We are the only fully integrated company that can provide the complete suite of subsea production equipment, umbilicals, and flowlines with the complete portfolio of installation and LOF services, enabling us to develop a subsea field as a single company. We compete with companies that supply some of the components, as well as installation companies. Our competitors include Aker Solutions ASA, Baker Hughes Company (“Baker Hughes”), Dril-Quip, Inc., McDermott International, Inc. (“McDermott”), National Oilwell Varco, Oceaneering International, Inc., Schlumberger, Ltd. (“Schlumberger”), and Subsea 7 S.A.

Seasonality

In the North Sea, winter weather generally subdues drilling activity, reducing vessel utilization and demand for subsea services as certain activities cannot be performed. As a result, the level of offshore activity in our Subsea segment is negatively impacted in the first quarter of each year.

Market Environment

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.

While still impacted by the pandemic, economic activity improved over the course of 2021. Increased global demand and production curtailments by the OPEC+ countries have resulted in improved oil prices, which in turn support market supply growth. Long-term demand for energy is forecast to rise, and we believe this outlook provides our customers with the confidence to increase investments in new sources of oil and natural gas production.

Strategy

We are transforming subsea energy production by safely providing innovative solutions that improve economics, enhance performance, and reduce emissions.

The energy landscape is evolving rapidly, yet oil and gas will remain important to the energy mix in the decades to come. Our vision for Subsea, which is focused on our integrated offering and enabled by our digital solutions and innovative products, unlocks new possibilities for growth both in oil and gas and in new energy sources. By capitalizing on our subsea expertise, core competencies, and integration capabilities, we will empower the production of oil and gas and new energies, while reducing carbon emissions.

Through our established Subsea services and our transformative offerings including iEPCI and Subsea 2.0™, we are making all types of energy produced offshore more sustainable, economical, and competitive.

As we look to the future, we remain focused on our innovative technologies and solutions, client relationships, and execution excellence. We will accomplish this by:

•Developing and empowering our people;

•Becoming a data-centric organization;

•Advancing automation and robotics; and

•Working towards all-electric fields.

Product Development

We are industrializing our Subsea business with Subsea 2.0 by using pre-engineered modular architectures to achieve a fully flexible suite of product offerings, while making an evolutionary shift from unique project requirements to a Configure to Order ("CTO") execution model.

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Our Subsea 2.0 configurable product platform consists of pre-engineered products designed to provide the flexibility to accommodate customer needs and functional requirements, combining field-proven and new technologies.

Our CTO execution model requires no product engineering work to deliver these configurable products to our clients, ensuring quality, manufacturing, supply chain, and services are fully industrialized to deliver the value offered with Subsea 2.0.

Our CTO Subsea 2.0 program attributes include:

•Pre-engineered standard configurations;

•Pre-approved and qualified supply chain;

•Pre-defined quality, code, and surveillance requirements;

•Optimized manufacturing with dedicated capacity; and

•Pre-defined and developed services.

Pivoting from bespoke Engineer to Order ("ETO") solutions unique to every project to pre-engineered CTO products, we can leverage the efficiencies our execution model creates and bring value to our clients through reduced lead time, an optimized execution model, and improved predictability and reliability for delivery.

Partnerships and Acquisitions

Acquisitions

In 2018, we entered into a joint venture with Island Offshore Management AS ("Island Offshore") called TIOS AS. In August 2021, we acquired the remaining 49% interest in TIOS AS at a total price of $48.6 million. This will accelerate the development of TechnipFMC’s integrated service model focused on maximizing value to our clients.

In 2018, we entered into a collaboration agreement with Magma Global Ltd. (“Magma Global”) to develop a new generation of hybrid flexible pipe for use in the traditional and new energy industries. As part of the collaboration, we purchased a minority ownership interest in Magma Global. In October 2021, we purchased the remaining ownership interest in Magma Global for $64.0 million.

Partnerships

Refer to the Other Business Information Relevant to Our Business Segments section of this Annual Report on Form 10-K for information about our partnerships.

Surface Technologies

The Surface Technologies segment designs, manufactures, and services products and systems used by companies involved in land and shallow water exploration and production of crude oil and natural gas. Our Surface Technologies product families include drilling, stimulation, production, measurement, and services. We manufacture most of our products internally in facilities located worldwide.

Principal Products and Services

Drilling. We provide a full range of drilling and completion systems for both standard and custom engineered applications. The customer base of our drilling and completion offerings is oil and gas exploration and production companies.

Surface Wellheads and Production Trees. Our products are used to control and regulate the flow of crude oil and natural gas from the well. The wellhead is a system of spools and sealing devices from which the entire downhole well string hangs and provides the structural support for surface production trees. Production trees are comprised of valves, actuators and chokes which can be combined into various configurations, depending on customer-specific requirements.

Surface wellheads and production trees are “per-well” systems which are designed for onshore shale, onshore conventional, and offshore shallow water platform applications, and are typically sold directly to exploration and production operators during the drilling and completion phases of the well lifecycle. Our surface wellhead and

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production tree systems are used worldwide, and we are one of the few companies that provide global coverage and a full range of system configurations, including conventional wellheads, Unihead® drill-thru wellheads designed for faster installation and drill-time optimization, and high-pressure, high-temperature (“HPHT”) systems for extreme production applications.

We also provide services associated with our surface wellhead and production tree portfolio, including service personnel and rental tooling for wellhead and production tree installation and life of field repair, refurbishment, and general maintenance. Our wellhead and production tree business relies on our ability to successfully provide the necessary field operations coverage, responsiveness, and reliability to prevent downtime and non-productive time during the drilling and completion phases.

Stimulation and Pressure Pumping. Our iComplete™ (“iComplete”) offering is the first integrated pressure containment kit for the onshore conventional stimulation market. Its CyberFrac™ digital platform reduces manpower in the red zone and enables efficiencies that significantly reduce greenhouse gas (“GHG”) emissions, lower downtime, and eliminate the integration burden for operators.

We are one of the few oilfield service providers that can offer an integrated solution covering the fracturing through flowback phases. iComplete provides our exploration and production customers with an integrated rental and service offering, including fracturing tree and manifold systems, as well as pressure control flowlines, flowback and well testing equipment, and field services.

Fracturing Tree and Manifold Systems. During the completion of a shale well, the well undergoes hydraulic fracturing. During this phase, durable and wear-resistant wellsite equipment is temporarily deployed. Our equipment is designed to sustain the high pressure and highly erosive fracturing fluid which is pumped through the well into the formation.

Our equipment (fracturing tree systems, fracturing valve greasing systems, hydraulic control units, fracturing manifold systems, and rigid and flexible flowlines) is temporarily laid out between the wellhead and the fracturing pump truck during hydraulic fracturing. Exploration and production operators typically rent this equipment directly from us during the hydraulic fracturing activities. Associated with our fracturing equipment rental is fracturing rig-up / rig-down field service personnel as well as oversight and operation of the equipment during the multiple fracturing stages for a shale well.

TechnipFMC’s manifold solutions help increase operational efficiency for a pad site with multiple wells. Our SuperFrac™ manifold provides time savings and pumping efficiencies when stimulating multiple wells on a single pad. The manifolds are installed and connected to multiple trees off the critical path, which allows our customers to fracture more stages per day in a compact footprint and efficiently move operations from one well to another, saving time and money. We also offer conventional and articulating arm manifold trailers, which are used as the connection point between fracturing pump trucks and the fracturing flowline and manifold system.

Our Ground Level Fracturing System is an essential tool for unconventional operators who use simultaneous operations to efficiently run completions in multi-well pads. The innovative system design uses various lengths of trunkline to align the SuperFrac™ manifold and fracturing tree at ground level, which minimizes the number of flowline connections for safer operation. We are a significant supplier of flowline pipework (rigid and flexible) that is used to move the fracturing product from the pump truck, via the manifold, into the fracturing trees.

Pressure Pumping. We design and manufacture equipment used in well completion and stimulation activities by major oilfield service and drilling companies, as well as by oil and gas exploration and production operators directly.

Flexibles. We have been a leading supplier of flexible lines since the 1970s and have successfully introduced our Coflexip® portfolio of flexible solutions for the onshore market. Our PumpFlex™ and WellFlex™ products can be incorporated into most shale operations and are an integral part of our iComplete system.

Flowline. We are a leading supplier of flowline products and services to the oilfield industry. From the original Chiksan® and Weco® products to our revolutionary equipment designs and integrated services, our family of flowline products and services provides our customers with reliable and durable pressure pumping equipment. Our facilities stock flowline products in the specific sizes, pressures, and materials common to each region. Our commitment is to help our customers worldwide attain maximum value from their pressure pumping assets by guaranteeing that the right products arrive at the job site in top working condition. Our total solutions approach

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includes the InteServ tracking and management system, mobile inspection and repair, strategically located service centers, and genuine Chiksan® and Weco® spare parts.

Well Service Pumps. We offer a diverse line of well service pumps for use in high-pressure pumping operations such as hydraulic fracturing and stimulation, including triplex and quintuplex pumps, each with its own industry-leading features, including: heavy-duty power ends, paired with main journal roller bearings and heavy-duty rod journal bearings, heavy-duty crankshafts, fluid cylinders, with accessible packing and valves, and made-to-order pumps. Our pumps can withstand some of the harshest operating conditions, with pressure ranges up to 20,000 psi and flow rates up to 1,500 gallons per minute.

Production. Our upstream production offering includes well control, safety and integrity systems, multiphase meter modules, in-line separation and processing systems, and standard pumps. These offerings are differentiated by our comprehensive portfolio of in-house compact, modular, and digital technologies, and are designed to enhance field project economics and reduce operating expenditures with an integrated system that spans from wellhead to pipeline.

Our iProduction™ system is the first automated integrated production platform for onshore unconventional. Our digital interface enables operators to manage their production operations remotely, leveraging Insitex data-monitoring technology. Our separation portfolio and measurement technologies, combined with our expertise in modularization, enable our customers to achieve first production faster with compact systems which are fully optimized and environmentally conscious.

Flowback and Well Testing Services. After a shale well is hydraulically fractured, the well moves to the flowback phase in which much of the fracturing fluid pumped into the well flows back out through the wellhead and fracturing tree system. This phase lasts until the wellbore flow is adequate for flow through the production facilities downstream of the wellsite. Our flowback and well testing offering includes chokes, desanders, and advanced well testing equipment and related services which are provided to exploration and production operators during the flowback phase. Our Automated Well Testing Package (“AWT™”) is now widely used in North America, enabling operators to remove personnel from processes and its digital package anticipates service. These offerings enable a substantial reduction in downtime and enhanced safety.

Well Control and Integrity Systems. We supply control components and safety systems designed to safely and efficiently run a wellpad, modules on an offshore platform, or a production facility. Our systems are based on standard, field-proven building blocks and designed for minimal maintenance during life of field operations.

Surface Multiphase Meter. Our multiphase meters (“MPMs”) are a collection of technologically advanced innovations that provide a differentiated approach to multiphase measurement. The patented technology in our MPMs offers many unique features that provide a step change in allocation measurement and allows for continuous surveillance of wells across a full range of operating conditions. Our MPMs provide real-time data to a central facility, or our cloud portal, for production reporting and remote notification and system troubleshooting.

Separation and Processing Systems. TechnipFMC provides industry-leading technology for the separation of oil, gas, sand, and water. These solutions are used in onshore production facilities and on offshore platforms worldwide. Our family of separation products delivers client success by increasing efficiency and throughput and reducing the footprint of processing facilities. Our separation systems offering includes internal components for oil and gas multiphase separation, in-line deliquidizers, and solids removal, as well as fully assembled separation modules and packages designed and fabricated for oil and gas separation, fracturing flowback treatment, solids removal, and primary produced water treatment.

Standard Pumps and Skid Systems. We provide complete skid solutions, from design consultation through startup and commissioning. We offer a diverse line of reciprocating pumps, customized according to the application with pressure ranges available up to 10,000 psi and flow rates up to 1,500 gallons per minute.

Automation and Digital Systems. Our hardware and software solutions automate and provide simple human interfaces for a number of our critical products. These digital offerings help enable the removal of personnel from critical zones, either offshore or onshore. In addition, the digital signatures from our products can then be interpreted and used via condition performance monitoring to eliminate unplanned downtime.

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Our recently launched E-Mission™(“E-Mission”) digital solution is the next level of optimization for surface production facilities. Using process automation and data, the system provides constant monitoring and adjustments in real time to minimize flaring by up to 50% while maximizing oil production. The technology is core to our iProduction™ offering and can be applied in existing facilities globally.

Measurement. We are making measurement smarter with integrated flow measurement and automation solutions, from the wellhead to the final point of sale. We deliver accurate and reliable measurement for the transportation, distribution, and storage of energy products by truck, rail, vessel, aircraft, and pipeline. We have the right products and systems to help with any application challenge. Our customers can reduce complexity by dealing with one supplier as we bring together reliable and accurate measurement and control systems, automation, and key data insights.

Services. We offer our customers a comprehensive suite of service packages to ensure optimal performance and reliability of our equipment. These service packages include all phases of the asset’s life cycle: from the early planning stages through testing and installation, commissioning, and operations, replacement and upgrade, maintenance, storage, preservation, intervention, integrity, decommissioning, and abandonment.

Our field proven integrated iExplore™(“iExplore”) services are designed to meet customer needs, minimize non-productive time, increase safety and optimize well economics long before oil and gas production is online. iExplore covers an extensive range of drilling and well testing requirements and accessories that deliver robust exploration solutions to meet any onshore or offshore jackup rig challenges. iExplore is backed by a large global rental fleet that provides fast asset deployment to support any local market across various regions.

Dependence on Key Customers

Generally, Surface Technologies’ customers are major integrated oil companies, national oil companies, independent exploration and production companies and oil and gas service companies. No single Surface Technologies customer accounted for 10 percent or more of our 2021 consolidated revenue.

Competition

Surface Technologies is a market leader for many of our products and services. Some of the factors that distinguish us from other companies in the same sector include our technological innovation, reliability, product quality, and ability to integrate across a broad portfolio scope. Surface Technologies competes with other companies that supply surface production equipment and pressure control products. Some of our major competitors include Baker Hughes, Cactus, Inc., Forum Energy Technologies, Inc., Gardner Denver, Inc., Schlumberger, Haliburton, and SPM Oil and Gas.

Market Environment

The global economic recovery in 2021 resulted in higher drilling and completion activity when compared to 2020. Activity in North America remained below pre-pandemic levels despite a significant market recovery. Outside of North America, which represented 65 percent of total segment revenue in 2021, activity remained resilient. We continued to benefit from our exposure to the Middle East, Asia Pacific and Northern Europe, all of which were supported by strength in gas-related activity. We believe the Middle East represents one of our largest opportunities in the current decade.

Strategy

We exist to transform the surface market to provide customers with breakthrough reductions in cost and carbon intensity in the drilling, completion, upstream production, and midstream and downstream transportation sectors. We will achieve this through:

Technology. We are committed to differentiated core products that enable integrated solutions to leverage the benefits of smarter designs.

Integration. Integrated ecosystems that reduce costs and increase uptime through pre-engineered, modular solutions which drive improvements in greenhouse gas emissions.

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Automation. Intelligent products that are remotely managed using actionable data, reducing manpower in the field, maximizing uptime, and enabling enhanced production.

Carbon reduction

Core competencies and capabilities in technology, innovation, project execution and services position us well as we drive opportunities in decarbonization and the energy transition. We are committed to reducing GHG emissions and our carbon footprint using lean processes and breakthrough technologies. Through our automation and software, we can prevent emissions before they occur. Our upstream production ecosystem iProduction™ eliminates the need for storage tanks and our measurement technologies have been used on biodiesel facilities and terminals. Our iComplete ecosystem also helps our customers reduce their carbon footprint by fully integrating wellsite operations, generating significant efficiencies through autonomous maintenance and remote data access.

Product Development

Leveraging the successful Subsea iEPCI model, Shallow Water iEPCI is our unique, fully integrated approach to configuring, managing, and executing marginal field development projects in the jackup drilling environment.

This ecosystem includes shallow water trees, modular platform solutions, SURF and associated installation, and tie-in solutions, all of which are designed to be standardized, fit for purpose and lighter weight for faster installation and transportation. Shallow Water iEPCI utilizes one single digital interface by combining our control and automation platform UCOS and the cloud-based data capabilities of insiteX. Our products stay connected to facilitate full remote control and monitoring, enabling time-based maintenance and improved safety offshore for unattended installations.

Our approach allows us to reduce complexity with seamless hardware and software systems integration, optimize installation activities, and reduce client risk. This allows us to transform our clients' marginal fields and meaningfully impact the life cycle costs on their projects.

TechnipFMC is the only company that can configure, manufacture, install and service an integrated system from the wellhead to the platform using a jackup rig or our owned fleet of vessels.

Our Shallow Water iEPCI differentiators:

•Shallow Water iEPCI™ leverages on the proven success of the Subsea iEPCI model;

•Simplicity of dealing with one supplier;

•Modular platform solutions for a range of applications;

•Proven pre-engineered solutions for the jack-up drilling environment;

•Connected products in the field, using one single digital interface; and

•Integrated seamless planning for operations, execution and life of field services.

Acquisitions and Investments

In December 2021, we officially inaugurated our new 56,000 square feet facility in Dhahran, Saudi Arabia. The facility, comprising two stories and a 13,000 square meter manufacturing space, is part of our continued investment in the Middle East to reinforce our leading position in delivering local solutions that extend asset life and improve project returns. The new facility positions us to respond to the expected increase in activity in the area while strengthening our capabilities, providing a solid platform for us to grow in what is a strategic market for our Surface Technologies business. The new facility will offer a broader range of capabilities and greater value-add in-country, supporting our full portfolio with high technology equipment in the drilling, completion, production, and pressure control sectors.

Also in December 2021 a 10-year framework agreement for wellheads, trees and associated services by the Abu Dhabi National Oil Company (ADNOC), our largest-ever Surface Technologies contract. Under the framework agreement, TechnipFMC will further grow in-country talent and expand existing manufacturing, assembly and test capabilities in Abu Dhabi in order to deliver the Company’s complete portfolio of surface wellheads and trees locally.

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OTHER BUSINESS INFORMATION RELEVANT TO OUR BUSINESS SEGMENTS

Capitalizing on Energy Transition

Since our inception as an integrated company in 2017, TechnipFMC has been pursuing innovation to reduce emissions within the conventional energy space. We have also been exploring ways to position ourselves in the energy transition by delivering differentiated solutions and leveraging our core competencies and existing resources. We believe offshore will be the next frontier of the energy transition and are ready to accelerate and grow our contribution. This is the role of our New Energy Ventures.

Our goal is to be a key enabler of the offshore renewables industry. To get there, we will leverage our subsea and surface expertise, our technology know-how, our collaborative and innovative mindset, as well as our demonstrated capabilities in project integration.

We will continue collaborating with energy companies and technology providers to bring to market innovative solutions that are best-suited for offshore applications, while maintaining an asset-light model within our business. Utilizing our expertise in integrated projects, we are able to serve as a system architect, from technology development to project delivery and life of field services.

As a result of our evolution in the new energies arena, we are further refining our market approach, which we define through three main pillars:

•Greenhouse gas removal;

•Offshore floating renewables; and

•Hydrogen.

Project integration is perhaps TechnipFMC’s strongest point of differentiation. We see strong integration potential across offshore renewable markets. For example, by combining wind and wave, or wind and hydrogen, we could maximize energy generation and efficiency, since the incremental capital expenditure and operational expenditure needed is much lower than a standalone product for the same energy generation. We will approach these new integration opportunities in renewable energies with a new execution model, which is integrated Offshore Novel Energies, or simply iONE™(“iONE”). iONE builds on the success of our iEPCI model in oil and gas, and leverages that experience in the new energy space. By acting as system integrator in a complex and rapidly changing environment, we can play a meaningful role in enabling offshore renewable solutions.

The Pillars

We will begin addressing greenhouse gas removal with carbon transportation and storage, a key enabler of the energy transition. We believe one of the safest and most efficient storage locations for greenhouse gases is offshore, is naturally occurring reservoirs and saline aquifers. Existing equipment developed by our Surface Technologies and Subsea businesses can be leveraged to achieve this aim. Our efforts in this area include:

•Development of our iCTS™ - Integrated Carbon Transportation and Storage System;

•A strategic alliance with Talos Energy to accelerate carbon capture and storage;

•The acquisition of Magma Global, manufacturer of the key gas transportation technologies thermoplastic composite pipe and hybrid flexible pipe; and

•An agreement to commercialize PETRONAS’ unique natural gas processing membrane which reduces emissions of CO2 and hydrogen sulfide by integrating the technology into our onshore and offshore production portfolio.

TechnipFMC aspires to lead the offshore floating renewables industry by leveraging our differentiated technologies, product standardization, and integrated approach. This emerging market is predicted to grow from near zero to an installed base of 30 gigawatts by 2030. Our efforts in this area include:

•A partnership with Magnora ASA, Magnora Offshore Wind, to develop floating offshore wind projects;

•A partnership with Bombora to develop the InSPIRE™ offshore wind and wave power solution;

•A partnership with Floating Power Plant, a renewable energy technology company, for an offshore green hydrogen pilot for the Canary Islands which will leverage Deep Purple™ (see below); and

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•A strategic investment in Orbital Marine Power, the world's most powerful floating tidal energy turbine, which we believe to be the most mature tidal technology.

We believe hydrogen will become a crucial carrier for the storage and transportation of energy, as well as bringing reliability, stability, and efficiency to renewable sources. Our strategy covers two areas: green hydrogen produced offshore by the electrolysis of water using renewable energy, and off-grid energy systems delivering renewable, stable power to traditional energy installations and remote islands. Our efforts in this area include:

•Deep Purple™ is our system to provide sustainable offshore renewable energy production by integrating wind energy and hydrogen production and storage;

•A partnership with Energias de Portugal (EDP) and others to develop a new platform for green hydrogen production offshore Portugal; and

•Working with renewable energy provider Statkraft towards a trial of large-scale offshore hydrogen storage at Hardanger Hydrogen Hub.

Sources and Availability of Raw Materials

Our business segments purchase carbon steel, stainless steel, aluminum, and steel castings and forgings from the global marketplace. We typically do not use single source suppliers for the majority of our raw material purchases; however, certain geographic areas of our businesses, or a project or group of projects, may heavily depend on certain suppliers for raw materials or supply of semi-finished goods. We believe the available supplies of raw materials are adequate to meet our needs.

Research and Development

We are engaged in research and development (“R&D”) activities directed toward the improvement of existing products and services, the design of specialized products to meet customer needs, and the development of new products, processes, and services. A large part of our product development spending has focused on the improved design and standardization of our Subsea products to meet our customer needs.

Patents, Trademarks, and Other Intellectual Property

We own a number of patents, trademarks, and licenses that are cumulatively important to our businesses. As part of our ongoing R&D focus, we seek patents when appropriate for new products, product improvements, and related service innovations. We have approximately 3,800 issued patents and pending patent applications worldwide. Further, we license intellectual property rights to or from third parties. We also own numerous trademarks and trade names and have approximately 410 registrations and pending applications worldwide.

We protect and promote our intellectual property portfolio and take actions we deem appropriate to enforce and defend our intellectual property rights. We do not believe, however, that the loss of any one patent, trademark, or license, or group of related patents, trademarks, or licenses would have a material adverse effect on our overall business.

Segment and Geographic Financial Information

The majority of our consolidated revenue and segment operating profits is generated in markets outside of the United States. Each segment’s revenue is dependent upon worldwide oil and gas exploration, production and petrochemical activity. Financial information about our segments and geographic areas is incorporated herein by reference from Note 7 to our consolidated financial statements in Part II, Item 8 of this Annual Report on Form 10-K.

Order Backlog

Information regarding order backlog is incorporated herein by reference from the section entitled “Inbound Orders and Order Backlog” in Part II, Item 7 of this Annual Report on Form 10-K.

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Website Access to Reports and Proxy Statement

Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, Proxy Statements, and Forms 3, 4, and 5 filed on behalf of directors and executive officers, and amendments to each of those reports and statements, are available free of charge through our website at www.technipfmc.com, under “Investors” as soon as reasonably practicable after such material is electronically filed with, or furnished to, the U.S. Securities and Exchange Commission (the “SEC”). Alternatively, our reports may be accessed through the website maintained by the SEC at www.sec.gov. Unless expressly noted, the information on our website or any other website is not incorporated by reference in this Annual Report on Form 10-K and should not be considered part of this Annual Report on Form 10-K or any other filing we make with the SEC.

HUMAN CAPITAL

People and culture are at the heart of our development strategy. People are our wealth and strength. We are committed to our employees, and our employee guidelines are specified in our Code of Business Conduct, which applies to all employees, regardless of their roles, and no matter where they work.

We believe that all our employees are entitled to fair treatment, courtesy, and respect, wherever they work: in the office, on vessels, on industrial and construction sites, or in client offices. We do not tolerate any form of abuse or harassment, and we will not tolerate any action, conduct, or behavior that is humiliating, intimidating, or hostile.

Furthermore, our hiring and employee development decisions are fair and objective. Employment decisions are based only on relevant qualifications, performance, demonstrated skills, experience, and other job-related factors, with our goal of creating a diverse, tolerant, and inclusive workforce.

Workforce Overview

Our workforce consists of the following:

	As of December 31,
	2021	2020	2019
Permanent employees	19,103	19,078	21,522
Temporary employees (fixed-term)	1,507	1,054	1,637
Employees on payroll	20,610	20,132	23,159
Contracted workforce	1,392	635	2,560
Total workforce	22,002	20,767	25,719

Attracting Talent

To position ourselves as an employer of choice, we continued to bring our Employee Value Proposition ("EVP") to life. We encouraged and included more people from our business to share their inspiring experiences and stories that truly reflects the diversity and plurality we have in the company. People from different cultures, generations, gender, races, disabilities and sexual preferences are represented by what they all have in common: inspiring experiences lived at TechnipFMC. We continue to explore how best we can share these experiences with external candidates as well as internally through different channels. A significant effort in 2021 was to improve the candidate experience when accessing our website’s new career page as well as on our internal EVP-dedicated web page.

The career pages aim to reflect key EVP messages as well as our commitments to Diversity and Inclusion and ESG to attract the right talent to our company.

Our recruitment system is becoming more standardized worldwide to improve the selection process. Global programs are being revised to provide a more dynamic, modern and attractive experience with relevant content. Our onboarding program will be further simplified, with better global alignment and more efficient communication to make the experience of new employees and line managers more efficient and connected. Our graduate program gained more global representation with an increase in participation across our business.

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Key performance indicators linked to talent acquisition are now available and accessible to key stakeholders through our internal tracking platform. These include the results of the exit interview, onboarding program and new employees; and evaluation of the selection process.

Developing and Keeping Talent

In 2021, we have further simplified the design and process of identifying key talents that was launched in 2020. We saw an improvement in our Leadership Succession Planning both in terms of depth and representation of underrepresented nationalities and U.S. minorities and gender. We have continued to work on Talking Talents (a process launched in 2020 to identify and support development of our key talents). As of December 31, 2021, we have 14 percent (an increase from 6 percent in 2020) of our employee population identified as flagged talents in our three main Career Pathways: Leadership, Technology and Project Management. This includes our Technical Expertise Program, which was also launched in 2020, where we welcomed new experts in 2021.

Leadership You was introduced in 2021, which provides leadership development opportunities not only for our leaders, but for all of our employees. We have also made other talent development tools available for all employees. Examples include Individual Development Plan, Continuous Multi Source Feedback and Inclusive Leadership Training.

Employee attrition in 2021 was 6.4 percent compared to 2.5 percent in 2020, attributable to a significant extent to the great reshuffle we witnessed across industries globally. Through dedicated efforts focused on key talents we managed to keep attrition rate lower at 5.6 percent.

In 2022, we will further improve our Performance Process and move from annual performance reviews and ratings to continuous feedback and check-ins between employees and managers thereby enabling an environment where our employees will have boundless opportunities to grow, contribute and their best. This will further improve our business and individual performance and focus on people development for our people.

As we continued to manage the ever-changing COVID-19 landscape, we have carried on sharpening our focus on enabling our people to grow, develop and share knowledge. The importance of being able to offer learning and knowledge-sharing opportunities in a digital, 24/7, and global environment has been key to our success. Building on our solid foundations, we delivered impactful courses, initiatives and solutions across all of our business segments, in addition to being particularly focused on leadership, technology and project management.

Technical Expertise Program

Building on the launch of the global Technical Expertise Program in late 2020, we executed the first-ever application and selection process for the program. It recognizes and rewards employees who have demonstrated technical mastery in their discipline, as well as:

•Technical impact. whether it is operational performance, product development or project management;

•People development. by inspiring others, enabling the full potential of people and teams, mentoring, sharing knowledge and expertise, and attracting other technical talent;

•Business impact. by developing business with existing or new customers, new solutions in existing markets, or new markets altogether; and

•Industry leadership. through internal and external professional visibility as a thought leader, both individually and as a representative of the Company’s technical leadership.

The Technical Expertise Program has more than 650 members, who share their knowledge broadly across the Company’s learning ecosystem, using knowledge management platforms such as The Bridge to connect with employees in almost 40 chartered global knowledge-sharing networks. The related knowledge repository, The Well, has more than 4,000 pages, which received in excess of 600,000 visits in 2021. The Well is connected with the Company’s competency management platform and provides direct access to competency-based content. Employees in all regions access these and other knowledge management social learning tools such as an Experts Explain webinar series and Illuminate podcasts to increase their knowledge about business and technical topics, and to share their own knowledge.

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Learning and Training

Engagement in the iLearn learning platform has seen a significant rebound in use in 2021, as we continue to embrace our digital transformation. In 2021, there were more than 26,000 pieces of creative and innovative learning content available, with ongoing releases of new and meaningful courses, to support skills development for our employees and enhance their performance in their role. In 2021, 76 percent of our training hours (up from 50 percent in 2020) and 96 percent of our course completions (up from 95 percent in 2020) were done in a digital or virtual environment, which resulted in 15.5 training hours per employee (up from 5.85 hours per employee in 2020). The areas of learning in 2021 were Health, Safety, Environment and Security; Human Resources; Legal; and Personal Effectiveness.

Promoting Cultural and Ethnic Diversity

We focus on our broad cultural and ethnic diversity, which we constantly promote and develop throughout the Company, through the internationalization of our teams, multicultural programs, and international mobility.

Providing Equal Employment Opportunities

Three of our Foundational Beliefs – integrity, respect, and sustainability – are tangibly embedded in fair employment practices and equal opportunity. The Company’s policy is that our employment decisions related to recruitment, selection, evaluation, compensation, and development, among others, are not influenced by unlawful or unfair discrimination on the basis of race, religion, gender, age, ethnic origin, nationality, sexual orientation, gender or gender reassignment, marital status, or disability.

It is our policy to encourage and give full and fair consideration to applications for employment from disabled people, and to assist with their training and development in light of their aptitudes and abilities. If an existing employee becomes disabled, it is the Company’s policy wherever practicable to provide continuing employment under our usual terms and conditions, and to provide training, career development, promotion opportunities and a safe work environment based on the requested, reasonable needs to disabled employees to the fullest extent possible.

In December 2021, we celebrated International Day of Persons with Disabilities. We had various initiatives to promote inclusion and respect featuring our colleagues throughout the globe, including:

•Inspiring stories featuring perspectives from leadership, disabled individuals and careers of disabled children;

•Creating awareness of invisible disabilities in a podcast; and

•Virtual iVolunteer event for People & Culture where senior managers recorded holiday greetings for Helping Hands for the Deaf through sign language and many other local events.

Strengthening Social Dialogue

The Company has developed a culture that is based on the values of trust, mutual respect, and dialogue. In accordance with local legislation, regular meetings with trade union-appointed and/or works council representatives are organized for information and/or consultation. The Company’s European Works Council (“EWC”) meets regularly and all of our European entities joined the EWC by the end of 2019. In 2021, the EWC elected its new members, who consist of employee representatives from France, Germany, the Netherlands, Norway, Poland, Portugal, and the United Kingdom.

Employee Engagement and Well-being

In 2021, we launched our first Company-wide employee engagement survey, with a remarkable 70 percent response rate.

The results were consistent with the oil and gas industry, but certainly have room for improvement. The results achieved and the commitments made by our Executive Leadership Team and business executives illustrate the importance of the survey initiative to the Company. The robust and analytical platform gives all managers the opportunity to work autonomously on their action plans.

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We continued to build on the strong foundations we laid in 2020, with the launch of our Well-being program in September 2021, in partnership with our Workplace Options platform, to help all employees be more successful at meeting their responsibilities at home and at work. Among the extensive resources available, we focused on mental health and all of our more than 20,000 people now have access to mental health resources and counselling. During the month of September 2021, webinars and Experts Explain webcasts were made available to stimulate discussion on the topic. As committed by our Chair and CEO in 2020, we annually celebrate the month of October as mental health awareness month with several activities to promote awareness. TechnipFMC also celebrates International Women's Day, PRIDE month and International Women in Engineering Day, among others.

Internal Communication

We have a robust internal communications strategy and support communication channels that ensure that we communicate with our employees in a timely and effective way. The effectiveness of internal communication is continually monitored and adjusted based on a focus group feedback program that reaches multiple levels across the Company. New digital tools help us gauge the effectiveness of our digital communication platforms. Employees are regularly consulted and provided with information on changes and events that may affect them through channels such as regular meetings, employee representatives, and the Company’s intranet site. These consultations and meetings ensure that employees are kept informed of the financial and economic factors affecting the Company’s performance and matters of concern to them.

Labor Relations and Collective Agreements

We seek to maintain constructive relationships with works councils and trades unions, and to comply with relevant local laws and collective agreements in relation to collective or individual labor relations. The Company also operates through local subsidiaries in many countries, a number of which, including those in France, Germany, and Norway, have legal requirements for works councils, which include employee representatives. We send regular information to all employees to share information about business success, changes to the organizational structure, and any major impact to the business or the Company. The same approach to sharing information and maintaining a regular dialogue with employees exists at a local level through the action of the local communications teams and managers. In countries where employee representatives or works councils are in place, the Company seeks to maintain an effective and regular dialogue. To get the direct feedback of employees, we performed an employee engagement survey globally in 2021. The results have been communicated and actions are being taken in all of our operations to improve employee relations and engagement. Every quarter, all employees receive a direct message from the Chair and CEO about the financial results of the Company and main business information.

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INFORMATION ABOUT OUR EXECUTIVE OFFICERS

Information regarding our executive officers called for by Item 401(b) of Regulation S-K is hereby included in Part I, Item 1 “Business” of this Annual Report on Form 10-K.

The following table indicates the names and ages of our executive officers as of February 28, 2022, including all offices and positions held by each in the past five years:

Name	Age	Current Position and Business Experience (Start Date)
Douglas J. Pferdehirt (a)	58	Chair and Chief Executive Officer (2019) Chief Executive Officer (2017)
Alf Melin (a)	52	Executive Vice President and Chief Financial Officer (2021) Senior Vice President, Finance Operations (2017) Senior Vice President, Surface Americas (2017)
Victoria Lazar (a)	56	Executive Vice President, Chief Legal Officer and Secretary (2020) Senior Vice President, General Counsel and Corporate Secretary of Bristow Group (2020) Executive Counsel, M&A of General Electric (2019) Associate General Counsel of Baker Hughes, a GE Company (2018) Associate General Counsel of GE Oil & Gas (2017)
Luana Duffé (a)	40	Executive Vice President, New Energy Ventures (2021) Vice President, Subsea Projects & Commercial and Country Manager for Brazil (2020) Vice President, Subsea Projects and Brazil Country Manager (2019) Vice President, Subsea Strategy (2018) Corporate Development Director (2018)
Nisha Rai (a)	46	Executive Vice President, People and Culture (2021) Vice President of Total Rewards (2020) Vice President, Head of Human Resources of MRC Global (2017)
Justin Rounce (a)	55	Executive Vice President and Chief Technology Officer (2018) President, Valves & Measurement of Schlumberger Limited (2018) Senior Vice President, Marketing & Technology of Schlumberger Limited (2016)
Jonathan Landes (a)	49	President, Subsea (2020) Senior Vice President, Subsea Commercial (2017) President, Subsea Projects North America (2017)
Barry Glickman (a)	53	President, Surface Technologies (2019) President, Engineering, Manufacturing and Supply Chain (2017)
Krisztina Doroghazi (b)	50	Senior Vice President, Controller, and Chief Accounting Officer (2018) Senior Vice President, Financing Planning and Reporting of MOL Group (2015)

__________________

(a)    Member of the Executive Leadership Team and a Rule 3b-7 executive officer and Section 16 officer under the Exchange Act.

(b)    Section 16 officer under the Exchange Act.

No family relationships exist among any of the above-listed officers, and there are no arrangements or understandings between any of the above-listed officers and any other person pursuant to which they serve as an officer. During the past 10 years, none of the above-listed officers was involved in any legal proceedings as defined in Item 401(f) of Regulation S-K. All officers are appointed by the Board of Directors to hold office until their successors are appointed.

ITEM 1A. RISK FACTORS    

Important risk factors that could impact our ability to achieve our anticipated operating results and growth plan goals are presented below. The following risk factors should be read in conjunction with discussions of our business and the factors affecting our business located elsewhere in this Annual Report on Form 10-K and in our other filings with the SEC.

Summary Risk Factors

The following is a summary of some of the risks and uncertainties that could materially adversely affect our business, financial condition and results of operations. You should read this summary together with the more detailed description of each risk factor contained below.

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Risks Related to Our Business and Industry

•Demand for our products and services depends on oil and gas industry activity and expenditure levels, which are directly affected by trends in the demand for and price of crude oil and natural gas.

•We operate in a competitive environment and unanticipated changes relating to competitive factors in our industry, including ongoing industry consolidation, may impact our results of operations.

•Our success depends on our ability to develop, implement, and protect new technologies and services.

•Cumulative loss of several major contracts, customers, or alliances may have an adverse effect on us, and the credit and commercial terms of certain contracts may subject us to further risks.

•The COVID-19 pandemic, the United Kingdom’s withdrawal from the European Union, and disruptions in the political, regulatory, economic, and social conditions of the countries in which we conduct business, could adversely affect our business or results of operations.

•DTC may cease to act as a depository and clearing agency for our shares.

•Our existing and future debt may limit cash flow available to invest in the ongoing needs of our business and could prevent us from fulfilling our obligations under our outstanding debt.

•A downgrade in our debt rating could restrict our ability to access the capital markets.

•Our acquisition and divestiture activities involve substantial risks.

•Demands to address Environmental, Social and Governance (“ESG”) matters could surpass our ability to meet demands and thus adversely affect our business.

•Uncertainties with respect to the energy transition may adversely affect our business.

Risks Related to Our Operations

•We may lose money on fixed-price contracts.

•New capital asset construction projects for vessels and manufacturing facilities are subject to risks, including delays and cost overruns.

•Our failure to timely deliver our backlog could affect future sales, profitability, and customer relationships.

•We face risks relating to our reliance on subcontractors, suppliers, and our joint venture partners.

•A failure or breach of our IT infrastructure or that of our subcontractors, suppliers or joint venture partners, including as a result of cyber-attacks, could adversely impact our business and results of operations.

•Pirates endanger our maritime employees and assets.

Risks Related to Legal Proceedings, Tax, and Regulatory Matters

•The industries in which we operate or have operated expose us to potential liabilities, including the installation or use of our products, which may not be covered by insurance or may be in excess of policy limits, or for which expected recoveries may not be realized.

•Our operations require us to comply with numerous laws and regulations, including those related to environmental protection and climate change, health and safety, privacy, data protection and data security, labor and employment, import/export controls, currency exchange, bribery and corruption, and taxation, violations of which could have a material adverse effect on our financial condition, results of operations, or cash flows.

•As an English public limited company, we must meet certain additional financial requirements before we may declare dividends or repurchase shares and certain capital structure decisions may require stockholder approval which may limit our flexibility to manage our capital structure.

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•Uninsured claims and litigation against us, including intellectual property litigation, could adversely impact our financial condition, results of operations, or cash flows.

•The IRS may not agree that we should be treated as a foreign corporation for U.S. federal tax purposes and may seek to impose an excise tax on gains recognized by certain individuals.

•U.S. tax laws and/or guidance could also affect our ability to engage in certain acquisition strategies and certain internal restructurings.

•We are subject to the tax laws of numerous jurisdictions; and challenges to the interpretation of, or future changes to, such laws could adversely affect us.

•We intend to be treated exclusively as a resident of the United Kingdom for tax purposes, but other tax authorities may seek to treat us as a tax resident of another jurisdiction, and we may not qualify for benefits under tax treaties entered into between the United Kingdom and other countries.

General Risk Factors

•We are a shareholder of Technip Energies and the value of our investment in Technip Energies may fluctuate and may result in an impact to our results of operations.

•Our businesses are dependent on the continuing services of our key managers and employees.

•Seasonal and weather conditions could adversely affect demand for our services and operations.

•Currency exchange rate fluctuations could adversely affect our financial condition, results of operations, or cash flows.

•We are exposed to risks in connection with our defined benefit pension plan commitments.

•We may be unable to obtain sufficient bonding capacity for certain contracts, and the need for performance and surety bonds could reduce availability under our credit facility.

Risks Related to Our Business and Industry

Demand for our products and services depends on oil and gas industry activity and expenditure levels, which are directly affected by trends in the demand for and price of crude oil and natural gas.

We are substantially dependent on conditions in the oil and gas industry, including (i) the level of exploration, development and production activity and (ii) capital spending. Any substantial or extended decline in these expenditures may result in the reduced pace of discovery and development of new reserves of oil and gas and the reduced exploration of existing wells, which could adversely affect demand for our products and services and, in certain instances, result in the cancellation, modification, or re-scheduling of existing orders in our backlog. These factors could have an adverse effect on our revenue and profitability. The level of exploration, development, and production activity is directly affected by trends in oil and natural gas prices, which historically have been volatile and are likely to continue to be volatile in the future.

Factors affecting the prices of oil and natural gas include, but are not limited to, the following:

•demand for hydrocarbons, which is affected by worldwide population growth, economic growth rates, and general economic and business conditions, including reductions in travel and commerce relating to the COVID-19 pandemic;

•costs of exploring for, producing, and delivering oil and natural gas;

•political and economic uncertainty, and socio-political unrest;

•governmental laws, policies, regulations and subsidies related to or affecting the production, use, and exportation/importation of oil and natural gas;

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•the ability or willingness of the Organization of Petroleum Exporting Countries and the 10 other oil producing countries, including Russia, Mexico and Kazakhstan (“OPEC+”) to set and maintain production level for oil;

•oil refining and transportation capacity and shifts in end-customer preferences toward fuel efficiency and the use of natural gas;

•technological advances affecting energy consumption;

•development, exploitation, relative price, and availability of alternative sources of energy and our customers’ shift of capital to the development of these sources;

•volatility in, and access to, capital and credit markets, which may affect our customers’ activity levels, and spending for our products and services;

•decrease in investors’ interest in hydrocarbon producers because of environmental and sustainability initiatives; and

•natural disasters.

The oil and gas industry has historically experienced periodic downturns, which have been characterized by diminished demand for oilfield services and downward pressure on the prices we charge. The oil and natural gas market remains quite volatile, and price recovery and business activity levels are dependent on variables beyond our control, such as geopolitical stability, increasing attention to global climate change resulting in pressure upon shareholders, financial institutions and/or financial markets to modify their relationships with oil and gas companies and to limit investments and/or funding to such companies, increasing likelihood of governmental regulations, enforcement, and investigations and private litigation due to increasing attention to global climate change, OPEC+’s actions to regulate its production capacity, changes in demand patterns, and international sanctions and tariffs. Continued volatility or any future reduction in demand for oilfield services could further adversely affect our financial condition, results of operations, or cash flows.

We operate in a highly competitive environment and unanticipated changes relating to competitive factors in our industry, including ongoing industry consolidation, may impact our results of operations.

We compete on the basis of a number of different factors, such as product offerings, project execution, customer service, and price. In order to compete effectively we must develop and implement innovative technologies and processes, and execute our clients’ projects effectively. We can give no assurances that we will continue to be able to compete effectively with the products and services or prices offered by our competitors.

Our industry, including our customers and competitors, has experienced unanticipated changes in recent years. Moreover, the industry is undergoing consolidation to create economies of scale and to control the value chain, which may affect demand for our products and services because of price concessions from our competitors or decreased customer capital spending. This consolidation activity could impact our ability to maintain market share, maintain or increase pricing for our products and services or negotiate favorable contract terms with our customers and suppliers, which could have a significant negative impact on our financial condition, results of operations or cash flows. We are unable to predict what effect consolidations and other competitive factors in the industry may have on pricing, capital spending by our customers, our selling strategies, our competitive position, our ability to retain customers or our ability to negotiate favorable agreements with our customers and suppliers.

The COVID-19 pandemic has reduced demand for our products and services, and has had, and may continue to have, an adverse impact on our financial condition, results of operations, and cash flows.

The COVID-19 pandemic, including actions taken by governments and businesses, has resulted in a reduction in global economic activity, including increased volatility in global oil and natural gas markets. Measures taken to address and limit the spread of the disease, such as stay-at-home orders, social distancing guidelines, and travel restrictions, have adversely affected the economies and financial markets of many countries. The resulting disruption to our operations, communications, travel, and supply chain may continue or increase in the future, and could limit the ability of our employees, partners, or vendors to operate efficiently or at all, and has had, and is reasonably likely to continue to have, an adverse impact on our financial condition, operating results, and cash flows.

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Uncertainty remains as to the potential impact of the COVID-19 pandemic on our operations, and we are closely monitoring the effects of the pandemic on commodity demands and on our customers. These effects may include adverse revenue and net income effects; disruptions to our operations; potential project delays or cancellations; employee impacts from illness, school closures, and other community response measures, which may lead to disruptions and decreased productivity; and temporary closures of our facilities or the facilities of our customers and suppliers. The pandemic has led to global supply chain challenges, which could adversely impact our ability to acquire certain equipment and materials, impact our ability complete projects and cause delays in completing projects, and materially and negatively impact our business results, operations, revenue, growth and overall financial condition.

COVID-19, and the uncertain regional and global economic conditions stemming from the pandemic, could also aggravate the other risk factors discussed herein, including but not limited to risks related to the demand for oil and gas, which may not recover immediately. The full extent to which the COVID-19 pandemic will impact our results is unknown and evolving and will depend on various factors and consequences beyond our control, such as the severity, duration, and spread of COVID-19; the development of new variants; the success of actions taken by governments and health organizations to combat the disease and treat its effects, including vaccine mandates, acceptance, distribution and efficacy; decisions by our alliance partners and customers regarding their business plans and capital expenditures; and the extent to which, and the timing of, general economic and operating conditions recover.

Our success depends on our ability to develop, implement, and protect new technologies and services and the intellectual property related thereto.

Our success depends on the ongoing development and implementation of new product designs, including the processes used by us to produce and market our products.

We continually attempt to develop new technologies for use in our business. However, there is no guarantee of future demand for those technologies because customers may be reluctant or unwilling to adopt our new technologies. In addition, we may also have difficulty negotiating satisfactory terms that would provide acceptable returns on our investment in the research and development of new technologies.

Development of new technology is critical to maintaining our competitiveness. However, we cannot assure that we will be able to successfully develop technology that our customers demand. Demand for our products and services may decline if we cannot keep pace with technological advances. Technology that is unavailable to us or that does not work as we expect, could adversely affect us. New technologies, services or standards could render some of our products and services obsolete, which could reduce our competitiveness and have a material adverse impact on our business, financial condition, cash flows and results of operation.

Additionally, we are exploring opportunities in greenhouse gas removal, offshore floating renewables (wind, wave and tidal energy), and hydrogen. Many technologies involved in those projects are novel and will need to be further developed before we can determine whether a renewable energy project is technologically feasible.

Our success also depends on our ability to protect and maintain critical intellectual property assets related to these developments. If we are not able to obtain patents, maintain trade secrets or obtain other protection of our intellectual property rights, if our patents are unenforceable or the claims allowed under our patents are not sufficient to protect our technology, or if we are not able to adequately protect our patents or trade secrets, we may not be able to continue to develop our services, products and related technologies. Additionally, our competitors may be able to independently develop technology that is similar to ours without infringing on our patents or gaining access to our trade secrets. If any of these events occurs, we may be unable to meet evolving industry requirements or do so at prices acceptable to our customers, which could adversely affect our financial condition, results of operations, or cash flows.

Due to the types of contracts we enter into and the markets in which we operate, the cumulative loss of several major contracts, customers, or alliances may have an adverse effect on our results of operations, and the credit and commercial terms of certain contracts may subject us to further risks.

We often enter into large, long-term contracts that, collectively, represent a significant portion of our revenue. These agreements, if terminated or breached, may have a larger impact on our operating results or our financial condition than shorter-term contracts due to the value at risk. Moreover, the global market for the production, transportation, and transformation of hydrocarbons and by-products, as well as the other industrial markets in which we operate, is

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dominated by a small number of companies. As a result, our business relies on a limited number of customers. If we were to lose several key contracts, customers, or alliances over a relatively short period of time, we could experience a significant adverse impact on our financial condition, results of operations, or cash flows.

Additionally, certain of our customers may require us to provide extended payment terms or other forms of financial support as a condition to obtaining commercial contracts. We have long-term contracts involving significant amounts to be paid by our customers toward the later stage of a project. Pursuant to these contracts, we may deliver products and services representing an important portion of the contract price before receiving any significant payment from the customer. Such arrangements could restrict the use of our cash and other resources for other projects and opportunities and our business could also be adversely affected if the financial condition of our customers erodes.

Disruptions in the political, regulatory, economic, and social conditions of the countries in which we conduct business could adversely affect our business or results of operations.

We operate in various countries across the world. Instability and unforeseen changes in any of the markets in which we conduct business, including economically and politically volatile areas or conflict or rumor of conflict could have an adverse effect on the demand for our services and products, our financial condition, or our results of operations. These factors include, but are not limited to, the following:

•nationalization and expropriation;

•potentially burdensome taxation;

•inflationary and recessionary markets, including capital and equity markets;

•civil unrest, labor issues, political instability, disease outbreaks, terrorist attacks, cyber terrorism, military activity, and wars;

•increasing attention to global climate change resulting in pressure from shareholders, financial institutions and/or financial markets;

•supply disruptions in key oil producing countries;

•the ability of OPEC+ to set and maintain production levels and pricing;

•trade restrictions, trade protection measures, price controls, or trade disputes;

•sanctions, such as prohibitions or restrictions by the United States against countries that are the targets of economic sanctions, or are designated as state sponsors of terrorism;

•foreign ownership restrictions;

•import or export licensing requirements;

•restrictions on operations, trade practices, trade partners, and investment decisions resulting from domestic and foreign laws, and regulations;

•regime changes;

•changes in, and the administration of, treaties, laws, and regulations including in response to public health issues;

•inability to repatriate income or capital;

•reductions in the availability of qualified personnel;

•foreign currency fluctuations or currency restrictions; and

•fluctuations in the interest rate component of forward foreign currency rates.

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DTC may cease to act as the depository and clearing agency for our shares.

Our shares were issued into the facilities of The Depository Trust Company (“DTC”) with respect to shares listed on the NYSE. DTC is a widely used mechanism that allows for rapid electronic transfers of securities between the participants in their respective systems, which include many large banks and brokerage firms. DTC has general discretion to cease to act as the depository and clearing agency for our shares. If DTC determines at any time that our shares are not eligible for continued deposit and clearance within its facilities, then we believe that our shares would not be eligible for continued listing on the NYSE, and trading in our shares would be disrupted. Any such disruption could have a material adverse effect on the trading price of our shares.

The United Kingdom’s withdrawal from the European Union may have a negative effect on global economic conditions, financial markets, and our business.

We are incorporated under the laws of England and Wales and have an operational headquarters in Houston, Texas, United States, with worldwide operations, including material business operations in Europe. The United Kingdom withdrew from the European Union on January 31, 2020 (“Brexit”). In connection with Brexit, the United Kingdom and the European Union agreed on the Trade and Cooperation Agreement (“TCA”) that governs the future trading relationship between the United Kingdom and the European Union in specified areas. The TCA took effect on January 1, 2021. The United Kingdom is no longer in the European Union customs union and is outside of the European Union single market. The TCA addresses trade, economic arrangements, law enforcement, judicial cooperation and a governance framework including procedures for dispute resolution, among other things. Because the agreement merely sets forth a framework in many respects and will require complex additional bilateral negotiations between the United Kingdom and the European Union as both parties continue to work on the rules for implementation, significant political and economic uncertainty remains about whether the terms of the relationship will differ materially from the terms before withdrawal.

These developments could have a material adverse effect on global economic conditions and the stability of the global financial markets and could significantly reduce global market liquidity and restrict the ability of key market participants to operate in certain financial markets. Asset valuations, currency exchange rates, and credit ratings may be especially subject to increased market volatility. In addition, there is a lack of clarity about the future United Kingdom laws and regulations as the United Kingdom determines which European Union laws to replicate or replace, including financial laws and regulations, tax and free trade agreements, intellectual property rights, supply chain logistics, environmental, health and safety laws and regulations, immigration laws, employment laws, and other rules that would apply to us and our subsidiaries, could increase our costs, restrict our access to capital within the United Kingdom and the European Union, depress economic activity, and further decrease foreign direct investment in the United Kingdom.

Any of these factors could have a material adverse effect on our business, financial condition, or results of operations.

Our existing and future debt may limit cash flow available to invest in the ongoing needs of our business and could prevent us from fulfilling our obligations under our outstanding debt.

We have substantial existing debt. As of December 31, 2021, our total debt was $2.0 billion. We also have the capacity under our debt agreements to incur substantial additional debt.

Our level of debt could have important consequences. For example, it could:

•require us to dedicate a substantial portion of our cash flow from operations to the payment of debt service, reducing the availability of our cash flow to fund working capital, capital expenditures, acquisitions, distributions, and other general partnership purposes;

•increase our vulnerability to adverse economic or industry conditions;

•limit our ability to obtain additional financing to react to changes in our business; or

•place us at a competitive disadvantage compared to businesses in our industry that have less debt.

Additionally, any failure to meet required payments on our debt or to comply with any covenants in the instruments governing our debt, could result in an event of default under the terms of those instruments. In the event of such

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default, the holders of such debt could elect to declare all the amounts outstanding under such instruments to be due and payable. Such default could also trigger a cross default on our other debt.

Our loans denominated in United States dollars (“USD”), at our option, and sterling-denominated loans, under our Revolving Credit Facility bear interest at an adjusted rate linked to the London Interbank Offered Rate (“LIBOR”) and our euro-denominated loans under the Revolving Credit Facility bear interest at an adjusted rate linked to the Euro Interbank Offered Rate (“EURIBOR”). LIBOR, EURIBOR and certain other interest “benchmarks” may be subject to further regulatory guidance and/or reform that could cause interest rates under our current or future debt agreements to perform differently than in the past or cause other unanticipated consequences. The United Kingdom’s Financial Conduct Authority (the “FCA”), which regulates LIBOR, has announced that the publication of LIBOR on the current basis would cease and no longer be representative immediately after December 31, 2021 (in the case of all sterling, euro, Swiss franc and Japanese yen settings, and one-week and two-month USD settings) and immediately after June 30, 2023 (in the case of all remaining USD settings). Despite this deferral in regard to USD, the FCA has confirmed that use of USD LIBOR will not be permitted in most new contracts after December 31, 2021 and while the FCA is requiring the LIBOR administrator to publish one-, three- and six-month sterling and Japanese yen LIBOR rates for a limited time following December 31, 2021 using a synthetic methodology, such synthetic LIBOR rates are also only permitted for legacy use. If the methods of calculating LIBOR change from their current form while we continue to rely on LIBOR, or if we adopt alternative benchmarks for our current or future debt, interest rates on our debt obligations may be adversely affected.

The terms of the agreements governing our existing indebtedness restrict our current and future operations, particularly our ability to respond to changes or to take certain actions.

The terms of the agreements governing our indebtedness contain a number of restrictive covenants that limit our flexibility in conducting our business and restrict our ability to take specific actions, including (subject to various exceptions) restrictions on incurring indebtedness, paying dividends, making certain loans and investments, selling assets or incurring liens which may limit our ability to compete effectively, or to take advantage of new business opportunities. In addition, the restrictive covenants in the credit agreement, dated February 16, 2021, that governs our $1,000,000,000 three-year senior secured multi-currency revolving credit facility (the “Revolving Credit Facility”) require us to maintain specified financial ratios and satisfy other financial condition tests.

A breach of the covenants or restrictions under our existing indebtedness could result in an event of default under the applicable indebtedness. Such default may allow the creditors to accelerate the related debt and may result in the acceleration of any other debt to which a cross-acceleration or cross-default provision applies. An event of default under our Revolving Credit Facility would also permit the lenders to terminate all commitments to extend further credit under that facility. Furthermore, if we were unable to repay the amounts due and payable under our Revolving Credit Facility, lenders thereunder could proceed against the collateral granted to them to secure that indebtedness. In the event our lenders or noteholders accelerate the repayment of our borrowings, we and our subsidiaries may not have sufficient assets to repay that indebtedness.

These restrictions may affect our ability to grow in accordance with our strategy. In addition, our financial results, our substantial indebtedness and our credit ratings could adversely affect the availability and terms of our financing.

Our acquisition and divestiture activities involve substantial risks.

We have made and expect to continue to pursue acquisitions, dispositions, or other investments that may strategically fit our business and/or growth objectives. We cannot provide assurances that we will be able to locate suitable acquisitions, dispositions, or investments, or that we will be able to consummate any such transactions on terms and conditions acceptable to us. Even if we do successfully execute such transactions, they may not result in anticipated benefits, which could have a material adverse effect on our financial results. If we are unable to successfully integrate and develop acquired businesses, we could fail to achieve anticipated synergies and cost savings, including any expected increases in revenues and operating results. We may not be able to successfully cause a buyer of a divested business to assume the liabilities of that business or, even if such liabilities are assumed, we may have difficulties enforcing our rights, contractual or otherwise, against the buyer. We may invest in companies or businesses that fail, causing a loss of all or part of our investment. In addition, if we determine that an other-than-temporary decline in the fair value exists for a company in which we have invested, we may have to write down that investment to its fair value and recognize the related write-down as an investment loss.

In connection with the Spin-off, we agreed to indemnify Technip Energies for certain liabilities, and Technip Energies agreed to indemnify us for certain liabilities. If we are required to act on these indemnities to Technip Energies, our

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financial results could be negatively impacted. Additionally, any indemnity from Technip Energies may not be sufficient to insure us against the full amount of liabilities for which we are responsible and Technip Energies may not be able to satisfy its indemnification obligations in the future.

Demands to address ESG matters could surpass our ability to meet demands and thus adversely affect our business.

There has been increasing attention from stakeholders, investors, customers on renewable energy and ESG practices and disclosures, including practices and disclosures related to greenhouse gases and climate change, and diversity and inclusion initiatives and governance standards. If we are unable to meet the ESG standards, investment and/or lending criteria set by these investors, we may lose investment and our reputation may be negatively affected. The increasing attention and pressure from the shareholders, financial institutions and/or financial markets could also increase the likelihood of governmental investigations and private litigation.

We are exploring investments in energy transition, and uncertainties with respect to these markets may adversely affect our business.

Uncertainties with respect to the energy transition may adversely affect our business. As a result of our evolution in the renewable energies arena, we are exploring opportunities in greenhouse gas removal, offshore floating renewables, and hydrogen. While we have subsea and surface expertise, as well as capabilities in project integration, we are exploring opportunities that are new to us, and therefore involve uncertainties and risks.

The market for renewable energy is also intensively competitive and rapidly evolving. If the demand for renewable energy fails to grow sufficiently, if new geopolitical, legislative or regulatory initiatives emerge and governments around the world reduce subsidies and economic incentives on renewable energy projects, or if market opportunities manifest themselves in areas that we do not focus on, our ventures in new energy may not succeed.

Limited operating experience or limited brand recognition in new energy markets may also limit our goals and targets on business expansion.

Risks Related to Our Operations

We may lose money on fixed-price contracts.

As is customary for some of our projects, we often agree to provide products and services under fixed-price contracts. We are subject to material risks in connection with such fixed-price contracts. It is not possible to estimate with complete certainty the final cost or margin of a project at the time of bidding or during the early phases of its execution. Actual expenses incurred in executing these fixed-price contracts can vary substantially from those originally anticipated for several reasons including, but not limited to, the following:

•unforeseen additional costs related to the purchase of substantial equipment, material, and components necessary for contract fulfillment or labor shortages in the markets where the contracts are performed;

•mechanical failure of our production equipment and machinery;

•delays caused by local weather conditions and/or natural disasters (including earthquakes, floods and public health crises such as the COVID-19 pandemic); and

•a failure of suppliers, subcontractors, or joint venture partners to perform their contractual obligations.

The realization of any material risks and unforeseen circumstances could also lead to delays in the execution schedule of a project. We may be held liable to a customer should we fail to meet project milestones or deadlines or to comply with other contractual provisions. Additionally, delays in certain projects could lead to delays in subsequent projects that were scheduled to use equipment and machinery still being utilized on a delayed project.

Pursuant to the terms of fixed-price contracts, we are not always able to increase the price of the contract to reflect factors that were unforeseen at the time our bid was submitted, and this risk may be heightened for projects with longer terms. Depending on the size of a project, variations from estimated contract performance, or variations in multiple contracts, could have a significant impact on our financial condition, results of operations or cash flows.

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Our failure to timely deliver our backlog could affect future sales, profitability, and relationships with our customers.

Many of the contracts we enter into with our customers require long manufacturing lead times due to complex technical and logistical requirements. These contracts may contain clauses related to liquidated damages or financial incentives regarding on-time delivery, and a failure by us to deliver in accordance with customer expectations could subject us to liquidated damages or loss of financial incentives, reduce our margins on these contracts, or result in damage to existing customer relationships. The ability to meet customer delivery schedules for this backlog is dependent upon a number of factors, including, but not limited to, access to raw materials required for production, an adequately trained and capable workforce, subcontractor performance, project engineering expertise and execution, sufficient manufacturing plant capacity, and appropriate planning and scheduling of manufacturing resources. Failure to deliver backlog in accordance with expectations could negatively impact our financial performance.

We face risks relating to our reliance on subcontractors, suppliers, and our joint venture partners.

We generally rely on subcontractors, suppliers, and our joint venture partners for the performance of our contracts. Although we are not dependent upon any single supplier, certain geographic areas of our business or a project or group of projects may depend heavily on certain suppliers for raw materials or semi-finished goods.

Any difficulty in engaging suitable subcontractors or acquiring equipment and materials could compromise our ability to generate a significant margin on a project or to complete such project within the allocated time frame. If subcontractors, suppliers or joint venture partners refuse to adhere to their contractual obligations with us, or are unable to do so due to a deterioration of their financial condition, we may be unable to find a suitable replacement at a comparable price, or at all. Moreover, the failure of one of our joint venture partners to perform their obligations in a timely and satisfactory manner could lead to additional obligations and costs being imposed on us as we may be obligated to assume our defaulting partner’s obligations or compensate our customers. Additionally, our supply chain, subcontractors, suppliers, and our joint venture partners may be adversely affected by the COVID-19 pandemic, which has created global shipping and logistics challenges such as extended shipping lead times and pricing pressures on transportation and logistics.

Any delay, failure to meet contractual obligations, or other event beyond our control or not foreseeable by us, that is attributable to a subcontractor, supplier or joint venture partner, could lead to delays in the overall progress of the project and/or generate significant extra costs. Even if we are entitled to make a claim for these extra costs against the defaulting supplier, subcontractor or joint venture partner, we may be unable to recover the entirety of these costs and this could materially adversely affect our business, financial condition or results of operations.

A failure or breach of our IT infrastructure or that of our subcontractors, suppliers or joint venture partners, including as a result of cyber-attacks, could adversely impact our business and results of operations.

The efficient operation of our business is dependent on the security and integrity of our IT systems, physical assets, and data that we process and maintain. Accordingly, we rely upon the capacity, reliability, and security of our IT hardware and software infrastructure and our ability to expand and update this infrastructure in response to changing needs and evolving threats. We have been subject to cyber-attacks in the past, including phishing, malware, ransomware and other security incidents. No such attack has had a material adverse effect on our business, however, this may not be the case with future attacks. Our systems and physical assets may be vulnerable to damages from such attacks, as well as from natural disasters, failures in hardware or software, power fluctuations, unauthorized access to data and systems, theft, loss or destruction of data (including confidential customer, employee or contractor information), human error, and other similar disruptions, and we cannot give assurance that any security measures we have implemented or may in the future implement will be sufficient to identify and prevent or mitigate such disruptions. In response to the COVID-19 pandemic, we have transitioned many of our employees to remote working arrangements which presents increased cybersecurity risks. If a cyber-attack, power outage, connectivity issue, or other event occurred that impacted our employees’ ability to work remotely, it may be difficult or, in certain cases, impossible, for us to continue our business for a substantial period of time.

We rely on third parties to support the operation of our IT hardware, software infrastructure, and cloud services, and in certain instances, utilize web-based and software-as-a-service applications, across a broad array of services and functions (e.g., human resources, finance, data transmission, communications, risk compliance, among others). The security and privacy measures implemented by such third parties, as well as the measures implemented by any

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entities we acquire or with whom we do business, may not be sufficient to identify or prevent cyber-attacks, and any such attacks may have a material adverse effect on our business. While our agreements with third parties, such as vendors, typically contain provisions that seek to eliminate or limit our exposure to liability for damages from a cyber-attack, we cannot ensure such provisions will withstand legal challenges or cover all or any such damages.

Threats to our IT systems and to those of our subcontractors, suppliers and joint venture partners arise from numerous sources, not all of which are within our or their control, including fraud or malice on the part of third parties, accidental technological failure, electrical or telecommunication outages, failures of computer servers or other damage to our property or assets, outbreaks of hostilities, terrorist acts, and social engineering (e.g., phishing). The frequency and magnitude of cyberattacks and other security incidents is expected to increase in the future and attackers are becoming more sophisticated. We, as well as other critical business partners, may be unable to anticipate, detect or prevent future attacks, particularly because the methodologies utilized by attackers change frequently or are not recognized until launched, and attackers are increasingly using techniques and tools designed to circumvent controls, to avoid detection, and to remove or obfuscate forensic evidence. The failure of our or others’ security controls and measures to prevent, detect, contain or remediate cyberattacks or other significant security incidents could disrupt our business and result in numerous adverse consequences, including reduced effectiveness and efficiency of operations, inappropriate disclosure of confidential and proprietary information, including personal data, litigation or regulatory investigations, actions and fines included for a breach of data protection laws, reputational harm, increased overhead costs including due to compliance requirements, and loss of important information, which could have a material adverse effect on our business and results of operations. In addition, we may be required to incur significant costs to protect against or to mitigate damage caused by these attacks, disruptions or other security incidents in the future. Our insurance coverage may not cover all of the costs and liabilities we incur as the result of these events, and if our business continuity and/or disaster recovery plans do not effectively and timely resolve issues resulting from a cyber-attack, we may suffer material adverse effects on our business.

Pirates endanger our maritime employees and assets.

We face material piracy risks in the Gulf of Guinea, the Somali Basin, and the Gulf of Aden, and, to a lesser extent, in Southeast Asia, Malacca, and the Singapore Straits. Piracy represents a risk for both our projects and our vessels, which operate and transport through sensitive maritime areas. Such risks have the potential to significantly harm our crews and to negatively impact the execution schedule for our projects. If our maritime employees or assets are endangered, additional time may be required to find an alternative solution, which may delay project realization and negatively impact our business, financial condition, or results of operations.

New capital asset construction projects for vessels and manufacturing facilities are subject to risks, including delays and cost overruns, which could have a material adverse effect on our financial condition, or results of operations.

From time to time, we carry out capital asset construction projects to maintain, upgrade, and develop our asset base, and such projects are subject to risks of delay and cost overruns that are inherent in any large construction project, resulting from numerous factors including, but not limited to, the following:

•shortages of key equipment, materials or skilled labor;

•delays in the delivery of ordered materials and equipment;

•design and engineering issues; and

•shipyard delays and performance issues.

Failure to complete construction in time, or the inability to complete construction in accordance with design specifications, may result in the loss of revenue. Additionally, capital expenditures for construction projects could materially exceed the initially planned investments, or there could be delays in putting such assets into operation.

Risks Related to Legal Proceedings,Tax and Regulatory Matters

The industries in which we operate or have operated expose us to potential liabilities, including the installation or use of our products, which may not be covered by insurance or may be in excess of policy limits, or for which expected recoveries may not be realized.

We are subject to potential liabilities arising from, among other possibilities, equipment malfunctions, equipment misuse, personal injuries, and natural disasters, any of which may result in hazardous situations, including

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uncontrollable flows of oil, gas or well fluids, or other sources of energy, fires, and explosions. Our insurance against these risks may not be adequate to cover our liabilities. Further, the insurance may not generally be available in the future or, if available, premiums may not be commercially justifiable. If we incur substantial liability and the damages are not covered by insurance or are in excess of policy limits, or if we were to incur liability at a time when we were not able to obtain liability insurance, such potential liabilities could have a material adverse effect on our business, results of operations, financial condition or cash flows.

Our operations require us to comply with numerous regulations, violations of which could have a material adverse effect on our financial condition, results of operations, or cash flows.

Our operations and manufacturing activities are governed by international, regional, transnational, and national laws and regulations in every place where we operate relating to matters such as environmental protection, health and safety, labor and employment, import/export controls, currency exchange, bribery and corruption, and taxation. These laws and regulations are complex, frequently change, and have tended to become more stringent over time. In the event the scope of these laws and regulations expand in the future, the incremental cost of compliance could adversely impact our financial condition, results of operations, or cash flows.

Our international operations are subject to anti-corruption laws and regulations, such as the U.S. Foreign Corrupt Practices Act (“FCPA”), the U.K. Bribery Act of 2010 (the “Bribery Act”), the anti-corruption provisions of French law n° 2016-1691 dated December 9, 2016 relating to Transparency, Anti-corruption and Modernization of the Business Practice (“Sapin II Law”), the Brazilian law nº 12,846/13, or the Brazilian Anti-Bribery Act (also known as the Brazilian Clean Company Act), and economic and trade sanctions, including those administered by the United Nations, the European Union, the Office of Foreign Assets Control of the U.S. Department of the Treasury (“U.S. Treasury”), and the U.S. Department of State. The FCPA prohibits corruptly providing anything of value to foreign officials for the purposes of obtaining or retaining business or securing any improper business advantage. We may deal with both governments and state-owned business enterprises, the employees of which are considered foreign officials for purposes of the FCPA. The provisions of the Bribery Act extend beyond bribery of foreign public officials and are more onerous than the FCPA in a number of other respects, including jurisdiction, non-exemption of facilitation payments, and penalties. Economic and trade sanctions restrict our transactions or dealings with certain sanctioned countries, territories, and designated persons.

As a result of doing business in countries throughout the world, including through partners and agents, we are exposed to a risk of violating anti-corruption laws and sanctions regulations. Some of the international locations in which we currently operate or may operate, in the future, have developing legal systems and may have higher levels of corruption than more developed nations. Our continued expansion and worldwide operations, including in developing countries, our development of joint venture relationships worldwide, and the employment of local agents in the countries in which we operate increase the risk of violations of anti-corruption laws and economic and trade sanctions. Violations of anti-corruption laws and economic and trade sanctions are punishable by civil penalties, including fines, denial of export privileges, injunctions, asset seizures, debarment from government contracts (and termination of existing contracts), and revocations or restrictions of licenses, as well as criminal fines and imprisonment. In addition, any major violations could have a significant impact on our reputation and, consequently, on our ability to win future business.

We have implemented policies and procedures designed to minimize and detect potential violations of laws and regulations in a timely manner but we can provide no assurance that such policies and procedures will be followed at all times or will effectively detect and prevent violations of the applicable laws by one or more of our employees, consultants, agents, or partners. The occurrence of any such violation could subject us to penalties and material adverse consequences on our business, financial condition, results of operations, or cash flows.

Compliance with environmental and climate change-related laws and regulations may adversely affect our business and results of operations.

Environmental laws and regulations in various countries affect the equipment, systems, and services we design, market, and sell, as well as the facilities where we manufacture our equipment and systems, and any other operations we undertake. We are required to invest financial and managerial resources to comply with environmental laws and regulations, and believe that we will continue to be required to do so in the future. Failure to comply with these laws and regulations may result in the assessment of administrative, civil, and criminal penalties, the imposition of remedial obligations, the issuance of orders enjoining our operations, or other claims and complaints. Additionally, our insurance and compliance costs may increase as a result of changes in environmental laws and regulations or changes in enforcement. These laws and regulations, as well as any new laws and

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regulations affecting exploration and development of drilling for crude oil and natural gas, are becoming increasingly strict and could adversely affect our business and operating results by increasing our costs, limiting the demand for our products and services, or restricting our operations.

Regulatory requirements related to ESG (including sustainability) matters have been, and are being, implemented in the European Union in particular, in relation to financial market participants. Such regulatory requirements are being implemented on a phased basis. We expect regulatory requirements related to, and investor focus on, ESG (including sustainability) matters to continue to expand in the EU, the United States, and more globally. We establish ESG objectives that align with our foundational beliefs and corporate strategy with an aim toward reducing our carbon footprint, while raising awareness and making advancements in inclusion and diversity. If, in relation to ESG (including sustainability) matters, we are not able to meet current and future regulatory requirements, the reporting requirements of regulators, or the current and future expectations of investors, customers or other stakeholders, our business and ability to raise capital may be adversely affected. In addition, negative attitudes toward or perceptions of fossil fuel products and their relationship to the environment and climate change may reduce the demand for production of oil and gas in areas of the world where our customers operate or otherwise limit our customers’ access to capital and thus reduce future demand for our products and services. Any of these trends may, in turn, adversely affect our financial condition, results of operations and cash flows.

Existing or future laws and regulations relating to greenhouse gas emissions and climate change may adversely affect our business.

Climate change continues to attract considerable public and scientific attention. As a result, numerous laws, regulations, and proposals have been made and are likely to continue to be made at the international, national, regional, and state levels of government to monitor and limit emissions of carbon dioxide, methane, and other “greenhouse gases” (“GHGs”). These efforts have included cap-and-trade programs, carbon taxes, GHG reporting and tracking programs and regulations that directly limit GHG emissions from certain sources. Such existing or future laws, regulations, and proposals concerning the release of GHGs or that concern climate change (including laws, regulations, and proposals that seek to mitigate the effects of climate change) may adversely impact demand for the equipment, systems and services we design, market and sell. For example, oil and natural gas exploration and production may decline as a result of such laws, regulations, and proposals, and as a consequence, demand for our equipment, systems and services may also decline. In addition, such laws, regulations, and proposals may also result in more onerous obligations with respect to our operations, including the facilities where we manufacture our equipment and systems. Such decline in demand for our equipment, systems and services and such onerous obligations in respect of our operations may adversely affect our financial condition, results of operations, or cash flows.

As an English public limited company, we must meet certain additional financial requirements before we may declare dividends or repurchase shares and certain capital structure decisions may require stockholder approval which may limit our flexibility to manage our capital structure. We may not be able to pay dividends or repurchase our ordinary shares in accordance with our announced intent, or at all.

Under English law, we will only be able to declare dividends, make distributions, or repurchase shares (other than out of the proceeds of a new issuance of shares for that purpose) out of “distributable profits.” Distributable profits are a company’s accumulated, realized profits, to the extent that they have not been previously utilized by distribution or capitalization, less its accumulated, realized losses, to the extent that they have not been previously written off in a reduction or reorganization of capital duly made. In addition, as a public limited company incorporated in England and Wales, we may only make a distribution if the amount of our net assets is not less than the aggregate of our called-up share capital and non-distributable reserves, to the extent that the distribution does not reduce the amount of those assets to less than that aggregate.

Our articles of association permit us by ordinary resolution of the stockholders to declare dividends, provided that the directors have made a recommendation as to its amount. The dividend shall not exceed the amount recommended by the Board of Directors. The directors may also decide to pay interim dividends if it appears to them that the profits available for distribution justify such payment. When recommending or declaring payment of a dividend, the directors are required under English law to comply with their duties, including considering our future financial requirements.

In addition, the Board of Directors’ determinations regarding dividends and share repurchases will depend on a variety of other factors, including our net income, cash flow generated from operations or other sources, liquidity position, and potential alternative uses of cash, such as acquisitions, as well as economic conditions and expected future financial results. Our ability to declare and pay future dividends and make future share repurchases will

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depend on our future financial performance, which in turn depends on the successful implementation of our strategy and on financial, competitive, regulatory, technical, general economic conditions, demand and selling prices for our products and services, and other factors specific to our industry or specific projects, many of which are beyond our control. Therefore, our ability to generate cash depends on the performance of our operations and could be limited by decreases in our profitability or increases in costs, regulatory changes, capital expenditures, or debt servicing requirements.

Any failure to pay dividends or repurchase shares of our ordinary shares could negatively impact our reputation, harm investor confidence in us, and cause the market price of our ordinary shares to decline.

Uninsured claims and litigation against us, including product liability and claims and intellectual property litigation, could adversely impact our financial condition, results of operations, or cash flows.

We could be impacted by the outcome of pending litigation, as well as unexpected litigation or proceedings. We have insurance coverage against operating hazards, including product liability claims and personal injury claims related to our products or operating environments in which our employees operate, to the extent deemed prudent by our management and to the extent insurance is available. However, our insurance policies are subject to exclusions, limitations, and other conditions and may not apply in all cases, for example, where willful wrongdoing on our part is alleged. Additionally, the nature and amount of that insurance may not be sufficient to fully indemnify us against liabilities arising out of pending and future claims and litigation. Additionally, in individual circumstances, certain proceedings or cases may also lead to our formal or informal exclusion from tenders or the revocation or loss of business licenses or permits. Our financial condition, results of operations, or cash flows could be adversely affected by unexpected claims not covered by insurance.

In addition, the tools, techniques, methodologies, programs, and components we use to provide our services may infringe upon the intellectual property rights of others. Infringement claims generally result in significant legal and other costs. The resolution of these claims could require us to pay damages, enter into license agreements or develop alternative technologies. The development of these technologies or the payment of royalties under licenses from third parties, if available, would increase our costs. If a license were not available, or we are not able to develop alternative technologies, we might not be able to continue providing a particular service or product, which could adversely affect our financial condition, results of operations, or cash flows.

We are subject to governmental regulation and other legal obligations related to privacy, data protection, and data security. Our actual or perceived failure to comply with such obligations could harm our business.

We are subject to international data protection laws, such as the General Data Protection Regulation 2016/679, or GDPR, in the European Economic Area, or EEA, and the UK equivalent (“UK GDPR”). The GDPR, UK GDPR and implementing legislation in the EEA and UK impose several stringent requirements for controllers and processors of personal data which have increased our obligations, including, for example, by requiring more robust disclosures to individuals, notifications, in some cases, of data breaches to regulators and data subjects, and a record of processing and other policies and procedures to be maintained to adhere to the accountability principle.

In addition, we are subject to the GDPR and UK GDPR’s rules on transferring personal data outside of the EEA and UK (including to the United States), and recent legal developments in Europe have created complexity and uncertainty regarding such transfers. Most recently, on July 16, 2020, the Court of Justice of the European Union (“CJEU”) invalidated the EU-US Privacy Shield Framework (“Privacy Shield”) under which personal data could be transferred from the European Union to US entities who had self-certified under the Privacy Shield scheme, and the decision cast uncertainly on when transfers could be made under the standard contractual clauses; compliance with such may require us to change processes by which we transfer data outside of the European Union and United Kingdom, including to the United States. As supervisory authorities issue further guidance on personal data export mechanisms, including circumstances where the standard contractual clauses cannot be used, and/or start taking enforcement action, we could suffer additional costs, complaints and/or regulatory investigations or fines, and/or if we are otherwise unable to transfer personal data between and among countries and regions in which we operate, it could affect the manner in which we provide our services, the geographical location or segregation of our relevant systems and operations, and could adversely affect our financial results.

We are also subject to evolving EU and UK privacy laws on cookies and e-marketing. In the European Union and the United Kingdom, regulators are increasingly focusing on compliance with requirements in the online behavioral advertising ecosystem, and current national laws that implement the ePrivacy Directive are highly likely to be replaced by an EU regulation known as the ePrivacy Regulation which will significantly increase fines for non-

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compliance. If regulators start to enforce the strict approach in recent guidance, this could lead to substantial costs, and require significant systems changes.

Failure to comply with the requirements of GDPR, UK GDPR and the local laws implementing or supplementing the GDPR could result in fines (for example, non-compliance with the GDPR or UK GDPR, specifically, may result in administrative fines or monetary penalties, by each regime, up to the greater of €20,000,000/ £17,000,000 or up to 4 percent of the total worldwide annual turnover of the preceding financial year). In addition, we may also face regulatory investigations and enforcement action, reputational damage, and civil claims including representative actions and other class action type litigation, potentially amounting to significant compensation or damages liabilities, as well as associated costs, diversion of internal resources, and reputational harm.

We are likely to be required to expend significant capital and other resources to ensure ongoing compliance with the GDPR, UK GDPR and other applicable data protection legislation, and we may be required to put in place additional control mechanisms which could be onerous and adversely affect our business, financial condition, results of operations, or cash flows.

The IRS may not agree that we should be treated as a foreign corporation for U.S. federal tax purposes and may seek to impose an excise tax on gains recognized by certain individuals.

Although we are incorporated in the United Kingdom, the U.S. Internal Revenue Service (the “IRS”) may assert that we should be treated as a U.S. “domestic” corporation (and, therefore, a U.S. tax resident) for U.S. federal income tax purposes pursuant to Section 7874 of the U.S. Internal Revenue Code of 1986, as amended (the “Code”). For U.S. federal income tax purposes, a corporation (i) is generally considered a “domestic” corporation (or U.S. tax resident) if it is organized in the United States or of any state or political subdivision therein, and (ii) is generally considered a “foreign” corporation (or non-U.S. tax resident) if it is not considered a domestic corporation. Because we are a U.K. incorporated entity, we would be considered a foreign corporation (and, therefore, a non-U.S. tax resident) under these rules. Section 7874 of the Code (“Section 7874”) provides an exception under which a foreign incorporated entity may, in certain circumstances, be treated as a domestic corporation for U.S. federal income tax purposes.

We do not believe this exception applies. However, the Section 7874 rules are complex and subject to detailed regulations, the application of which is uncertain in various respects. It is possible that the IRS will not agree with our position. Should the IRS successfully challenge our position, it is also possible that an excise tax under Section 4985 of the Code (the “Section 4985 Excise Tax”) may be assessed against certain “disqualified individuals” (including former officers and directors of FMC Technologies, Inc.) on certain stock-based compensation held thereby. We may, if we determine that it is appropriate, provide disqualified individuals with a payment with respect to the Section 4985 Excise Tax, so that, on a net after-tax basis, they would be in the same position as if no such Section 4985 Excise Tax had been applied.

In addition, there can be no assurance that there will not be a change in law or interpretation, including with retroactive effect, that might cause us to be treated as a domestic corporation for U.S. federal income tax purposes.

U.S. tax laws and/or guidance could affect our ability to engage in certain acquisition strategies and certain internal restructurings.

Even if we are treated as a foreign corporation for U.S. federal income tax purposes, Section 7874, U.S. Treasury regulations, and other guidance promulgated thereunder may adversely affect our ability to engage in certain future acquisitions of U.S. businesses or to restructure the non-U.S. members of our group. These limitations, if applicable, may affect the tax efficiencies that otherwise might be achieved in such potential future transactions or restructurings.

In addition, the IRS and the U.S. Treasury have issued final and temporary regulations providing that, even if we are treated as a foreign corporation for U.S. federal income tax purposes, certain intercompany debt instruments issued on or after April 4, 2016 will be treated as equity for U.S. federal income tax purposes, therefore limiting U.S. tax benefits and resulting in possible U.S. withholding taxes. Although the U.S. Treasury, through recent guidance, removes certain documentation requirements that would otherwise be imposed with respect to covered debt instruments, announces an intention to further modify and possibly withdraw certain classification rules relating to covered debt instruments, and further indicates that these rules generally are the subject of continuing study and may be further materially modified, the current regulations may adversely affect our future effective tax rate and could also impact our ability to engage in future restructurings if such transactions cause an existing intercompany debt instrument to be treated as reissued for U.S. federal income tax purposes.

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We are subject to the tax laws of numerous jurisdictions; challenges to the interpretation of, or future changes to, such laws could adversely affect us.

We and our subsidiaries are subject to tax laws and regulations in the United Kingdom, the United States, France, and numerous other jurisdictions in which we and our subsidiaries operate. These laws and regulations are inherently complex, and we are, and will continue to be, obligated to make judgments and interpretations about the application of these laws and regulations to our operations and businesses. The interpretation and application of these laws and regulations could be challenged by the relevant governmental authorities, which could result in administrative or judicial procedures, actions, or sanctions, which could be material.

On December 22, 2017, the Tax Cuts and Jobs Act was signed into law in the United States, which made extensive changes to the U.S. taxation of multinational companies, and is subject to continuing regulatory and possible legislative changes, especially given the new Administration and Congress in the United States. In addition, the U.S. Congress, the U.K. Government, the European Union, the Organization for Economic Co-operation and Development (the “OECD”), and other government agencies in jurisdictions where we and our affiliates do business have an extended focus on issues related to the taxation of multinational corporations. For instance, in October 2021, the OECD released additional proposals under Base Erosion and Profit Shifting that provide for a global minimum tax of 15%, and to date approximately 140 countries have tentatively signed a framework agreeing in principle to this initiative. The implementation of this global minimum tax, however, is contingent upon the independent actions of participating countries and is subject to further negotiation among OECD member states. New tax initiatives, directives, and rules, such as the U.S. Tax Cuts and Jobs Act, the OECD’s Base Erosion and Profit Shifting initiative, and the European Union’s Anti-Tax Avoidance Directives, may increase our tax burden and require additional compliance-related expenditures. As a result, our financial condition, results of operations, or cash flows may be adversely affected. Moreover, the U.S. government, and other jurisdictions in which we do business, may enact significant changes to the taxation of business entities including, among others, the imposition of minimum taxes or surtaxes on certain types of income. The likelihood of these changes being enacted or implemented is unclear. Further changes, including with retroactive effect, in the tax laws of the United States, the United Kingdom, the European Union, or other countries in which we and our affiliates do business could adversely affect us.

We may not qualify for benefits under tax treaties entered into between the United Kingdom and other countries.

We operate in a manner such that we believe we are eligible for benefits under tax treaties between the United Kingdom and other countries. However, our ability to qualify for such benefits will depend on whether we are treated as a U.K. tax resident, the requirements contained in each treaty and applicable domestic laws, on the facts and circumstances surrounding our operations and management, and on the relevant interpretation of the tax authorities and courts. For example, because of Brexit, we may lose some or all of the benefits of tax treaties between the United States and the remaining members of the European Union, and face higher tax liabilities, which may be significant. Another example is the Multilateral Convention to Implement Tax Treaty Related Measures to Prevent Base Erosion and Profit Shifting (the “MLI”), which entered into force for participating jurisdictions on July 1, 2018. The MLI recommends that countries adopt a “limitation-on-benefit” (“LOB”) rule and/or a “principal purpose test” (“PPT”) rule with regards to their tax treaties. The application of the LOB rule or the PPT rule could deny us treaty benefits (such as a reduced rate of withholding tax) that were previously available and as such there remains uncertainty as to whether and, if so, to what extent such treaty benefits will continue to be available. The position is likely to remain uncertain for a number of years.

The failure by us or our subsidiaries to qualify for benefits under tax treaties entered into between the United Kingdom and other countries could result in adverse tax consequences to us (including an increased tax burden and increased filing obligations) and could result in certain tax consequences of owning and disposing of our shares.

We intend to be treated exclusively as a resident of the United Kingdom for tax purposes, but French or other tax authorities may seek to treat us as a tax resident of another jurisdiction.

We are incorporated in the United Kingdom. English law currently provides that we will be regarded as a U.K. resident for tax purposes from incorporation and shall remain so unless (i) we are concurrently a resident in another jurisdiction (applying the tax residence rules of that jurisdiction) that has a double tax treaty with the United Kingdom and (ii) there is a tiebreaker provision in that tax treaty which allocates exclusive residence to that other jurisdiction.

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In this regard, we have a permanent establishment in France to satisfy certain French tax requirements imposed by the French Tax Code with respect to the Merger. Although it is intended that we will be treated as having our exclusive place of tax residence in the United Kingdom, the French tax authorities may claim that we are a tax resident of France if we were to fail to maintain our “place of effective management” in the United Kingdom. Any such claim would be settled between the French and U.K. tax authorities pursuant to the mutual assistance procedure provided for by the tax treaty concluded between France and the United Kingdom. There is no assurance that these authorities would reach an agreement that we will remain exclusively a U.K. tax resident; an adverse determination could materially and adversely affect our business, financial condition, results of operations, or cash flows. A failure to maintain exclusive tax residency in the United Kingdom could result in adverse tax consequences to us and our subsidiaries and could result in certain adverse changes in the tax consequences of owning and disposing of our shares.

General Risk Factors

Our businesses are dependent on the continuing services of our key managers and employees.

We depend on key personnel. The loss of any key personnel could adversely impact our business if we are unable to implement key strategies or transactions in their absence. The loss of qualified employees or failure to retain and motivate additional highly skilled employees required for the operation and expansion of our business could hinder our operation and expansion, as well as our ability to successfully conduct research activities and develop marketable products and services.

Seasonal and weather conditions could adversely affect demand for our services and operations.

Our business may be materially affected by variation from normal weather patterns, such as cooler or warmer summers and winters. Adverse weather conditions, such as hurricanes in the Gulf of Mexico or extreme winter conditions in Canada, and the North Sea, may interrupt or curtail our operations, or our customers’ operations, cause supply disruptions or loss of productivity, and may result in a loss of revenue or damage to our equipment and facilities, which may or may not be insured. In addition, acute or chronic physical impacts of climate change, such as sea level rise, coastal storm surge, inland flooding from intense rainfall and hurricane-strength winds may damage our facilities or the facilities of key third parties. Increasing concentrations of greenhouse gases in the Earth’s atmosphere may produce climate changes that increase variation from normal weather patterns, such as increased frequency and severity of storms, floods, droughts, and other climatic events, which could further impact our operations. Significant physical effects of climate change could also have a direct effect on our operations and an indirect effect on our business by interrupting the operations of those with whom we do business. Any of these events or outcomes could have a material adverse effect on our business, financial condition, cash flows, or results of operations.

Currency exchange rate fluctuations could adversely affect our financial condition, results of operations, or cash flows.

We conduct operations around the world in many different currencies. Because a significant portion of our revenue is denominated in currencies other than our reporting currency, the U.S. dollar, changes in exchange rates will produce fluctuations in our revenue, costs, and earnings, and may also affect the book value of our assets and liabilities and related equity. We hedge transaction impacts on margins and earnings where a transaction is not in the functional currency of the business unit, but we do not hedge translation impacts on earnings. Our efforts to minimize our currency exposure through such hedging transactions may not be successful depending on market and business conditions. Moreover, certain currencies in which we conduct operations, specifically currencies in countries such as Angola and Nigeria, do not actively trade in the global foreign exchange markets and may subject us to increased foreign currency exposures. As a result, fluctuations in foreign currency exchange rates may adversely affect our financial condition, results of operations, or cash flows.

We are exposed to risks in connection with our defined benefit pension plan commitments.

We have funded and unfunded defined benefit pension plans, which provide defined benefits based on years of service and salary. We are required to recognize the funded status of defined benefit post-retirement plans as an asset or liability in the consolidated balance sheet and recognize changes in that funded status in comprehensive income in the year in which the changes occur. Further, we are required to measure each plan’s assets and its obligations that determine its funded status as of the date of the consolidated balance sheet. Each defined benefit pension plan’s assets are invested in different asset classes and their value may fluctuate in accordance with market conditions. Any deterioration in the value of the defined benefit pension plan assets could therefore increase

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our obligations. Any such increases in our net pension obligations could adversely affect our financial condition due to increased additional outflow of funds to finance the pension obligations.

In addition, applicable law and/or the terms of the relevant defined benefit pension plan may require us to make cash contributions or provide financial support upon the occurrence of certain events. We cannot predict whether, or to what extent, changing market or economic conditions, regulatory changes or other factors will further increase our pension expense or funding obligations. For further information regarding our pension liabilities, see Note 22 for further information.

We may be unable to obtain sufficient bonding capacity for certain contracts, and the need for performance and surety bonds could reduce availability under our credit facility.

In line with industry practice, we are often required to post standby letters of credit to customers or enter into surety bond arrangements in favor of customers. Those letters of credit and surety bond arrangements generally protect customers against our failure to perform our obligations under the applicable contracts. If we are unable to renew or obtain a sufficient level of bonding capacity in the future, we may be precluded from bidding for certain contracts or contracting with certain customers. Additionally, even if we are able to successfully renew or obtain performance or payment bonds, we may be required to post letters of credit in connection with the bonds. The letters of credit would reduce availability under our credit facility. Furthermore, under standard terms in the surety market, sureties issue bonds on a project-by-project basis and can decline to issue bonds at any time or require the posting of additional collateral as a condition to issuing or renewing any bonds. If we were to experience an interruption or reduction in the availability of bonding capacity as a result of these or any other reasons, we may be unable to compete for or work on projects that require bonding.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES         

Our corporate headquarters is in Newcastle, England. We also maintain corporate offices in Houston, Texas, where significant worldwide global support activity occurs. In addition, we own or lease numerous properties throughout the world.

We believe our properties and facilities are suitable for their present and intended purposes and are operating at a level consistent with the requirements of the industry in which we operate. We also believe that our leases are at competitive or market rates and do not anticipate any difficulty in leasing suitable additional space upon expiration of our current lease terms.

The following table shows our principal properties by reporting segment at December 31, 2021:

Location	Segment
Africa
Hassi Messaoud, Algeria	Surface
Lagos, Nigeria	Subsea
Lobito, Angola	Subsea
Luanda, Angola	Subsea
Malabo, Equatorial Guinea	Subsea
Port Harcourt, Nigeria	Subsea
Takoradi, Ghana	Subsea
Asia
Chennai, India	Subsea
Hyderabad, India	Surface
Jakarta, Indonesia	Surface
Johor, Malaysia	Subsea
Kuala Lumpur, Malaysia	Subsea
Noida, India	Subsea, Surface

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Location	Segment
Nusajaya, Malaysia	Subsea, Surface
Singapore	Subsea, Surface
Australia
Henderson, Australia	Subsea
Perth, Australia	Subsea
Europe
Aberdeen, United Kingdom	Surface
Aktau, Kazakhstan	Subsea, Surface
Arnhem, The Netherlands	Surface
Atyrau, Kazakhstan	Subsea, Surface
Bergen, Norway	Subsea
Courbevoie (Paris - La Défense), France	Subsea
Dunfermline, United Kingdom	Subsea, Surface
Ellerbek, Germany	Surface
Evanton, United Kingdom	Subsea
Horten, Norway	Subsea
Kongsberg, Norway	Subsea, Surface
Krakow, Poland	Subsea
Le Trait, France	Subsea
Lisbon, Portugal	Subsea
Lysaker, Norway	Subsea
Moscow, Russia	Subsea, Surface
Newcastle, United Kingdom	Subsea
Orkanger, Norway	Subsea
Sens, France	Surface
Stavanger, Norway	Subsea, Surface
Veenord, Netherlands	Surface
Westhill, United Kingdom	Subsea
Middle East
Abu Dhabi, United Arab Emirates	Surface
Dammam, Saudi Arabia	Surface
Doha, Qatar	Surface
North America
Brighton (Colorado), United States	Surface
Charleroi (Pennsylvania), United States	Surface
Davis (California), United States	Subsea
Erie (Pennsylvania), United States	Surface
Houston (Texas), United States	Subsea, Surface
Odessa (Texas), United States	Surface
Oklahoma City (Oklahoma), United States	Surface
San Antonio (Texas), United States	Surface
Stephenville (Texas), United States	Surface
St. John’s (Newfoundland), Canada	Subsea
Theodore (Alabama), United States	Subsea
South America
Georgetown, Guyana	Subsea
Macaé, Brazil	Subsea
Neuquén, Argentina	Surface

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Location	Segment
Rio de Janeiro, Brazil	Subsea, Surface
São João da Barra, Brazil	Subsea
Veracruz, Mexico	Surface
Yopal, Columbia	Surface

The following table shows marine vessels in which we held an interest or operated as of December 31, 2021:

Vessel Name	Vessel Type	Special Equipment
Deep Blue	PLSV	Reeled pipelay/flexible pipelay/umbilical systems
Deep Energy	PLSV	Reeled pipelay/flexible pipelay/umbilical systems
Apache II	PLSV	Reeled pipelay/umbilical systems
Deep Orient	HCV	Construction/installation systems
North Sea Atlantic	HCV	Construction/installation systems
Skandi Africa	HCV	Construction/installation systems
Deep Arctic	DSV/HCV	Diver support systems
Deep Discoverer	DSV/HCV	Diver support systems
Deep Explorer	DSV/HCV	Diver support systems
Skandi Vitória	PLSV	Flexible pipelay/umbilical systems
Skandi Niterói	PLSV	Flexible pipelay/umbilical systems
Coral do Atlantico	PLSV	Flexible pipelay/umbilical systems
Deep Star	PLSV	Flexible pipelay/umbilical systems
Skandi Açu	PLSV	Flexible pipelay/umbilical systems
Skandi Búzios	PLSV	Flexible pipelay/umbilical systems
Skandi Olinda	PLSV	Flexible pipelay/umbilical systems
Skandi Recife	PLSV	Flexible pipelay/umbilical systems

PLSV: Pipelay Support Vessel

HCV: Heavy Duty Construction Vessel

DSV: Diving Support Vessel

ITEM 3. LEGAL PROCEEDINGS

We are involved in various pending or potential legal actions or disputes in the ordinary course of our business. These actions and disputes can involve our agents, suppliers, clients, and join venture partners and can include claims related to payment of fees, service quality, and ownership arrangements, including certain put or call options. Management is unable to predict the ultimate outcome of these actions because of their inherent uncertainty. However, management believes that the most probable, ultimate resolution of these matters will not have a material adverse effect on our consolidated financial position, results of operations, or cash flows.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

PART II

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Our ordinary shares are listed on the NYSE and trade under the symbol “FTI.”

For information about dividends, see Note 18 “Stockholders’ Equity” to the Consolidated Financial Statements in Item 8.

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As of February 18, 2022, according to data provided by our transfer agent, there were 105 shareholders of record. However, many of our shareholders hold their shares in "street name" by a nominee of Depository Trust Company, which is a single shareholder of record. We estimate that there were approximately 20,900 shareholders whose shares were held in “street name” by banks, brokers, or other financial institutions as of December 31, 2021.

We had no unregistered sales of equity securities during the year ended December 31, 2021.

Issuer Purchases of Equity Securities

We did not have any purchases of equity securities during the year ended December 31, 2021.

Performance Graph

The graph below compares the cumulative total shareholder return on our ordinary shares for the period from January 17, 2017 to December 31, 2021 with the Standard & Poor’s 500 Index (“S&P 500 Index”) and PHLX Oil Services Index. The comparison assumes $100 was invested, including reinvestment of dividends, if any, in our ordinary shares on January 17, 2017 and in both of the indexes on the same date. The results shown in the graph below are not necessarily indicative of future performance.

	As of December 31,
	2017		2018		2019		2020		2021
TechnipFMC plc	$	87.76	$	55.89	$	62.63	$	28.03	$	23.73
S&P 500 Index	119.82		114.56		150.62		178.32		229.46
PHLX Oil Services Index	82.00		44.93		44.68		25.88		31.25

ITEM 6. [RESERVED]

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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.

	Year Ended December 31,						Change
(In millions, except percentages)	2021		2020		2019		2021 vs. 2020				2020 vs. 2019
Revenue	$	6,403.5	$	6,530.6	$	6,950.2	$	(127.1)	(1.9)	%	$	(419.6)	(6.0)	%
Costs and expenses
Cost of sales	5,579.6		5,835.8		5,892.1		(256.2)		(4.4)	%	(56.3)		(1.0)	%
Selling, general and administrative expense	644.9		724.1		795.7		(79.2)		(10.9)	%	(71.6)		(9.0)	%
Research and development expense	78.4		75.3		149.5		3.1		4.1	%	(74.2)		(49.6)	%
Impairment, restructuring and other expense	66.7		3,402.0		2,456.7		(3,335.3)		(98.0)	%	945.3		38.5	%
Merger transaction and integration costs	—		—		14.2		—		—	%	(14.2)		(100.0)	%
Total costs and expenses	6,369.6		10,037.2		9,308.2		(3,667.6)		(36.5)	%	729.0		7.8	%
Other income (expense), net	46.6		25.1		(181.6)		21.5		85.7	%	206.7		113.8	%
Income from equity affiliates	0.6		64.6		59.8		(64.0)		(99.1)	%	4.8		8.0	%
Income from investment in Technip Energies	322.2		—		—		322.2		—	%	—		—	%
Loss on early extinguishment of debt	(61.9)		—		—		(61.9)		—	%	—		—	%
Net interest expense	(143.3)		(81.8)		(91.3)		(61.5)		(75.2)	%	9.5		10.4	%
Income (loss) before income taxes	198.1		(3,498.7)		(2,571.1)		3,696.8		105.7	%	(927.6)		(36.1)	%
Provision for income taxes	111.1		19.4		79.0		91.7		472.7	%	(59.6)		(75.4)	%
Income (loss) from continuing operations	87.0		(3,518.1)		(2,650.1)		3,605.1		102.5	%	(868.0)		(32.8)	%
(Income) loss from continuing operations attributable to non-controlling interests	0.8		(34.5)		4.6		35.3		102.3	%	(39.1)		(850.0)	%
Income (loss) from continuing operations attributable to TechnipFMC plc	87.8		(3,552.6)		(2,645.5)		3,640.4		102.5	%	(907.1)		(34.3)	%
Income (loss) from discontinued operations	(72.6)		280.2		238.0		(352.8)		(125.9)	%	42.2		17.7	%
Income from discontinued operations attributable to non-controlling interests	(1.9)		(15.2)		(7.7)		13.3		87.5	%	(7.5)		(97.4)	%
Net income (loss) attributable to TechnipFMC plc	$	13.3	$	(3,287.6)	$	(2,415.2)	$	3,300.9	100.4	%	$	(872.4)	(36.1)	%

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

	Year Ended December 31,									Favorable/(Unfavorable)
(In millions, except %)	2021			2020			2019			2021 vs. 2020				2020 vs. 2019
Revenue	$	5,329.1		$	5,471.4		$	5,419.5		$	(142.3)	(2.6)	%	$	51.9	1.0	%
Operating profit (loss)	$	141.4		$	(2,815.5)		$	(1,442.7)		$	2,956.9	105.0	%	$	(1,372.8)	(95.2)	%
Operating profit (loss) as a percentage of revenue	2.7		%	(51.5)		%	(26.6)		%			54.2	pts.			(24.9)	pts.

Subsea revenue decreased by $142.3 million, primarily due to a lower starting backlog as market conditions linked to COVID-19 pandemic negatively impacted order intake in the prior year. Despite these challenges, we continued to demonstrate strong execution of our backlog.

Subsea operating profit for the year ended December 31, 2021, improved versus the prior year, primarily due to the significant reduction in non-cash impairment charges as well as benefits from prior year cost reduction activities.

Refer to “Non-GAAP Measures” for more information regarding our segment operating results.

Surface Technologies

	Year Ended December 31,									Favorable/(Unfavorable)
(In millions, except %)	2021			2020			2019			2021 vs. 2020				2020 vs. 2019
Revenue	$	1,074.4		$	1,059.2		$	1,530.7		$	15.2	1.4	%	$	(471.5)	(30.8)	%
Operating profit (loss)	$	42.0		$	(429.3)		$	(662.7)		$	471.3	109.8	%	$	233.4	35.2	%
Operating profit (loss) as a percentage of revenue	3.9		%	(40.5)		%	(43.3)		%			44.4	pts.			2.8	pts.

Surface Technologies revenue increased by $15.2 million, or 1.4% year-over-year, primarily driven by the increase in Middle East, Latin America and North America. Revenue outside of North America represented 65% of total segment revenue in 2021.

Surface Technologies operating profit improved significantly versus the prior year, primarily due to the significant reduction in non-cash impairment charges as well as favorable product mix and benefits from prior year cost reduction initiatives.

Refer to “Non-GAAP Measures” for more information regarding our segment operating results.

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Corporate Items

	Year Ended December 31,						Favorable/(Unfavorable)
(In millions, except %)	2021		2020		2019		2021 vs. 2020				2020 vs. 2019
Corporate expense	$	(118.1)	$	(131.9)	$	(238.9)	$	13.8	10.5	%	$	107.0	44.8	%

Corporate expenses decreased by $13.8 million or 10.5% year-over-year, primarily due to decreased costs associated with our corporate support functions.

Refer to “Non-GAAP Measures” for more information regarding our segment operating results.

NON-GAAP MEASURES

In addition to financial results determined in accordance with U.S. generally accepted accounting principles (“GAAP”), we provide non-GAAP financial measures (as defined in Item 10 of Regulation S-K of the Securities Exchange Act of 1934, as amended) below:

•Income (loss) from continuing operations attributable to TechnipFMC plc, excluding charges and credits, as well as measures derived from it;

•Income (loss) before net interest expense and taxes, excluding charges and credits (“Adjusted operating profit”) and Adjusted operating profit margin;

•Adjusted diluted earnings (loss) per share from continuing operations attributable to TechnipFMC plc;

•Depreciation and amortization, excluding charges and credits (“Adjusted depreciation and amortization”);

•Earnings before net interest expense, income taxes, depreciation and amortization, excluding charges and credits (“Adjusted EBITDA”) and Adjusted EBITDA margin;

•Corporate expenses excluding charges and credits;

•Net (debt) cash; and

•Free cash flow (deficit) from continuing operations.

Management believes that the exclusion of charges and credits from these financial measures enables investors and management to more effectively evaluate our operations and consolidated results of operations period-over-period, and to identify operating trends that could otherwise be masked or misleading to both investors and management by the excluded items. These measures are also used by management as performance measures in determining certain incentive compensation. The foregoing non-GAAP financial measures should be considered in addition to, not as a substitute for or superior to, other measures of financial performance prepared in accordance with GAAP.

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The following is a reconciliation of the most comparable financial measures under GAAP to the non-GAAP financial measures.

	Year Ended
	December 31, 2021
	Income (loss) from continuing operations attributable to TechnipFMC plc		Loss attributable to non-controlling interests from continuing operations		Provision for income taxes		Net interest expense and loss on early extinguishment of debt		Income before net interest expense and income taxes (Operating profit)		Depreciation and amortization		Earnings before net interest expense, income taxes, depreciation and amortization (EBITDA)
TechnipFMC plc, as reported	$	87.8	$	(0.8)	$	111.1	$	205.2	$	403.3	$	385.4	$	788.7
Charges and (credits):
Impairment and other charges*	85.8		—		—		—		85.8		—		85.8
Restructuring and other charges**	27.3		—		0.8		—		28.1		—		28.1
Income from investment in Technip Energies	(322.2)		—		—		—		(322.2)		—		(322.2)
Adjusted financial measures	$	(121.3)	$	(0.8)	$	111.9	$	205.2	$	195.0	$	385.4	$	580.4
Diluted earnings per share from continuing operations attributable to TechnipFMC plc, as reported	$	0.19
Adjusted diluted loss per share from continuing operations attributable to TechnipFMC plc	$	(0.27)

*Includes $36.7 million impairment relating to our equity method investment.

** Includes inventory write off of approximately $10.5 million.

	Year Ended
	December 31, 2020
	Loss from continuing operations attributable to TechnipFMC plc		Income attributable to non-controlling interests from continuing operations		Provision for income taxes		Net interest expense		Loss before net interest expense and income taxes (Operating profit)		Depreciation and amortization		Earnings before net interest expense, income taxes, depreciation and amortization (EBITDA)
TechnipFMC plc, as reported	$	(3,552.6)	$	34.5	$	19.4	$	81.8	$	(3,416.9)	$	412.1	$	(3,004.8)
Charges and (credits):
Impairment and other charges	3,260.4		—		13.4		—		3,273.8		—		3,273.8
Restructuring and other charges	65.4		—		5.0		—		70.4		—		70.4
Direct Covid-19 expenses	51.6		—		6.2		—		57.8		—		57.8
Purchase price accounting adjustment	6.6		—		1.9		—		8.5		(8.5)		—
Adjusted financial measures	$	(168.6)	$	34.5	$	45.9	$	81.8	$	(6.4)	$	403.6	$	397.2
Diluted loss per share from continuing operations attributable to TechnipFMC plc, as reported	$	(7.92)
Adjusted diluted loss per share from continuing operations attributable to TechnipFMC plc	$	(0.38)

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	Year Ended
	December 31, 2021
	Subsea			Surface Technologies			Corporate Expense		Foreign Exchange, net		Total
Revenue	$	5,329.1		$	1,074.4		$	—	$	—	$	6,403.5
Operating profit (loss), as reported (pre-tax)	$	141.4		$	42.0		$	(118.1)	$	338.0	$	403.3
Charges and (credits):
Impairment and other charges*	80.9			1.9			3.0		—		85.8
Restructuring and other charges**	19.8			5.7			2.6		—		28.1
Income from investment in Technip Energies	—			—			—		(322.2)		(322.2)
Subtotal	100.7			7.6			5.6		(322.2)		(208.3)
Adjusted Operating profit (loss)	242.1			49.6			(112.5)		15.8		195.0
Depreciation and amortization	317.2			64.8			3.4		—		385.4
Adjusted EBITDA	$	559.3		$	114.4		$	(109.1)	$	15.8	$	580.4
Operating profit margin, as reported	2.7		%	3.9		%					6.3		%
Adjusted operating profit margin	4.5		%	4.6		%					3.0		%
Adjusted EBITDA margin	10.5		%	10.6		%					9.1		%

*Includes $36.7 million impairment relating to our equity method investment.

** Includes inventory write off of approximately $10.5 million.

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	Year Ended
	December 31, 2020
	Subsea			Surface Technologies			Corporate Expense		Foreign Exchange, net		Total
Revenue	$	5,471.4		$	1,059.2		$	—	$	—	$	6,530.6
Operating loss, as reported (pre-tax)	$	(2,815.5)		$	(429.3)		$	(131.9)	$	(40.2)	$	(3,416.9)
Charges and (credits):
Impairment and other charges	2,854.5			419.3			—		—		3,273.8
Restructuring and other charges	52.9			13.2			4.3		—		70.4
Direct COVID - 19 expenses	50.1			7.7			—		—		57.8
Purchase price accounting adjustments	8.5			—			—		—		8.5
Subtotal	2,966.0			440.2			4.3		—		3,410.5
Adjusted operating profit (loss)	150.5			10.9			(127.6)		(40.2)		(6.4)
Adjusted depreciation and amortization	316.4			70.1			17.1		—		403.6
Adjusted EBITDA	$	466.9		$	81.0		$	(110.5)	$	(40.2)	$	397.2
Operating profit margin, as reported	(51.5)		%	(40.5)		%					(52.3)		%
Adjusted operating profit margin	2.8		%	1.0		%					(0.1)		%
Adjusted EBITDA margin	8.5		%	7.6		%					6.1		%

INBOUND ORDERS AND ORDER BACKLOG

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

	Inbound Orders Year Ended December 31,
(In millions)	2021		2020
Subsea	$	4,960.9	$	4,003.0
Surface Technologies	1,793.3		1,061.2
Total inbound orders	$	6,754.2	$	5,064.2

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. The scheduling of some future work included in our order backlog has been impacted by COVID-19 related disruptions and remains subject to future adjustment. See Note 6 to our consolidated financial statements for further details.

	Order Backlog December 31,
(In millions)	2021		2020
Subsea	$	6,533.0	$	6,876.0
Surface Technologies	1,124.7		413.5
Total order backlog	$	7,657.7	$	7,289.5

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Subsea - Order backlog for Subsea as of December 31, 2021, decreased by $0.3 billion from December 31, 2020. Subsea backlog of $6.5 billion as of December 31, 2021, was composed of various subsea projects, including Total Mozambique LNG; Eni Coral; Petrobras Buzios, Mero I, Mero II and Marlim; ExxonMobil Payara; Petronas Limbayong; Reliance MJ-1; Equinor Breidablikk; Husky West White Rose; Santos Barossa Phase I and Tullow Jubilee South East.

Surface Technologies - Order backlog for Surface Technologies as of December 31, 2021, increased by $711.2 million compared to December 31, 2020, driven by a ten-year contract awarded in 2021 from ADNOC. Given the short-cycle nature of the business, most orders are quickly converted into sales revenue; longer contracts are typically converted within twelve months.

Non-consolidated backlog - As of December 31, 2021, we had $578.7 million of non-consolidated order backlog in our Subsea segment. Non-consolidated order backlog reflects the proportional share of backlog related to joint ventures that is not consolidated due to our minority ownership position.

LIQUIDITY AND CAPITAL RESOURCES

Most of our cash is managed centrally and flows through centralized bank accounts controlled and maintained by TechnipFMC globally and in many operating 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.

(In millions)	December 31, 2021		December 31, 2020
Cash and cash equivalents	$	1,327.4	$	1,269.2
Short-term debt and current portion of long-term debt	(277.6)		(624.7)
Long-term debt, less current portion	(1,727.3)		(2,835.5)
Net debt	$	(677.5)	$	(2,191.0)

Cash Flows

Cash flows for the years ended December 31, 2021, 2020 and 2019 were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Cash provided by operating activities from continuing operations	$	715.0	$	772.4	$	357.7
Cash provided (required) by investing activities from continuing operations	821.8		(120.8)		(378.5)
Cash required by financing activities from continuing operations	(1,447.3)		(651.9)		(165.6)
Net cash attributable to discontinued operations	(3,555.9)		(605.6)		(169.3)
Effect of exchange rate changes on cash and cash equivalents	(14.0)		223.5		5.9
Decrease in cash and cash equivalents	$	(3,480.4)	$	(382.4)	$	(349.8)
Working capital from continuing operations	$	497.5	$	717.7	$	91.0
Free cash flow (deficit) from continuing operations	$	523.3	$	516.3	$	(55.0)

Operating cash flows from continuing operations - During 2021 and 2020, we generated $715.0 million and $772.4 million, respectively, in operating cash flows from continuing operations. The decrease of $57.4 million in cash generated by operating activities from continuing operations in 2021 as compared to 2020 was primarily due to timing differences on project milestones and vendor payments.

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Investing cash flows from continuing operations - Investing activities from continuing operations provided $821.8 million in 2021 and used $120.8 million of cash in 2020. The increase of $942.6 million in cash provided by investing activities was primarily due to the proceeds received from the sale of our investment in Technip Energies, the sales of assets and decreased capital expenditures during 2021.

Financing cash flows from continuing operations - Financing activities from continuing operations used $1,447.3 million and $651.9 million in 2021 and 2020, respectively. The increase of $795.4 million in cash used for financing activities was due primarily to the increased debt pay down activity during 2021.

Working capital represents total changes in operating current assets and liabilities.

Free cash flow (deficit) 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).

	Year Ended December 31,
(In millions)	2021		2020		2019
Cash provided by operating activities from continuing operations	$	715.0	$	772.4	$	357.7
Capital expenditures	(191.7)		(256.1)		(412.7)
Free cash flow (deficit) from continuing operations	$	523.3	$	516.3	$	(55.0)

Debt and Liquidity

Debt Financing Transactions

During 2021, we executed a series of refinancing transactions in connection with the Spin-off, in order to provide a capital structure with sufficient cash resources to support future operating and investment plans.

Debt Issuance

•On February 16, 2021, we entered into a credit agreement, which provides for a $1.0 billion three-year senior secured multi-currency revolving credit facility (“Revolving Credit Facility”), including a $450.0 million letter of credit subfacility; and

•On January 29, 2021, we issued $1.0 billion of 6.50% senior notes due 2026 (the “2021 Notes”).

Repayment of Debt

The proceeds from the debt issuance described above along with the available cash on hand were used to fund:

•the repayment of all $542.4 million of the outstanding Synthetic Convertible Bonds that matured in January 2021;

•the repayment of all $500.0 million aggregate principal amount of outstanding 3.45% Senior Notes due 2022;

•the termination of the $2.5 billion senior unsecured revolving credit facility we entered into on January 17, 2017; the termination of the €500.0 million Euro Facility entered into on May 19, 2020; and the termination of the CCFF Program entered into on May 19, 2020. In connection with the termination of these credit facilities, we repaid $830.9 million of the outstanding commercial paper borrowings.

Availability of borrowings under the Revolving Credit Facility is reduced by the outstanding letters of credit issued against the facility. As of December 31, 2021, there were $16.7 million letters of credit outstanding and availability of borrowings under the Revolving Credit Facility was $983.3 million.

During 2021, we completed two tender offers and purchased for cash $366.9 million of the outstanding 2021 Notes. We paid a cash premium of $29.5 million to the note holders who tendered and wrote-off $8.9 million of bond issuance costs. In connection with the repayment of all $500.0 million aggregate principal amount of outstanding 3.45% Senior Notes due 2022, we recorded a loss on extinguishment of debt of $23.5 million. As of December 31,

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2021, we were in compliance with all debt covenants. See Note 17 to our consolidated financial statements for further details.

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 ratings with Moody’s are Ba1 for our long-term unsecured, guaranteed 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 24 and 25 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

For a description of our contractual obligations such as debt and leases, see Part II, Item 8 Notes to Consolidated Financial Statements Note 5 (Leases) and Note 17 (Debt).

Purchase obligations - In the normal course of business, we enter into agreements with our suppliers to purchase raw materials or services. These agreements include a requirements that our suppliers provide products or services to our specifications and requires us to make a firm purchase commitment to suppliers. As 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. The future purchase obligations as of December 31, 2021 are as follows:

	Payments Due by Period
(In millions)	Total payments		Less than 1 year		1-3 years		3-5 years		After 5 years
Purchase obligations	$	636.4	$	564.9	$	71.2	$	0.3	$	—

Financial Position Outlook

We are committed to a strong balance sheet and ample liquidity that will enable us to access capital markets throughout the cycle. We believe our liquidity continues to exceed the level required to achieve this goal. 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 2022 are estimated to be approximately $230.0 million. Projected capital expenditures do not include any contingent capital that may be needed to respond to contract awards.

In addition, we intend to conduct an orderly sale of our remaining stake in Technip Energies over time and will use the proceeds from future sales to further reduce our net leverage. We do not intend to remain a long-term shareholder of Technip Energies and anticipate that we will exit our ownership stake in an orderly manner within a year. The carrying amount of the investment as of December 31, 2021 was $317.3 million. In January 2022, we sold

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an additional 9.0 million Technip Energies shares and received €118.4 million, or $135.1 million in net proceeds. As of February 25, 2022, the value of our investment in Technip Energies was $155.3 million.

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, primarily 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, including estimated fees or profits, 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.

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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 operating income for the year ended December 31, 2021 was negatively impacted by approximately $68.4 million, as a result of changes in contract estimates related to projects that were in progress as of December 31, 2020. During the year ended December 31, 2021, we recognized changes in our estimates that had an impact on our margin in the amounts of $(72.5) million and $4.1 million in our Subsea and Surface Technologies segments, respectively. The changes in contract estimates are attributed to worse than expected 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, 2021, 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

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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 primarily 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:

(In millions, except basis points)	Increase (Decrease) in 2021 Pension Expense Before Income Taxes		Increase (Decrease) in Projected Benefit Obligation as of December 31, 2021
25 basis point decrease in discount rate	$	0.9	$	(2.2)
25 basis point increase in discount rate	$	(0.9)	$	2.1
25 basis point decrease in expected long-term rate of return on plan assets	$	2.8	N/A
25 basis point increase in expected long-term rate of return on plan assets	$	(2.8)	N/A

Determination of Fair Value in Business Combinations

Accounting for the acquisition of a business requires the allocation of the purchase price to the various assets acquired and liabilities assumed at their respective fair values. The determination of fair value requires the use of significant estimates and assumptions, and in making these determinations, management uses all available information. If necessary, we have up to one year after the acquisition closing date to finalize these fair value determinations. For tangible and identifiable intangible assets acquired in a business combination, the determination of fair value utilizes several valuation methodologies including discounted cash flows which has assumptions with respect to the timing and amount of future revenue and expenses associated with an asset. The assumptions made in performing these valuations include, but are not limited to, discount rates, future revenues and operating costs, projections of capital costs, and other assumptions believed to be consistent with those used by principal market participants. Due to the specialized nature of these calculations, we engage third-party specialists to assist management in evaluating our assumptions as well as appropriately measuring the fair value of assets acquired and liabilities assumed. See Note 3 to our consolidated financial statements for further details.

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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.

Impairment of Goodwill

Goodwill represents the excess of cost over the fair market value of net assets acquired in business combinations. Goodwill is not subject to amortization but is tested for impairment at a reporting unit level on an annual basis, or more frequently if impairment indicators arise. We have established October 31 as the date of our annual test for impairment of goodwill. We identify a potential impairment by comparing the fair value of the applicable reporting unit to its net book value, including goodwill. If the net book value exceeds the fair value of the reporting unit, we measure the impairment by comparing the carrying value of the reporting unit to its fair value. Reporting units with goodwill are tested for impairment using a quantitative impairment test.

When using the quantitative impairment test, determining the fair value of a reporting unit is judgmental in nature and involves the use of significant estimates and assumptions. We estimate the fair value of our reporting units using a discounted future cash flow model. The majority of the estimates and assumptions used in a discounted future cash flow model involve unobservable inputs reflecting management’s own assumptions about the assumptions market participants would use in estimating the fair value of a business. These estimates and assumptions include revenue growth rates and operating margins used to calculate projected future cash flows, discount rates and future economic and market conditions. Our estimates are based upon assumptions believed to be reasonable, but they are inherently uncertain and unpredictable and do not reflect unanticipated events and circumstances that may occur.

The income approach estimates fair value by discounting each reporting unit’s estimated future cash flows using a weighted-average cost of capital that reflects current market conditions and the risk profile of the reporting unit. To arrive at our future cash flows, we use estimates of economic and market assumptions, including growth rates in revenues, costs, estimates of future expected changes in operating margins, tax rates and cash expenditures. Future revenues are also adjusted to match changes in our business strategy. We believe this approach is an appropriate valuation method. Under the market multiple approach, we determine the estimated fair value of each of our reporting units by applying transaction multiples to each reporting unit’s projected EBITDA and then averaging that estimate with similar historical calculations using either a one, two or three year average. Our reporting unit valuations were determined primarily by utilizing the income approach, with a lesser weighting attributed the market multiple approach.

As of December 31, 2021, we did not have any goodwill balance outstanding.

See Notes 16 and 20 to our consolidated financial statements for further details.

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

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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 we have also raised with DOJ certain other projects performed by Technip S.A. subsidiaries in Brazil between 2002 and 2013. The DOJ has 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”)) about these existing matters.

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 will not be required to have a monitor and will, instead, provide 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 will also provide the DOJ reports on our anti-corruption program during the term of the DPA.

In Brazil, 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 have committed, as part of those agreements, to make certain enhancements to their compliance programs in Brazil during a two-year self-reporting period, which aligns 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.

To date, the investigation by 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 recently informed us that it is reviewing historical projects in Angola. We are not aware of any evidence that would support a finding of liability with respect to these projects, whether the PNF would seek 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 4 to our consolidated financial statements for further details.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are subject to financial market risks, including fluctuations in foreign currency exchange rates and interest rates. In order to manage and mitigate our exposure to these risks, we may use derivative financial instruments in accordance with established policies and procedures. We do not use derivative financial instruments for speculative purposes. As of December 31, 2021 and 2020, substantially all of our derivative holdings consisted of foreign currency forward contracts and foreign currency instruments embedded in purchase and sale contracts.

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These forward-looking disclosures only address potential impacts from market risks as they affect our financial instruments and do not include other potential effects that could impact our business as a result of changes in foreign currency exchange rates, interest rates, commodity prices or equity prices.

Foreign Currency Exchange Rate Risk

We conduct operations around the world in a number of different currencies. Many of our significant foreign subsidiaries have designated the local currency as their functional currency. Our earnings are therefore subject to change due to fluctuations in foreign currency exchange rates when the earnings in foreign currencies are translated into U.S. dollars. We do not hedge this translation impact on earnings. A 10% increase or decrease in the average exchange rates of all foreign currencies as of December 31, 2021, would have changed our revenue and income before income taxes attributable to TechnipFMC by approximately $303.5 million and $16.8 million, respectively.

When transactions are denominated in currencies other than our subsidiaries’ respective functional currencies, we manage these exposures through the use of derivative instruments. We primarily use foreign currency forward contracts to hedge the foreign currency fluctuation associated with firmly committed and forecasted foreign currency denominated payments and receipts. The derivative instruments associated with these anticipated transactions are usually designated and qualify as cash flow hedges, and as such the gains and losses associated with these instruments are recorded in other comprehensive income until such time that the underlying transactions are recognized. Unless these cash flow contracts are deemed to be ineffective or are not designated as cash flow hedges at inception, changes in the derivative fair value will not have an immediate impact on our results of operations since the gains and losses associated with these instruments are recorded in other comprehensive income. When the anticipated transactions occur, these changes in value of derivative instrument positions will be offset against changes in the value of the underlying transaction. When an anticipated transaction in a currency other than the functional currency of an entity is recognized as an asset or liability on the balance sheet, we also hedge the foreign currency fluctuation of these assets and liabilities with derivative instruments after netting our exposures worldwide. These derivative instruments do not qualify as cash flow hedges.

Occasionally, we enter into contracts or other arrangements containing terms and conditions that qualify as embedded derivative instruments and are subject to fluctuations in foreign exchange rates. In those situations, we enter into derivative foreign exchange contracts that hedge the price or cost fluctuations due to movements in the foreign exchange rates. These derivative instruments are not designated as cash flow hedges.

For our foreign currency forward contracts hedging anticipated transactions that are accounted for as cash flow hedges, a 10% increase in the value of the U.S. dollar would have resulted in an additional loss of $55.4 million in the net fair value of cash flow hedges reflected in our consolidated balance sheet as of December 31, 2021.

Interest Rate Risk

We assess effectiveness of forward foreign currency contracts designated as cash flow hedges based on changes in fair value attributable to changes in spot rates. We exclude the impact attributable to changes in the difference between the spot rate and the forward rate for the assessment of hedge effectiveness and recognize the change in fair value of this component immediately in earnings. Considering that the difference between the spot rate and the forward rate is proportional to the differences in the interest rates of the countries of the currencies being traded, we do not have significant exposure in the unrealized valuation of our forward foreign currency contracts to relative changes in interest rates between countries in our results of operations. To the extent any one interest rate increases by 10% across all tenors and other countries’ interest rates remain fixed, and assuming no change in discount rates, we would expect to recognize a decrease of $3.0 million in unrealized earnings in the period of change. Based on our portfolio as of December 31, 2021, we have material positions with exposure to interest rates in the United States, Brazil, the United Kingdom, Singapore, the European Community, and Norway.

59

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Stockholders of TechnipFMC plc

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the accompanying consolidated balance sheets of TechnipFMC plc and its subsidiaries (the “Company”) as of December 31, 2021 and 2020, and the related consolidated statements of income, of comprehensive income, of changes in stockholders’ equity and of cash flows for each of the three years in the period ended December 31, 2021, including the related notes and schedule of valuation and qualifying accounts for each of the three years in the period ended December 31, 2021 appearing under Item 15 (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Change in Accounting Principle

As discussed in Note 1 to the consolidated financial statements, the Company changed the manner in which it accounts for leases in 2019.

Basis for Opinions

The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Annual Report on Internal Control over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable

60

assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Critical Audit Matters

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

Revenue Recognition - Determination of Estimated Costs to Complete for Long-Term Contracts

As described in Note 6 to the consolidated financial statements, approximately 68% of the total revenue of $6.4 billion for the year ended December 31, 2021 is generated from long-term contracts. For the Company’s long-term contracts, because of control transferring over time, revenue is recognized based on the extent of progress towards completion of the performance obligation. As disclosed by management, 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. The Company generally uses the cost-to-cost measure of progress for its contracts because it best depicts the transfer of control to the customer that occurs as the Company incurs costs on the 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, including estimated fees or profits, are recorded proportionally as costs are incurred. Due to the nature of the work required to be performed on many of the performance obligations, management’s estimation of total revenue and cost at completion is complex, subject to many variables and requires significant judgment. There are many factors, including, but not limited to, the ability to properly execute the engineering and design phases consistent with customers’ expectations, the availability and costs of labor and materials resources, productivity, and weather, all of which can affect the accuracy of cost estimates, and ultimately, future profitability.

The principal considerations for our determination that performing procedures relating to revenue recognition - determination of estimated costs to complete for long-term contracts is a critical audit matter are the significant judgment by management when determining the estimated costs to complete for long-term contracts, which in turn led to a high degree of auditor judgment, subjectivity and effort in performing procedures and evaluating management’s significant assumptions related to the estimated costs to complete.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the revenue recognition process, including controls over the determination of estimated costs to complete for long-term contracts. These procedures also included, among others, testing management’s process for determining the estimated costs to complete for a selection of long-term contracts by (i) obtaining executed purchase orders and agreements; (ii) evaluating the appropriateness of the method to measure progress towards completion; (iii) testing the completeness and accuracy of the underlying data used by management; and (iv) evaluating the reasonableness of significant assumptions related to the estimated costs to complete. Evaluating the reasonableness of significant assumptions involved assessing management’s ability to reasonably estimate costs to complete long-term contracts, as applicable, by (i) performing procedures to assess the reasonableness of estimated costs to complete; (ii) testing management’s process to evaluate the timely identification of circumstances which may warrant a modification to a previous cost estimate; (iii) testing management’s process to evaluate contract contingencies relative to the contractual terms and actual progress of contracts; and (iv) performing procedures to assess the reasonableness of changes in life of project margin.

61

/s/ PricewaterhouseCoopers LLP

Houston, Texas

February 28, 2022

We have served as the Company’s auditor since 2017.

62

TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

	Year Ended
(In millions, except per share data)	2021		2020		2019
Revenue
Service revenue	$	3,440.7	$	3,266.8	$	3,412.0
Product revenue	2,804.4		3,121.8		3,271.7
Lease revenue	158.4		142.0		266.5
Total revenue	6,403.5		6,530.6		6,950.2
Costs and expenses
Cost of service revenue	3,084.7		2,946.9		2,769.5
Cost of product revenue	2,366.5		2,772.2		2,954.7
Cost of lease revenue	128.4		116.7		167.9
Selling, general and administrative expense	644.9		724.1		795.7
Research and development expense	78.4		75.3		149.5
Impairment, restructuring and other expense (Note 20)	66.7		3,402.0		2,456.7
Merger transaction and integration costs	—		—		14.2
Total costs and expenses	6,369.6		10,037.2		9,308.2
Other income (expense), net	46.6		25.1		(181.6)
Income from equity affiliates (Note 13)	0.6		64.6		59.8
Income from Investment in Technip Energies	322.2		—		—
Income (loss) before net interest expense and income taxes	403.3		(3,416.9)		(2,479.8)
Interest income	14.0		52.3		43.6
Interest expense	(157.3)		(134.1)		(134.9)
Loss on early extinguishment of debt	(61.9)		—		—
Income (loss) before income taxes	198.1		(3,498.7)		(2,571.1)
Provision for income taxes (Note 22)	111.1		19.4		79.0
Income (loss) from continuing operations	87.0		(3,518.1)		(2,650.1)
(Income) loss from continuing operations attributable to non-controlling interests	0.8		(34.5)		4.6
Income (loss) from continuing operations attributable to TechnipFMC plc	87.8		(3,552.6)		(2,645.5)
Income (loss) from discontinued operations	(72.6)		280.2		238.0
Income from discontinued operations attributable to non-controlling interests	(1.9)		(15.2)		(7.7)
Net income (loss) attributable to TechnipFMC plc	$	13.3	$	(3,287.6)	$	(2,415.2)
Earnings (loss) per share from continuing operations attributable to TechnipFMC plc
Basic	$	0.19	$	(7.92)	$	(5.91)
Diluted	$	0.19	$	(7.92)	$	(5.91)
Earnings (loss) per share from discontinued operations attributable to TechnipFMC
Basic	$	(0.17)	$	0.59	$	0.51
Diluted	$	(0.16)	$	0.59	$	0.51
Total earnings (loss) per share attributable to TechnipFMC plc
Basic	$	0.03	$	(7.33)	$	(5.39)
Diluted	$	0.03	$	(7.33)	$	(5.39)
Weighted average shares outstanding (Note 8)
Basic	450.5		448.7		448.0
Diluted	454.6		448.7		448.0

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

63

TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Year Ended
(In millions)	2021		2020		2019
Net income (loss) attributable to TechnipFMC plc	$	13.3	$	(3,287.6)	$	(2,415.2)
(Income) loss from continuing operations attributable to non-controlling interests	0.8		(34.5)		4.6
Income from discontinued operations attributable to non-controlling interests	(1.9)		(15.2)		(7.7)
Net income (loss) attributable to TechnipFMC plc, including non-controlling interests	14.4		(3,237.9)		(2,412.1)
Foreign currency translation adjustments
Net gains (losses) arising during the period	27.6		(169.1)		15.6
Reclassification adjustment for net gains included in net loss	—		—		(12.0)
Foreign currency translation adjustments(a)	27.6		(169.1)		3.6
Net gains (losses) on hedging instruments
Net gains (losses) arising during the period	(19.8)		25.4		8.9
Reclassification adjustment for net (gains) losses included in net income	(11.8)		13.0		18.2
Net gains (losses) on hedging instruments (b)	(31.6)		38.4		27.1
Pension and other post-retirement benefits
Net gains (losses) arising during the period	71.2		(88.3)		(81.5)
Prior service cost arising during the period	(0.4)		(4.6)		(0.7)
Reclassification adjustment for settlement losses included in net income	2.7		1.4		0.2
Reclassification adjustment for amortization of prior service cost included in net income	0.4		0.9		2.0
Reclassification adjustment for amortization of net actuarial loss included in net income	14.9		6.9		0.8
Net pension and other post-retirement benefits (c)	88.8		(83.7)		(79.2)
Other comprehensive income (loss), net of tax	84.8		(214.4)		(48.5)
Comprehensive income (loss)	99.2		(3,452.3)		(2,460.6)
Comprehensive income attributable to non-controlling interests	0.5		(50.3)		(2.4)
Comprehensive income (loss) attributable to TechnipFMC plc	$	99.7	$	(3,502.6)	$	(2,463.0)

(a)Net of income tax (expense) benefit of nil, nil and $7.9 million for the years ended December 31, 2021, 2020 and 2019, respectively.

(b)Net of income tax (expense) benefit of $8.8 million, $(9.7) million and $(6.9) million for the years ended December 31, 2021, 2020 and 2019, respectively.

(c)Net of income tax (expense) benefit of $(19.6) million, $25.5 million and $20.3 million for the years ended December 31, 2021, 2020 and 2019, respectively.

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

64

TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES CONSOLIDATED BALANCE SHEETS
(In millions, except par value data)	December 31,
Assets	2021		2020
Cash and cash equivalents	$	1,327.4	$	1,269.2
Trade receivables, net of allowances of $38.1 in 2021 and $40.2 in 2020	911.9		987.7
Contract assets, net of allowances of $1.1 in 2021 and $2.4 in 2020	966.0		886.8
Inventories, net (Note 10)	1,031.9		1,252.8
Derivative financial instruments (Note 24)	110.3		268.7
Income taxes receivable	85.0		274.7
Advances paid to suppliers	79.4		96.3
Other current assets (Note 11)	512.3		683.4
Investment in Technip Energies	317.3		—
Current assets of discontinued operations	—		5,725.1
Total current assets	5,341.5		11,444.7
Investments in equity affiliates (Note 13)	292.4		305.5
Property, plant and equipment, net (Note 15)	2,597.2		2,756.2
Operating lease right-of-use assets (Note 5)	707.9		784.9
Finance lease right-of-use assets (Note 5)	52.2		27.5
Intangible assets, net (Note 16)	813.7		851.3
Deferred income taxes (Note 22)	74.3		34.2
Derivative financial instruments (Note 24)	10.5		29.2
Other assets	130.4		175.6
Non-current assets of discontinued operations	—		3,283.5
Total assets	$	10,020.1	$	19,692.6
Liabilities and equity
Short-term debt and current portion of long-term debt (Note 17)	$	277.6	$	624.7
Operating lease liabilities (Note 5)	126.2		195.5
Finance lease liabilities (Note 5)	0.7		26.9
Accounts payable, trade	1,294.3		1,201.0
Contract liabilities	1,012.9		1,046.8
Accrued payroll	194.1		186.8
Derivative financial instruments (Note 24)	161.0		157.5
Income taxes payable	124.6		61.2
Other current liabilities (Note 11)	660.4		818.3
Current liabilities of discontinued operations	—		6,096.5
Total current liabilities	3,851.8		10,415.2
Long-term debt, less current portion (Note 17)	1,727.3		2,835.5
Operating lease liabilities, less current portion (Note 5)	646.8		632.8
Finance lease liabilities (Note 5)	51.1		—
Deferred income taxes (Note 22)	47.5		79.3
Accrued pension and other post-retirement benefits, less current portion (Note 23)	113.4		268.4
Derivative financial instruments (Note 24)	15.5		18.8
Other liabilities	148.3		103.3
Non-current liabilities of discontinued operations	—		1,081.3
Total liabilities	6,601.7		15,434.6
Commitments and contingent liabilities (Note 21)
Mezzanine equity
Redeemable non-controlling interest	—		43.7
Stockholders’ equity (Note 18)
Ordinary shares, $1 par value; 618.3 shares authorized in 2021 and 2020; 450.7 shares and 449.5 shares issued and outstanding in 2021 and 2020, respectively; nil shares canceled in 2021 and 2020, respectively	450.7		449.5
Capital in excess of par value of ordinary shares	9,160.8		10,242.4
Accumulated deficit	(4,903.8)		(4,915.2)
Accumulated other comprehensive loss	(1,305.0)		(1,622.5)
Total TechnipFMC plc stockholders’ equity	3,402.7		4,154.2
Non-controlling interests	15.7		40.4
Non-controlling interests of discontinued operations	—		19.7
Total equity	3,418.4		4,214.3
Total liabilities and equity	$	10,020.1	$	19,692.6

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

65

TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Year Ended December 31,
(In millions)	2021		2020		2019
Cash provided (required) by operating activities
Net income (loss)	$	14.4	$	(3,237.9)	$	(2,412.1)
Net (income) loss from discontinued operations	72.6		(280.2)		(238.0)
Adjustments to reconcile net loss to cash provided (required) by operating activities
Depreciation	291.3		308.7		363.0
Amortization	94.1		103.4		104.7
Impairments (Note 20)	49.1		3,273.8		2,480.3
Employee benefit plan and share-based compensation costs	34.3		36.4		48.6
Deferred income tax provision (benefit), net	(95.1)		(31.8)		27.9
Income from investment in Technip Energies	(322.2)		—		—
Unrealized loss (gain) on derivative instruments and foreign exchange	30.8		(13.3)		22.4
Loss from equity affiliates, net of dividends received	(0.6)		(58.2)		(58.9)
Loss on early extinguishment of debt	61.9		—		—
Other	(5.5)		(32.7)		(97.1)
Changes in operating assets and liabilities, net of effects of acquisitions
Trade receivables, net and contract assets	(73.1)		433.4		(142.5)
Inventories, net	197.7		87.4		(173.3)
Accounts payable, trade	93.8		(236.4)		(56.1)
Contract liabilities	0.9		(61.8)		352.0
Income taxes payable (receivable), net	214.7		(56.1)		(31.1)
Other current assets and liabilities, net	63.5		551.2		142.0
Other non-current assets and liabilities, net	(7.6)		(13.5)		25.9
Cash provided by operating activities from continuing operations	715.0		772.4		357.7
Cash provided (required) by operating activities from discontinued operations	66.3		(115.5)		490.8
Cash provided by operating activities	781.3		656.9		848.5
Cash provided (required) by investing activities
Capital expenditures	(191.7)		(256.1)		(412.7)
Payment to acquire debt securities	(29.1)		(3.9)		(71.6)
Proceeds from sale of debt securities	27.4		51.5		18.9
Acquisitions, net of cash acquired	(15.3)		—		16.0
Proceeds from sale of assets	104.6		45.5		7.4
Proceeds from sales of investment in Technip Energies	900.9		—		—
Proceeds from repayment of advance to joint venture	25.0		26.7		62.0
Other	—		15.5		1.5
Cash provided (required) by investing activities from continuing operations	821.8		(120.8)		(378.5)
Cash required by investing activities from discontinued operations	(4.5)		(59.8)		(41.3)
Cash provided (required) by investing activities	817.3		(180.6)		(419.8)
Cash required by financing activities
Net decrease in short-term debt	(62.0)		(31.9)		(49.6)
Net increase (decrease) in commercial paper	(974.3)		(340.9)		113.3
Proceeds from issuance of long-term debt	1,164.4		223.2		96.2
Repayments of long-term debt	(1,462.2)		(423.9)		—
Payments for debt issuance cost	(60.4)		—		—
Purchase of ordinary shares	—		—		(92.7)
Dividends paid	—		(59.2)		(232.8)
Acquisition of non-controlling interest	(48.6)		—		—
Other	(4.2)		(19.2)		—
Cash required by financing activities from continuing operations	(1,447.3)		(651.9)		(165.6)
Cash required by financing activities from discontinued operations	(3,617.7)		(430.3)		(618.8)
Cash required by financing activities	(5,065.0)		(1,082.2)		(784.4)
Effect of changes in foreign exchange rates on cash and cash equivalents	(14.0)		223.5		5.9
Decrease in cash and cash equivalents	(3,480.4)		(382.4)		(349.8)
Cash and cash equivalents in the statement of cash flows, beginning of year	4,807.8		5,190.2		5,540.0
Cash and cash equivalents in the statement of cash flows, end of year	$	1,327.4	$	4,807.8	$	5,190.2

66

	Year Ended December 31,
(In millions)	2021		2020		2019
Supplemental disclosures of cash flow information attributable to continuing operations
Cash paid for interest (net of interest capitalized)	$	104.1	$	96.0	$	91.5
Cash paid for income taxes (net of refunds received)	$	25.1	$	107.8	$	104.2

The following table provides a reconciliation of cash, cash equivalents reported in the consolidated balance sheets to the total of the amounts in the consolidated statements of cash flows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Cash and cash equivalents	$	1,327.4	$	1,269.2	$	1,563.1
Cash and cash equivalents attributable to discontinued operations	—		3,538.6		3,627.1
Total cash and cash equivalents in the statement of cash flows	$	1,327.4	$	4,807.8	$	5,190.2

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

67

TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

(In millions)	Ordinary Shares		Ordinary Shares Held in Treasury and Employee Benefit Trust		Capital in Excess of Par Value of Ordinary Shares		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Non- controlling Interest		Total Stockholders’ Equity
Balance as of December 31, 2018	$	450.5	$	(2.4)	$	10,197.0	$	1,072.2	$	(1,359.7)	$	31.3	$	10,388.9
Adoption of accounting standards	—		—		—		1.8		—		—		1.8
Net income (loss)	—		—		—		(2,415.2)		—		3.1		(2,412.1)
Other comprehensive loss	—		—		—		—		(47.8)		(0.7)		(48.5)
Cancellation of treasury shares (Note 18)	(4.0)		—		(88.7)		—		—		—		(92.7)
Issuance of ordinary shares	0.6		—		—		—		—		—		0.6
Net sales of ordinary shares for employee benefit trust	—		2.4		—		—		—		—		2.4
Cash dividends declared ($0.52 per share) (Note 18)	—		—		—		(232.8)		—		—		(232.8)
Share-based compensation (Note 19)	—		—		74.5		—		—		—		74.5
Other	—		—		—		10.9		—		(4.9)		6.0
Balance as of December 31, 2019	$	447.1	$	—	$	10,182.8	$	(1,563.1)	$	(1,407.5)	$	28.8	$	7,688.1
Adoption of accounting standards	—		—		—		(7.8)		—		—		(7.8)
Net income (loss)	—		—		—		(3,287.6)		—		49.7		(3,237.9)
Other comprehensive loss	—		—		—		—		(215.0)		0.6		(214.4)
Issuance of ordinary shares	2.4		—		(9.4)		—		—		—		(7.0)
Cash dividends declared ($0.13 per share) (Note 18)	—		—		—		(59.2)		—		—		(59.2)
Share-based compensation (Note 19)	—		—		69.0		—		—		—		69.0
Distributions to non-controlling interest	—		—		—		(9.4)		—		(2.1)		(11.5)
Other	—		—		—		11.9		—		(16.9)		(5.0)
Balance as of December 31, 2020	$	449.5	$	—	$	10,242.4	$	(4,915.2)	$	(1,622.5)	$	60.1	$	4,214.3
Net income	—		—		—		13.3		—		1.1		14.4
Other comprehensive income	—		—		—		—		86.4		(1.6)		84.8
Issuance of ordinary shares	1.2		—		—		—		—		—		1.2
Share-based compensation (Note 19)	—		—		26.8		—		—		—		26.8
Spin-off of Technip Energies (Note 2)	—		—		(1,108.4)		—		231.1		(19.9)		(897.2)
Accrued distributions to non-controlling interest	—		—		—		—		—		(15.0)		(15.0)
Other	—		—		—		(1.9)		—		(9.0)		(10.9)
Balance as of December 31, 2021	$	450.7	$	—	$	9,160.8	$	(4,903.8)	$	(1,305.0)	$	15.7	$	3,418.4

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

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TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1. BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of operations - TechnipFMC plc and consolidated subsidiaries (“TechnipFMC,” “we,” “us” or “our”) is a global leader in oil and gas projects, technologies, systems and services through our business segments: Subsea and Surface Technologies. We have manufacturing operations worldwide, strategically located to facilitate delivery of our products, systems and services to our customers.

Basis of presentation - Our consolidated financial statements were prepared in U.S. dollars and in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and rules and regulations of the Securities and Exchange Commission (“SEC”) pertaining to annual financial information. The preparation of financial statements in conformity with these accounting principles requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Ultimate results could differ from our estimates.

Principles of consolidation - The consolidated financial statements include the accounts of TechnipFMC and its majority-owned subsidiaries and affiliates. Intercompany accounts and transactions are eliminated in consolidation.

Use of estimates - The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. Such estimates include, but are not limited to, estimates of total contract profit or loss on long-term construction-type contracts; estimated realizable value on excess and obsolete inventory; estimates related to pension accounting; estimates related to fair value for purposes of assessing goodwill, long-lived assets and intangible assets for impairment; estimates of fair value in business combinations and estimates related to income taxes.

Investments in the common stock of unconsolidated affiliates - The equity method of accounting is used to account for investments in unconsolidated affiliates where we have the ability to exert significant influence over the affiliates’ operating and financial policies. We measure equity investments not accounted for under the equity method at fair value and recognize any changes in fair value in net income. For certain construction joint ventures, we use the proportionate consolidation method, whereby our proportionate share of each entity’s assets, liabilities, revenues and expenses are included in the appropriate classifications in the consolidated financial statements. Intercompany balances and transactions have been eliminated in preparing the consolidated financial statements.

Investments in unconsolidated affiliates are assessed for impairment whenever events or changes in facts and circumstances indicate the carrying value of the investments may not be fully recoverable. When such a condition is subjectively determined to be other than temporary, the carrying value of the investment is written down to fair value. Management’s assessment as to whether any decline in value is other than temporary is based on our ability and intent to hold the investment and whether evidence indicating the carrying value of the investment is recoverable within a reasonable period of time outweighs evidence to the contrary. Management generally considers our investments in equity method investees to be strategic, long-term investments and completes its assessments for impairment with a long-term viewpoint.

Investments in which ownership is less than 20% or that do not represent significant investments are reported in other assets in the consolidated balance sheets. Where no active market exists and where no other valuation method can be used, these financial assets are maintained at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer.

We determine whether investments involve a variable interest entity (“VIE”) based on the characteristics of the subject entity. If the entity is determined to be a VIE, then management determines if we are the primary beneficiary of the entity and whether or not consolidation of the VIE is required. The primary beneficiary consolidating the VIE must normally have both (i) the power to direct the activities that most significantly affect the VIE’s economic performance and (ii) the obligation to absorb significant losses of or the right to receive significant benefits from the VIE. If we are deemed to be the primary beneficiary, the VIE is consolidated and the other party’s equity interest in the VIE is accounted for as a non-controlling interest. Our unconsolidated VIEs are accounted for using the equity method of accounting.

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Business combinations - Business combinations are accounted for using the acquisition method of accounting. Under the acquisition method, assets acquired and liabilities assumed are recorded at their respective fair values as of the acquisition date. Determining the fair value of assets and liabilities involves significant judgment regarding methods and assumptions used to calculate estimated fair values. The purchase price is allocated to the acquired assets, assumed liabilities and identifiable intangible assets based on their estimated fair values. Any excess of the purchase price over the estimated fair values of the net assets acquired is recorded as goodwill. Transaction related costs are expensed as incurred. 

Leases - The majority of our leases are operating leases. We account for leases in accordance with Accounting Standard Codification (“ASC”)Topic 842, Leases, which we adopted on January 1, 2019 using the modified retrospective method. See Note 5 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 ASC Topic 606, Revenue from Contracts with Customers. See Note 6 for further details.

Contract costs to obtain a contract - Our incremental direct costs of obtaining a contract are deferred and amortized over the period of contract performance or a longer period, generally the estimated life of the customer relationship, if renewals are expected and the renewal commission is not commensurate with the initial commission. We classify deferred commissions as current or non-current based on the timing of when we expect to recognize the expense. The current and non-current portions of deferred commissions are included in other current assets and other assets, respectively, in our consolidated balance sheets.

Amortization of deferred commissions is included in selling, general and administrative expenses in our consolidated statements of income.

Cash equivalents - Cash equivalents are highly-liquid, short-term investments with original maturities of three months or less from their date of purchase.

Trade receivables, net of allowances - An allowance for doubtful accounts is provided on receivables equal to the estimated uncollectible amounts and is calculated based on loss rates from historical data. We develop loss-rate statistics on the basis of the amount written off over the life of the receivable and adjust these historical credit loss trends for forward-looking factors specific to the debtors and the economic environment to determine lifetime expected losses.

Inventories - Inventories are stated at the lower of cost or net realizable value, except as it relates to inventory measured using the last-in, first-out (“LIFO”) method, for which the inventories are stated at the lower of cost or market. Inventory costs include those costs directly attributable to products, including all manufacturing overhead, but excluding costs to distribute. Cost for a significant portion of the U.S. domiciled inventories is determined on the LIFO method. The first-in, first-out (“FIFO”) or weighted average methods are used to determine the cost for the remaining inventories. Write-down of inventories is recorded when the net realizable value of inventories is lower than their net book value.

Property, plant and equipment - Property, plant, and equipment is recorded at cost. Depreciation is principally provided on the straight-line basis over the estimated useful lives of the assets (vessels - 10 to 30 years; buildings - 10 to 50 years; and machinery and equipment - 3 to 20 years). Gains and losses are realized upon the sale or retirement of assets and are recorded in other income (expense), net on our consolidated statements of income. Maintenance and repair costs are expensed as incurred. Expenditures that extend the useful lives of property, plant and equipment are capitalized and depreciated over the estimated new remaining life of the asset.

Impairment of property, plant and equipment - Property, plant and equipment are reviewed for impairment whenever events or changes in circumstances indicate the carrying value of the long-lived asset may not be recoverable. The carrying value of an asset group 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 impairment loss is measured as the amount by which the carrying value of the long-lived asset exceeds its fair value.

Long-lived assets classified as held for sale are reported at the lower of carrying value or fair value less cost to sell.

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Goodwill - Goodwill is not subject to amortization but is tested for impairment on an annual basis (or more frequently if impairment indicators arise) by comparing the estimated fair value of each reporting unit to its carrying value, including goodwill. A reporting unit is defined as an operating segment or one level below the operating segment. We have established October 31 as the date of our annual test for impairment of goodwill. Reporting units with goodwill are tested for impairment using a quantitative impairment test known as the income approach, which estimates fair value by discounting each reporting unit’s estimated future cash flows using a weighted-average cost of capital that reflects current market conditions and the risk profile of the reporting unit. To arrive at our future cash flows, we use estimates of economic and market assumptions, including growth rates in revenues, costs, estimates of future expected changes in operating margins, tax rates and cash expenditures. Future revenues are also adjusted to match changes in our business strategy. If the fair value of the reporting unit is less than its carrying amount as a result of this method, then an impairment loss is recorded.

A lower fair value estimate in the future for any of our reporting units could result in goodwill impairments. Factors that could trigger a lower fair value estimate include sustained price declines of the reporting unit’s products and services, cost increases, regulatory or political environment changes, changes in customer demand, and other changes in market conditions, which may affect certain market participant assumptions used in the discounted future cash flow model. As of December 31, 2021, we did not have any goodwill outstanding.

Intangible assets - Our acquired intangible assets are generally amortized on a straight-line basis over their estimated useful lives, which generally range from 2 to 20 years. Our acquired intangible assets do not have indefinite lives. Intangible assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of the intangible asset may not be recoverable. The carrying amount of an intangible 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 intangible asset exceeds its fair value.

Capitalized software costs are recorded at cost. Capitalized software costs include purchases of software and internal and external costs incurred during the application development stage of software projects. These costs are amortized on a straight-line basis over the estimated useful lives. For internal use software, the useful lives range from 3 to 10 years. For Internet website costs, the estimated useful lives do not exceed 3 years.

Research and development expense is expensed as incurred. Research and development expense includes improvement of existing products and services, design and development of new products and services and test of new technologies.

Debt instruments - Debt instruments include senior and private placement notes and other borrowings. Issuance fees and redemption premium on debt instruments are included in the cost of debt in the consolidated balance sheets, as an adjustment to the nominal amount of the debt. Loan origination costs for revolving credit facilities are recorded as an asset and amortized over the life of the underlying debt.

Fair value measurements - Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the reporting date. The fair value framework requires the categorization of assets and liabilities measured at fair value into three levels based upon the assumptions (inputs) used to price the assets or liabilities, with the exception of certain assets and liabilities measured using the net asset value practical expedient, which are not required to be leveled. Level 1 provides the most reliable measure of fair value, whereas Level 3 generally requires significant management judgment. The three levels are defined as follows:

•Level 1: Unadjusted quoted prices in active markets for identical assets and liabilities.

•Level 2: Observable inputs other than quoted prices included in Level 1. For example, quoted prices for similar assets or liabilities in active markets or quoted prices for identical assets or liabilities in inactive markets.

•Level 3: Unobservable inputs reflecting management’s own assumptions about the assumptions market participants would use in pricing the asset or liability.

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Income taxes - Current income taxes are provided on income reported for financial statement purposes, adjusted for transactions that do not enter into the computation of income taxes payable in the same year. Deferred tax assets and liabilities are measured using enacted tax rates for the expected future tax consequences of temporary differences between the carrying amounts and the tax basis of assets and liabilities. A valuation allowance is established whenever management believes that it is more likely than not that deferred tax assets may not be realizable.

Income taxes are not provided on our equity in undistributed earnings of foreign subsidiaries or affiliates to the extent we have determined that the earnings are indefinitely reinvested. Income taxes are provided on such earnings in the period in which we can no longer support that such earnings are indefinitely reinvested.

Tax benefits related to uncertain tax positions are recognized when it is more likely than not, based on the technical merits, that the position will be sustained upon examination.

We classify interest expense and penalties recognized on underpayments of income taxes as income tax expense.

Share-based compensation - The measurement of share-based compensation expense on restricted share awards and performance share awards is based on the market price at the grant date and the number of shares awarded. We use Black-Scholes options pricing model to measure the fair value of stock options granted on or after January 1, 2017. The stock-based compensation expense for each award is recognized ratably over the applicable service period or the period beginning at the start of the service period and ending when an employee becomes eligible for retirement, after taking into account estimated forfeitures.

Earnings per ordinary share (“EPS”) - Basic EPS is computed using the weighted-average number of ordinary shares outstanding during the year. We use the treasury stock method to compute diluted EPS which gives effect to the potential dilution of earnings that could have occurred if additional shares were issued for awards granted under our incentive compensation and stock plan. The treasury stock method assumes proceeds that would be obtained upon exercise of awards granted under our incentive compensation and stock plan are used to purchase outstanding ordinary shares at the average market price during the period.

Foreign currency - Financial statements of operations for which the U.S. dollar is not the functional currency, and which are located in non-highly inflationary countries, are translated into U.S. dollars prior to consolidation. Assets and liabilities are translated at the exchange rate in effect at the balance sheet date, while income statement accounts are translated at the average exchange rate for each period. For these operations, translation gains and losses are recorded as a component of accumulated other comprehensive income (loss) in stockholders’ equity until the foreign entity is sold or liquidated. For operations in highly inflationary countries and where the local currency is not the functional currency, inventories, property, plant and equipment, and other non-current assets are converted to U.S. dollars at historical exchange rates, and all gains or losses from conversion are included in net income. Foreign currency effects on cash, cash equivalents and debt in highly inflationary economies are included in interest income or expense.

For certain committed and anticipated future cash flows and recognized assets and liabilities which are denominated in a foreign currency, we may choose to manage our risk against changes in the exchange rates, when compared against the functional currency, through the economic netting of exposures instead of derivative instruments. Cash outflows or liabilities in a foreign currency are matched against cash inflows or assets in the same currency, such that movements in exchange rates will result in offsetting gains or losses. Due to the inherent unpredictability of the timing of cash flows, gains and losses in the current period may be economically offset by gains and losses in a future period. All gains and losses are recorded in our consolidated statements of income in the period in which they are incurred. Gains and losses from the remeasurement of assets and liabilities are recognized in other income (expense), net.

Derivative instruments - Derivatives are recognized on the consolidated balance sheets at fair value, with classification as current or non-current based upon the maturity of the derivative instrument. Changes in the fair value of derivative instruments are recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on the type of hedging transaction and whether a derivative is designated as, and is effective as, a hedge. Each instrument is accounted for individually and assets and liabilities are not offset.

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Hedge accounting is only applied when the derivative is deemed to be highly effective at offsetting changes in anticipated cash flows of the hedged item or transaction. Changes in fair value of derivatives that are designated as cash flow hedges are deferred in accumulated other comprehensive income (loss) until the underlying transactions are recognized in earnings. At such time, related deferred hedging gains or losses are recorded in earnings on the same line as the hedged item. Effectiveness is assessed at the inception of the hedge and on a quarterly basis. Effectiveness of forward contract cash flow hedges are assessed based solely on changes in fair value attributable to the change in the spot rate. The change in the fair value of the contract related to the change in forward rates is excluded from the assessment of hedge effectiveness. Changes in this excluded component of the derivative instrument, along with any ineffectiveness identified, are recorded in earnings as incurred. We document our risk management strategy and hedge effectiveness at the inception of, and during the term of, each hedge.

We also use forward contracts to hedge foreign currency assets and liabilities, for which we do not apply hedge accounting. The changes in fair value of these contracts are recognized in other income (expense), net on our consolidated statements of income, as they occur and offset gains or losses on the remeasurement of the related asset or liability.

Reclassifications - Certain prior-year amounts have been reclassified to conform to the current year’s presentation.

NOTE 2. DISCONTINUED OPERATIONS

The Spin-off

On February 16, 2021, we completed our separation of the Technip Energies business segment. The transaction was structured as a spin-off (the “Spin-off”), which occurred by way of a pro rata dividend (the “Distribution”) to our shareholders of 50.1% 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., Eastern Standard 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.

In connection with the Spin-off, TechnipFMC and Technip Energies entered into a separation and distribution agreement, as well as various other agreements, including, among others, a tax matters agreement, an employee matters agreement and a transition services agreement and certain agreements relating to intellectual property. These agreements provide for the allocation between TechnipFMC and Technip Energies of assets, employees, taxes, liabilities and obligations attributable to periods prior to, at and after the Spin-off.

Discontinued Operations

The Spin-off represented a strategic shift that will have a major impact on our operations and consolidated financial statements. Accordingly, historical results of Technip Energies prior to the Distribution on February 16, 2021 have been presented as discontinued operations in our consolidated statements of income, consolidated balance sheets and consolidated statements of cash flows for the years ended December 31, 2021, 2020 and 2019. Our consolidated statements of income, consolidated balance sheets and consolidated statements of cash flows and notes to the consolidated financial statements have been updated to reflect continuing operations only.

The following table summarizes the components of income from discontinued operations, net of tax:

	Year Ended
(In millions)	2021		2020		2019
Revenue	$	906.0	$	6,520.0	$	6,458.9
Costs and expenses	(932.0)		(5,899.0)		(5,627.6)
Other income and (expense), net	(18.6)		(206.8)		(396.0)
Income (loss) from discontinued operations before income taxes	$	(44.6)	$	414.2	$	435.3
Income (loss) from discontinued operations, net of income taxes	$	(72.6)	$	280.2	$	238.0

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Supplemental information:

	Year Ended
(In millions)	2021		2020		2019
Capital expenditures	$	5.1	$	35.7	$	41.7
Depreciation and amortization expense	17.1		35.1		41.9
Research and development expense	4.4		44.5		13.4

Assets and liabilities of discontinued operations are summarized below:

	December 31,
(In millions)	2020
Assets
Cash and cash equivalents	$	3,538.6
Trade receivables, net of allowances	1,302.1
Contract assets	380.8
Other current assets	503.6
Total current assets of discontinued operations	5,725.1
Property, plant and equipment, net of accumulated depreciation	105.6
Goodwill	2,512.5
Other assets	665.4
Total non-current assets of discontinued operations	3,283.5
Total assets of discontinued operations	$	9,008.6
Liabilities
Accounts payable, trade	$	1,539.5
Contract liabilities	3,689.3
Other current liabilities	867.7
Total current liabilities of discontinued operations	6,096.5
Long-term debt, less current portion	482.2
Operating lease liabilities	248.2
Other liabilities	350.9
Total non-current liabilities of discontinued operations	1,081.3
Total liabilities of discontinued operations	$	7,177.8

On February 16, 2021, all assets and liabilities of Technip Energies were spun-off; therefore, as of December 31, 2021, there were no assets and liabilities classified as discontinued operations. During the fourth quarter of 2021, we finalized the disposition process, which resulted in an immaterial adjustment to the net assets transferred to Technip Energies in the statement of stockholders’ equity. As of December 31, 2021, we had $84.4 million and $72.2 million of accounts receivable and accounts payable, respectively, outstanding with Technip Energies.

NOTE 3. BUSINESS COMBINATION AND OTHER TRANSACTIONS

2021

Magma Global Ltd.

In 2018, we entered into a collaboration agreement with Magma Global Ltd. (“Magma Global”) to develop a new generation of hybrid flexible pipe for use in the traditional and new energy industries. As part of the collaboration, we purchased a minority ownership interest in Magma Global.

In October 2021, we entered into a transaction to purchase the remaining ownership interest in Magma Global for $64.0 million. The cash consideration will be paid to the shareholders of Magma Global in three annual installments. The first payment of $23.9 million was paid on October 12, 2021. Magma technology enables the manufacture of

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Thermoplastic Composite Pipe (TCP) using Polyether Ether Ketone (PEEK) polymer, which is highly resistant to corrosive compounds, such as CO2.

With the step acquisition of the remaining outstanding shares of Magma Global and our resulting control of the company, we recorded a $36.7 million impairment during the third quarter of 2021 to adjust our equity method investment to its estimated fair market value. The impairment charge is included in income/loss from equity affiliates line in our consolidated statement of income.

As a result of the purchase price allocation of the remaining interest, we recognized $50.2 million of intangible assets consisting primarily of in-process research and development and trademarks, which are being amortized on a straight-line basis over 15 years. The fair value of the identifiable intangible assets has been estimated using an income approach.

TIOS

In accordance with the Share Purchase Agreement between Technip-Coflexip UK Holdings Limited (“TUK”) and Island Offshore Management AS (“Island Offshore”) that was executed on March 12, 2018, whereby TUK initially purchased 51% of the shares of TIOS AS (“TIOS”), a joint venture between TUK and Island Offshore, TUK acquired the remaining 49% interest in TIOS at a total price of $48.6 million during the third quarter of 2021. As of December 31, 2020, we owned a 51% share in TIOS and the redeemable non-controlling interest was recorded as mezzanine equity at fair value of $43.7 million. As of December 31, 2021 and 2020, TIOS was fully consolidated.

2019

On December 30, 2019, we completed the acquisition of the remaining 50% interest in Technip Odebrecht PLSV CV (“TOP CV”). TOP CV was formed as a joint venture between Technip SA and Ocyan SA to provide pipeline installation ships to Petroleo Brasileiro SA (“Petrobras”) for their work in oil and gas fields offshore Brazil with results reported in our Subsea segment using the equity method of accounting. Subsequent to this transaction the investment became a fully consolidated entity. In connection with the acquisition, we acquired $391.0 million in assets, including two vessels valued at $335.2 million. In addition, we assumed $239.9 million of liabilities, including a $203.1 million term loan. As a result of the acquisition, we recorded a net loss of $0.9 million. The net loss on acquisition was comprised of the impairment charge of $84.2 million partially offset by a gain on bargain purchase of $83.3 million included within restructuring and other charges in our consolidated statement of income.

NOTE 4. NEW ACCOUNTING STANDARDS

Recently Adopted Accounting Standards under GAAP

In August 2018, the FASB issued ASU No. 2018-14, “Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans.” This update amends ASC 715 to add, remove, and clarify disclosure requirements related to defined benefit pension and other post-retirement plans. We adopted this amendment as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In December 2019, the FASB issued ASU No. 2019-12, “Income Taxes to Topic 740—Simplifying the Accounting for Income Taxes.” The amendments simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740. This update also improves and simplifies areas of GAAP for which cost and complexity can be reduced while maintaining or improving the usefulness of the information provided to users of financial statements. We adopted this amendment as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In January 2020, the FASB issued ASU No. 2020-01, “Investments—Equity Securities (Topic 321),” “Investments—Equity Method and Joint Ventures (Topic 323),” and “Derivatives and Hedging (Topic 815)—Clarifying the Interactions between Topic 321, Topic 323, and Topic 815,” and made targeted improvements to address certain aspects of accounting for financial instruments. This update clarifies that a company should consider observable transactions that require a company to either apply or discontinue the equity method of accounting under Topic 323, Investments—Equity Method and Joint Ventures, for the purposes of applying the measurement alternative in accordance with Topic 321 immediately before applying or upon discontinuing the equity method. The new ASU

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also clarifies that, when determining the accounting for certain forward contracts and purchased options, a company should not consider whether underlying securities would be accounted for under the equity method or fair value option upon settlement or exercise. We adopted this amendment as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In October 2020, the FASB issued ASU No. 2020-10, “Codification Improvements.” The amendments in this update improve consistency by amending the accounting standards codification (the “Codification”) to include all disclosure guidance in the appropriate sections and clarify the application of various provisions in the Codification by amending and adding new headings, cross-referencing to other guidance, and refining or correcting terminology. We adopted this update as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In August 2020, the FASB issued ASU No. 2020-06, “Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815 – 40).” This update simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts in an entity’s own equity. We adopted this update as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

Recently Issued Accounting Standards under GAAP

In March 2020, the FASB issued ASU No. 2020-04, “Facilitation of the Effects of Reference Rate Reform on Financial Reporting (Topic 848).” In addition, in January 2021, FASB issued ASU No. 2021-01, “Reference Rate Reform (Topic 848)” which clarifies the scope of Topic 848. The amendments in these updates apply only to contracts, hedging relationships, and other transactions that reference the London interbank offered rate (“LIBOR”) or another reference rate expected to be discontinued because of reference rate reform. The expedients and exceptions provided by the amendments do not apply to contract modifications made and hedging relationships entered into or evaluated after December 31, 2022, except for hedging relationships existing as of December 31, 2022, that an entity has elected certain optional expedients for and that are retained through the end of the hedging relationship. The amendments in this update were issued as of March 12, 2020, effective through December 31, 2022. We do not anticipate the adoption of this update to have a material impact on our consolidated financial statements.

In October 2021, the FASB issued ASU No. 2021-08, “Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers.” This ASU requires entities to apply Topic 606 to recognize and measure contract assets and contract liabilities in a business combination. The amendments are effective for public business entities for fiscal years, including interim periods within those fiscal years, beginning after December 15, 2022. The amendment is this update should be applied with early adoption permitted. We do not anticipate the adoption of this update to have a material impact on our consolidated financial statements.

We consider the applicability and impact of all ASUs. We assessed ASUs not listed above and determined that they either were not applicable or were not expected to have a material impact on our financial statements.

NOTE 5. LEASES

Lessee Arrangements

We lease real estate, including land, buildings and warehouses, machinery/equipment, vessels, vehicles, and various types of manufacturing and data processing equipment, from a lessee perspective. Leases of real estate generally provide for payment of property taxes, insurance, and repairs by us. Substantially all our leases are classified as operating leases.

We determine if an arrangement is a lease at inception by assessing whether an identified asset exists and if we have the right to control the use of the identified asset. Operating leases are included in Operating lease right-of-use assets, Operating lease liabilities (current), and Operating lease liabilities (non-current) in our consolidated balance sheets. Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease right-of-use assets and liabilities are recognized at the commencement date based on the present value of the remaining lease payments over the lease term. With the exception of rare cases in which the implicit rate is readily determinable, we use our incremental borrowing rate based on the information available at the commencement date in determining the present value of lease payments. The Operating lease right-of-use assets also includes any lease prepayments

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made and excludes lease incentives we received from the lessor. Lease cost for lease payments is recognized on a straight-line basis over the lease term. Several of our leases provide for certain guarantees of residual value. We estimate and include in the determination of lease payments any amount probable of being owed under these residual value guarantees.

Lease terms within our lessee arrangements may include options to extend/renew or terminate the lease and/or purchase the underlying asset when it is reasonably certain that we will exercise that option. TechnipFMC applies a portfolio approach by asset class to determine lease term renewals. The leases within these portfolios are categorized by asset class and have initial lease terms that vary depending on the asset class. The renewal terms range from 60 days to 5 years for asset classes such as temporary residential housing, forklifts, vehicles, vessels, office and IT equipment, and tool rentals, and up to 15 years or more for commercial real estate. Short-term leases with an initial term of 12 months or less that do not include a purchase option are not recorded on the balance sheet. Lease costs for short-term leases are recognized on a straight-line basis over the lease term and amounts related to short-term leases are disclosed within our financial statements.

TechnipFMC has variable lease payments, including adjustments to lease payments based on an index or rate (such as the Consumer Price Index), fair value adjustments to lease payments, and common area maintenance, real estate taxes, and insurance payments in triple-net real estate leases. Variable lease payments that depend on an index or a rate (such as the Consumer Price Index or a market interest rate) are included when measuring consideration within our lease arrangements using the payments’ base rate or index. Variable payments that do not depend on an index or rate are recognized in the consolidated income statements and are disclosed as “variable lease costs” in the period they are incurred.

We adopted the practical expedient to not separate lease and non-lease components for all asset classes except for vessels, which have significant non-lease components.

TechnipFMC currently subleases certain of its leased real estate and vessels to third parties.

The following table is a summary of the Company’s components of net lease cost for the years ended December 31, 2021 and 2020:

	Year Ended December 31,
(In millions)	2021		2020
Operating lease costs including variable costs	$	175.9	$	195.6
Short-term lease costs	5.2		11.0
Less: sublease income	2.4		2.8
Net lease cost	$	178.7	$	203.8

Supplemental cash flow information related to leases for the years ended December 31, 2021 and 2020 is as follows:

	Year Ended December 31,
(In millions)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	176.5	$	206.5
Right-of-use assets obtained in exchange for lease liabilities
Operating leases	$	114.9	$	421.3
Finance leases	$	24.6	$	26.9

Supplemental balance sheet information related to leases as of December 31, 2021 and 2020 is as follows:

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	December 31,
(In millions, except lease term and discount rate)	2021		2020
Weighted average remaining lease term
Operating leases	13.3 years		13.6 years
Finance leases	1.1 years		0.6 years
Weighted average discount rate
Operating leases	5.86	%	5.35	%
Finance leases	1.2	%	2.1	%

Maturities of operating and finance lease liabilities as of December 31, 2021 are as follows:

(In millions)	Maturity of Operating Lease Liabilities		Maturity of Finance Lease Liabilities
2022	$	150.2	$	1.0
2023	108.3		103.0
2024	102.3		—
2025	83.1		—
2026	74.7		—
Thereafter	675.9		—
Total lease payments	1,194.5		104.0
Less: Imputed interest (a)	421.5		52.2
Total lease liabilities (b)	$	773.0	$	51.8

Note: For leases that commenced prior to 2019, minimum lease payments exclude payments to landlords for real estate taxes and common area maintenance.

(a)Calculated using the interest rate for each lease.

(b)Includes the current portion of $126.9 million.

In December 2020, TechnipFMC sold its leased office building at Gremp Campus in Houston, Texas on behalf of the existing lessor to Oak Street Real Estate Capital, LLC (“New Lessor”). TechnipFMC also sold the underlying land at Gremp Campus, which the Company owned, to the New Lessor. TechnipFMC concurrently executed a new lease agreement for both the land and the office building (collectively, “Gremp Campus Properties”) with New Lessor.

The new lease agreement of Gremp Campus Properties commenced on December 11, 2020 and the initial term ends on December 31, 2042. TechnipFMC paid net cash of $1.8 million in connection with the new lease agreement and recognized a loss of $3.1 million from derecognition of the existing lease. There was no gain or loss from the sale of the land at Gremp Campus.

Lessor Arrangements

We lease real estate including land, buildings and warehouses, machinery/equipment, and vessels from a lessor perspective. We determine if an arrangement is a lease at inception by assessing whether an identified asset exists and if the customer has the right to control the use of the identified asset. We use our implicit rate for our lessor arrangements. We have elected the practical expedient available for lessors to not separate lease and non-lease components for vessels. If the non-lease component is predominant in our contracts, we account for the contracts under the revenue recognition guidance in ASU 2014-09, “Revenue from Contracts with Customers” (Topic 606). If the lease component is predominant in our contracts, we account for the contracts under the lease guidance in Topic 842. We estimate the amount we expect to derive from the underlying asset following the end of the lease term based on remaining economic life. Our lessor arrangements generally do not include any residual value guarantees. We recognize lessee payments of lessor costs such as taxes and insurance on a net basis when the lessee pays those costs directly to a third party or when the amount paid by the lessee is not readily determinable.

Our operating lease revenue, including variable revenue, was $158.4 million and $142.0 million for the years ended December 31, 2021 and 2020, respectively. During the next five years, we expect to receive $19.3 million in

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total undiscounted cash flows, of which $18.3 million is expected to be received in 2022 and $1.0 million is expected to be received in 2023.

NOTE 6. REVENUE

The majority of our revenue is from long-term contracts associated with designing and manufacturing products and systems and providing services to customers involved in exploration and production of crude oil and natural gas.

Significant Revenue Recognition Criteria Explained

Allocation of transaction price to performance obligations - A contract’s transaction price is allocated to each distinct performance obligation and recognized as revenue, when, or as, the performance obligation is satisfied. To determine the proper revenue recognition method, we evaluate whether two or more contracts should be combined and accounted for as one single contract and whether the combined or single contract should be accounted for as more than one performance obligation. This evaluation requires significant judgment; some of our contracts have a single performance obligation as the promise to transfer the individual goods or services is not separately identifiable from other promises in the contracts and, therefore, not distinct.

Variable consideration - 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 variable considerations that can either increase or decrease the transaction price. Variability in the transaction price arises primarily due to liquidated damages. We consider our experience with similar transactions and expectations regarding the contract in estimating the amount of variable consideration to which we will be entitled, and determining whether the estimated variable consideration should be constrained. We include estimated amounts 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. Our estimates of variable consideration are based largely on an assessment of our anticipated performance and all information (historical, current and forecasted) that is reasonably available to us.

Payment terms - Progress billings are generally issued upon completion of certain phases of the work as stipulated in the contract. Payment terms may either be fixed, lump-sum or driven by time and materials (e.g., daily or hourly rates, plus materials). Because typically the customer retains a small portion of the contract price until completion of the contract, our contracts generally result in revenue recognized in excess of billings which we present as contract assets on the balance sheet. Amounts billed and due from our customers are classified as receivables in the consolidated balance sheets. The portion of the payments retained by the customer until final contract settlement is not considered a significant financing component because the intent is to protect the customer. For some contracts, we may be entitled to receive an advance payment. We recognize a liability for these advance payments in excess of revenue recognized and present it as contract liabilities in the consolidated balance sheets. The advance payment typically is not considered a significant financing component because it is used to meet working capital demands that can be higher in the early stages of a contract and to protect us from the other party failing to adequately complete some or all of its obligations under the contract.

Warranty - Certain contracts include an assurance-type warranty clause, typically between 18 to 36 months, to guarantee that the products comply with agreed specifications. A service-type warranty may also be provided to the customer; in such a case, management allocates a portion of the transaction price to the warranty based on the estimated stand-alone selling price of the service-type warranty.

Revenue recognized over time - Our performance obligations are satisfied over time as work progresses or at a point in time. Revenue from products and services transferred to customers over time accounted for approximately 68%, 72% and 68% of our revenue for the years ended December 31, 2021, 2020 and 2019, respectively. Typically, revenue is recognized over time using an input measure (e.g., costs incurred to date relative to total estimated costs at completion) to measure progress.

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Cost-to-cost method - For our long-term contracts, because of control transferring over time, revenue is recognized based on the extent of progress towards completion of the performance obligation. We generally use the cost-to-cost measure of progress for our contracts because it best depicts the transfer of control to the customer which 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, including estimated fees or profits, are recorded proportionally as costs are incurred. Any expected losses on construction-type contracts in progress are charged to earnings, in total, in the period the losses are identified.

Right to invoice practical expedient - The right-to-invoice practical expedient can be applied to a performance obligation satisfied over time if we have a right to invoice the customer for an amount that corresponds directly with the value transferred to the customer for our performance completed to date. When this practical expedient is used, we do not estimate variable consideration at the inception of the contract to determine the transaction price or for disclosure purposes. We have contracts which have payment terms dictated by daily or hourly rates where some contracts may have mixed pricing terms which include a fixed fee portion. For contracts in which we charge the customer a fixed rate based on the time or materials spent during the project that correspond to the value transferred to the customer, we recognize revenue in the amount to which we have the right to invoice.

Contract modifications - Contracts are often modified to account for changes in contract specifications and requirements. We consider contract modifications to exist when the modification either creates new, or changes the existing, enforceable rights and obligations. Most of our contract modifications are for goods or services that are not distinct from the existing contract due to the significant integration service provided in the context of the contract and are accounted for as if they were part of that existing contract. The effect of a contract modification on the transaction price and our measure of progress for the performance obligation to which it relates is recognized as an adjustment to revenue (either as an increase in or a reduction of revenue) on a cumulative catch-up basis.

Revenue Recognition by Segment

The following is a description of principal activities separated by reportable segments from which TechnipFMC generates its revenue. See Note 7 for more detailed information about reportable segments.

Subsea

Our Subsea segment manufactures and designs products and systems, performs engineering, procurement and project management and provides services used by oil and gas companies involved in offshore exploration and production of crude oil and natural gas. Systems and services may be sold separately or as combined integrated systems and services offered within one contract. Many of the systems and products TechnipFMC supplies for subsea applications are highly engineered to meet the unique demands of our customers’ field properties and are typically ordered one to two years prior to installation. We often receive advance payments and progress billings from our customers in order to fund initial development and working capital requirements.

Under Subsea engineering, procurement, construction and installation contracts, revenue is principally generated from long-term contracts with customers. We have determined these contracts generally have one performance obligation as the delivered product is highly customized to customer and field specifications. We generally recognize revenue over time for such contracts as the customized products do not have an alternative use for TechnipFMC and we have an enforceable right to payment plus a reasonable profit for performance completed to date.

Our Subsea segment also performs an array of subsea services including (i) installation services, (ii) asset management services (iii) product optimization, (iv) inspection, maintenance and repair services, and (v) well access and intervention services, where revenue is generally earned through the execution of either installation-type or maintenance-type contracts. For either contract-type, management has determined that the performance of the service generally represents one single performance obligation. We have determined that revenue from these contracts is recognized over time as the customer simultaneously receives and consumes the benefit of the services.

Surface Technologies

Our Surface Technologies segment designs, manufactures and supplies technologically advanced wellhead systems and high pressure valves and pumps used in stimulation activities for oilfield service companies and provides installation, flowback and other services for exploration and production companies.

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We provide a full range of drilling, completion and production wellhead systems for both standard and custom-engineered applications. Under pressure control product contracts, we design and manufacture flowline products, under the Weco®/Chiksan® trademarks, articulating frac arm manifold trailers, well service pumps, compact valves and reciprocating pumps used in well completion and stimulation activities by major oilfield service companies. Performance obligations within these systems are satisfied either through delivery of a standardized product or equipment or the delivery of a customized product or equipment.

For contracts with a standardized product or equipment performance obligation, management has determined that because there is limited customization to products sold within such contracts and the asset delivered can be resold to another customer, revenue should be recognized as of a point in time, upon transfer of control to the customer and after the customer acceptance provisions have been met.

For contracts with a customized product or equipment performance obligation, the revenue is recognized over time, as the manufacturing of our product does not create an asset with an alternative use for us and we have an enforceable right to payment plus a reasonable profit for performance completed to date.

This segment also designs, manufactures and services measurement products globally. Contract-types include standard product or equipment and maintenance-type services where we have determined that each contract under this product line represents one performance obligation.

Revenue from standard measurement equipment contracts is recognized at a point in time, while maintenance-type contracts are typically priced at a daily or hourly rate. We have determined that revenue for these contracts is recognized over time because the customer simultaneously receives and consumes the benefit of the services.

Disaggregation of Revenue

We disaggregate revenue by geographic location and contract type. The following table presents total revenue by geography for each reportable segment for the years ended December 31, 2021, 2020 and 2019:

	Reportable Segments
	Year Ended December 31,
	2021				2020				2019
(In millions)	Subsea		Surface Technologies		Subsea		Surface Technologies		Subsea		Surface Technologies
Europe, Central Asia	$	1,404.4	$	191.5	$	1,664.1	$	192.7	1,690.2		160.1
North America	753.6		372.7		899.7		367.9		660.8		751.9
Latin America	1,157.7		86.7		1,042.4		76.6		1,139.5		108.6
Asia Pacific	927.4		104.2		772.1		131.0		673.3		195.4
Africa	1,057.3		44.0		908.6		46.9		836.4		62.7
Middle East	28.7		275.3		184.5		244.1		419.3		252.0
Total revenue	$	5,329.1	$	1,074.4	$	5,471.4	$	1,059.2	$	5,419.5	$	1,530.7

The following table represents revenue by contract type for each reportable segment for the years ended December 31, 2021, 2020 and 2019:

	Reportable Segments
	Year Ended December 31,
	2021				2020				2019
(In millions)	Subsea		Surface Technologies		Subsea		Surface Technologies		Subsea		Surface Technologies
Services	$	3,282.0	$	158.7	$	3,121.1	$	150.2	$	3,141.0	$	271.0
Products	2,002.5		801.9		2,295.4		821.9		2,162.5		1,109.2
Lease(a)	44.6		113.8		54.9		87.1		116.0		150.5
Total revenue	$	5,329.1	$	1,074.4	$	5,471.4	$	1,059.2	$	5,419.5	$	1,530.7

(a)Represents revenue not subject to ASC Topic 606.

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Contract Balances

The timing of revenue recognition, billings and cash collections results in billed accounts receivable, costs and estimated earnings in excess of billings on uncompleted contracts (contract assets), and billings in excess of costs and estimated earnings on uncompleted contracts (contract liabilities) in the consolidated balance sheets. Any expected contract losses are recorded in the period in which they become probable.

Contract Assets - Contract Assets include unbilled amounts typically resulting from sales under long-term contracts when revenue is recognized over time and revenue recognized exceeds the amount billed to the customer, and right to payment is not just subject to the passage of time. Amounts may not exceed their net realizable value. Costs and estimated earnings in excess of billings on uncompleted contracts are generally classified as current.

Contract Liabilities - We sometimes receive advances or deposits from our customers, before revenue is recognized, resulting in contract liabilities.

The following table provides information about net contract assets (liabilities) as of December 31, 2021 and 2020:

	December 31,
(In millions)	2021		2020		$ change		% change
Contract assets	$	966.0	$	886.8	$	79.2	8.9
Contract (liabilities)	(1,012.9)		(1,046.8)		33.9		3.2
Net contract (liabilities)	$	(46.9)	$	(160.0)	$	113.1	70.7

The increase in our contract assets from December 31, 2020 to December 31, 2021 was primarily due to the timing of project milestones.

The decrease in our contract liabilities was primarily due to completion of performance obligations for contracts, for which consideration was received in advance of the work performed during the period.

In order to determine revenue recognized in the period from contract liabilities, we first allocate revenue to the individual contract liability balance outstanding at the beginning of the period until the revenue exceeds that balance. Any subsequent revenue we recognize increases contract asset balance. Revenue recognized for the years ended December 31, 2021 and 2020 that were included in the contract liabilities balance as of December 31, 2020 and 2019 was $305.3 million and $484.3 million, respectively.

In addition, net revenue recognized for the years ended December 31, 2021 and 2020 from our performance obligations satisfied in previous periods had favorable (unfavorable) impacts of $25.9 million and $(21.7) million, respectively. This primarily relates to the changes in the estimate of the stage of completion that impacted revenue.

Transaction Price Allocated to the Remaining Unsatisfied Performance Obligations

Remaining unsatisfied performance obligations (“RUPO” or “order backlog”) represent the transaction price for products and services for which we have a material right, but work has not been performed. Transaction price of the order backlog includes the base transaction price, variable consideration and changes in transaction price. The order backlog table does not include contracts for which we recognize revenue at the amount to which we have the right to invoice for services performed. The transaction price of order backlog related to unfilled, confirmed customer orders is estimated at each reporting date. As of December 31, 2021, the aggregate amount of the transaction price allocated to order backlog was $7,657.7 million. TechnipFMC expects to recognize revenue on approximately 49.0% of the order backlog through 2022 and 51.0% thereafter.

The following table details the order backlog for each business segment as of December 31, 2021:

(In millions)	2022		2023		Thereafter
Subsea	$	3,372.8	$	2,227.5	$	932.7
Surface Technologies	376.8		95.2		652.7
Total remaining unsatisfied performance obligations	$	3,749.6	$	2,322.7	$	1,585.4

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NOTE 7. BUSINESS SEGMENTS

Management’s determination of our reporting segments was made on the basis of our strategic priorities within each segment and the differences in the products and services we provide, which corresponds to the manner in which our Chair and Chief Executive Officer, as our chief operating decision maker, reviews and evaluates operating performance to make decisions about resources to be allocated to the segment. We now operate under two reportable segments: Subsea and Surface Technologies.

•Subsea - designs and manufactures products and systems, performs engineering, procurement and project management, and provides services used by oil and gas companies involved in offshore exploration and production of crude oil and natural gas.

•Surface Technologies - designs and manufactures products and systems and provides services used by oil and gas companies involved in land and shallow water exploration and production of crude oil and natural gas; designs, manufactures, and supplies technologically advanced high-pressure valves and fittings for oilfield service companies; and also provides flowback and well testing services.

Segment operating profit (loss) is defined as total segment revenue less segment operating expenses. Income (loss) from equity method investments is included in computing segment operating profit. The following items have been excluded in computing segment operating profit (loss): corporate staff expense, foreign exchange gains (losses), income from investment in Technip Energies, net interest income (expense) associated with corporate debt facilities and income taxes.

Information by business segment

Segment revenue and segment operating profit (loss) were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Segment revenue
Subsea	$	5,329.1	$	5,471.4	$	5,419.5
Surface Technologies	1,074.4		1,059.2		1,530.7
Total revenue	$	6,403.5	$	6,530.6	$	6,950.2
Segment operating profit (loss)
Subsea	$	141.4	$	(2,815.5)	$	(1,442.7)
Surface Technologies	42.0		(429.3)		(662.7)
Total segment operating profit (loss)	183.4		(3,244.8)		(2,105.4)
Corporate items
Merger transaction and integration costs	—		—		(14.2)
Legal expenses	—		—		(33.0)
Other corporate expenses (a)	(118.1)		(131.9)		(191.7)
Net interest expense	(143.3)		(81.8)		(91.3)
Loss on early extinguishment of debt	(61.9)		—		—
Income from investment in Technip Energies	322.2		—		—
Foreign exchange gains (losses)	15.8		(40.2)		(135.5)
Total corporate items	14.7		(253.9)		(465.7)
Income (loss) before income taxes(b)	$	198.1	$	(3,498.7)	$	(2,571.1)

(a)Other corporate expenses primarily include corporate staff expenses, share-based compensation expenses, certain long-lived assets impairments, restructuring and other expenses and other employee benefits.

(b)Includes amounts attributable to non-controlling interests.

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Segment assets were as follows:

	December 31,
(In millions)	2021		2020
Segment assets
Subsea	$	6,532.5	$	6,796.6
Surface Technologies	1,420.0		1,758.3
Total segment assets	7,952.5		8,554.9
Corporate (a)	2,067.6		2,129.1
Assets from discontinued operations	—		9,008.6
Total assets	$	10,020.1	$	19,692.6

(a)Corporate includes cash, investment in Technip Energies, LIFO adjustments, deferred income tax balances, property, plant and equipment and intercompany eliminations not associated with a specific segment, pension assets and the fair value of derivative financial instruments.

Other business segment information is as follows:

	Capital Expenditures						Depreciation and Amortization						Research and Development Expense
	Year Ended December 31,						Year Ended December 31,						Year Ended December 31,
(In millions)	2021		2020		2019		2021		2020		2019		2021		2020		2019
Subsea	$	149.4	$	213.6	$	287.5	$	317.2	$	324.9	$	345.0	$	73.2	$	66.5	$	134.2
Surface Technologies	36.8		38.5		96.0		64.8		70.1		107.1		5.2		8.8		15.3
Corporate	5.5		4.0		29.2		3.4		17.1		15.6		—		—		—
Total	$	191.7	$	256.1	$	412.7	$	385.4	$	412.1	$	467.7	$	78.4	$	75.3	$	149.5

Information by geography

Revenue by geography was identified based on the country where our products and services were delivered, and is as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Revenue
United States	$	1,137.2	$	1,320.1	$	1,458.6
Norway	979.9		1,216.6		1,352.6
Brazil	767.8		600.6		1,086.2
United Kingdom	542.5		489.0		535.8
Mozambique	472.0		320.4		80.0
Australia	419.8		122.5		133.4
Angola	406.3		482.8		498.1
Guyana	314.7		330.1		7.2
Indonesia	224.9		280.0		262.6
Singapore	216.3		219.9		190.5
Malaysia	206.9		190.0		197.2
India	109.8		26.8		—
Trinidad	78.1		106.3		42.8
Israel	26.8		179.3		319.6
All other countries	500.5		646.2		785.6
Total revenue	$	6,403.5	$	6,530.6	$	6,950.2

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Long-lived assets by geography represent property, plant and equipment, net, and are as follows:

	December 31,
(In millions)	2021		2020
Long-lived assets
United Kingdom	$	882.9	$	928.8
Netherlands	414.7		417.6
United States	383.4		439.1
Norway	271.9		312.1
Brazil	265.5		259.9
All other countries	378.8		398.7
Total long-lived assets	$	2,597.2	$	2,756.2

NOTE 8. EARNINGS (LOSS) PER SHARE

A reconciliation of the number of shares used for the basic and diluted earnings (loss) per share calculation was as follows:

	Year Ended December 31,
(In millions, except per share data)	2021		2020		2019
Income (loss) from continuing operations attributable to TechnipFMC plc	$	87.8	$	(3,552.6)	$	(2,645.5)
Income (loss) from discontinued operations attributable to TechnipFMC plc	(74.5)		265.0		230.3
Net income (loss) attributable to TechnipFMC plc	$	13.3	$	(3,287.6)	$	(2,415.2)
Weighted average number of shares outstanding	450.5		448.7		448.0
Dilutive effect of restricted stock units	4.1		—		—
Total shares and dilutive securities	454.6		448.7		448.0
Basic and diluted earnings (loss) per share attributable to TechnipFMC plc:
Earnings (loss) per share from continuing operations attributable to TechnipFMC plc
Basic	$	0.19	$	(7.92)	$	(5.91)
Diluted	$	0.19	$	(7.92)	$	(5.91)
Earnings (loss) per share from discontinued operations attributable to TechnipFMC plc
Basic	$	(0.17)	$	0.59	$	0.51
Diluted	$	(0.16)	$	0.59	$	0.51
Total earnings (loss) per share attributable to TechnipFMC plc
Basic and diluted	$	0.03	$	(7.33)	$	(5.39)

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For the years ended December 31, 2020 and 2019, we incurred net losses; therefore, the impact of any incremental shares from our share-based compensation awards would be anti-dilutive. For the years ended December 31, 2020 and 2019, 3.8 million shares and 4.3 million shares, respectively, were anti-dilutive due to a net loss position.

Weighted average shares of the following share-based compensation awards were excluded from the calculation of diluted weighted average number of shares where the assumed proceeds exceed the average market price from the calculation of diluted weighted average number of shares, because their effect would be anti-dilutive:

	Year Ended December 31,
(millions of shares)	2021	2020	2019
Share option awards	1.7	4.6	4.0
Restricted share units	0.1	1.8	—
Performance shares	—	1.9	1.6
Total	1.8	8.3	5.6

NOTE 9. RECEIVABLES

We manage our receivables portfolios using published default risk as a key credit quality indicator for our loans and receivables. Our loans receivable and security deposits were related to sales of long-lived assets or businesses, loans to related parties for capital expenditure purposes, or security deposits for lease arrangements.

We manage our held-to-maturity debt securities using published credit ratings as a key credit quality indicator as our held-to-maturity debt securities consist of government bonds.

The table below summarizes the amortized cost basis of financial assets by years of origination and credit quality. The key credit quality indicator is updated as of December 31, 2021.

(In millions)	Year of origination	Balance as of December 31, 2021		Balance as of December 31, 2020
Loans receivables, security deposits and other
Moody’s rating Ba2	2019	$	50.9	$	107.6
Debt securities at amortized cost
Moody’s rating B3	2019	24.0		23.7
Total financial assets		$	74.9	$	131.3

Credit Losses

For contract assets, trade receivables, loans receivable, and security deposits and other, we have elected to calculate an expected credit loss based on loss rates from historical data. We develop loss-rate statistics on the basis of the amount written-off over the life of the financial assets and contract assets and adjust these historical credit loss trends for forward-looking factors specific to the debtors and the economic environment to determine lifetime expected losses.

For held-to-maturity debt securities at amortized cost, we evaluate whether the debt securities are considered to have low credit risk at the reporting date using available, reasonable and supportable information.

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The table below shows the roll-forward of allowance for credit losses as of December 31, 2021 and 2020, respectively.

	Balance as of December 31, 2021
(In millions)	Trade receivables		Contract assets		Loans receivable		Security deposit and other		Held-to-maturity debt securities
Allowance for credit losses at December 31, 2020	$	40.2	$	2.4	$	7.5	$	0.4	$	0.5
Current period provision (release) for expected credit losses	3.5		(1.3)		(7.2)		(0.1)		2.2
Recoveries	(5.6)		—		—		—		—
Allowance for credit losses at December 31, 2021	$	38.1	$	1.1	$	0.3	$	0.3	$	2.7

	Balance as of December 31, 2020
(In millions)	Trade receivables		Contract assets		Loans receivable		Security deposit and other		Held-to-maturity debt securities
Allowance for credit losses at December 31, 2019	$	59.4	$	4.5	$	9.5	$	0.7	$	1.1
Current period provision for expected credit losses	27.2		0.5		(0.2)		(0.3)		(0.6)
Write-offs charged against the allowance	(43.0)		—		—		—		—
Recoveries	(3.4)		(2.6)		(1.8)		—		—
Allowance for credit losses at December 31, 2020	$	40.2	$	2.4	$	7.5	$	0.4	$	0.5

Certain trade receivables are due in one year or less.

NOTE 10. INVENTORIES

Inventories consisted of the following:

	December 31,
(In millions)	2021		2020
Raw materials	$	250.1	$	270.3
Work in process	178.7		242.7
Finished goods	603.1		739.8
Inventories, net	$	1,031.9	$	1,252.8

All amounts in the table above are reported net of obsolescence reserves of $116.6 million and $155.7 million as of December 31, 2021 and 2020, respectively.

Net inventories accounted for under the LIFO method totaled $350.1 million and $408.5 million as of December 31, 2021 and 2020, respectively. The current replacement costs of LIFO inventories exceeded their recorded values by $10.9 million and $11.6 million as of December 31, 2021 and 2020, respectively.

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NOTE 11. OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES

Other current assets consisted of the following:

	December 31,
(In millions)	2021		2020
Value - added tax receivables	$	222.4	$	256.9
Sundry receivables	106.1		138.4
Other taxes receivables	70.6		73.8
Prepaid expenses	50.7		78.1
Current financial assets at amortized cost	21.9		40.6
Held-to-maturity investments	8.8		24.2
Assets held for sale	5.0		47.3
Other	26.8		24.1
Total other current assets	$	512.3	$	683.4

Other current liabilities consisted of the following:

	December 31,
(In millions)	2021		2020
Warranty accruals and project contingencies	$	119.5	$	168.8
Legal provisions	121.7		127.6
Value - added tax and other taxes payable	71.0		109.6
Compensation accrual	85.7		54.3
Social security liability	70.4		67.9
Provisions	23.6		53.0
Current portion of accrued pension and other post-retirement benefits	5.2		6.9
Other accrued liabilities	163.3		230.2
Total other current liabilities	$	660.4	$	818.3

NOTE 12. WARRANTY OBLIGATIONS

Warranty obligations are included within other current liabilities in our consolidated balance sheets as of December 31, 2021 and 2020. A reconciliation of warranty obligations for the years ended December 31, 2021 and 2020 is as follows:

	Year Ended December 31,
(In millions)	2021		2020
Balance at beginning of period	$	109.6	$	121.7
Warranty expenses	54.0		52.0
Adjustment to existing accruals	(56.5)		(48.2)
Claims paid	(20.9)		(15.9)
Balance at end of period	$	86.2	$	109.6

NOTE 13. INVESTMENTS

Equity Method Investments

The equity method of accounting is used to account for investments in unconsolidated affiliates where we can have the ability to exert significant influence over the affiliates operating and financial policies.

Our equity investments were as follows as of December 31, 2021 and 2020:

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			December 31,
			2021		2020
(In millions, except %)	Percentage Owned		Carrying Value
Dofcon Brasil AS	50.0	%	276.9		234.7
Magma Global Limited	—	%	—		51.4
Serimax Holdings SAS	20.0	%	15.0		18.8
Other			0.5		0.6
Investments in equity affiliates			$	292.4	$	305.5

Our income from equity affiliates for the years ended December 31, 2021, 2020 and 2019, was $0.6 million, $64.6 million and $59.8 million, respectively and included within our Subsea segment.

Our major equity method investments are as follows:

Dofcon Brasil AS (“Dofcon”) - is an affiliated company in the form of a joint venture between TechnipFMC and DOF Subsea and was founded in 2006. Dofcon provides Pipe-Laying Support Vessels (PLSVs) for work in oil and gas fields offshore Brazil. Dofcon is considered a VIE because it does not have sufficient equity to finance its activities without additional subordinated financial support from other parties. We are not the primary beneficiary of the VIE. As such, we have accounted for our 50% investment using the equity method of accounting with results reported in our Subsea segment.

Magma Global Limited (“Magma Global”) - In 2018, we entered into a collaboration agreement with Magma Global to develop a new generation of hybrid flexible pipe for use in the traditional and new energy industries. As part of the collaboration, we purchased a 25% ownership interest in Magma Global. In October 2021, we purchased the remaining ownership interest in Magma Global for $64.0 million. See Note 3 for further details.

Serimax Holdings SAS (“Serimax”) - is an affiliated company in the form of a joint venture between TechnipFMC and Vallourec SA and was founded in 2016. Serimax is headquartered in Paris, France and provides rigid pipes welding services for work in oil and gas fields around the world. We have accounted for our 20% investment using the equity method of accounting with results reported in our Subsea segment.

Investment in Technip Energies

As discussed in Note 2, immediately following the completion of the Spin-off, we owned 49.9% of the outstanding shares of Technip Energies. At the Spin-off date, on initial recognition of the investment, we elected to account for our investment in Technip Energies at fair value with all subsequent changes in fair value for the investment reported in our consolidated statement of income.

On January 7, 2021, Bpifrance Participations SA (“BPI”) entered into the Share Purchase Agreement with us pursuant to which BPI agreed to purchase a portion of our retained stake in Technip Energies N.V. (the “BPI Investment”) for $200.0 million (the “Purchase Price”), subject to certain adjustments. On March 31, 2021, BPI ultimately purchased 7.5 million shares in Technip Energies from us for $100.0 million. Accordingly, on April 8, 2021, we refunded $100.0 million to BPI as a result of their revised level of investment.

On April 27, 2021 we sold 25.0 million Technip Energies shares, representing 14% of Technip Energies’ share capital, through a private placement by way of an accelerated bookbuild offering (the “April Placement”). The sale price of the shares in the April Placement was set at €11.10 per share, yielding total gross proceeds of €277.5 million, or $335.2 million.

Concurrently with the April Placement, Technip Energies purchased from us 1.8 million shares of Technip Energies (equivalent to 1% of share capital) at €11.10 per share, corresponding to the price of the April Placement (the “Concurrent Sale to Technip Energies”). The sale of shares to Technip Energies yielded total gross proceeds of €20.0 million or $24.2 million. This purchase was separate from the April Placement.

On July 29, 2021 we announced the sale of 16.0 million Technip Energies shares, representing approximately 9% of Technip Energies’ issued and outstanding share capital, through a private placement by way of an accelerated bookbuild offering (the “July Placement”). The sale price of the shares in the July Placement was set at €11.20 per share, yielding total gross proceeds of €179.2 million, or $213.1 million. We agreed to a 60-day lock-up for our remaining shares in Technip Energies, subject to waiver from the Joint Global Coordinators and certain other customary exceptions.

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On September 2, 2021 we announced the sale of 17.6 million Technip Energies shares, representing approximately 10% of Technip Energies’ issued and outstanding share capital, through a private sale transaction with HAL Investments, the Dutch investment subsidiary of HAL Holding, N.V. (the “September Sale”). The sale price of the shares in the September Sale was set at €11.15 per share, yielding total gross proceeds of €196.2 million, or $231.5 million. The Joint Global Coordinators from the July Placement granted a waiver of the 60-day lock-up solely for the purpose of the September Sale.

The September Sale was completed in two tranches. The first tranche of 8.6 million shares was sold and settled in September for gross proceeds of €96.3 million, or $114.4 million. The second tranche of 9.0 million shares was settled on October 22, 2021 for gross proceeds of €99.9 million, or $116.4 million.

As a result of the reduced ownership interest in Technip Energies and related loss of significant influence, we discontinued the use of equity method of accounting for our interest in Technip Energies. Following the September sale, we account for our remaining ownership interest in Technip Energies as equity security at fair value.

As of December 31, 2021, we retained a direct stake of 21.9 million shares, representing 12.2% of Technip Energies’ issued and outstanding share capital. There is no lock-up associated with our remaining stake in Technip Energies. The carrying amount of our investment in Technip Energies as of December 31, 2021 was $317.3 million.

For the year ended December 31, 2021, we recognized $322.2 million of income related to our investment in Technip Energies. The amounts recognized include purchase price discounts on the sales of shares and a fair value revaluation gains and losses of our investment. See Note 26 for further details.

NOTE 14. RELATED PARTY TRANSACTIONS

Receivables, payables, revenues and expenses which are included in our consolidated financial statements for all transactions with related parties, defined as entities related to our directors and main shareholders as well as the partners of our consolidated joint ventures, were as follows.

Trade receivables consisted of trade receivables due from the following related parties:

	December 31,
(In millions)	2021		2020
Equinor ASA	$	—	$	24.1
Dofcon Navegacao	22.7		4.2
Techdof Brasil AS	4.5		8.0
Others	2.5		1.7
Total trade receivables	$	29.7	$	38.0

Dofcon Navegacao and Dofcon Brasil AS are our equity method investments and Techdof Brasil AS is a wholly owned subsidiary of Dofcon Brasil AS. In October 2020, we added a new member to our Board of Directors who was an executive of Equinor ASA up through January 2021.

Payables consisted of payables due to the following related parties:

	December 31,
(In millions)	2021		2020
Crescent Energy	$	2.7	$	—
Dofcon Navegacao	$	—	$	1.5
Arkema S.A.	0.9		0.5
Others	1.9		2.6
Total trade payables	$	5.5	$	4.6

Additionally, we have a note receivable balance of $12.6 million and $37.6 million with Dofcon Brasil AS as of December 31, 2021 and 2020, respectively. These are included in other assets in our consolidated balance sheets.

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Revenue consisted of amount from following related parties:

	Year Ended December 31,
(In millions)	2021		2020		2019
Equinor ASA	$	—	$	119.6	$	—
Anadarko Petroleum Company	—		—		67.1
TOP CV	—		—		11.9
Dofcon Navegacao	9.9		3.4		8.4
Techdof Brasil AS	15.8		11.2		8.3
Others	14.0		18.5		14.4
Total revenue	$	39.7	$	152.7	$	110.1

A member of our Board of Directors (the “Director”) served on the Board of Directors of Anadarko Petroleum Company (“Anadarko”) until August 2019. In August 2019, Anadarko was acquired by Occidental Petroleum Corporation (“Occidental”). As a result, the Director no longer serves as a member of the Board of Directors of Anadarko. The Director is not an officer or director of Occidental.

TOP CV was previously an equity method affiliate that became a fully consolidated subsidiary on December 30, 2019. See Note 3 for further details.

Expenses consisted of amounts to following related parties:

	Year Ended December 31,
(In millions)	2021		2020		2019
Arkema S.A.	$	3.8	$	1.5	$	3.8
Serimax Holdings SAS	7.6		0.4		17.7
Magma Global Limited	8.8		14.0		7.3
Jumbo Shipping	—		16.0		4.5
Dofcon Navegacao	26.7		24.0		1.8
Altus Intervention	—		3.6		1.8
Others	18.5		17.6		17.8
Total expenses	$	65.4	$	77.1	$	54.7

Serimax Holdings SAS is an equity method affiliate. Members of our Board of Directors served on the Board of Directors for Jumbo Shipping. Magma Global Limited was an equity method affiliate through September 30, 2021. In October 2021, we purchased the remaining ownership interest in Magma Global, see Note 3 for further details.

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NOTE 15. PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment consisted of the following: 

	December 31,
(In millions)	2021		2020
Land and land improvements	$	79.4	$	80.0
Buildings	471.6		514.6
Vessels	1,979.0		1,968.1
Machinery and equipment	1,849.0		1,871.8
Office fixtures and furniture	121.9		125.4
Construction in process	110.5		147.3
Other	189.8		203.2
	4,801.2		4,910.4
Accumulated depreciation	(2,204.0)		(2,154.2)
Property, plant and equipment, net	$	2,597.2	$	2,756.2

Depreciation expense was $291.3 million, $308.7 million and $363.0 million in 2021, 2020 and 2019, respectively. The amount of interest cost capitalized was not material for the years presented.

During 2021 and 2020, we determined the carrying amount of certain of our long-lived assets exceeded their fair value and recorded impairments. See Note 20 for further details.

NOTE 16. GOODWILL AND INTANGIBLE ASSETS

Goodwill - We record goodwill as the excess of the purchase price over the fair value of the net assets acquired in acquisitions accounted for under the purchase method of accounting. We test goodwill for impairment annually as of October 31 of each year, or more frequently if circumstances indicate possible impairment. We identify a potential impairment by comparing the fair value of the applicable reporting unit (which is consistent with our business segments) to its net book value, including goodwill. If the net book value exceeds the fair value of the reporting unit, we measure the impairment by comparing the carrying value of the reporting unit to its fair value.

We test our goodwill for impairment by comparing the fair value of each of our reporting units to their net carrying value. Our impairment analysis is quantitative; however, it includes subjective estimates based on assumptions regarding future growth rates, interest rates and operating expenses.

The income approach estimates fair value by discounting each reporting unit’s estimated future cash flows using a weighted-average cost of capital that reflects current market conditions and the risk profile of the reporting unit. To arrive at our future cash flows, we use estimates of economic and market assumptions, including growth rates in revenues, costs, estimates of future expected changes in operating margins, tax rates and capital expenditures. Future revenues are also adjusted to match changes in our business strategy. We believe this approach is an appropriate valuation method. Under the market multiple approach, we determine the estimated fair value of each of our reporting units by applying transaction multiples to each reporting unit’s projected EBITDA and then averaging that estimate with similar historical calculations using either a one, two or three year average. Our reporting unit valuations were determined primarily by utilizing the income approach and the market multiple approach.

During the first quarter of 2020, triggering events were identified which led to performing interim goodwill impairment testing in our reporting units as of March 31, 2020. These events included the COVID-19 pandemic breakout, commodity price declines, and a significant decrease in our market capitalization as well as those of our peers and customers. The fair value for our reporting units for the interim testing was valued using a market approach. An appropriate control premium was considered for each of the reporting units and applied to the output of the market approach. An interim impairment test during the first quarter of 2020 resulted in $2,747.5 million and $335.9 million of goodwill impairment charges recorded in our Subsea and Surface Technologies segments, respectively. Subsequent to the charges, we do not have any goodwill recorded in either of our segment.

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The carrying amount of goodwill by reporting segment was as follows:

(In millions)	Subsea		Surface Technologies		Total
December 31, 2019	$	2,792.8	$	335.7	$	3,128.5
Impairments	(2,747.5)		(335.9)		(3,083.4)
Translation	(45.3)		0.2		(45.1)
December 31, 2020	$	—	$	—	$	—

Intangible assets - The components of intangible assets were as follows:

	December 31,
	2021				2020
(In millions)	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
Acquired technology	$	247.0	$	122.4	$	247.1	$	98.1
Customer relationships	285.4		142.9		285.3		114.4
Licenses, patents and trademarks	694.6		220.7		690.3		189.3
Software	108.2		84.8		111.3		81.1
Other	54.0		4.7		10.4		10.2
Total intangible assets	$	1,389.2	$	575.5	$	1,344.4	$	493.1

We recorded $94.1 million, $103.4 million and $104.7 million in amortization expense related to intangible assets during the years ended December 31, 2021, 2020 and 2019, respectively. During the years 2022 through 2026, annual amortization expense is expected to be $87 million in each of the five years and $351 million thereafter in the aggregate.

NOTE 17. DEBT

Overview

Long-term debt consisted of the following:

	December 31,
(In millions)	2021		2020
Commercial paper	$	—	$	1,043.7
Synthetic bonds due 2021	—		551.2
3.45% Senior Notes due 2022	—		500.0
3.40% 2012 Private placement notes due 2022	169.9		184.0
3.15% 2013 Private placement notes due 2023	288.8		312.9
5.75% 2020 Private placement notes due 2025	226.5		245.4
6.50% Senior notes due 2026	633.1		—
4.00% 2012 Private placement notes due 2027	84.9		92.0
4.00% 2012 Private placement notes due 2032	113.3		122.7
3.75% 2013 Private placement notes due 2033	113.3		122.7
Bank borrowings and other	397.4		298.4
Unamortized debt issuance costs and discounts	(22.3)		(12.8)
Total debt	2,004.9		3,460.2
Less: current borrowings	277.6		624.7
Long-term debt	$	1,727.3	$	2,835.5

Debt maturities as of December 31, 2021, are as follows:

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	Payments Due by Period
(In millions)	Total payments		Less than 1 year		1-3 years		3-5 years		After 5 years
Total debt	$	2,004.9	$	277.6	$	402.1	$	942.9	$	382.3

Debt Financing Transactions in Connection with the Spin-off

In connection with the Spin-off, we executed a series of refinancing transactions, in order to provide a capital structure with sufficient cash resources to support future operating and investment plans.

Debt Issuance

•On February 16, 2021, we entered into a credit agreement, which provides for a $1.0 billion three-year senior secured multi-currency revolving credit facility (“Revolving Credit Facility”) including a $450.0 million letter of credit sub-facility; and

•On January 29, 2021, we issued $1.0 billion of 6.50% senior notes due 2026 (the “2021 Notes”).

Repayment of Debt

The proceeds from the debt issuance described above along with the available cash on hand, were used to fund:

•the repayment of all $542.4 million of the outstanding Synthetic Convertible Bonds that matured in January 2021;

•the repayment of all $500.0 million aggregate principal amount of outstanding 3.45% Senior Notes due 2022. In connection with the repayment, we recorded a loss on extinguishment of debt of $23.5 million related to the difference between the amount paid and the net carrying value of the debt; and

•the termination of the $2.5 billion senior unsecured revolving credit facility entered into on January 17, 2017; the termination of the €500.0 million Euro Facility entered into on May 19, 2020, and the termination of the CCFF Program entered into on May 19, 2020. In connection with the termination of these credit facilities, we repaid $830.9 million of the outstanding commercial paper borrowings.

Credit Facilities and Debt

Revolving Credit Facility - On February 16, 2021, we entered into a credit agreement, which provides for a $1.0 billion three-year senior secured multi-currency Revolving Credit Facility including a $450.0 million letter of credit sub-facility. We incurred $34.8 million of debt issuance costs in connection with the Revolving Credit Facility. These debt issuance costs are deferred and are included in other assets in our consolidated balance sheet as of December 31, 2021. The deferred debt issuance costs are amortized to interest expense over the term of the Revolving Credit Facility.

Availability of borrowings under the Revolving Credit Facility is reduced by the outstanding letters of credit issued against the facility. As of December 31, 2021, there were $16.7 million letters of credit outstanding and availability of borrowings under the Revolving Credit Facility was $983.3 million.

Borrowings under the Revolving Credit Facility bear interest at the following rates, plus an applicable margin, depending on currency:

•U.S. dollar-denominated loans bear interest, at the Company’s option, at a base rate or an adjusted rate linked to the London interbank offered rate (“Adjusted LIBOR”); and

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•Euro-denominated loans bear interest on an adjusted rate linked to the Euro interbank offered rate.

The applicable margin for borrowings under the Revolving Credit Facility ranges from 2.50% to 3.50% for Eurocurrency loans and 1.50% to 2.50% for base rate loans, depending on a total leverage ratio. The Revolving Credit Facility is subject to customary representations and warranties, covenants, events of default, mandatory repayment provisions and financial covenants.

2021 Notes - On January 29, 2021, we issued $1.0 billion of 6.50% senior notes due 2026. The interest on the 2021 Notes is paid semi-annually on February 1 and August 1 of each year, beginning on August 1, 2021. The 2021 Notes are senior unsecured obligations and are guaranteed on a senior unsecured basis by substantially all of our wholly-owned U.S. subsidiaries and non-U.S. subsidiaries in Brazil, the Netherlands, Norway, Singapore and the United Kingdom. We incurred $25.7 million of debt issuance costs in connection with issuance of the 2021 Notes. These debt issuance costs are deferred and are included in long-term debt in our consolidated balance sheet as of December 31, 2021. The deferred debt issuance costs are amortized to interest expense over the term of the 2021 Notes, which approximates the effective interest method.

During 2021, we completed two tender offers and purchased for cash $366.9 million of the outstanding 2021 Notes. We paid a cash premium of $29.5 million to the note holders who tendered and wrote-off $8.9 million of bond issuance costs.

As of December 31, 2021, we were in compliance with all debt covenants.

Commercial paper - As of December 31, 2021, we had no commercial paper outstanding. In accordance with the terms of the new Revolving Credit Facility, we do not have an ability to issue any new commercial paper notes going forward. As of December 31, 2020, our commercial paper borrowings had a weighted average interest rate of 0.34% on the U.S. dollar denominated borrowings. Commercial paper borrowings were issued at market interest rates. As of December 31, 2020, we had $225.8 million of outstanding commercial paper borrowings under this program.

Synthetic bonds - In 2016, we issued €450.0 million principal amount of 0.875% convertible bonds. Interest on the synthetic bonds was payable semi-annually in arrears on January 25 and July 25 of each year, beginning July 26, 2016. The synthetic bonds were repaid during the first quarter of 2021.

Senior Notes - As of December 31, 2020, we had outstanding 3.45% $500.0 million senior notes due October 1, 2022. The senior notes were redeemed during the first quarter of 2021.

Private Placement Notes

2020 Issuance:

During 2020, we completed the private placement of €200 million aggregate principal amount of the 2020 Private Placement Notes. The 2020 Private Placement Notes bear interest of 5.75% and are due June 2025. Prior to 2021, these notes had an interest of 4.50%. Interest on the notes is payable annually in arrears on June 30 of each year beginning June 30, 2020. The 2020 Private Placement Notes contain usual and customary covenants and events of default for notes of this type.

2013 Issuances:

In October 2013, we completed the private placement of €355.0 million aggregate principal amount of senior notes. The notes were issued in three tranches with €100.0 million bearing interest at 3.75% and due October 2033 (the “Tranche A 2033 Notes”), €130.0 million bearing interest of 3.15% and due October 2023 (the “Tranche B 2023 Notes) and €125.0 million bearing interest of 3.15% and due October 2023 (the “Tranche C 2023 Notes” and, collectively with the “Tranche A 2033 Notes and the “Tranche B 2023 Notes”, the “2013 Private Placement Notes”).

Interest on the Tranche A 2033 Notes is payable annually in arrears on October 7 each year, beginning October 7, 2014. Interest on the Tranche B 2023 Notes is payable annually in arrears on October 16 of each year beginning October 16, 2014. Interest on the Tranche C 2023 Notes is payable annually in arrears on October 18 of each year, beginning October 18, 2014.

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2012 Issuances:

In June 2012, we completed the private placement of €325.0 million aggregate principal amount of notes. The notes were issued in three tranches with €150.0 million bearing interest at 3.40% and due June 2022 (the “Tranche A 2022 Notes”), €75.0 million bearing interest of 4.0% and due June 2027 (the “Tranche B 2027 Notes”) and €100.0 million bearing interest of 4.0% and due June 2032 (the “Tranche C 2032 Notes” and, collectively with the “Tranche A 2022 Notes and the “Tranche B 2027 Notes,” the “2012 Private Placement Notes”). Interest on the Tranche A 2022 Notes and the Tranche C 2032 Notes is payable annually in arrears on June 14 of each year beginning June 14, 2013. Interest on the Tranche B 2027 Notes is payable annually in arrears on June 15 of each year, beginning June 15, 2013.

The 2013 and 2012 Private Placement Notes contain usual and customary covenants and events of default for notes of this type. In the event of a change of control resulting in a downgrade in the rating of the notes below BBB-, the 2013 and 2012 Private Placement Notes may be redeemed early at the request of any bondholder, at its sole discretion. The 2013 and 2012 Private Placement Notes are our unsecured obligations. The 2013 and 2012 Private Placement Notes will rank equally in right of payment with all of our existing and future unsubordinated debt.

Term loan - In December 2016, we entered into a £160.0 million term loan agreement to finance the Deep Explorer, a diving support vessel (“DSV”), maturing December 2028. Under the loan agreement, interest accrues at an annual rate of 2.813%. This loan agreement contains usual and customary covenants and events of default for loans of this type.

Bank borrowings - In January 2019, we executed a sale-leaseback transaction to finance the purchase of a deepwater dive support vessel, Deep Discoverer (the “Vessel”) for the full transaction price of $116.8 million. The sale-leaseback agreement (“Charter”) was entered into with a French joint-stock company, owned by Credit Industrial et Commercial (“CIC”) which was formed for the sole purpose to purchase and act as the lessor of the Vessel. It is a variable interest entity, which is fully consolidated in our consolidated financial statements. The transaction was funded through debt of $96.2 million which is primarily long-term, expiring on January 8, 2031.

Foreign committed credit - We have committed credit lines at many of our international subsidiaries for immaterial amounts. We utilize these facilities for asset financing and to provide a more efficient daily source of liquidity. The effective interest rates depend upon the local national market.

NOTE 18. STOCKHOLDERS’ EQUITY

Cash dividends paid during the years ended December 31, 2021, 2020 and 2019 were nil, $59.2 million and $232.8 million, respectively.

As an English public limited company, we are required under U.K. law to have available “distributable reserves” to conduct share repurchases or pay dividends to shareholders. Distributable reserves are a statutory requirement and are not linked to a GAAP reported amount (e.g., retained earnings). The declaration and payment of dividends require the authorization of our Board of Directors, provided that such dividends on issued share capital may be paid only out of our “distributable reserves” on our statutory balance sheet. Therefore, we are not permitted to pay dividends out of share capital, which includes share premium. On November 27, 2019, we redeemed 50,000 redeemable shares of £1 each and cancelled one deferred ordinary share of £1 in the capital of TechnipFMC.

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The following is a summary of our capital stock activity for the years ended December 31, 2021, 2020 and 2019:

(Number of shares in millions)	Ordinary Shares Issued	Ordinary Shares Held in  Employee Benefit Trust	Treasury Stock
December 31, 2018	450.5	0.1	—
Stock awards	0.6	—	—
Treasury stock purchases	—	—	4.0
Treasury stock cancellation	(4.0)	—	(4.0)
Net stock purchased for employee benefit trust	—	(0.1)	—
December 31, 2019	447.1	—	—
Stock awards	2.4	—	—
December 31, 2020	449.5	—	—
Stock awards	1.2	—	—
December 31, 2021	450.7	—	—

In 2017, the Board of Directors authorized a share repurchase program of up to $500.0 million in ordinary shares and in December 2018, the Board of Directors authorized an extension of the share repurchase program of up to $300.0 million of additional shares. During the years ended December 31, 2021, 2020 and 2019, we repurchased nil, nil and $92.7 million of shares, respectively. As of December 31, 2021, we had $207.8 million of shares authorized for repurchase. Repurchased shares are canceled and not held in treasury. Canceled treasury shares are accounted for using the constructive retirement method.

Accumulated other comprehensive income (loss) - Accumulated other comprehensive income (loss) consisted of the following:

(In millions)	Foreign Currency Translation		Hedging		Defined Pension  and Other Post-Retirement Benefits		Accumulated Other Comprehensive  Loss Attributable to TechnipFMC plc		Accumulated Other Comprehensive  Loss Attributable to Non-Controlling Interest
December 31, 2019	$	(1,230.1)	$	(5.8)	$	(171.6)	$	(1,407.5)	$	(4.7)
Other comprehensive income (loss) before reclassifications, net of tax	(171.1)		26.8		(92.9)		(237.2)		0.6
Reclassification adjustment for net (gains) losses included in net income, net of tax	—		13.0		9.2		22.2		—
Other comprehensive income (loss), net of tax	(171.1)		39.8		(83.7)		(215.0)		0.6
December 31, 2020	$	(1,401.2)	$	34.0	$	(255.3)	$	(1,622.5)	$	(4.1)
Other comprehensive income (loss) before reclassifications, net of tax	29.2		(19.8)		70.8		80.2		(1.6)
Reclassification adjustment for net (gains) losses included in net income, net of tax	—		(11.8)		18.0		6.2		—
Other comprehensive income (loss), net of tax	29.2		(31.6)		88.8		86.4		(1.6)
Spin-off of Technip Energies	213.6		(19.7)		37.2		231.1		—
December 31, 2021	$	(1,158.4)	$	(17.3)	$	(129.3)	$	(1,305.0)	$	(5.7)

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Reclassifications out of accumulated other comprehensive income (loss) - Reclassifications out of accumulated other comprehensive income (loss) consisted of the following:

	Year Ended December 31,
(In millions)	2021		2020		2019
Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified out of Accumulated Other Comprehensive Loss						Affected Line Item in the Consolidated Statement of Income
Gains on foreign currency translation	$	—	$	—	$	12.0	Other income (expense), net
Gains (losses) on hedging instruments
Foreign exchange contracts	$	(29.7)	$	(83.7)	$	(26.6)	Revenue
	10.7		68.5		12.0		Costs of sales
	0.2		(0.4)		—		Selling, general and administrative expense
	32.9		(4.4)		(9.1)		Other Income (expense), net
	14.1		(20.0)		(23.7)		Income (loss) before income taxes
	2.3		(7.0)		(5.5)		Provision (benefit) for income taxes
	$	11.8	$	(13.0)	$	(18.2)	Net income (loss)
Pension and other post-retirement benefits
Settlements and curtailments	$	(3.3)	$	(2.2)	$	(0.3)	(a)
Amortization of actuarial gain (loss)	(18.2)		(9.0)		(2.5)		(a)
Amortization of prior service credit (cost)	(0.5)		(1.2)		(1.0)		(a)
	(22.0)		(12.4)		(3.8)		Income (loss) before income taxes
	(4.0)		(3.2)		(0.8)		Provision (benefit) for income taxes
	$	(18.0)	$	(9.2)	$	(3.0)	Net income (loss)

(a)    These accumulated other comprehensive income components are included in the computation of net periodic pension cost (See Note 23 for further details).

NOTE 19. SHARE-BASED COMPENSATION

Incentive compensation and award plan - On January 11, 2017, we adopted the TechnipFMC plc Incentive Award Plan (the “Plan”). The Plan provides certain incentives and awards to officers, employees, non-employee directors and consultants of TechnipFMC and its subsidiaries. The Plan allows our Board of Directors to make various types of awards to non-employee directors and the Compensation Committee (the “Committee”) of the Board of Directors to make various types of awards to other eligible individuals. Awards may include share options, share appreciation rights, performance share units, restricted share units, restricted shares or other awards authorized under the Plan. All awards are subject to the Plan’s provisions, including all share-based grants previously issued prior to consummation of the merger of FMC Technologies and Technip S.A. (the “Merger”). Under the Plan, 24.1 million ordinary shares were authorized for awards in 2017. On the record date of the Spin-off, 11.9 million shares remained available under the Plan, which were adjusted to reflect the Spin-off using an adjustment ratio, calculated as the ratio of the closing price of shares of TechnipFMC on the NYSE on the date immediately after the Spin-off. After this adjustment, 15.2 million ordinary shares remained authorized for awards under the Plan as of February 17, 2021. As of  December 31, 2021, 7.8 million ordinary shares were available for future grant

The exercise price for options is determined by the Committee but cannot be less than the fair market value of our ordinary shares at the grant date. Restricted share and performance share unit grants generally vest after three years of service.

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Under the Plan, our Board of Directors has the authority to grant non-employee directors share options, restricted shares, restricted share units and performance shares. Unless otherwise determined by our Board of Directors, awards to non-employee directors generally vest one year from the date of grant. All restricted share units awarded prior to 2020 will be settled when a non-executive director ceases services on the Board of Directors. Beginning with the 2020 equity award, non-executive directors now have the opportunity to elect the year in which they will take receipt of the equity grants from either (a) a period of 1 to 10 years from the grant date or (b) upon their separation from Board service. The elections are made prior to the beginning of the grant year and are irrevocable after December 31 of the year prior to grant. Restricted share units are settled when a director ceases services to the Board of Directors. As of December 31, 2021, outstanding awards to active and retired non-employee directors included 184.6 thousand of share units.

The measurement of share-based compensation expense on restricted share awards is based on the market price and fair value at the grant date and the number of shares awarded. The fair value of performance shares is estimated using a combination of the closing stock price on the grant date and the Monte Carlo simulation model. We use Black-Scholes options pricing model to measure the fair value of stock options granted on or after January 1, 2017.

The share-based compensation expense for each award is recognized ratably over the applicable service period or the period beginning at the start of the service period and ending when an employee becomes eligible for retirement (currently age 62 under the Plan), after taking into account estimated forfeitures.

We recognize compensation expense and the corresponding tax benefits for awards under the Plan. The compensation expense under the Plan for continuing operations was as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Share-based compensation expense	$	26.8	$	38.3	$	44.4
Income tax benefits related to share-based compensation expense	7.2		10.3		12.0

In connection with the Spin-off and in accordance with the employee matters agreement, TechnipFMC has made certain adjustments to the exercise price and the number of share-based compensation awards. Share options and restricted share units were modified and converted into similar awards of the entity where the employee is working post the Spin-off using an adjustment ratio with the intention of preserving the intrinsic value of the awards prior to the Spin-off. Performance share units have been modified and converted to restricted share units at the target value using the adjustment ratio. The pre-tax share-based compensation expense due to the adjustments was $5.2 million in fiscal year 2021. All outstanding share awards and share options for employees transferred to Technip Energies were cancelled in connection with the Spin-off.

Additionally, in connection with the Spin-off, the Board of Directors approved amendments to certain outstanding long-term incentive awards on January 28, 2021. The amendments provided for the accelerated vesting on February 2, 2021 of certain stock-based awards that were otherwise scheduled to vest between June 1, 2021 and November 31, 2021.

As of December 31, 2021, the portion of share-based compensation expense related to outstanding awards to be recognized in future periods is as follows:

	December 31, 2021
Share-based compensation expense not yet recognized (in millions)	$	51.6
Weighted-average recognition period (in years)	1.4

Restricted Share Units

A summary of the non-vested restricted share units’ activity is as follows:

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(Shares in thousands)	Shares	Weighted-Average  Grant Date  Fair Value
Non-vested as of December 31, 2020	6,121.9	$	18.43
Granted	2,893.0	$	7.97
Vested	(667.1)	$	37.57
Cancelled/forfeited	(882.6)	$	13.75
Adjustment due to the Spin-off	2,124.3	$	12.37
Non-vested as of December 31, 2021	9,589.5	$	11.35

The total grant date fair value of restricted stock share units vested during the years ended December 31, 2021, 2020 and 2019 was $25.1 million, $51.8 million and $10.2 million, respectively.

Performance Share Units

The Board of Directors has granted certain employees, senior executives and directors performance share units that vest subject to achieving satisfactory performances. For performance share units issued on or after January 1, 2017, performance is based on results of return on invested capital and total shareholder return (“TSR”).

For the performance share units which vest based on TSR, the fair value of performance shares is estimated using a combination of the closing stock price on the grant date and the Monte Carlo simulation model. The weighted-average fair value and the assumptions used to measure the fair value of performance share units subject to performance-adjusted vesting conditions in the Monte Carlo simulation model were as follows:

	Year Ended December 31,
	2021		2020		2019
Weighted-average fair value (a)	$11.50		$10.02		$29.04
Expected volatility (b)	62.70	%	38.30	%	34.00	%
Risk-free interest rate (c)	0.35	%	0.40	%	2.42	%
Expected performance period in years (d)	2.9		3.0		3.0

(a) The weighted-average fair value was based on performance share units granted during the period.

(b) Expected volatility is based on normalized historical volatility of our shares over a preceding period commensurate with the expected term of the performance share units.

(c) The risk-free rate for the expected term of the performance share units is based on the U.S. Treasury yield curve in effect at the time of grant.

(d) For awards subject to service-based vesting, due to the lack of historical exercise and post-vesting termination patterns of the post-Merger employee base, the expected term was estimated using a simplified method for all awards granted in 2021, 2020 and 2019.

A summary of the non-vested performance share units’ activity is as follows:

(Shares in thousands)	Shares	Weighted-Average  Grant Date  Fair Value
Non-vested as of December 31, 2020	4,840.7	$	17.55
Granted	2,426.2	$	11.50
Vested	(111.3)	$	30.42
Cancelled/forfeited	(1,723.2)	$	16.03
Adjustment due to the Spin-off	(3,122.8)	$	12.37
Non-vested as of December 31, 2021	2,309.6	$	13.26

The total grant date fair value of performance share units vested during years ended December 31, 2021, 2020 and 2019 was $3.4 million, $43.2 million and $13.3 million, respectively.

Share Option Awards

The fair value of each share option award is estimated as of the date of grant using the Black-Scholes options pricing model.

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Share options awarded prior to 2017 were granted subject to performance criteria based upon certain targets, such as TSR, return on capital employed, and operating income from recurring activities. Subsequent share options granted are time-based awards vesting over three years.

There were no share option awards granted in 2021 or 2020. The weighted-average fair value and the assumptions used to measure fair value of 2019 grant were as follows:

	December 31, 2019
Weighted-average fair value (a)	$	5.64
Expected volatility (b)	32.5		%
Risk-free interest rate (c)	2.5		%
Expected dividend yield	2.6		%
Expected term in years (d)	6.5

(a)The weighted-average fair value was based on stock options granted during the period.

(b)Expected volatility is based on normalized historical volatility of our shares over a preceding period commensurate with the expected term of the option.

(c)The risk-free rate for the expected term of the option is based on the U.S. Treasury yield curve in effect at the time of grant.

(d)For awards subject to service-based vesting, due to the lack of historical exercise and post-vesting termination patterns of the post-Merger employee base, the expected term was estimated using a simplified method for all awards granted in 2019.

The following is a summary of share option transactions during the year ended December 31, 2021:

	Number of Shares	Weighted average exercise price		Weighted average remaining life (in years)
Balance as of December 31, 2020	4,598.4	$	29.77	4.2
Granted	—	$	—
Exercised	—	$	—
Cancelled	(532.0)	$	24.10
Adjustment due to the Spin-off	(2,490.3)	$	—
Balance as of December 31, 2021	1,576.1	$	20.17	6.3
Exercisable as of December 31, 2021	939.3	$	22.99	5.6

The aggregate intrinsic value of stock options outstanding and stock options exercisable as of December 31, 2021 was nil and nil, respectively.

Cash received from the share option exercises was nil, during each of the years ended December 31, 2021, 2020 and 2019. The total intrinsic value of share options exercised during each of the years ended December 31, 2021, 2020 and 2019 was nil. To exercise share options, an employee may choose (1) to pay, either directly or by way of the group savings plan, the share option strike price to obtain shares, or (2) to sell the shares immediately after having exercised the share option (in this case, the employee does not pay the strike price but instead receives the intrinsic value of the share options in cash).

The following summarizes significant ranges of outstanding and exercisable share options as of December 31, 2021:

	Options Outstanding				Options Exercisable
Exercise Price Range	Number of options (in thousands)	Weighted average remaining life (in years)	Weighted average exercise price		Number of options (in thousands)	Weighted average exercise price
$16.00-$19.00	636.7	7.2	$	16.46	—	$	—
$20.00-$24.00	721.2	5.6	$	22.28	721.2	$	22.28
$25.00-$26.00	218.2	5.6	$	25.32	218.1	$	25.32
Total	1,576.1	6.3	$	20.17	939.3	$	22.99

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NOTE 20. IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES

Impairment, restructuring and other expenses were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Subsea	$	53.5	$	2,957.5	$	1,748.4
Surface Technologies	7.6		440.2		704.2
Corporate and other	5.6		4.3		4.1
Total impairment, restructuring and other expenses	$	66.7	$	3,402.0	$	2,456.7

Goodwill and Long-Lived Assets Impairments

Goodwill and long-lived assets impairments were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Subsea	$	44.2	$	2,854.5	$	1,794.8
Surface Technologies	1.9		419.3		685.5
Corporate and other	3.0		—		—
Total impairments	$	49.1	$	3,273.8	$	2,480.3

Subsequent to the Spin-off, certain real estate rationalization actions were taken, and as a result, we recorded $24.2 million of impairment charges relating to our operating lease right-of-use assets and $24.9 million of impairment of property, plant and equipment during the year ended December 31, 2021.

Due to the substantial decline in global demand for oil caused by the COVID-19 pandemic in 2020 we reviewed the future utilization of our vessels and service potential of our subsea service and surface equipment and determined that the carrying amount of our goodwill and some of our long-lived assets exceeded their respective fair values. We recorded $3,083.4 million and $190.4 million, respectively, related to goodwill and long-lived assets impairments. The $190.4 million of long-lived asset impairments during the year ended December 31, 2020 consisted of $88.4 million attributable to plant, equipment and various machinery infrastructure in our Subsea operating segment; $82.0 million mainly related to building and surface equipment in our Surface Technologies reportable segment; and $20.0 million of operating lease right-of-use assets impairments.

The prolonged downturn in the energy market and its corresponding impact on our business outlook in 2019 led us to conclude the carrying amount of certain of our assets in our Subsea and Surface Technologies segments exceeded their fair value as of December 31, 2019. During the 2019 year we recorded $1,988.7 million and $491.6 million, respectively, related to goodwill and long-lived assets impairments. The $491.6 million of long-lived asset impairments during the year ended December 31, 2019, primarily consisted of $153.8 million related to vessels in our Subsea operating segment and $168.9 million related to our flexible pipe and umbilical manufacturing facilities in our Surface Technologies reportable segment due to the prolonged downturn in the energy market and its corresponding impact on our business outlook.

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that carrying amounts of such assets may not be recoverable. Assessing the recoverability of assets to be held and used requires the use of unobservable inputs, which involves significant judgment. Such judgments include expected future asset utilization while taking into account reduced future capital spending by certain customers in response to market conditions.

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Restructuring and Other Expenses

Restructuring and other charges primarily consisted of severance and other employee related costs and COVID-19 related expenses across all segments. Restructuring and other expenses were as follows:

	Year Ended December 31,
	2021		2020				2019
(In millions)	Restructuring and other charges		Restructuring and other charges		COVID-19 expenses		Restructuring and other charges
Subsea	$	9.3	$	52.9	$	50.1	$	(46.4)
Surface Technologies	5.7		13.2		7.7		18.7
Corporate and other	2.6		4.3		—		4.1
Total	$	17.6	$	70.4	$	57.8	$	(23.6)

COVID-19 related expenses represent unplanned, one-off, incremental and non-recoverable costs incurred solely as a result of the COVID-19 pandemic situation, which would not have been incurred otherwise. COVID-19 related expenses primarily included (a) employee payroll and travel, operational disruptions associated with quarantining, personnel travel restrictions to job sites, and shutdown of manufacturing plants and sites; (b) supply chain and related expediting costs of accelerated shipments for previously ordered and undelivered products; (c) costs associated with implementing additional information technology to support remote working environments; and (d) facilities-related expenses to ensure safe working environments.

Prolonged uncertainty in energy markets could lead to further future reductions in capital spending from our customer base. In turn, this may lead to changes in our strategy. We will continue to take actions designed to mitigate the adverse effects of the rapidly changing market environment and expect to continue to adjust our cost structure to market conditions. If market conditions continue to deteriorate, we may record additional restructuring charges and additional impairments of our long-lived assets, operating lease right-of-use assets and equity method investments.

NOTE 21. COMMITMENTS AND CONTINGENT LIABILITIES

Contingent liabilities associated with guarantees - In the ordinary course of business, we enter into standby letters of credit, performance bonds, surety bonds, and other guarantees with financial institutions for the benefit of our customers, vendors, and other parties. The majority of these financial instruments expire within five years. Management does not expect any of these financial instruments to result in losses that, if incurred, would have a material adverse effect on our consolidated financial position, results of operations, or cash flows.

Guarantees made by our consolidated subsidiaries consisted of the following:

(In millions)	December 31, 2021
Financial guarantees (a)	$	177.4
Performance guarantees (b)	1,069.0
Maximum potential undiscounted payments	$	1,246.4

(a)Financial guarantees represent contracts that contingently require a guarantor to make payments to a guaranteed party based on changes in an underlying agreement that is related to an asset, a liability or an equity security of the guaranteed party. These tend to be drawn down only if there is a failure to fulfill our financial obligations.

(b)Performance guarantees represent contracts that contingently require a guarantor to make payments to a guaranteed party based on another entity's failure to perform under a nonfinancial obligating agreement. Events that trigger payment are performance-related, such as failure to ship a product or provide a service.

We believe the ultimate resolution of our known contingencies will not materially adversely affect our consolidated financial position, results of operations, or cash flows.

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Contingent liabilities associated with legal and tax matters - We are involved in various pending or potential legal and tax actions or disputes in the ordinary course of our business. These actions and disputes can involve our agents, suppliers, clients, and venture partners, and can include claims related to payment of fees, service quality, and ownership arrangements, including certain put or call options. We are unable to predict the ultimate outcome of these actions because of their inherent uncertainty. However, we believe that the most probable, ultimate resolution of these matters will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.

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 U.S. Foreign Corrupt Practices Act (“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 we have also raised with the DOJ certain other projects performed by Technip S.A. subsidiaries in Brazil between 2002 and 2013. The DOJ has 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.

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 will not be required to have a monitor and will, instead, provide 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 will also provide the DOJ reports on our anti-corruption program during the term of the DPA.

In Brazil, 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 have committed, as part of those agreements, to make certain enhancements to their compliance programs in Brazil during a two-year self-reporting period, which aligns 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.

To date, the investigation by 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 recently 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, 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 anticorruption 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.

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Contingent liabilities associated with liquidated damages - Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a conforming claim under these provisions. These contracts define the conditions under which our customers may make claims against us for liquidated damages. Based upon the evaluation of our performance and other commercial and legal analysis, management believes we have appropriately recognized probable liquidated damages as of December 31, 2021 and 2020, and that the ultimate resolution of such matters will not materially affect our consolidated financial position, results of operations, or cash flows.

NOTE 22. INCOME TAXES

Components of income (loss) from continuing operations before income taxes - U.S. and outside U.S. components of income (loss) from continuing operations before income taxes were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
United States	$	(288.2)	$	(2,169.3)	$	(2,376.4)
Outside United States	486.3		(1,329.4)		(194.7)
Income (loss) from continuing operations before income taxes	$	198.1	$	(3,498.7)	$	(2,571.1)

Provision (benefit) for income tax - The provision for income taxes consisted of:

	Year Ended December 31,
(In millions)	2021		2020		2019
Current
United States	$	0.2	$	(18.3)	$	39.1
Outside United States	206.0		69.5		12.0
Total current income taxes	206.2		51.2		51.1
Deferred
United States	—		(2.8)		3.8
Outside United States	(95.1)		(29.0)		24.1
Total deferred income taxes	(95.1)		(31.8)		27.9
Provision for income taxes	$	111.1	$	19.4	$	79.0

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Deferred tax assets and liabilities - Significant components of deferred tax assets and liabilities were as follows: 

	December 31,
(In millions)	2021		2020
Deferred tax assets attributable to
Accrued expenses	$	173.0	$	133.0
Capital loss	21.1		21.1
Non-deductible interest	95.4		77.0
Foreign tax credit carryforwards	136.5		134.4
Other tax credits	146.0		163.8
Net operating loss carryforwards	455.5		383.5
Inventories	1.2		16.6
Research and development credit	3.8		2.9
Foreign exchange	17.2		—
Provisions for pensions and other long-term employee benefits	31.9		66.1
Contingencies	38.3		2.9
Margin recognition on construction contracts	18.0		20.6
Leases	183.4		170.4
Other	5.4		0.6
Deferred tax assets	1,326.7		1,192.9
Valuation allowance	(935.5)		(815.1)
Deferred tax assets, net of valuation allowance	391.2		377.8
Deferred tax liabilities attributable to
Revenue in excess of billings on contracts accounted for under the percentage of completion method	32.2		33.6
U.S. tax on foreign subsidiaries’ undistributed earnings not indefinitely reinvested	—		4.2
Property, plant and equipment, intangibles and other assets	162.8		180.1
Foreign exchange	—		43.9
Leases	169.4		161.1
Deferred tax liabilities	364.4		422.9
Net deferred tax assets/(liabilities)	$	26.8	$	(45.1)

At December 31, 2021 and 2020, the carrying amount of net deferred tax assets and the related valuation allowance included the impact of foreign currency translation adjustments.

Non-deductible interest. At December 31, 2021, deferred tax assets include tax benefits related to certain intercompany interest costs which are not currently deductible, but which may be deductible in future periods. If not utilized, these costs will become permanently non-deductible beginning in 2025. Management believes that it is more likely than not that we will not be able to deduct these costs before expiration of the carry forward period; therefore, we have established an uncertain tax position and valuation allowance against the related deferred tax assets.

Foreign tax credit carryforwards. At December 31, 2021, deferred tax assets included U.S. foreign tax credit carryforwards of $136.5 million, which, if not utilized, will begin to expire in 2023. Realization of these deferred tax assets is dependent on the generation of sufficient U.S. taxable income prior to the above date. Based on long-term forecasts of operating results, management believes that it is more likely than not that our U.S. earnings over the forecast period will not result in sufficient U.S. taxable income to fully realize these deferred tax assets; therefore, we have established a valuation allowance against the related deferred tax assets. In its analysis, management has considered the effect of deemed dividends and other expected adjustments to U.S. earnings that are required in determining U.S. taxable income. Non-U.S. earnings subject to U.S. tax, including deemed dividends for U.S. tax purposes, were $19.5 million in 2021, $0.1 million in 2020 and $21.4 million in 2019.

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Net operating loss carryforwards. At December 31, 2021, we had $455.5 million of tax-effected net operating loss carryforwards, with approximately $23.5 million estimated to be utilized against our unrecognized tax benefits. The ultimate realization of these deferred tax assets depends on our ability to generate sufficient taxable income in the appropriate taxing jurisdiction. Our deferred tax assets from net operating losses will expire as follows:

(In millions)	Net Operating Loss
2022 – 2026	$	55.4
2027 – 2031	42.0
2032 – 2042	70.1
Non-Expiring	288.0
	$	455.5

Unrecognized tax benefits - The following table presents a summary of changes in our unrecognized tax benefits: 

(In millions)	Federal, State and Foreign Tax
Balance at December 31, 2019	$	57.6
Reductions for tax positions related to prior years	(7.9)
Reductions for tax positions related to current year	(2.9)
Reductions for tax positions due to settlements	(0.6)
Balance at December 31, 2020	46.2
Reductions for tax positions related to prior years	(15.2)
Additions for tax positions related to current year	39.9
Reductions for tax positions due to settlements	(2.1)
Balance at December 31, 2021	$	68.8

The amounts reported above for uncertain tax positions excludes interest and penalties of $0.2 million, $0.6 million, and nil for the years ended December 31, 2021, 2020, and 2019, respectively. Interest and penalties relating to these uncertain tax positions were included in income tax expense in our consolidated statements of income. It is reasonably possible that within twelve months, $14.3 million of assets for unrecognized tax benefits will be settled. This amount is reflected in income taxes payable, the remaining balance of the unrecognized tax benefit is recorded in other long term liabilities. As of December 31, 2021, a net $32.5 million unrecognized tax benefit, without a net operating loss carryforward or other deferred tax asset to offset, would positively impact the effective tax rate and be recognized as additional tax benefits in our statement of operations if resolved in our favor.

We operate in numerous jurisdictions around the world and could be subject to multiple tax audits at any given time. Most notably, the following tax years and thereafter remain subject to examination: 2012 for Norway, 2016 for Nigeria, 2017 for Brazil, 2019 for France, and 2018 for the United States.

TechnipFMC plc is a public limited company incorporated under the laws of England and Wales. Therefore, our earnings are subject to the U.K. statutory rate which is 19.0% for 2021, 2020, and 2019.

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Effective income tax rate reconciliation - The effective income tax rate was different from the statutory U.K. income tax rate due to the following:

	Year Ended December 31,
	2021		2020		2019
Statutory income tax rate	19.0	%	19.0	%	19.0	%
Net difference resulting from
Foreign earnings subject to different tax rates	24.4	%	1.3	%	3.4	%
Adjustments to prior year taxes	(52.4)	%	(1.2)	%	0.8	%
Net change in unrecognized tax benefits	12.3	%	—	%	—	%
Changes in valuation allowance	65.4	%	(0.9)	%	(7.2)	%
Deferred tax asset/liability revaluation for tax rate change	(12.2)	%	0.3	%	(0.4)	%
Impairments	—	%	(19.5)	%	(19.7)	%
Non-deductible legal provision	—	%	0.3	%	1.1	%
Other	(0.4)	%	0.1	%	(0.1)	%
Effective income tax rate	56.1	%	(0.6)	%	(3.1)	%

Income tax holidays. We did not benefit from income tax holidays in 2021.

NOTE 23. PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS

We have funded and unfunded defined benefit pension plans, which provide defined benefits based on years of service and final average salary.

On December 31, 2017, we amended the U.S. retirement plans (the “Plans”) to freeze benefit accruals for all participants of the Plans as of December 31, 2017. After that date, participants in the Plans will no longer accrue any further benefits and participants’ benefits under the Plans will be determined based on credited service and eligible earnings as of December 31, 2017.

Foreign-based employees are eligible to participate in TechnipFMC-sponsored or government-sponsored benefit plans to which we contribute. Several of the foreign defined benefit pension plans sponsored by us provide for employee contributions; the remaining plans are noncontributory. The most significant of these plans are in the Netherlands, France, and the United Kingdom.

We have other post-retirement benefit plans covering substantially all of our U.S. unionized employees. The post-retirement health care plans are contributory; the post-retirement life insurance plans are noncontributory.

We are required to recognize the funded status of defined benefit post-retirement plans as an asset or liability in the consolidated balance sheet and recognize changes in that funded status in comprehensive income (loss) in the year in which the changes occur. Further, we are required to measure the plan’s assets and its obligations that determine its funded status as of the date of the consolidated balance sheet. We have applied this guidance to our domestic pension and other post-retirement benefit plans as well as for many of our non-U.S. plans, including those in the United Kingdom, Germany, France and Canada. Pension expense measured in compliance with GAAP for the other non-U.S. pension plans is not materially different from the locally reported pension expense.

In connection with the Spin-off, certain international plans were transferred to Technip Energies and reported as discontinued operations for the years ended December 31, 2020 and 2019.

The funded status of our U.S. Pension Plans, certain foreign pension plans and U.S. post-retirement health care and life insurance benefit plans, together with the associated balances recognized in our consolidated balance sheets as of December 31, 2021 and 2020, were as follows:

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	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Accumulated benefit obligation	$	653.6	$	589.1	$	684.7	$	598.1
Projected benefit obligation at January 1	$	684.7	$	656.4	$	669.7	$	585.1	$	9.4	$	10.2
Service cost	—		10.0		—		10.4		—		—
Interest cost	18.0		9.8		22.2		11.3		0.3		0.4
Actuarial (gain) loss	7.1		(32.5)		53.9		30.4		(0.7)		(0.2)
Settlements	(22.6)		—		(25.6)		(2.6)		—		—
Foreign currency exchange rate changes	—		(11.9)		—		23.6		(0.2)		(0.6)
Plan participants’ contributions	—		0.9		—		1.1		—		—
Benefits paid	(33.6)		(22.0)		(35.5)		(17.8)		(0.4)		(0.4)
Other	—		(9.1)		—		14.9		—		—
Projected benefit obligation as of December 31	653.6		601.6		684.7		656.4		8.4		9.4
Fair value of plan assets at January 1	483.7		591.5		520.0		521.2		—		—
Actual return on plan assets	61.1		46.4		14.3		40.1		—		—
Company contributions	28.9		19.6		—		27.1		—		—
Foreign currency exchange rate changes	—		(8.9)		—		20.4		—		—
Settlements	(22.6)		—		(19.6)		(1.9)		—		—
Plan participants’ contributions	—		0.9		—		1.1		—		—
Benefits paid	(33.6)		(22.0)		(31.0)		(15.8)		—		—
Other	—		—		—		(0.7)		—		—
Fair value of plan assets as of December 31	517.5		627.5		483.7		591.5		—		—
Funded status of the plans (liability) as of December 31	$	(136.1)	$	25.9	$	(201.0)	$	(64.9)	$	(8.4)	$	(9.4)

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Current portion of accrued pension and other post-retirement benefits	$	(2.9)	$	(1.7)	$	(4.6)	$	(1.6)	$	(0.6)	$	(0.7)
Accrued pension and other post-retirement benefits, net of current portion	(133.2)		27.6		(196.4)		(63.3)		(7.8)		(8.7)
Funded status as of December 31	$	(136.1)	$	25.9	$	(201.0)	$	(64.9)	$	(8.4)	$	(9.4)

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The following table summarizes the pre-tax amounts in accumulated other comprehensive (income) loss as of December 31, 2021 and 2020 that have not been recognized as components of net periodic benefit cost:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Pre-tax amounts recognized in accumulated other comprehensive (income) loss
Unrecognized actuarial loss	$	156.6	$	15.9	$	198.4	$	79.1	$	0.4	$	1.3
Unrecognized prior service cost	—		3.4		—		3.9		—		—
Accumulated other comprehensive (income) loss as of December 31	$	156.6	$	19.3	$	198.4	$	83.0	$	0.4	$	1.3

The following tables summarize the projected and accumulated benefit obligations and fair values of plan assets where the projected or accumulated benefit obligation exceeds the fair value of plan assets as of December 31, 2021 and 2020:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Plans with underfunded or non-funded projected benefit obligation
Aggregate projected benefit obligation	$	652.2	$	57.9	$	684.7	$	513.1	$	8.4	$	9.4
Aggregate fair value of plan assets	$	516.0	$	—	$	483.7	$	442.7	$	—	$	—

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Plans with underfunded or non-funded accumulated benefit obligation
Aggregate accumulated benefit obligation	$	652.2	$	46.7	$	684.7	$	50.8	$	—	$	—
Aggregate fair value of plan assets	$	516.0	$	—	$	483.7	$	—	$	—	$	—

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The following table summarizes the components of net periodic benefit cost (income) for the years ended December 31, 2021, 2020 and 2019:

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
(In millions)	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Components of net periodic benefit cost (income)
Service cost	$	—	$	10.0	$	—	$	10.4	$	—	$	7.0	$	—	$	—	$	—
Interest cost	18.0		9.8		22.2		11.3		25.6		13.7		0.3		0.4		0.5
Expected return on plan assets	(31.9)		(25.0)		(45.4)		(36.5)		(41.6)		(31.3)		—		—		—
Settlement cost	2.8		—		1.4		0.5		—		—		—		—		—
Curtailment benefit	—		0.4		—		—		—		—		—		—		—
Amortization of net actuarial loss (gain)	16.8		1.4		6.9		0.6		1.8		0.3		0.1		0.1		—
Amortization of prior service cost (credit)	—		0.5		—		0.6		—		0.4		—		—		—
Net periodic benefit cost (income)	$	5.7	$	(2.9)	$	(14.9)	$	(13.1)	$	(14.2)	$	(9.9)	$	0.4	$	0.5	$	0.5

The following table summarizes changes in plan assets and benefit obligations recognized in other comprehensive income (loss) for the years ended December 31, 2021, 2020 and 2019:

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
(In millions)	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Changes in plan assets and benefit obligations recognized in other comprehensive income (loss)
Net actuarial gain (loss) arising during period	$	(22.1)	$	(58.4)	$	(85.1)	$	(26.8)	$	(50.2)	$	(37.5)	$	—	$	—	$	—
Prior service (cost) credit arising during period	—		0.6		—		—		—		(0.9)		—		—		—
Settlements and curtailments	(2.8)		(0.4)		1.4		0.4		—		—		—		—		—
Amortization of net actuarial loss (gain)	(16.8)		(1.4)		6.9		0.6		1.8		0.3		—		(0.1)		—
Amortization of prior service cost (credit)	—		(0.5)		—		0.6		—		0.4		—		—		—
Other	—		—		—		(7.5)		—		(1.5)		(0.9)		(0.6)		1.5
Total recognized in other comprehensive income (loss)	$	(41.7)	$	(60.1)	$	(76.8)	$	(32.7)	$	(48.4)	$	(39.2)	$	(0.9)	$	(0.7)	$	1.5

Included in accumulated other comprehensive income (loss) as of December 31, 2021, are noncash, pre-tax charges which have not yet been recognized in net periodic benefit cost (income). The estimated amounts expected to be amortized from the portion of each component of accumulated other comprehensive income (loss) as a component of net period benefit cost (income), during the next fiscal year are as follows:

	Pensions				Other Post-retirement Benefits
(In millions)	U.S.		Int’l
Net actuarial losses	$	12.0	$	—	$	—
Prior service cost	$	—	$	0.4	$	—

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Key assumptions - The following weighted-average assumptions were used to determine the benefit obligations: 

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
	U.S.		Int’l		U.S.		Int’l
Discount rate	2.90	%	1.99	%	2.70	%	1.48	%	5.26	%	3.63	%
Rate of compensation increase	N/A		3.15	%	N/A		2.93	%	4.00	%	4.00	%

The following weighted-average assumptions were used to determine net periodic benefit cost: 

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Discount rate	2.70	%	3.09	%	3.40	%	2.01	%	4.40	%	2.89	%	4.46	%	4.48	%	5.32	%
Rate of compensation increase	N/A		3.15	%	N/A		3.84	%	N/A		3.80	%	4.00	%	4.00	%	4.00	%
Expected rate of return on plan assets	6.75	%	2.22	%	7.75	%	7.27	%	8.65	%	7.15	%	N/A		N/A		N/A

Our estimate of expected rate of return on plan assets is primarily based on the historical performance of plan assets, current market conditions, our asset allocation and long-term growth expectations.

Plan assets - We actively monitor how the duration and the expected yield of the investments are matching the expected cash outflows arising from the pension obligations. We have not changed the processes used to manage its risks from previous periods. Investments are well diversified, such that the failure of any single investment would not have a material impact on the overall level of assets. Our pension investment strategy emphasizes maximizing returns consistent with balancing risk. Excluding our international plans with insurance-based investments, 98.8% of our total pension plan assets represent the U.S. qualified plan and the U.K. plan. These plans are primarily invested in equity securities to maximize the long-term returns of the plans. The investment managers of these assets, including the hedge funds and limited partnerships, use Graham and Dodd fundamental investment analysis to select securities that have a margin of safety between the price of the security and the estimated value of the security. This value-oriented approach tends to mitigate the risk of a large equity allocation.

The following is a description of the valuation methodologies used for the pension plan assets. There have been no changes in the methodologies used as of December 31, 2021 and 2020.

•Cash is valued at cost, which approximates fair value.

•Equity securities are comprised of common stock and preferred stock. The fair values of equity securities are valued at the closing price reported on the active market on which the securities are traded.

•Fair values of registered investment companies and common/collective trusts are valued based on quoted market prices, which represent the net asset value (“NAV”) of shares held. Registered investment companies primarily include investments in emerging market bonds. Common/collective trusts primarily includes money market instruments with short maturities.

•Insurance contracts are valued at book value, which approximates fair value, and is calculated using the prior-year balance plus or minus investment returns and changes in cash flows.

•The fair values of hedge funds are valued using the NAV as determined by the administrator or custodian of the fund. The funds primarily invest in U.S. and international equities, debt securities and other hedge funds.

•The fair values of limited partnerships are valued using the NAV as determined by the administrator or custodian of the fund. The partnerships primarily invest in U.S. and international equities and debt securities.

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•Real estate and other investments primarily consist of real estate investment trusts and other investments. These investments are measured at quoted market prices, which represent the NAV of the securities held in such funds at year end.

Our pension plan assets measured at fair value on a recurring basis are as follows as of December 31, 2021 and 2020. Refer to “Fair value measurements” in Note 1 to these consolidated financial statements for a description of the levels.

(In millions)	U.S.										International
December 31, 2021	Total		Level 1		Level 2		Level 3		Net Asset Value (a)		Total		Level 1		Level 2		Level 3		Net Asset Value (a)
Cash and cash equivalents	$	43.4	$	43.4	$	—	$	—	$	—	$	40.5	$	40.5	$	—	$	—	$	—
Equity securities
U.S. companies	102.1		102.1		—		—		—		45.5		45.5		—		—		—
International companies	2.1		2.1		—		—		—		143.4		143.4		—		—		—
Registered investment companies	37.9		—		—		—		37.9		36.0		—		—		—		36.0
Insurance contracts	—		—		—		—		—		—		—		—		—		—
Hedge funds	138.8		—		—		—		138.8		291.0		—		—		—		291.0
Limited partnerships	192.5		—		—		—		192.5		3.6		—		—		—		3.6
Real estate and other investments	0.6		0.6		—		—		—		69.7		69.7		—		—		—
Total assets	$	517.4	$	148.2	$	—	$	—	$	369.2	$	629.7	$	299.1	$	—	$	—	$	330.6
December 31, 2020
Cash and cash equivalents	$	38.1	$	38.1	$	—	$	—	$	—	$	66.3	$	66.3	$	—	$	—	$	—
Equity securities
U.S. companies	83.3		83.3		—		—		—		96.3		96.3		—		—		—
International companies	1.1		1.1		—		—		—		208.4		208.4		—		—		—
Registered investment companies	38.4		—		—		—		38.4		68.2		—		—		—		68.2
Hedge funds	160.9		—		—		—		160.9		98.3		—		—		—		98.3
Limited partnerships	160.9		—		—		—		160.9		14.5		—		—		—		14.5
Real estate and other investments	1.0		1.0		—		—		—		39.5		39.5		—		—		—
Total assets	$	483.7	$	123.5	$	—	$	—	$	360.2	$	591.5	$	410.5	$	—	$	—	$	181.0

(a)Certain investments that are measured at fair value using net asset value per share (or its equivalent) have not been classified in the fair value hierarchy.

Contributions - We expect to contribute approximately $12.3 million to our international pension plans, representing primarily the U.K. qualified pension plans in 2022. We do not expect to make any contributions to our U.S. Qualified Pension Plan and our U.S. Non-Qualified Defined Benefit Pension Plan in 2022. All of the contributions are expected to be in the form of cash. In 2021 and 2020, we contributed $34.3 million and $27.1 million to all pension plans, respectively.

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Estimated future benefit payments - The following table summarizes expected benefit payments from our various pension and post-retirement benefit plans through 2031. Actual benefit payments may differ from expected benefit payments.

	Pensions				Other Post-retirement Benefits
(In millions)	U.S.		International
2022	$	33.3	$	22.0	$	0.6
2023	31.4		22.4		0.6
2024	31.7		23.8		0.6
2025	32.3		24.4		0.5
2026	32.7		25.6		0.5
2027-2031	165.9		149.9		2.3

Savings plans - The TechnipFMC Retirement Savings Plan (“Qualified Plan”), a qualified salary reduction plan under Section 401(k) of the Internal Revenue Code, is a defined contribution plan. Additionally, we have a non-qualified deferred compensation plan, the Non-Qualified Plan, which allows certain highly compensated employees the option to defer the receipt of a portion of their salary. We match a portion of the participants’ deferrals to both plans. Both plans relate to FMC Technologies, Inc.

Participants in the Non-Qualified Plan earn a return based on hypothetical investments in the same options as our 401(k) plan. Changes in the market value of these participant investments are reflected as an adjustment to the deferred compensation liability with an offset to other income (expense), net. As of December 31, 2021 and 2020, our liability for the Non-Qualified Plan was $24.1 million and $22.8 million, respectively, and was recorded in other liabilities in our consolidated balance sheets. We hedge the financial impact of changes in the participants’ hypothetical investments by purchasing the investments that the participants have chosen. Changes in the fair value of these investments are recognized as an offset to other income (expense), net in our consolidated statements of income. As of December 31, 2021 and 2020, we had investments for the Non-Qualified Plan totaling $24.1 million and $22.8 million at fair market value, respectively.

During the years ended December 31, 2021, and 2020 we recognized expense of $21.5 million and $21.3 million, respectively for matching contributions to these plans in 2021 and 2020, respectively. Additionally, during the years ended December 31, 2021 and 2020, we recognized expense of $9.0 million and $8.3 million, respectively, for non-elective contributions.

NOTE 24. DERIVATIVE FINANCIAL INSTRUMENTS

For purposes of mitigating the effect of changes in exchange rates, we hold derivative financial instruments to hedge the risks of certain identifiable and anticipated transactions and recorded assets and liabilities in our consolidated balance sheets. The types of risks hedged are those relating to the variability of future earnings and cash flows caused by movements in foreign currency exchange rates. Our policy is to hold derivatives only for the purpose of hedging risks associated with anticipated foreign currency purchases and sales created in the normal course of business, and not for speculative purposes.

Generally, we enter into hedging relationships such that changes in the fair values or cash flows of the transactions being hedged are expected to be offset by corresponding changes in the fair value of the derivatives. For derivative instruments that qualify as a cash flow hedge, the effective portion of the gain or loss of the derivative, which does not include the time value component of a forward currency rate, is reported as a component of other comprehensive income (“OCI”) and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings. For derivative instruments not designated as hedging instruments, any change in the fair value of those instruments is reflected in earnings in the period such change occurs.

We hold the following types of derivative instruments:

Foreign exchange rate forward contracts – The purpose of these instruments is to hedge the risk of changes in future cash flows of anticipated purchase or sale commitments denominated in foreign currencies and recorded assets and liabilities in our consolidated balance sheets. As of December 31, 2021, we held the following material net positions: 

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	Net Notional Amount Bought (Sold)
(In millions)		USD Equivalent
Euro	775.4	878.2
British pound	(197.2)	(265.9)
Malaysian ringgit	(627.4)	(150.5)
Norwegian krone	967.9	109.8
Brazilian real	1,299.8	232.9
Singapore dollar	125.4	92.9
Mexican peso	(116.7)	(5.7)
Australian dollar	182.4	132.2
Indian rupee	881.4	11.8
Kuwaiti Dinar	(3.3)	(10.9)
Russian Ruble	925.0	12.5
Canadian dollar	19.2	15.1
Indonesian rupiah	(45,656.9)	(3.2)
U.S. dollar	(1,119.9)	(1,119.9)

Foreign exchange rate instruments embedded in purchase and sale contracts – The purpose of these instruments is to match offsetting currency payments and receipts for particular projects, or comply with government restrictions on the currency used to purchase goods in certain countries. As of December 31, 2021, our portfolio of these instruments included the following material net positions: 

	Net Notional Amount Bought (Sold)
(In millions)		USD Equivalent
Brazilian real	52.5	9.4
Euro	(7.3)	(8.3)
Norwegian krone	6.1	0.7
U.S. dollar	(1.2)	(1.2)

Fair value amounts for all outstanding derivative instruments have been determined using available market information and commonly accepted valuation methodologies. See Note 25 for further details. Accordingly, the estimates presented may not be indicative of the amounts that we would realize in a current market exchange and may not be indicative of the gains or losses we may ultimately incur when these contracts are settled.

The following table presents the location and fair value amounts of derivative instruments reported in the consolidated balance sheets:

	December 31, 2021				December 31, 2020
(In millions)	Assets		Liabilities		Assets		Liabilities
Derivatives designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments	$	106.4	$	139.5	$	189.5	$	141.9
Long-term - Derivative financial instruments	10.5		15.5		28.9		18.8
Total derivatives designated as hedging instruments	116.9		155.0		218.4		160.7
Derivatives not designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments	3.9		21.5		79.2		15.6
Long-term - Derivative financial instruments	—		—		0.3		—
Total derivatives not designated as hedging instruments	3.9		21.5		79.5		15.6
Total derivatives	$	120.8	$	176.5	$	297.9	$	176.3

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Cash flow hedges of forecasted transactions, net of tax, which qualify for hedge accounting, resulted in accumulated other comprehensive gains (losses) of $(18.7) million and $12.9 million as of December 31, 2021 and 2020, respectively. We expect to transfer an approximately $3.4 million gain from accumulated OCI to earnings during the next 12 months when the anticipated transactions actually occur. All anticipated transactions currently being hedged are expected to occur by the second half of 2024.

The following tables present the location of gains (losses) in the consolidated statements of income related to derivative instruments designated as cash flow hedges. 

	Gain (Loss) Recognized in OCI
	Year Ended December 31,
(In millions)	2021		2020		2019
Foreign exchange contracts	$	(26.3)	$	3.8	$	12.2

The following represents the effect of cash flow hedge accounting on the consolidated statements of income for the year ended December 31, 2021, 2020 and 2019:

	Year Ended December 31,
(In millions)	2021								2020								2019
Total amount of income (expense) presented in the consolidated statements of income associated with hedges and derivatives	Revenue		Cost of sales		Selling, general and administrative expense		Other income (expense), net		Revenue		Cost of sales		Selling, general and administrative expense		Other income (expense), net		Revenue		Cost of sales		Other income (expense), net
Amounts reclassified from accumulated OCI to income (loss)	$	(29.7)	$	10.7	$	0.2	$	32.9	$	(83.7)	$	68.5	$	(0.4)	$	(0.2)	$	(26.6)	$	12.0	$	(1.3)
Amounts excluded from effectiveness testing	(1.8)		(3.3)		—		3.8		7.7		(9.8)		(0.2)		0.3		0.6		(7.6)		(7.2)
Total cash flow hedge gain (loss) recognized in income	(31.5)		7.4		0.2		36.7		(76.0)		58.7		(0.6)		0.1		(26.0)		4.4		(8.5)
Gain (loss) recognized in income on derivatives not designated as hedging instruments	1.3		0.3		—		(13.3)		(0.8)		3.4		—		35.9		(1.6)		0.2		(21.4)
Total	$	(30.2)	$	7.7	$	0.2	$	23.4	$	(76.8)	$	62.1	$	(0.6)	$	36.0	$	(27.6)	$	4.6	$	(29.9)

Balance Sheet Offsetting - We execute derivative contracts with counterparties that consent to a master netting agreement which permits net settlement of the gross derivative assets against gross derivative liabilities. Each instrument is accounted for individually and assets and liabilities are not offset. As of December 31, 2021 and 2020, we had no collateralized derivative contracts. The following tables present both gross information and net information of recognized derivative instruments:

	December 31, 2021						December 31, 2020
(In millions)	Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount		Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount
Derivative assets	$	120.8	$	(78.6)	$	42.2	$	297.9	$	(128.7)	$	169.2
Derivative liabilities	$	176.5	$	(78.6)	$	97.9	$	176.3	$	(128.7)	$	47.6

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NOTE 25. FAIR VALUE MEASUREMENTS

Recurring Fair Value Measurements

Assets and liabilities measured at fair value on a recurring basis were as follows: 

	December 31, 2021								December 31, 2020
(In millions)	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Assets
Investments
Investment in Technip Energies	$	317.3	$	317.3	$	—	$	—	$	—	$	—	$	—	$	—
Equity securities(a)	25.0		25.0		—		—		23.4		23.4		—		—
Money market fund	2.4		—		2.4		—		1.7		—		1.7		—
Stable value fund(b)	0.3		—		—		—		0.9		—		—		—
Held-to-maturity debt securities	24.0		—		24.0		—		24.2		—		24.2		—
Derivative financial instruments
Foreign exchange contracts	120.8		—		120.8		—		297.9		—		297.9		—
Assets held for sale	5.0		—		—		5.0		47.3		—		—		47.3
Total assets	$	494.8	$	342.3	$	147.2	$	5.0	$	395.4	$	23.4	$	323.8	$	47.3
Liabilities
Derivative financial instruments
Foreign exchange contracts	176.5		—		176.5		—		176.3		—		176.3		—
Total liabilities	$	176.5	$	—	$	176.5	$	—	$	176.3	$	—	$	176.3	$	—

(a)Includes fixed income and other investments measured at fair value.

(b)Certain investments that are measured at fair value using net asset value per share (or its equivalent) have not been classified in the fair value hierarchy.

Investment in Technip Energies - The fair value of our investment in Technip Energies is based on quoted prices that we have the ability to access in public markets, see Note 13 for further details.

Equity securities and Available-for-sale Securities - The fair value measurement of our traded securities and Available-for-sale-Securities is based on quoted prices that we have the ability to access in public markets.

Stable value fund and Money market fund - Stable value fund and money market fund are valued at the net asset value of the shares held at the end of the quarter, which is based on the fair value of the underlying investments using information reported by our investment advisor at quarter-end.

Held-to-maturity debt securities - Held-to-maturity debt securities consist of government bonds. These investments are stated at amortized cost, which approximates fair value.

Assets held for sale - The fair value of our assets held for sale was determined using a market approach that took into consideration the expected sales price. As of December 31, 2020, our G1200 vessel is classified as held for sale. In March 2021, we entered into a Memorandum of Agreement to sell the vessel. We completed the sale and received $48.0 million in cash proceeds during the second quarter of 2021.

Redeemable non-controlling interest - In accordance with the Share Purchase Agreement between Technip-Coflexip UK Holdings Limited (“TUK”) and Island Offshore Management AS (“Island Offshore”) that was executed on March 12, 2018, whereby TUK initially purchased 51% of the shares of TIOS AS, a joint venture between TUK and Island Offshore, TUK acquired the remaining 49% interest in TIOS at a total price of $48.6 million during the third quarter of 2021. As of December 31, 2020, we owned a 51% share in TIOS and the redeemable non-controlling interest was recorded as mezzanine equity at fair value of $43.7 million.

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Derivative financial instruments - We use the income approach 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 by using the spread of similar companies in the same industry, of similar size and with the same credit rating.

We currently 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. See Note 24 for further details.

Nonrecurring Fair Value Measurements

Fair value of long-lived, non-financial assets - Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that carrying amounts of such assets may not be recoverable.

The following summarizes impairments of long-lived assets and related post-impairment fair value for the years ended December 31, 2021 and 2020:

	Year Ended December 31,
	2021				2020
(In millions)	Impairment		Fair Value		Impairment		Fair Value
Long-lived assets(a)	$	49.1	$	25.5	$	190.4	$	452.5

(a)Measuring these asset groups for recoverability required the use of unobservable inputs that require significant judgment. Such judgments include expected future asset utilization while taking into account reduced future capital spending by certain customers in response to market conditions.

Other fair value disclosures

The carrying amounts of cash and cash equivalents, trade receivables, accounts payable, short-term debt, commercial paper, debt associated with our bank borrowings, credit facilities, as well as amounts included in other current assets and other current liabilities that meet the definition of financial instruments, approximate fair value.

Fair value of debt - We use a market approach to determine the fair value of our fixed-rate debt using observable market data, which results in a Level 2 fair value measurement. The estimated fair value of our private placement notes, senior notes and synthetic bonds was $1,706.1 million and $2,199.2 million as of December 31, 2021 and December 31, 2020, respectively.

Credit risk - By their nature, financial instruments involve risk, including credit risk, for non-performance by counterparties. Financial instruments that potentially subject us to credit risk primarily consist of trade receivables and derivative contracts. We manage the credit risk on financial instruments by transacting only with what management believes are financially secure counterparties, requiring credit approvals and credit limits and monitoring counterparties’ financial condition. Our maximum exposure to credit loss in the event of non-performance by the counterparty is limited to the amount drawn and outstanding on the financial instrument. Allowances for losses on trade receivables are established based on collectability assessments. We mitigate credit risk on derivative contracts by executing contracts only with counterparties that consent to a master netting agreement, which permits the net settlement of gross derivative assets against gross derivative liabilities.

NOTE 26. SUBSEQUENT EVENTS

On January 10, 2022 we announced the sale of 9.0 million Technip Energies shares, representing approximately 5% of Technip Energies’ issued and outstanding share capital, through a private sale transaction (the “January Sale”). The sale price of the shares in the January Sale was set at €13.15 per share, yielding total net proceeds of €118.4 million, or $135.1 million. Upon completion of the January Sale, we retain a direct stake of 12.9 million

118

shares, representing 7.1% of Technip Energies’ issued and outstanding share capital. As of February 25, 2022, the value of our investment in Technip Energies was $155.3 million.

On January 14, 2022 we paid £6 million, or $8.3 million for 750,000 ordinary shares in Orbital Marine Power (Orbital) to complete the investment in accordance with the Memorandum of Understanding between Technip Holding Benelux B.V. and Orbital. Orbital is a Scotland-based renewable energy company focused on the development and global application of its floating turbine technology. Upon completion of the investment, we will hold approximately 10.2% of the ordinary shares in Orbital.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

As of December 31, 2021, and under the direction of our Chief Executive Officer and Chief Financial Officer, we evaluated the effectiveness of our disclosure controls and procedures, as defined in Rule 13a-15(e) under the Exchange Act. Based upon this evaluation, our Chief Executive Officer and Chief Financial Officer concluded as of December 31, 2021, that our disclosure controls and procedures were effective.

Management’s Annual Report on Internal Control over Financial Reporting

Management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Exchange Act.

Management evaluated the effectiveness of our internal control over financial reporting as of December 31, 2021 based on the framework in Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). As a result of this evaluation, management concluded that our internal control over financial reporting was effective as of December 31, 2021.

The effectiveness of our internal control over financial reporting as of December 31, 2021, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report included herein.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting during the quarter ended December 31, 2021 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

ITEM 9B. OTHER INFORMATION

None.

ITEM 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS

Not applicable.

PART III

119

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

See Part I, Item 1 “Executive Officers of the Registrant” of this Annual Report on Form 10-K for information regarding our executive officers. The information set forth under the sections “Corporate Governance,” “Proposals 1(a) - 1(i) - Election of Directors”, and if applicable, “Delinquent Section 16(a) Reports” in our 2022 Proxy Statement is incorporated herein by reference.

We have adopted a Code of Business Conduct, which is applicable to our directors, officers, and employees, including our principal executive officer, financial and accounting officers, and persons performing similar functions. Our Code of Business Conduct may be found on our website at www.technipfmc.com under “About us-Ethics and Compliance” and is available in print to shareholders without charge by submitting a request to 13460 Lockwood Rd., Houston, Texas 77044, Attention: Corporate Secretary. We intend to satisfy the disclosure requirements under the Securities and Exchange Act of 1934, as amended, regarding an amendment to or waiver from a provision of our Code of Business Conduct by posting such information on our website.

Name	Principal Occupation
Douglas J. Pferdehirt	Chair and Chief Executive Officer of TechnipFMC.
Eleazar de Carvalho Filho	Founding Partner of Virtus BR Partners Assessoria Corporativa Ltda. and Founding Partner of Sinfonia Consultoria Financeira e Participações Ltda., financial advisory and consulting firms.
Claire S. Farley	Former Vice Chairman in the Energy & Infrastructure business of KKR & Co. L.P., a global investment firm.
Peter Mellbye	Former Executive Vice President, Development & Production, International, of Statoil ASA, an international oil and gas company.
John O’Leary	Chief Executive Officer of Strand Energy, a Dubai-based company specializing in business development in the oil and gas industry.
Margareth Øvrum	Former Executive Vice President of Development and Production Brazil of Equinor ASA, an international oil and gas company.
Kay G. Priestly	Former Chief Executive Officer of Turquoise Hill Resources Ltd., an international mining company.
John Yearwood	Former Chief Executive Officer, President, and Chief Operating Officer of Smith International, Inc., a supplier of services and manufactured products to oil and gas exploration and production companies.
Sophie Zurquiyah	Chief Executive Officer of CGG S.A., a global geoscience technology leader.

ITEM 11. EXECUTIVE COMPENSATION

Information required by this item is incorporated herein by reference from the sections entitled “Director Compensation,” “Corporate Governance - Compensation Committee Interlocks and Insider Participation in Compensation Decisions,” “Executive Compensation Discussion and Analysis” and “Compensation Committee Report” of our Proxy Statement for the 2022 Annual General Meeting of Shareholders.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED SHAREHOLDER MATTERS

Information required by this item is incorporated herein by reference from the section entitled “Security Ownership of Certain Beneficial Owners and Management” of our Proxy Statement for the 2022 Annual General Meeting of Shareholders.

As of December 31, 2021, our securities authorized for issuance under equity compensation plans were as follows:

(shares in thousands)	Number of Securities  to be Issued  Upon Exercise of Outstanding Options, Warrants and Rights	Weighted Average  Exercise Price of  Outstanding Options, Warrants and Rights		Number of Securities Remaining Available for Future Issuance under Equity Compensation Plans
Equity compensation plans approved by security holders	1,576.1	$	20.17	14,352.3
Equity compensation plans not approved by security holders	—	—		—
Total	1,576.1	$	20.17	14,352.3

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

Information required by this item is incorporated herein by reference from the sections entitled “Transactions with Related Persons” and “Corporate Governance - Director Independence” of our Proxy Statement for the 2022 Annual General Meeting of Shareholders.

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

Information required by this item is incorporated herein by reference from the sections entitled “Proposal 5 — Ratification of U.S. Auditor” of our Proxy Statement for the 2022 Annual General Meeting of Shareholders.

PART IV

ITEM 15. EXHIBIT AND FINANCIAL STATEMENT SCHEDULES

(a)The following documents are filed as part of this Annual Report on Form 10-K:

1.The following consolidated financial statements of TechnipFMC plc and subsidiaries are filed as part of this Annual Report on Form 10-K under Part II, Item 8:

Reports of Independent Registered Public Accounting Firm on Consolidated Financial Statements (PCAOB ID: 238)

Consolidated Statements of Income for the Years Ended December 31, 2021, 2020 and 2019

Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2021, 2020, and 2019

Consolidated Balance Sheets as of December 31, 2021 and 2020

Consolidated Statements of Cash Flows for the Years Ended December 31, 2021, 2020 and 2019

Consolidated Statements of Changes in Stockholders’ Equity for the Years Ended December 31, 2021, 2020 and 2019

Notes to Consolidated Financial Statements

2.Financial Statement Schedule:

See “Schedule II - Valuation and Qualifying Accounts” included herein. All other schedules are omitted because of the absence of conditions under which they are required or because information called for is shown in the consolidated financial statements and notes thereto in Part II, Item 8 of this Annual Report on Form 10-K.

3.Exhibits:

See “Index of Exhibits” filed as part of this Annual Report on Form 10-K.

121

Part IV

Item 15 (a) (2), Financial Statement Schedule

Schedule II—Valuation and Qualifying Accounts

(In millions)			Additions
Description	Balance at Beginning of  Period		Charged to  Costs and Expenses		Charged to Other Accounts (a)		Deductions and Adjustments (b)		Balance at End of Period
Year Ended December 31, 2019
Trade receivables allowance for doubtful accounts	$	58.7	$	27.7	$	3.5	$	(32.5)	$	57.4
Valuation allowance for deferred tax assets	$	496.6	$	184.9	$	—	$	47.6	$	729.1
Year Ended December 31, 2020
Trade receivables allowance for doubtful accounts (c)	$	57.4	$	38.0	$	1.3	$	(56.5)	$	40.2
Valuation allowance for deferred tax assets	$	729.1	$	104.4	$	(11.3)	$	(7.1)	$	815.1
Year Ended December 31, 2021
Trade receivables allowance for doubtful accounts	$	40.2	$	17.0	$	(10.8)	$	(8.3)	$	38.1
Valuation allowance for deferred tax assets	$	815.1	$	129.7	$	(12.0)	$	2.7	$	935.5

(a)"Additions charged to other accounts” includes translation adjustments.

(b)“Deductions and adjustments” includes write-offs, net of recoveries, increases in allowances offset by increases to deferred tax assets, and reductions in the allowances credited to expense.

(c)On January 1, 2020, we adopted ASU 2016-13, resulting in a $2.0 million increase to our trade receivables allowance for credit losses.

See accompanying Report of Independent Registered Public Accounting Firm.

ITEM 16. SUMMARY

None.

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INDEX OF EXHIBITS

Exhibit      Number	Exhibit Description
2.1	Business Combination Agreement, dated as of June 14, 2016, by and among FMC Technologies, Inc., TechnipFMC plc (f/k/a FMC Technologies SIS Limited) and Technip S.A. (incorporated by reference from Annex A-1 to the Registration Statement on Form S-4, as amended, filed on October 21, 2016) (File No. 333-213067)
2.1.a	Amendment No. 1 to Business Combination Agreement, dated as of December 14, 2016, by and among FMC Technologies, Inc., TechnipFMC plc (f/k/a TechnipFMC Limited) and Technip S.A. (incorporated by reference from Exhibit 2.1 to the Current Report on Form 8-K filed on December 14, 2016) (File No. 333-213067)
2.2	Joinder Agreement, dated as of December 14, 2016, by and among FMC Technologies, Inc., TechnipFMC plc (f/k/a TechnipFMC Limited), Technip S.A., TechnipFMC Holdings Limited, TechnipFMC US Holdings LLC and TechnipFMC US Merger Sub LLC (incorporated by reference from Exhibit 2.2 to the Current Report on Form 8-K filed on December 14, 2016) (File No. 333-213067)
3.1	Articles of Association of TechnipFMC plc (incorporated by reference from Exhibit 3.1 to the Current Report on Form 8-K filed on January 17, 2017) (File No. 001-37983)
4.1	Indenture, dated March 29, 2017, between TechnipFMC plc and U.S. Bank National Association, as trustee (incorporated by reference from Exhibit 4.1 to the Current Report on Form 8-K filed on March 30, 2017) (File No. 001-37983)
4.1.a	Second Supplemental Indenture, dated March 29, 2017, between TechnipFMC plc and U.S. Bank National Association, as trustee (including the form of 3.45% Senior Notes due 2022) (incorporated by reference from Exhibit 4.3 to the Current Report on Form 8-K filed on March 30, 2017) (File No. 001-37983)
4.2	Indenture, dated January 29, 2021, between TechnipFMC plc and U.S. Bank National Association, as trustee (including the form of 6.500% Senior Note due 2026) (incorporated by reference from Exhibit 4.1 to the Current Report on Form 8-K filed on January 29, 2021 (File No. 001-37983)
4.2.a	Supplemental Indenture, dated February 16, 2021, by and among TechnipFMC plc, the guarantors party thereto, and U.S. Bank National Association, as trustee (incorporated by reference from Exhibit 4.1 to the Current Report on Form 8-K filed on February 16, 2021) (File No. 001-37983)
4.3	Description of Registrant’s Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934, as amended (incorporated by reference from Exhibit 4.2 to the Annual Report on Form 10-K filed on March 3, 2020) (File No. 001-37983)
10.1*	Amended and Restated FMC Technologies, Inc. Non-Qualified Savings and Investment Plan, dated July 31, 2008 (incorporated by reference from Exhibit 10.9 to the Annual Report on Form 10-K of FMC Technologies, Inc. filed on March 1, 2010) (File No. 001-16489)
10.1a*	First Amendment of FMC Technologies, Inc. Non-Qualified Savings and Investment Plan, dated October 29, 2009 (incorporated by reference from Exhibit 10.9 to the Quarterly Report on Form 10-Q of FMC Technologies, Inc. filed on November 3, 2009) (File No. 001-16489)
10.1b*	Second Amendment of FMC Technologies, Inc. Non-Qualified Savings and Investment Plan, dated December 18, 2015 (incorporated by reference from Exhibit 10.14.b to the Annual Report on Form 10-K of FMC Technologies, Inc. filed on February 24, 2016) (File No. 001-16489)
10.2*	Amended and Restated TechnipFMC plc Incentive Award Plan (incorporated by reference from Exhibit 10.2 to the Annual Report on Form 10-K filed on March 11, 2019) (File No. 001-37983)
10.3*	Form of Restricted Stock Unit Agreement pursuant to the TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on August 4, 2017) (File No. 001-37983)
10.3a*	Form of Restricted Stock Unit Agreement pursuant to the Amended and Restated TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on May 9, 2019) (File No. 001-37983)
10.3b*	Form of Restricted Stock Unit Agreement pursuant to the TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on May 4, 2020) (File No. 001-37983)
10.4*	Form of Restricted Stock Unit Agreement pursuant to the TechnipFMC plc Incentive Award Plan (Non-Employee Director) (incorporated by reference from Exhibit 10.2 to the Quarterly Report on Form 10-Q filed on August 4, 2017) (File No. 001-37983)
10.5*	Form of Performance Stock Unit Agreement pursuant to the TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.3 to the Quarterly Report on Form 10-Q filed on August 4, 2017) (File No. 001-37983)
10.5a*	Form of Performance Stock Unit Agreement pursuant to the Amended and Restated TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.2 to the Quarterly Report on Form 10-Q filed on May 9, 2019) (File No. 001-37983)
10.5b*	Form of Performance Stock Unit Agreement pursuant to the TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.2 to the Quarterly Report on Form 10-Q filed on May 4, 2020) (File No. 001-37983)
10.6*	Form of Nonqualified Stock Option Agreement pursuant to the TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.4 to the Quarterly Report on Form 10-Q filed on August 4, 2017) (File No. 001-37983)
10.6a*	Form of Nonqualified Stock Option Agreement pursuant to the Amended and Restated TechnipFMC plc Incentive Award Plan (Employee) (incorporated by reference from Exhibit 10.3 to the Quarterly Report on Form 10-Q filed on May 9, 2019) (File No. 001-37983)
10.7*	2013 Technip Incentive and Reward Plan (Rules of the Performance Shares Plan) June 14, 2013 allocation (incorporated by reference from Exhibit 99.4 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.8*	2013 Technip Incentive and Reward Plan (Stock Option Plan Rules) June 14, 2013 allocation (incorporated by reference from Exhibit 99.5 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.9*	2013 Technip Incentive and Reward Plan (Rules of the Performance Shares Plan) January 10, 2014 allocation (incorporated by reference from Exhibit 99.6 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.10*	2013 Technip Incentive and Reward Plan (Stock Option Plan Rules) January 10, 2014 allocation (incorporated by reference from Exhibit 99.7 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.11*	2014 Technip Incentive and Reward Plan (Rules of the Performance Shares Plan) December 10, 2014 allocation (incorporated by reference from Exhibit 99.8 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.12*	2015 Technip Incentive and Reward Plan (Stock Option Plan Rules) September 7, 2015 allocation (incorporated by reference from Exhibit 99.9 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.13*	2016 Technip Incentive and Reward Plan (Rules of the Performance Shares Plan) July 1, 2016 allocation (incorporated by reference from Exhibit 99.10 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.14*	2016 Technip Incentive and Reward Plan (Stock Option Plan Rules) July 1, 2016 allocation (incorporated by reference from Exhibit 99.11 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.15*	2016 Technip Incentive and Reward Plan (Rules of the Performance Shares Plan) December 6, 2016 allocation (incorporated by reference from Exhibit 99.12 to the Registration Statement on Form S-8 of TechnipFMC plc, filed on February 27, 2017) (File No. 333-216289)
10.16*	Form of TechnipFMC plc Executive Severance Agreement (incorporated by reference from Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on November 2, 2020) (File No. 001-37983)
10.17*	Service Agreement between TechnipFMC plc and Thierry Pilenko dated January 16, 2017 (incorporated by reference from Exhibit 10.21 to the Annual Report on Form 10-K filed on April 2, 2018) (File No. 001-37983)
10.18*	Letter Agreement between TechnipFMC plc and Thierry Pilenko dated September 20, 2017 (incorporated by reference from Exhibit 10.22 to the Annual Report on Form 10-K filed on April 2, 2018) (File No. 001-37983)
10.19*	Form of Executive Director Appointment Letter (incorporated by reference from Exhibit 10.2 to the Current Report on Form 8-K filed on January 17, 2017) (File No. 001-37983)
10.20	Form of Non-Executive Director Appointment Letter (incorporated by reference from Exhibit 10.3 to the Current Report on Form 8-K filed on January 17, 2017) (File No. 001-37983)
10.21	Form of Director Deed of Indemnity (Directors) (incorporated by reference from Exhibit 10.2 to the Current Report on Form 8-K filed on January 17, 2017) (File No. 001-37983)
10.22*	Form of Deed of Indemnity (Executive Officers) (incorporated by reference from Exhibit 10.3 to the Current Report on Form 8-K filed on January 17, 2017) (File No. 001-37983)
10.23	Form of Director Deed of Indemnity (Executive Directors) (incorporated by reference from Exhibit 10.4 to the Current Report on Form 8-K filed on January 17, 2017) (File No. 001-37983)
10.24*	TechnipFMC plc Directors Deferred Compensation Plan (incorporated by reference from Exhibit 10.25 to the Annual Report on Form 10-K filed on March 5, 2021) (File No. 001-37983)
10.25	US$2,500,000,000 Facility Agreement, dated January 12, 2017, by and among FMC Technologies, Inc., Technip Eurocash SNC and TechnipFMC plc, as borrowers; JPMorgan Chase Bank, N.A., as agent; SG Americas Securities, LLC as syndication agent; and the other lenders party thereto (incorporated by reference from Exhibit 10.1 to the Current Report on Form 8-K filed on January 17, 2017) (File No. 001-37983)
10.26	Form of Commercial Paper Dealer Agreement, by and among FMC Technologies, Inc., as Issuer, TechnipFMC plc, as Guarantor, and the Dealer party thereto (incorporated by reference from Exhibit 10.1 to the Current Report on Form 8-K filed on September 20, 2017) (File No. 001-37983)
10.27	Separation and Distribution Agreement, dated as of January 7, 2021, by and between the Company and Technip Energies B.V. (incorporated by reference from Exhibit 10.1 to the Current Report on Form 8-K filed on January 12, 2021) (File No. 001-37983)
10.28	Share Purchase Agreement, dated as of January 7, 2021, by and between the Company and Bpifrance Participations SA (incorporated by reference from Exhibit 10.2 to the Current Report on Form 8-K filed on January 12, 2021) (File No. 001-37983)
10.28a	Amendment No. 1, dated March 31, 2021, to the Share Purchase Agreement, dated as of January 7, 2021, by and between the Company and Bpifrance Participations SA (incorporated by reference from Exhibit 99.5 to the Schedule 13D/A filed on April 1, 2021) (File No. 005-89993)
10.29	Relationship Agreement, dated as of January 7, 2021, by and among the Company, Technip Energies B.V. and Bpifrance Participations SA (incorporated by reference from Exhibit 10.3 to the Current Report on Form 8-K filed on January 12, 2021) (File No. 001-37983)
10.29a	Amendment No. 1, dated May 6, 2021, to the Relationship Agreement, dated as of January 7, 2021, by and among the Company, Technip Energies B.V. and Bpifrance Participations SA (incorporated by reference from Exhibit 10.2 to the Quarterly Report on Form 10-Q filed on July 29, 2021) (File No. 001-37983)
10.30	Commitment Letter, dated as of January 7, 2021, by and among the Company and the financial institutions party thereto (incorporated by reference from Exhibit 10.4 to the Current Report on Form 8-K filed on January 12, 2021) (File No. 001-37983)
10.31	Dealer Agreement, dated as of May 19, 2020 between TechnipFMC plc, as Issuer; FMC Technologies, Inc., as Guarantor; and Bank of America Merrill Lynch International DAC, as Arranger and Dealer (incorporated by reference from Exhibit 10.1 to the Current Report on Form 8-K filed on May 21, 2020) (File No. 001-37983)
10.32	Issuing and Paying Agency Agreement, dated as of May 19, 2020 between TechnipFMC plc, as Issuer; FMC Technologies, Inc., as Guarantor; and Bank of America, National Association, London Branch, as Issue and Paying Agent and Calculation Agent (incorporated by reference from Exhibit 10.2 to the Current Report on Form 8-K filed on May 21, 2020) (File No. 001-37983)
10.33	€500,000,000 Facility Agreement dated as of May 19, 2020 between TechnipFMC plc and Technip Eurocash SNC, as borrowers; HSBC France, as Agent; and the lenders party thereto (incorporated by reference from Exhibit 10.3 to the Current Report on Form 8-K filed on May 21, 2020) (File No. 001-37983)
10.34	Amendment and Restatement Agreement to €500,000,000 Facility Agreement dated as of June 12, 2020 between TechnipFMC plc and Technip Eurocash SNC, as borrowers; HSBC France, as Agent; and the lenders party thereto (incorporated by reference from Exhibit 10.2 to the Current Report on Form 8-K filed on June 15, 2020) (File No. 001-37983)
10.35	Amendment No. 1 to $2,500,000,000 Facility Agreement, dated as of June 12, 2020, by and among TechnipFMC plc, FMC Technologies, Inc. and Technip Eurocash SNC, as borrowers; JPMorgan Chase Bank, N.A., as agent and an arranger; SG Americas Securities LLC as an arranger; and the other lenders party thereto (incorporated by reference from Exhibit 10.1 to the Current Report on Form 8-K filed on June 15, 2020) (File No. 001-37983)
10.36	Tax Matters Agreement, dated as of February 16, 2021 by and between TechnipFMC plc and Technip Energies B.V. (incorporated by reference from Exhibit 10.1 to the Current Report on Form 8-K filed on February 16, 2021) (File No. 001-37983)
10.37	Employee Matters Agreement, dated as of February 15, 2021, by and between TechnipFMC plc and Technip Energies B.V. (incorporated by reference from Exhibit 10.2 to the Current Report on Form 8-K filed on February 16, 2021) (File No. 001-37983)
10.38	Transition Services Agreement, dated as of February 15, 2021 by and between TechnipFMC plc and Technip Energies B.V. (incorporated by reference from Exhibit 10.3 to the Current Report on Form 8-K filed on February 16, 2021) (File No. 001-37983)
10.39	Patent License Agreement, dated as of February 15, 2021 by and between TechnipFMC plc and Technip Energies B.V. (incorporated by reference from Exhibit 10.4 to the Current Report on Form 8-K filed on February 16, 2021) (File No. 001-37983)
10.40	Coexistence and Trademark Matters Agreement, dated as of February 15, 2021 by and between TechnipFMC plc and Technip Energies B.V. (incorporated by reference from Exhibit 10.5 to the Current Report on Form 8-K filed on February 16, 2021) (File No. 001-37983)
10.41	Credit Agreement, dated February 16, 2021, by and among TechnipFMC plc, JPMorgan Chase Bank, N.A., Citigroup Global Markets Inc. or an affiliate, DNB Capital, LLC or an affiliate, Société Générale, Sumitomo Mitsui Banking Corporation, Wells Fargo Securities, LLC and BofA Securities, Inc., collectively, as lead arrangers, JPMorgan Chase Bank, N.A., as administrative agent, Standard Chartered Bank, as documentation agent, and the lenders party thereto (incorporated by reference from Exhibit 10.6 to the Current Report on Form 8-K filed on February 16, 2021) (File No. 001-37983)
10.41a	First Amendment, dated April 29, 2021, to the Credit Agreement, dated February 16, 2021, by and among TechnipFMC plc, JPMorgan Chase Bank, N.A., Citigroup Global Markets Inc. or an affiliate, DNB Capital, LLC or an affiliate, Société Générale, Sumitomo Mitsui Banking Corporation, Wells Fargo Securities, LLC and BofA Securities, Inc., collectively, as lead arrangers, JPMorgan Chase Bank, N.A., as administrative agent, Standard Chartered Bank, as documentation agent, and the lenders party thereto (incorporated by reference from Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on July 29, 2021) (File No. 001-37983)
10.41b	Second Amendment, dated October 6, 2021, to the Credit Agreement, dated February 16, 2021, by and among TechnipFMC plc, JPMorgan Chase Bank, N.A., Citigroup Global Markets Inc. or an affiliate, DNB Capital, LLC or an affiliate, Société Générale, Sumitomo Mitsui Banking Corporation, Wells Fargo Securities, LLC and BofA Securities, Inc., collectively, as lead arrangers, JPMorgan Chase Bank, N.A., as administrative agent, Standard Chartered Bank, as documentation agent, and the lenders party thereto (incorporated by reference from Exhibit 10.1 to the Quarterly Report on Form 10-Q filed on October 27, 2021) (File No. 001-37983)
10.42	Form of Share Purchase Contract (filed as Appendix A to TechnipFMC plc’s Definitive Proxy Statement on Schedule 14A filed April 9, 2021, File No. 001-37983, and incorporated herein by reference)
10.43	Form of Rule 10b-5 Share Repurchase Contract (filed as Appendix B to TechnipFMC plc’s Definitive Proxy Statement on Schedule 14A filed April 9, 2021, File No. 001-37983, and incorporated herein by reference)
21.1	List of Significant Subsidiaries
23.1	Consent of PricewaterhouseCoopers LLP
31.1	Certification of Chief Executive Officer
31.2	Certification of Chief Financial Officer
32.1**	Certification of Chief Executive Officer pursuant to 18 U.S.C.
32.2**	Certification of Chief Financial Officer pursuant to 18 U.S.C.
101.INS	XBRL Instance Document – the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH	Inline XBRL Taxonomy Extension Schema Document.
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	Inline XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase Document.
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

* Indicates a management contract or compensatory plan or arrangement.

** Furnished with this Form 10-K.

123

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

TechnipFMC plc (Registrant)
By:	/S/    KRISZTINA DOROGHAZI
	Krisztina Doroghazi Senior Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer and a Duly Authorized Officer)

Date: February 28, 2022

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Signature	Title	Date
/S/   DOUGLAS J. PFERDEHIRT	Chair and Chief Executive Officer (Principal Executive Officer)	February 28, 2022
Douglas J. Pferdehirt
/S/    ALF MELIN	Executive Vice President, Chief Financial Officer (Principal Financial Officer)	February 28, 2022
Alf Melin
/S/    ELEAZAR DE CARVALHO FILHO	Director	February 28, 2022
Eleazar de Carvalho Filho
/S/    CLAIRE S. FARLEY	Director	February 28, 2022
Claire S. Farley
/S/    PETER MELLBYE	Director	February 28, 2022
Peter Mellbye
/S/    JOHN O’LEARY	Director	February 28, 2022
John O’Leary
/S/   MARGARETH ØVRUM	Director	February 28, 2022
Margareth Øvrum
/S/    KAY G. PRIESTLY	Director	February 28, 2022
Kay G. Priestly
/S/    JOHN YEARWOOD	Director	February 28, 2022
John Yearwood
/S/    SOPHIE ZURQUIYAH	Director	February 28, 2022
Sophie Zurquiyah

124

EX-21.1

Exhibit 21.1

TechnipFMC plc

Significant Subsidiaries of the Registrant

December 31, 2021

Name of Company	Country of Incorporation
Asiaflex Products Sdn Bhd	Malaysia
Flexi France SAS	France
FMC Technologies Inc	United States
Lusotechnip Engenharia, Sociedade Unipessoal Lda.	Portugal
PT Technip Indonesia	Indonesia
Techdof Brasil AS	Norway
Technip Brasil - Engenharia, Instalacoes E Apoio Maritimo Ltda	Brazil
Technip Marine (M) Sdn Bhd	Malaysia
Technip Middle East FZCO	United Arab Emirates
Technip Mozambique Lda	Mozambique
Technip Norge AS	Norway
Technip N-Power SAS	France
Technip Offshore International SAS	France
Technip UK Ltd	United Kingdom
Technip-Coflexip U.K Holdings Ltd.	United Kingdom
TechnipFMC Cash B.V.	Netherlands
TechnipFMC Corporate Holdings Ltd.	United Kingdom
TechnipFMC Guyana Inc	Guyana
TechnipFMC International Finance Ltd	United Kingdom
TechnipFMC International Holdings BV	Netherlands
TechnipFMC International UK Ltd	United Kingdom
TechnipFMC PLSV C.V.	Netherlands
TechnipFMC Umbilicals Ltd.	United Kingdom
TechnipFMC US Holdings, Inc	United States
TIOS AS	Norway

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statements on FormS-8 (333-216284) and on Form S-3 (No 333-240355) of TechnipFMC plc of our report dated February 28, 2022 relating to the financial statements and financial statement schedulesand the effectiveness of internal control over financial reporting, which appears in this Form 10-K.

/s/PricewaterhouseCoopers LLP

Houston, Texas

February 28, 2022

EX-31.1

Exhibit 31.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

PURSUANT TO RULE 13A-14(A) AND RULE 15D-14(A)

OF THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Douglas J. Pferdehirt, certify that:

1.I have reviewed this annual report on Form 10-K for the period ended December 31, 2021 of TechnipFMC plc (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)    Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 28, 2022

/s/ DOUGLAS J. PFERDEHIRT

Douglas J. Pferdehirt

Executive Chairman and Chief Executive Officer

(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION OF CHIEF FINANCIAL OFFICER

PURSUANT TO RULE 13A-14(A) AND RULE 15D-14(A)

OF THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Alf Melin, certify that:

1.I have reviewed this annual report on Form 10-K for the period ended December 31, 2021 of TechnipFMC plc (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)    Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 28, 2022

/s/ ALF MELIN

Alf Melin

Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

EX-32.1

Exhibit 32.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

UNDER SECTION 906 OF THE SARBANES-OXLEY

ACT OF 2002, 18 U.S.C. SECTION 1350

I, Douglas J. Pferdehirt, Executive Chairman and Chief Executive Officer of TechnipFMC plc (the “Company”), do hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(a) The Annual Report on Form 10-K of the Company for the period ended December 31, 2021, as filed with the Securities and Exchange Commission (the “Report”), fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(b) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: February 28, 2022

/s/ DOUGLAS J. PFERDEHIRT

Douglas J. Pferdehirt

Executive Chairman and Chief Executive Officer

(Principal Executive Officer)

EX-32.2

Exhibit 32.2

CERTIFICATION OF CHIEF FINANCIAL OFFICER

UNDER SECTION 906 OF THE SARBANES-OXLEY

ACT OF 2002, 18 U.S.C. SECTION 1350

I, Alf Melin, Executive Vice President and Chief Financial Officer of TechnipFMC plc (the “Company”), do hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(a) The Annual Report on Form 10-K of the Company for the period ended December 31, 2021, as filed with the Securities and Exchange Commission (the “Report”), fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(b) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: February 28, 2022

/s/ ALF MELIN

Alf Melin

Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

XML

Cover - USD ($)
$ in Billions

12 Months Ended

Dec. 31, 2021

Feb. 22, 2022

Jun. 30, 2021

Document And Entity Information [Abstract]

Document Type

10-K

Document Annual Report

true

Document Period End Date

Dec. 31, 2021

Current Fiscal Year End Date

--12-31

Document Transition Report

false

Entity File Number

001-37983

Entity Registrant Name

TechnipFMC plc

Entity Incorporation, State or Country Code

X0

Entity Tax Identification Number

98-1283037

Entity Address, Address Line One

Hadrian House,Wincomblee Road

Entity Address, City or Town

Newcastle Upon Tyne

Entity Address, Country

GB

Entity Address, Postal Zip Code

NE6 3PL

Country Region

44

City Area Code

191

Local Phone Number

295-0303

Title of 12(b) Security

Ordinary shares, $1.00 par value per share

Trading Symbol

FTI

Security Exchange Name

NYSE

Entity Well-known Seasoned Issuer

Yes

Entity Voluntary Filers

No

Entity Current Reporting Status

Yes

Entity Interactive Data Current

Yes

Entity Filer Category

Large Accelerated Filer

Entity Small Business

false

Entity Emerging Growth Company

false

ICFR Auditor Attestation Flag

true

Entity Shell Company

false

Entity Public Float

$ 3.3

Documents Incorporated by Reference [Text Block]

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s definitive Proxy Statement relating to its 2022 Annual General Meeting of Shareholders are incorporated by reference into Part III of this Annual Report on Form 10-K where indicated. The 2022 Proxy Statement will be filed with the U.S. Securities and Exchange Commission within 120 days after the end of the fiscal year to which this report relates.

Entity Common Stock, Shares Outstanding

450,700,480

Entity Central Index Key

0001681459

Amendment Flag

false

Document Fiscal Year Focus

2021

Document Fiscal Period Focus

FY

XML

Audit Information	12 Months Ended
	Dec. 31, 2021
Audit information [Abstract]
Auditor Firm ID	238
Auditor Name	PricewaterhouseCoopers LLP
Auditor Location	Houston, Texas

XML

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenue
Lease revenue	$ 158.4	$ 142.0	$ 266.5
Total revenue	6,403.5	6,530.6	6,950.2
Costs and expenses
Cost of lease revenue	128.4	116.7	167.9
Selling, general and administrative expense	644.9	724.1	795.7
Research and development expense	78.4	75.3	149.5
Impairment, restructuring and other expense	66.7	3,402.0	2,456.7
Merger transaction and integration costs	0.0	0.0	14.2
Total costs and expenses	6,369.6	10,037.2	9,308.2
Other income (expense), net	46.6	25.1	(181.6)
Income from equity affiliates (Note 13)	0.6	64.6	59.8
Income from Investment in Technip Energies	322.2	0.0	0.0
Income (loss) before net interest expense and income taxes	403.3	(3,416.9)	(2,479.8)
Interest income	14.0	52.3	43.6
Interest expense	(157.3)	(134.1)	(134.9)
Loss on early extinguishment of debt	(61.9)	0.0	0.0
Income (loss) before income taxes	198.1	(3,498.7)	(2,571.1)
Provision for income taxes (Note 22)	111.1	19.4	79.0
Income (loss) from continuing operations	87.0	(3,518.1)	(2,650.1)
(Income) loss from continuing operations attributable to non-controlling interests	0.8	(34.5)	4.6
Income (loss) from continuing operations attributable to TechnipFMC plc	87.8	(3,552.6)	(2,645.5)
Income (loss) from discontinued operations	(72.6)	280.2	238.0
Income from discontinued operations attributable to non-controlling interests	(1.9)	(15.2)	(7.7)
Net income (loss) attributable to TechnipFMC plc	$ 13.3	$ (3,287.6)	$ (2,415.2)
Earnings (loss) per share from continuing operations attributable to TechnipFMC plc
Earnings (loss) per share from continuing operations basic (usd per share)	$ 0.19	$ (7.92)	$ (5.91)
Earnings (loss) per share from continued operations diluted (usd per share)	0.19	(7.92)	(5.91)
Earnings (loss) per share from discontinued operations basic (usd per share)	(0.17)	0.59	0.51
Earnings (loss) per share from discontinued operations diluted (usd per share)	(0.16)	0.59	0.51
Earnings (loss) per share from continuing operations basic (usd per share)	0.03	(7.33)	(5.39)
Earnings (loss) per share from continuing operations diluted (usd per share)	$ 0.03	$ (7.33)	$ (5.39)
Weighted average shares outstanding (Note 8)
Basic (in shares)	450.5	448.7	448.0
Diluted (in shares)	454.6	448.7	448.0
Service revenue
Revenue
Revenue	$ 3,440.7	$ 3,266.8	$ 3,412.0
Costs and expenses
Cost of product revenue	3,084.7	2,946.9	2,769.5
Product revenue
Revenue
Revenue	2,804.4	3,121.8	3,271.7
Costs and expenses
Cost of product revenue	$ 2,366.5	$ 2,772.2	$ 2,954.7

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest [Abstract]
Net income (loss) attributable to TechnipFMC plc		$ 13.3	$ (3,287.6)	$ (2,415.2)
(Income) loss from continuing operations attributable to non-controlling interests		(0.8)	34.5	(4.6)
Income from discontinued operations attributable to non-controlling interests		1.9	15.2	7.7
Net income (loss) attributable to TechnipFMC plc, including non-controlling interests		14.4	(3,237.9)	(2,412.1)
Foreign currency translation adjustments
Net gains (losses) arising during the period		27.6	(169.1)	15.6
Reclassification adjustment for net (gains) losses included in net income, net of tax		0.0	0.0	(12.0)
Foreign currency translation adjustments	[1]	27.6	(169.1)	3.6
Net gains (losses) on hedging instruments
Net gains (losses) arising during the period		(19.8)	25.4	8.9
Reclassification adjustment for net (gains) losses included in net income		(11.8)	13.0	18.2
Net gains (losses) on hedging instruments	[2]	(31.6)	38.4	27.1
Pension and other post-retirement benefits
Net gains (losses) arising during the period		71.2	(88.3)	(81.5)
Prior service cost arising during the period		(0.4)	(4.6)	(0.7)
Reclassification adjustment for settlement losses included in net income		2.7	1.4	0.2
Reclassification adjustment for amortization of prior service cost included in net income		0.4	0.9	2.0
Reclassification adjustment for amortization of net actuarial loss included in net income		14.9	6.9	0.8
Net pension and other post-retirement benefits	[3]	88.8	(83.7)	(79.2)
Other comprehensive income (loss), net of tax		84.8	(214.4)	(48.5)
Comprehensive income (loss)		99.2	(3,452.3)	(2,460.6)
Comprehensive income attributable to non-controlling interests		0.5	(50.3)	(2.4)
Comprehensive income (loss) attributable to TechnipFMC plc		$ 99.7	$ (3,502.6)	$ (2,463.0)

[1] Net of income tax (expense) benefit of nil, nil and $7.9 million for the years ended December 31, 2021, 2020 and 2019, respectively.

[2] Net of income tax (expense) benefit of $8.8 million, $(9.7) million and $(6.9) million for the years ended December 31, 2021, 2020 and 2019, respectively.

[3] Net of income tax (expense) benefit of $(19.6) million, $25.5 million and $20.3 million for the years ended December 31, 2021, 2020 and 2019, respectively.

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Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest [Abstract]
Foreign currency translation adjustments, tax (expense) benefit	$ 0.0	$ 0.0	$ 7.9
Net income tax (expense) benefit	8.8	(9.7)	(6.9)
Net income tax (expense) benefit	$ (19.6)	$ 25.5	$ 20.3

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Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets
Cash and cash equivalents	$ 1,327.4	$ 1,269.2
Trade receivables, net of allowances of $38.1 in 2021 and $40.2 in 2020	911.9	987.7
Contract assets, net of allowances of $1.1 in 2021 and $2.4 in 2020	966.0	886.8
Inventories, net (Note 10)	1,031.9	1,252.8
Derivative financial instruments (Note 24)	110.3	268.7
Income taxes receivable	85.0	274.7
Advances paid to suppliers	79.4	96.3
Other current assets (Note 11)	512.3	683.4
Investment in Technip Energies	317.3	0.0
Current assets of discontinued operations	0.0	5,725.1
Total current assets	5,341.5	11,444.7
Investments in equity affiliates (Note 13)	292.4	305.5
Property, plant and equipment, net (Note 15)	2,597.2	2,756.2
Operating lease right-of-use assets (Note 5)	707.9	784.9
Finance lease right-of-use assets (Note 5)	52.2	27.5
Intangible assets, net (Note 16)	813.7	851.3
Deferred income taxes (Note 22)	74.3	34.2
Derivative financial instruments (Note 24)	10.5	29.2
Other assets	130.4	175.6
Non-current assets of discontinued operations	0.0	3,283.5
Total assets	10,020.1	19,692.6
Liabilities and equity
Short-term debt and current portion of long-term debt (Note 17)	277.6	624.7
Operating lease liabilities (Note 5)	126.2	195.5
Finance lease liabilities (Note 5)	0.7	26.9
Accounts payable, trade	1,294.3	1,201.0
Contract liabilities	1,012.9	1,046.8
Accrued payroll	194.1	186.8
Derivative financial instruments (Note 24)	161.0	157.5
Income taxes payable	124.6	61.2
Other current liabilities (Note 11)	660.4	818.3
Current liabilities of discontinued operations	0.0	6,096.5
Total current liabilities	3,851.8	10,415.2
Long-term debt, less current portion (Note 17)	1,727.3	2,835.5
Operating lease liabilities, less current portion (Note 5)	646.8	632.8
Finance lease liabilities (Note 5)	51.1	0.0
Deferred income taxes (Note 22)	47.5	79.3
Accrued pension and other post-retirement benefits, less current portion (Note 23)	113.4	268.4
Derivative financial instruments (Note 24)	15.5	18.8
Other liabilities	148.3	103.3
Non-current liabilities of discontinued operations	0.0	1,081.3
Total liabilities	6,601.7	15,434.6
Commitments and contingent liabilities (Note 21)
Redeemable non-controlling interest	0.0	43.7
Stockholders’ equity (Note 18)
Ordinary shares, $1 par value; 618.3 shares authorized in 2021 and 2020; 450.7 shares and 449.5 shares issued and outstanding in 2021 and 2020, respectively; nil shares canceled in 2021 and 2020, respectively	450.7	449.5
Capital in excess of par value of ordinary shares	9,160.8	10,242.4
Accumulated deficit	(4,903.8)	(4,915.2)
Accumulated other comprehensive loss	(1,305.0)	(1,622.5)
Total TechnipFMC plc stockholders’ equity	3,402.7	4,154.2
Total equity	3,418.4	4,214.3
Total liabilities and equity	10,020.1	19,692.6
Non-controlling interests
Stockholders’ equity (Note 18)
Non-controlling interests	15.7	40.4
Non-controlling interests of discontinued operations
Assets
Total assets	0.0	9,008.6
Stockholders’ equity (Note 18)
Non-controlling interests	$ 0.0	$ 19.7

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Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Statement of Financial Position [Abstract]
Receivables, allowances	$ 38.1	$ 40.2
Allowance for contract assets	$ 1.1	$ 2.4
Ordinary shares, par value (in dollars)	$ 1	$ 1
Ordinary shares, shares authorized (in shares)	618,300,000	618,300,000
Ordinary shares, shares issued (in shares)	450,700,000	449,500,000
Ordinary shares, shares outstanding (in shares)	450,700,000	449,500,000
Canceled shares (in shares)	0	0
Ordinary shares, $1 par value; 618.3 shares authorized in 2021 and 2020; 450.7 shares and 449.5 shares issued and outstanding in 2021 and 2020, respectively; nil shares canceled in 2021 and 2020, respectively	$ 450.7	$ 449.5

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Consolidated Statements Of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash provided (required) by operating activities
Net income (loss)	$ 14.4	$ (3,237.9)	$ (2,412.1)
Income (loss) from discontinued operations, net of income taxes	72.6	(280.2)	(238.0)
Adjustments to reconcile net loss to cash provided (required) by operating activities
Depreciation	291.3	308.7	363.0
Amortization	94.1	103.4	104.7
Impairments (Note 20)	49.1	3,273.8	2,480.3
Employee benefit plan and share-based compensation costs	34.3	36.4	48.6
Deferred income tax provision (benefit), net	(95.1)	(31.8)	27.9
Income from investment in Technip Energies	(322.2)	0.0	0.0
Unrealized loss (gain) on derivative instruments and foreign exchange	30.8	(13.3)	22.4
Loss from equity affiliates, net of dividends received	(0.6)	(58.2)	(58.9)
Loss on early extinguishment of debt	61.9	0.0	0.0
Other	(5.5)	(32.7)	(97.1)
Changes in operating assets and liabilities, net of effects of acquisitions
Trade receivables, net and contract assets	(73.1)	433.4	(142.5)
Inventories, net	197.7	87.4	(173.3)
Accounts payable, trade	93.8	(236.4)	(56.1)
Contract liabilities	0.9	(61.8)	352.0
Income taxes payable (receivable), net	214.7	(56.1)	(31.1)
Other current assets and liabilities, net	63.5	551.2	142.0
Other non-current assets and liabilities, net	(7.6)	(13.5)	25.9
Cash provided by operating activities from continuing operations	715.0	772.4	357.7
Cash provided (required) by operating activities from discontinued operations	66.3	(115.5)	490.8
Cash provided by operating activities	781.3	656.9	848.5
Cash provided (required) by investing activities
Capital expenditures	(191.7)	(256.1)	(412.7)
Payment to acquire debt securities	(29.1)	(3.9)	(71.6)
Proceeds from sale of debt securities	27.4	51.5	18.9
Acquisitions, net of cash acquired	(15.3)	0.0	16.0
Proceeds from sale of assets	104.6	45.5	7.4
Proceeds from sales of investment in Technip Energies	900.9	0.0	0.0
Proceeds from repayment of advance to joint venture	25.0	26.7	62.0
Other	0.0	15.5	1.5
Cash provided (required) by investing activities from continuing operations	821.8	(120.8)	(378.5)
Cash required by investing activities from discontinued operations	(4.5)	(59.8)	(41.3)
Cash provided (required) by investing activities	817.3	(180.6)	(419.8)
Cash required by financing activities
Net decrease in short-term debt	(62.0)	(31.9)	(49.6)
Net increase (decrease) in commercial paper	(974.3)	(340.9)	113.3
Proceeds from issuance of long-term debt	1,164.4	223.2	96.2
Repayments of long-term debt	(1,462.2)	(423.9)	0.0
Payments for debt issuance cost	(60.4)	0.0	0.0
Purchase of ordinary shares	0.0	0.0	(92.7)
Dividends paid	0.0	(59.2)	(232.8)
Acquisition of non-controlling interest	(48.6)	0.0	0.0
Other	(4.2)	(19.2)	0.0
Cash required by financing activities from continuing operations	(1,447.3)	(651.9)	(165.6)
Cash required by financing activities from discontinued operations	(3,617.7)	(430.3)	(618.8)
Cash required by financing activities	(5,065.0)	(1,082.2)	(784.4)
Effect of changes in foreign exchange rates on cash and cash equivalents	(14.0)	223.5	5.9
Decrease in cash and cash equivalents	(3,480.4)	(382.4)	(349.8)
Cash and cash equivalents in the statement of cash flows, beginning of year	4,807.8	5,190.2	5,540.0
Cash and cash equivalents in the statement of cash flows, end of year	1,327.4	4,807.8	5,190.2
Supplemental disclosures of cash flow information attributable to continuing operations
Cash paid for interest (net of interest capitalized)	104.1	96.0	91.5
Cash paid for income taxes (net of refunds received)	25.1	107.8	104.2
Cash and cash equivalents	1,327.4	1,269.2	1,563.1
Cash and cash equivalents attributable to discontinued operations	0.0	3,538.6	3,627.1
Total cash and cash equivalents in the statement of cash flows	$ 1,327.4	$ 4,807.8	$ 5,190.2

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Consolidated Statements of Changes in Stockholders' Equity € in Millions, $ in Millions	USD ($)	EUR (€)	Cumulative Effect, Period of Adoption, Adjustment USD ($)	Ordinary Shares Issued USD ($)	Ordinary Shares Held in Treasury and Employee Benefit Trust USD ($)	Capital in Excess of Par Value of Ordinary Shares USD ($)	Retained Earnings (Accumulated Deficit) USD ($)	Retained Earnings (Accumulated Deficit) Cumulative Effect, Period of Adoption, Adjustment USD ($)	Accumulated Other Comprehensive Income (Loss) USD ($)	Non- controlling Interest USD ($)
Beginning balance at Dec. 31, 2018	$ 10,388.9			$ 450.5	$ (2.4)	$ 10,197.0	$ 1,072.2		$ (1,359.7)	$ 31.3
Beginning balance (Accounting Standards Update 2014-09) at Dec. 31, 2018			$ 1.8					$ 1.8
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(2,412.1)						(2,415.2)			3.1
Other comprehensive loss	(48.5)								(47.8)	(0.7)
Cancellation of treasury shares (Note 18)	(92.7)			(4.0)		(88.7)
Issuance of ordinary shares	0.6			0.6
Cash dividends declared	(232.8)	€ (232.8)					(232.8)
Net sales of ordinary shares for employee benefit trust	2.4				2.4
Share-based compensation (Note 19)	74.5					74.5
Other	6.0						10.9			(4.9)
Ending balance at Dec. 31, 2019	7,688.1			447.1	0.0	10,182.8	(1,563.1)		(1,407.5)	28.8
Ending balance (Accounting Standards Update 2016-02) at Dec. 31, 2019			$ (7.8)					$ (7.8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(3,237.9)						(3,287.6)			49.7
Other comprehensive loss	(214.4)								(215.0)	0.6
Cancellation of treasury shares (Note 18)	0.0
Issuance of ordinary shares	(7.0)			2.4		(9.4)
Cash dividends declared	(59.2)	€ (59.2)					(59.2)
Share-based compensation (Note 19)	69.0					69.0
Distributions to non-controlling interest	(11.5)						(9.4)			(2.1)
Other	(5.0)						11.9			(16.9)
Ending balance at Dec. 31, 2020	4,214.3			449.5	0.0	10,242.4	(4,915.2)		(1,622.5)	60.1
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	14.4						13.3			1.1
Other comprehensive loss	84.8								86.4	(1.6)
Cancellation of treasury shares (Note 18)	0.0
Issuance of ordinary shares	1.2			1.2
Cash dividends declared	0.0
Share-based compensation (Note 19)	26.8					26.8
Spin-off of Technip Energies (Note 2)	(897.2)					(1,108.4)			231.1	(19.9)
Distributions to non-controlling interest	(15.0)									(15.0)
Other	(10.9)						(1.9)			(9.0)
Ending balance at Dec. 31, 2021	$ 3,418.4			$ 450.7	$ 0.0	$ 9,160.8	$ (4,903.8)		$ (1,305.0)	$ 15.7

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Consolidated Statements of Changes in Stockholders' Equity (Parentheticals) - $ / shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Statement of Stockholders' Equity [Abstract]
Common stock, dividends (in usd per share)	$ 0.13	$ 0.52

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BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of operations - TechnipFMC plc and consolidated subsidiaries (“TechnipFMC,” “we,” “us” or “our”) is a global leader in oil and gas projects, technologies, systems and services through our business segments: Subsea and Surface Technologies. We have manufacturing operations worldwide, strategically located to facilitate delivery of our products, systems and services to our customers.

Basis of presentation - Our consolidated financial statements were prepared in U.S. dollars and in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and rules and regulations of the Securities and Exchange Commission (“SEC”) pertaining to annual financial information. The preparation of financial statements in conformity with these accounting principles requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Ultimate results could differ from our estimates.

Principles of consolidation - The consolidated financial statements include the accounts of TechnipFMC and its majority-owned subsidiaries and affiliates. Intercompany accounts and transactions are eliminated in consolidation.

Use of estimates - The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. Such estimates include, but are not limited to, estimates of total contract profit or loss on long-term construction-type contracts; estimated realizable value on excess and obsolete inventory; estimates related to pension accounting; estimates related to fair value for purposes of assessing goodwill, long-lived assets and intangible assets for impairment; estimates of fair value in business combinations and estimates related to income taxes.

Investments in the common stock of unconsolidated affiliates - The equity method of accounting is used to account for investments in unconsolidated affiliates where we have the ability to exert significant influence over the affiliates’ operating and financial policies. We measure equity investments not accounted for under the equity method at fair value and recognize any changes in fair value in net income. For certain construction joint ventures, we use the proportionate consolidation method, whereby our proportionate share of each entity’s assets, liabilities, revenues and expenses are included in the appropriate classifications in the consolidated financial statements. Intercompany balances and transactions have been eliminated in preparing the consolidated financial statements.

Investments in unconsolidated affiliates are assessed for impairment whenever events or changes in facts and circumstances indicate the carrying value of the investments may not be fully recoverable. When such a condition is subjectively determined to be other than temporary, the carrying value of the investment is written down to fair value. Management’s assessment as to whether any decline in value is other than temporary is based on our ability and intent to hold the investment and whether evidence indicating the carrying value of the investment is recoverable within a reasonable period of time outweighs evidence to the contrary. Management generally considers our investments in equity method investees to be strategic, long-term investments and completes its assessments for impairment with a long-term viewpoint.

Investments in which ownership is less than 20% or that do not represent significant investments are reported in other assets in the consolidated balance sheets. Where no active market exists and where no other valuation method can be used, these financial assets are maintained at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer.

We determine whether investments involve a variable interest entity (“VIE”) based on the characteristics of the subject entity. If the entity is determined to be a VIE, then management determines if we are the primary beneficiary of the entity and whether or not consolidation of the VIE is required. The primary beneficiary consolidating the VIE must normally have both (i) the power to direct the activities that most significantly affect the VIE’s economic performance and (ii) the obligation to absorb significant losses of or the right to receive significant benefits from the VIE. If we are deemed to be the primary beneficiary, the VIE is consolidated and the other party’s equity interest in the VIE is accounted for as a non-controlling interest. Our unconsolidated VIEs are accounted for using the equity method of accounting.

Business combinations - Business combinations are accounted for using the acquisition method of accounting. Under the acquisition method, assets acquired and liabilities assumed are recorded at their respective fair values as of the acquisition date. Determining the fair value of assets and liabilities involves significant judgment regarding methods and assumptions used to calculate estimated fair values. The purchase price is allocated to the acquired assets, assumed liabilities and identifiable intangible assets based on their estimated fair values. Any excess of the purchase price over the estimated fair values of the net assets acquired is recorded as goodwill. Transaction related costs are expensed as incurred. 

Leases - The majority of our leases are operating leases. We account for leases in accordance with Accounting Standard Codification (“ASC”)Topic 842, Leases, which we adopted on January 1, 2019 using the modified retrospective method. See Note 5 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 ASC Topic 606, Revenue from Contracts with Customers. See Note 6 for further details.

Contract costs to obtain a contract - Our incremental direct costs of obtaining a contract are deferred and amortized over the period of contract performance or a longer period, generally the estimated life of the customer relationship, if renewals are expected and the renewal commission is not commensurate with the initial commission. We classify deferred commissions as current or non-current based on the timing of when we expect to recognize the expense. The current and non-current portions of deferred commissions are included in other current assets and other assets, respectively, in our consolidated balance sheets.

Amortization of deferred commissions is included in selling, general and administrative expenses in our consolidated statements of income.

Cash equivalents - Cash equivalents are highly-liquid, short-term investments with original maturities of three months or less from their date of purchase.

Trade receivables, net of allowances - An allowance for doubtful accounts is provided on receivables equal to the estimated uncollectible amounts and is calculated based on loss rates from historical data. We develop loss-rate statistics on the basis of the amount written off over the life of the receivable and adjust these historical credit loss trends for forward-looking factors specific to the debtors and the economic environment to determine lifetime expected losses.

Inventories - Inventories are stated at the lower of cost or net realizable value, except as it relates to inventory measured using the last-in, first-out (“LIFO”) method, for which the inventories are stated at the lower of cost or market. Inventory costs include those costs directly attributable to products, including all manufacturing overhead, but excluding costs to distribute. Cost for a significant portion of the U.S. domiciled inventories is determined on the LIFO method. The first-in, first-out (“FIFO”) or weighted average methods are used to determine the cost for the remaining inventories. Write-down of inventories is recorded when the net realizable value of inventories is lower than their net book value.

Property, plant and equipment - Property, plant, and equipment is recorded at cost. Depreciation is principally provided on the straight-line basis over the estimated useful lives of the assets (vessels - 10 to 30 years; buildings - 10 to 50 years; and machinery and equipment - 3 to 20 years). Gains and losses are realized upon the sale or retirement of assets and are recorded in other income (expense), net on our consolidated statements of income. Maintenance and repair costs are expensed as incurred. Expenditures that extend the useful lives of property, plant and equipment are capitalized and depreciated over the estimated new remaining life of the asset.

Impairment of property, plant and equipment - Property, plant and equipment are reviewed for impairment whenever events or changes in circumstances indicate the carrying value of the long-lived asset may not be recoverable. The carrying value of an asset group 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 impairment loss is measured as the amount by which the carrying value of the long-lived asset exceeds its fair value.

Long-lived assets classified as held for sale are reported at the lower of carrying value or fair value less cost to sell.

Goodwill - Goodwill is not subject to amortization but is tested for impairment on an annual basis (or more frequently if impairment indicators arise) by comparing the estimated fair value of each reporting unit to its carrying value, including goodwill. A reporting unit is defined as an operating segment or one level below the operating segment. We have established October 31 as the date of our annual test for impairment of goodwill. Reporting units with goodwill are tested for impairment using a quantitative impairment test known as the income approach, which estimates fair value by discounting each reporting unit’s estimated future cash flows using a weighted-average cost of capital that reflects current market conditions and the risk profile of the reporting unit. To arrive at our future cash flows, we use estimates of economic and market assumptions, including growth rates in revenues, costs, estimates of future expected changes in operating margins, tax rates and cash expenditures. Future revenues are also adjusted to match changes in our business strategy. If the fair value of the reporting unit is less than its carrying amount as a result of this method, then an impairment loss is recorded.

A lower fair value estimate in the future for any of our reporting units could result in goodwill impairments. Factors that could trigger a lower fair value estimate include sustained price declines of the reporting unit’s products and services, cost increases, regulatory or political environment changes, changes in customer demand, and other changes in market conditions, which may affect certain market participant assumptions used in the discounted future cash flow model. As of December 31, 2021, we did not have any goodwill outstanding.

Intangible assets - Our acquired intangible assets are generally amortized on a straight-line basis over their estimated useful lives, which generally range from 2 to 20 years. Our acquired intangible assets do not have indefinite lives. Intangible assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of the intangible asset may not be recoverable. The carrying amount of an intangible 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 intangible asset exceeds its fair value.

Capitalized software costs are recorded at cost. Capitalized software costs include purchases of software and internal and external costs incurred during the application development stage of software projects. These costs are amortized on a straight-line basis over the estimated useful lives. For internal use software, the useful lives range from 3 to 10 years. For Internet website costs, the estimated useful lives do not exceed 3 years.

Research and development expense is expensed as incurred. Research and development expense includes improvement of existing products and services, design and development of new products and services and test of new technologies.

Debt instruments - Debt instruments include senior and private placement notes and other borrowings. Issuance fees and redemption premium on debt instruments are included in the cost of debt in the consolidated balance sheets, as an adjustment to the nominal amount of the debt. Loan origination costs for revolving credit facilities are recorded as an asset and amortized over the life of the underlying debt.

Fair value measurements - Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the reporting date. The fair value framework requires the categorization of assets and liabilities measured at fair value into three levels based upon the assumptions (inputs) used to price the assets or liabilities, with the exception of certain assets and liabilities measured using the net asset value practical expedient, which are not required to be leveled. Level 1 provides the most reliable measure of fair value, whereas Level 3 generally requires significant management judgment. The three levels are defined as follows:

•Level 1: Unadjusted quoted prices in active markets for identical assets and liabilities.

•Level 2: Observable inputs other than quoted prices included in Level 1. For example, quoted prices for similar assets or liabilities in active markets or quoted prices for identical assets or liabilities in inactive markets.

•Level 3: Unobservable inputs reflecting management’s own assumptions about the assumptions market participants would use in pricing the asset or liability.

Income taxes - Current income taxes are provided on income reported for financial statement purposes, adjusted for transactions that do not enter into the computation of income taxes payable in the same year. Deferred tax assets and liabilities are measured using enacted tax rates for the expected future tax consequences of temporary differences between the carrying amounts and the tax basis of assets and liabilities. A valuation allowance is established whenever management believes that it is more likely than not that deferred tax assets may not be realizable.

Income taxes are not provided on our equity in undistributed earnings of foreign subsidiaries or affiliates to the extent we have determined that the earnings are indefinitely reinvested. Income taxes are provided on such earnings in the period in which we can no longer support that such earnings are indefinitely reinvested.

Tax benefits related to uncertain tax positions are recognized when it is more likely than not, based on the technical merits, that the position will be sustained upon examination.

We classify interest expense and penalties recognized on underpayments of income taxes as income tax expense.

Share-based compensation - The measurement of share-based compensation expense on restricted share awards and performance share awards is based on the market price at the grant date and the number of shares awarded. We use Black-Scholes options pricing model to measure the fair value of stock options granted on or after January 1, 2017. The stock-based compensation expense for each award is recognized ratably over the applicable service period or the period beginning at the start of the service period and ending when an employee becomes eligible for retirement, after taking into account estimated forfeitures.

Earnings per ordinary share (“EPS”) - Basic EPS is computed using the weighted-average number of ordinary shares outstanding during the year. We use the treasury stock method to compute diluted EPS which gives effect to the potential dilution of earnings that could have occurred if additional shares were issued for awards granted under our incentive compensation and stock plan. The treasury stock method assumes proceeds that would be obtained upon exercise of awards granted under our incentive compensation and stock plan are used to purchase outstanding ordinary shares at the average market price during the period.

Foreign currency - Financial statements of operations for which the U.S. dollar is not the functional currency, and which are located in non-highly inflationary countries, are translated into U.S. dollars prior to consolidation. Assets and liabilities are translated at the exchange rate in effect at the balance sheet date, while income statement accounts are translated at the average exchange rate for each period. For these operations, translation gains and losses are recorded as a component of accumulated other comprehensive income (loss) in stockholders’ equity until the foreign entity is sold or liquidated. For operations in highly inflationary countries and where the local currency is not the functional currency, inventories, property, plant and equipment, and other non-current assets are converted to U.S. dollars at historical exchange rates, and all gains or losses from conversion are included in net income. Foreign currency effects on cash, cash equivalents and debt in highly inflationary economies are included in interest income or expense.

For certain committed and anticipated future cash flows and recognized assets and liabilities which are denominated in a foreign currency, we may choose to manage our risk against changes in the exchange rates, when compared against the functional currency, through the economic netting of exposures instead of derivative instruments. Cash outflows or liabilities in a foreign currency are matched against cash inflows or assets in the same currency, such that movements in exchange rates will result in offsetting gains or losses. Due to the inherent unpredictability of the timing of cash flows, gains and losses in the current period may be economically offset by gains and losses in a future period. All gains and losses are recorded in our consolidated statements of income in the period in which they are incurred. Gains and losses from the remeasurement of assets and liabilities are recognized in other income (expense), net.

Derivative instruments - Derivatives are recognized on the consolidated balance sheets at fair value, with classification as current or non-current based upon the maturity of the derivative instrument. Changes in the fair value of derivative instruments are recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on the type of hedging transaction and whether a derivative is designated as, and is effective as, a hedge. Each instrument is accounted for individually and assets and liabilities are not offset.

Hedge accounting is only applied when the derivative is deemed to be highly effective at offsetting changes in anticipated cash flows of the hedged item or transaction. Changes in fair value of derivatives that are designated as cash flow hedges are deferred in accumulated other comprehensive income (loss) until the underlying transactions are recognized in earnings. At such time, related deferred hedging gains or losses are recorded in earnings on the same line as the hedged item. Effectiveness is assessed at the inception of the hedge and on a quarterly basis. Effectiveness of forward contract cash flow hedges are assessed based solely on changes in fair value attributable to the change in the spot rate. The change in the fair value of the contract related to the change in forward rates is excluded from the assessment of hedge effectiveness. Changes in this excluded component of the derivative instrument, along with any ineffectiveness identified, are recorded in earnings as incurred. We document our risk management strategy and hedge effectiveness at the inception of, and during the term of, each hedge.

We also use forward contracts to hedge foreign currency assets and liabilities, for which we do not apply hedge accounting. The changes in fair value of these contracts are recognized in other income (expense), net on our consolidated statements of income, as they occur and offset gains or losses on the remeasurement of the related asset or liability.

Reclassifications - Certain prior-year amounts have been reclassified to conform to the current year’s presentation.

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DISCONTINUED OPERATIONS

12 Months Ended

Dec. 31, 2021

Discontinued Operations and Disposal Groups [Abstract]

DISCONTINUED OPERATIONS

DISCONTINUED OPERATIONS

The Spin-off

On February 16, 2021, we completed our separation of the Technip Energies business segment. The transaction was structured as a spin-off (the “Spin-off”), which occurred by way of a pro rata dividend (the “Distribution”) to our shareholders of 50.1% 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., Eastern Standard 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.

In connection with the Spin-off, TechnipFMC and Technip Energies entered into a separation and distribution agreement, as well as various other agreements, including, among others, a tax matters agreement, an employee matters agreement and a transition services agreement and certain agreements relating to intellectual property. These agreements provide for the allocation between TechnipFMC and Technip Energies of assets, employees, taxes, liabilities and obligations attributable to periods prior to, at and after the Spin-off.

Discontinued Operations

The Spin-off represented a strategic shift that will have a major impact on our operations and consolidated financial statements. Accordingly, historical results of Technip Energies prior to the Distribution on February 16, 2021 have been presented as discontinued operations in our consolidated statements of income, consolidated balance sheets and consolidated statements of cash flows for the years ended December 31, 2021, 2020 and 2019. Our consolidated statements of income, consolidated balance sheets and consolidated statements of cash flows and notes to the consolidated financial statements have been updated to reflect continuing operations only.

The following table summarizes the components of income from discontinued operations, net of tax:

	Year Ended
(In millions)	2021		2020		2019
Revenue	$	906.0	$	6,520.0	$	6,458.9
Costs and expenses	(932.0)		(5,899.0)		(5,627.6)
Other income and (expense), net	(18.6)		(206.8)		(396.0)
Income (loss) from discontinued operations before income taxes	$	(44.6)	$	414.2	$	435.3
Income (loss) from discontinued operations, net of income taxes	$	(72.6)	$	280.2	$	238.0

Supplemental information:

	Year Ended
(In millions)	2021		2020		2019
Capital expenditures	$	5.1	$	35.7	$	41.7
Depreciation and amortization expense	17.1		35.1		41.9
Research and development expense	4.4		44.5		13.4

Assets and liabilities of discontinued operations are summarized below:

	December 31,
(In millions)	2020
Assets
Cash and cash equivalents	$	3,538.6
Trade receivables, net of allowances	1,302.1
Contract assets	380.8
Other current assets	503.6
Total current assets of discontinued operations	5,725.1
Property, plant and equipment, net of accumulated depreciation	105.6
Goodwill	2,512.5
Other assets	665.4
Total non-current assets of discontinued operations	3,283.5
Total assets of discontinued operations	$	9,008.6
Liabilities
Accounts payable, trade	$	1,539.5
Contract liabilities	3,689.3
Other current liabilities	867.7
Total current liabilities of discontinued operations	6,096.5
Long-term debt, less current portion	482.2
Operating lease liabilities	248.2
Other liabilities	350.9
Total non-current liabilities of discontinued operations	1,081.3
Total liabilities of discontinued operations	$	7,177.8

On February 16, 2021, all assets and liabilities of Technip Energies were spun-off; therefore, as of December 31, 2021, there were no assets and liabilities classified as discontinued operations. During the fourth quarter of 2021, we finalized the disposition process, which resulted in an immaterial adjustment to the net assets transferred to Technip Energies in the statement of stockholders’ equity. As of December 31, 2021, we had $84.4 million and $72.2 million of accounts receivable and accounts payable, respectively, outstanding with Technip Energies.

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BUSINESS COMBINATION AND OTHER TRANSACTIONS

12 Months Ended

Dec. 31, 2021

Business Combinations [Abstract]

BUSINESS COMBINATION AND OTHER TRANSACTIONS

BUSINESS COMBINATION AND OTHER TRANSACTIONS

2021

Magma Global Ltd.

In 2018, we entered into a collaboration agreement with Magma Global Ltd. (“Magma Global”) to develop a new generation of hybrid flexible pipe for use in the traditional and new energy industries. As part of the collaboration, we purchased a minority ownership interest in Magma Global.

In October 2021, we entered into a transaction to purchase the remaining ownership interest in Magma Global for $64.0 million. The cash consideration will be paid to the shareholders of Magma Global in three annual installments. The first payment of $23.9 million was paid on October 12, 2021. Magma technology enables the manufacture of

Thermoplastic Composite Pipe (TCP) using Polyether Ether Ketone (PEEK) polymer, which is highly resistant to corrosive compounds, such as CO2.

With the step acquisition of the remaining outstanding shares of Magma Global and our resulting control of the company, we recorded a $36.7 million impairment during the third quarter of 2021 to adjust our equity method investment to its estimated fair market value. The impairment charge is included in income/loss from equity affiliates line in our consolidated statement of income.

As a result of the purchase price allocation of the remaining interest, we recognized $50.2 million of intangible assets consisting primarily of in-process research and development and trademarks, which are being amortized on a straight-line basis over 15 years. The fair value of the identifiable intangible assets has been estimated using an income approach.

TIOS

In accordance with the Share Purchase Agreement between Technip-Coflexip UK Holdings Limited (“TUK”) and Island Offshore Management AS (“Island Offshore”) that was executed on March 12, 2018, whereby TUK initially purchased 51% of the shares of TIOS AS (“TIOS”), a joint venture between TUK and Island Offshore, TUK acquired the remaining 49% interest in TIOS at a total price of $48.6 million during the third quarter of 2021. As of December 31, 2020, we owned a 51% share in TIOS and the redeemable non-controlling interest was recorded as mezzanine equity at fair value of $43.7 million. As of December 31, 2021 and 2020, TIOS was fully consolidated.

2019

On December 30, 2019, we completed the acquisition of the remaining 50% interest in Technip Odebrecht PLSV CV (“TOP CV”). TOP CV was formed as a joint venture between Technip SA and Ocyan SA to provide pipeline installation ships to Petroleo Brasileiro SA (“Petrobras”) for their work in oil and gas fields offshore Brazil with results reported in our Subsea segment using the equity method of accounting. Subsequent to this transaction the investment became a fully consolidated entity. In connection with the acquisition, we acquired $391.0 million in assets, including two vessels valued at $335.2 million. In addition, we assumed $239.9 million of liabilities, including a $203.1 million term loan. As a result of the acquisition, we recorded a net loss of $0.9 million. The net loss on acquisition was comprised of the impairment charge of $84.2 million partially offset by a gain on bargain purchase of $83.3 million included within restructuring and other charges in our consolidated statement of income.

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NEW ACCOUNTING STANDARDS

12 Months Ended

Dec. 31, 2021

Accounting Standards Update and Change in Accounting Principle [Abstract]

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS

Recently Adopted Accounting Standards under GAAP

In August 2018, the FASB issued ASU No. 2018-14, “Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans.” This update amends ASC 715 to add, remove, and clarify disclosure requirements related to defined benefit pension and other post-retirement plans. We adopted this amendment as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In December 2019, the FASB issued ASU No. 2019-12, “Income Taxes to Topic 740—Simplifying the Accounting for Income Taxes.” The amendments simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740. This update also improves and simplifies areas of GAAP for which cost and complexity can be reduced while maintaining or improving the usefulness of the information provided to users of financial statements. We adopted this amendment as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In January 2020, the FASB issued ASU No. 2020-01, “Investments—Equity Securities (Topic 321),” “Investments—Equity Method and Joint Ventures (Topic 323),” and “Derivatives and Hedging (Topic 815)—Clarifying the Interactions between Topic 321, Topic 323, and Topic 815,” and made targeted improvements to address certain aspects of accounting for financial instruments. This update clarifies that a company should consider observable transactions that require a company to either apply or discontinue the equity method of accounting under Topic 323, Investments—Equity Method and Joint Ventures, for the purposes of applying the measurement alternative in accordance with Topic 321 immediately before applying or upon discontinuing the equity method. The new ASU

also clarifies that, when determining the accounting for certain forward contracts and purchased options, a company should not consider whether underlying securities would be accounted for under the equity method or fair value option upon settlement or exercise. We adopted this amendment as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In October 2020, the FASB issued ASU No. 2020-10, “Codification Improvements.” The amendments in this update improve consistency by amending the accounting standards codification (the “Codification”) to include all disclosure guidance in the appropriate sections and clarify the application of various provisions in the Codification by amending and adding new headings, cross-referencing to other guidance, and refining or correcting terminology. We adopted this update as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

In August 2020, the FASB issued ASU No. 2020-06, “Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815 – 40).” This update simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts in an entity’s own equity. We adopted this update as of January 1, 2021, which did not have a material impact on our consolidated financial statements.

Recently Issued Accounting Standards under GAAP

In March 2020, the FASB issued ASU No. 2020-04, “Facilitation of the Effects of Reference Rate Reform on Financial Reporting (Topic 848).” In addition, in January 2021, FASB issued ASU No. 2021-01, “Reference Rate Reform (Topic 848)” which clarifies the scope of Topic 848. The amendments in these updates apply only to contracts, hedging relationships, and other transactions that reference the London interbank offered rate (“LIBOR”) or another reference rate expected to be discontinued because of reference rate reform. The expedients and exceptions provided by the amendments do not apply to contract modifications made and hedging relationships entered into or evaluated after December 31, 2022, except for hedging relationships existing as of December 31, 2022, that an entity has elected certain optional expedients for and that are retained through the end of the hedging relationship. The amendments in this update were issued as of March 12, 2020, effective through December 31, 2022. We do not anticipate the adoption of this update to have a material impact on our consolidated financial statements.

In October 2021, the FASB issued ASU No. 2021-08, “Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers.” This ASU requires entities to apply Topic 606 to recognize and measure contract assets and contract liabilities in a business combination. The amendments are effective for public business entities for fiscal years, including interim periods within those fiscal years, beginning after December 15, 2022. The amendment is this update should be applied with early adoption permitted. We do not anticipate the adoption of this update to have a material impact on our consolidated financial statements.

We consider the applicability and impact of all ASUs. We assessed ASUs not listed above and determined that they either were not applicable or were not expected to have a material impact on our financial statements.

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LEASES

12 Months Ended

Dec. 31, 2021

Leases [Abstract]

LEASES

LEASES

Lessee Arrangements

We lease real estate, including land, buildings and warehouses, machinery/equipment, vessels, vehicles, and various types of manufacturing and data processing equipment, from a lessee perspective. Leases of real estate generally provide for payment of property taxes, insurance, and repairs by us. Substantially all our leases are classified as operating leases.

We determine if an arrangement is a lease at inception by assessing whether an identified asset exists and if we have the right to control the use of the identified asset. Operating leases are included in Operating lease right-of-use assets, Operating lease liabilities (current), and Operating lease liabilities (non-current) in our consolidated balance sheets. Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease right-of-use assets and liabilities are recognized at the commencement date based on the present value of the remaining lease payments over the lease term. With the exception of rare cases in which the implicit rate is readily determinable, we use our incremental borrowing rate based on the information available at the commencement date in determining the present value of lease payments. The Operating lease right-of-use assets also includes any lease prepayments

made and excludes lease incentives we received from the lessor. Lease cost for lease payments is recognized on a straight-line basis over the lease term. Several of our leases provide for certain guarantees of residual value. We estimate and include in the determination of lease payments any amount probable of being owed under these residual value guarantees.

Lease terms within our lessee arrangements may include options to extend/renew or terminate the lease and/or purchase the underlying asset when it is reasonably certain that we will exercise that option. TechnipFMC applies a portfolio approach by asset class to determine lease term renewals. The leases within these portfolios are categorized by asset class and have initial lease terms that vary depending on the asset class. The renewal terms range from 60 days to 5 years for asset classes such as temporary residential housing, forklifts, vehicles, vessels, office and IT equipment, and tool rentals, and up to 15 years or more for commercial real estate. Short-term leases with an initial term of 12 months or less that do not include a purchase option are not recorded on the balance sheet. Lease costs for short-term leases are recognized on a straight-line basis over the lease term and amounts related to short-term leases are disclosed within our financial statements.

TechnipFMC has variable lease payments, including adjustments to lease payments based on an index or rate (such as the Consumer Price Index), fair value adjustments to lease payments, and common area maintenance, real estate taxes, and insurance payments in triple-net real estate leases. Variable lease payments that depend on an index or a rate (such as the Consumer Price Index or a market interest rate) are included when measuring consideration within our lease arrangements using the payments’ base rate or index. Variable payments that do not depend on an index or rate are recognized in the consolidated income statements and are disclosed as “variable lease costs” in the period they are incurred.

We adopted the practical expedient to not separate lease and non-lease components for all asset classes except for vessels, which have significant non-lease components.

TechnipFMC currently subleases certain of its leased real estate and vessels to third parties.

The following table is a summary of the Company’s components of net lease cost for the years ended December 31, 2021 and 2020:

	Year Ended December 31,
(In millions)	2021		2020
Operating lease costs including variable costs	$	175.9	$	195.6
Short-term lease costs	5.2		11.0
Less: sublease income	2.4		2.8
Net lease cost	$	178.7	$	203.8

Supplemental cash flow information related to leases for the years ended December 31, 2021 and 2020 is as follows:

	Year Ended December 31,
(In millions)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	176.5	$	206.5
Right-of-use assets obtained in exchange for lease liabilities
Operating leases	$	114.9	$	421.3
Finance leases	$	24.6	$	26.9

Supplemental balance sheet information related to leases as of December 31, 2021 and 2020 is as follows:

	December 31,
(In millions, except lease term and discount rate)	2021		2020
Weighted average remaining lease term
Operating leases	13.3 years		13.6 years
Finance leases	1.1 years		0.6 years
Weighted average discount rate
Operating leases	5.86	%	5.35	%
Finance leases	1.2	%	2.1	%

Maturities of operating and finance lease liabilities as of December 31, 2021 are as follows:

(In millions)	Maturity of Operating Lease Liabilities		Maturity of Finance Lease Liabilities
2022	$	150.2	$	1.0
2023	108.3		103.0
2024	102.3		—
2025	83.1		—
2026	74.7		—
Thereafter	675.9		—
Total lease payments	1,194.5		104.0
Less: Imputed interest (a)	421.5		52.2
Total lease liabilities (b)	$	773.0	$	51.8

Note: For leases that commenced prior to 2019, minimum lease payments exclude payments to landlords for real estate taxes and common area maintenance.

(a)Calculated using the interest rate for each lease.

(b)Includes the current portion of $126.9 million.

In December 2020, TechnipFMC sold its leased office building at Gremp Campus in Houston, Texas on behalf of the existing lessor to Oak Street Real Estate Capital, LLC (“New Lessor”). TechnipFMC also sold the underlying land at Gremp Campus, which the Company owned, to the New Lessor. TechnipFMC concurrently executed a new lease agreement for both the land and the office building (collectively, “Gremp Campus Properties”) with New Lessor.

The new lease agreement of Gremp Campus Properties commenced on December 11, 2020 and the initial term ends on December 31, 2042. TechnipFMC paid net cash of $1.8 million in connection with the new lease agreement and recognized a loss of $3.1 million from derecognition of the existing lease. There was no gain or loss from the sale of the land at Gremp Campus.

Lessor Arrangements

We lease real estate including land, buildings and warehouses, machinery/equipment, and vessels from a lessor perspective. We determine if an arrangement is a lease at inception by assessing whether an identified asset exists and if the customer has the right to control the use of the identified asset. We use our implicit rate for our lessor arrangements. We have elected the practical expedient available for lessors to not separate lease and non-lease components for vessels. If the non-lease component is predominant in our contracts, we account for the contracts under the revenue recognition guidance in ASU 2014-09, “Revenue from Contracts with Customers” (Topic 606). If the lease component is predominant in our contracts, we account for the contracts under the lease guidance in Topic 842. We estimate the amount we expect to derive from the underlying asset following the end of the lease term based on remaining economic life. Our lessor arrangements generally do not include any residual value guarantees. We recognize lessee payments of lessor costs such as taxes and insurance on a net basis when the lessee pays those costs directly to a third party or when the amount paid by the lessee is not readily determinable.

Our operating lease revenue, including variable revenue, was $158.4 million and $142.0 million for the years ended December 31, 2021 and 2020, respectively. During the next five years, we expect to receive $19.3 million in

total undiscounted cash flows, of which $18.3 million is expected to be received in 2022 and $1.0 million is expected to be received in 2023.

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REVENUE

12 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

REVENUE

REVENUE

The majority of our revenue is from long-term contracts associated with designing and manufacturing products and systems and providing services to customers involved in exploration and production of crude oil and natural gas.

Significant Revenue Recognition Criteria Explained

Allocation of transaction price to performance obligations - A contract’s transaction price is allocated to each distinct performance obligation and recognized as revenue, when, or as, the performance obligation is satisfied. To determine the proper revenue recognition method, we evaluate whether two or more contracts should be combined and accounted for as one single contract and whether the combined or single contract should be accounted for as more than one performance obligation. This evaluation requires significant judgment; some of our contracts have a single performance obligation as the promise to transfer the individual goods or services is not separately identifiable from other promises in the contracts and, therefore, not distinct.

Variable consideration - 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 variable considerations that can either increase or decrease the transaction price. Variability in the transaction price arises primarily due to liquidated damages. We consider our experience with similar transactions and expectations regarding the contract in estimating the amount of variable consideration to which we will be entitled, and determining whether the estimated variable consideration should be constrained. We include estimated amounts 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. Our estimates of variable consideration are based largely on an assessment of our anticipated performance and all information (historical, current and forecasted) that is reasonably available to us.

Payment terms - Progress billings are generally issued upon completion of certain phases of the work as stipulated in the contract. Payment terms may either be fixed, lump-sum or driven by time and materials (e.g., daily or hourly rates, plus materials). Because typically the customer retains a small portion of the contract price until completion of the contract, our contracts generally result in revenue recognized in excess of billings which we present as contract assets on the balance sheet. Amounts billed and due from our customers are classified as receivables in the consolidated balance sheets. The portion of the payments retained by the customer until final contract settlement is not considered a significant financing component because the intent is to protect the customer. For some contracts, we may be entitled to receive an advance payment. We recognize a liability for these advance payments in excess of revenue recognized and present it as contract liabilities in the consolidated balance sheets. The advance payment typically is not considered a significant financing component because it is used to meet working capital demands that can be higher in the early stages of a contract and to protect us from the other party failing to adequately complete some or all of its obligations under the contract.

Warranty - Certain contracts include an assurance-type warranty clause, typically between 18 to 36 months, to guarantee that the products comply with agreed specifications. A service-type warranty may also be provided to the customer; in such a case, management allocates a portion of the transaction price to the warranty based on the estimated stand-alone selling price of the service-type warranty.

Revenue recognized over time - Our performance obligations are satisfied over time as work progresses or at a point in time. Revenue from products and services transferred to customers over time accounted for approximately 68%, 72% and 68% of our revenue for the years ended December 31, 2021, 2020 and 2019, respectively. Typically, revenue is recognized over time using an input measure (e.g., costs incurred to date relative to total estimated costs at completion) to measure progress.

Cost-to-cost method - For our long-term contracts, because of control transferring over time, revenue is recognized based on the extent of progress towards completion of the performance obligation. We generally use the cost-to-cost measure of progress for our contracts because it best depicts the transfer of control to the customer which 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, including estimated fees or profits, are recorded proportionally as costs are incurred. Any expected losses on construction-type contracts in progress are charged to earnings, in total, in the period the losses are identified.

Right to invoice practical expedient - The right-to-invoice practical expedient can be applied to a performance obligation satisfied over time if we have a right to invoice the customer for an amount that corresponds directly with the value transferred to the customer for our performance completed to date. When this practical expedient is used, we do not estimate variable consideration at the inception of the contract to determine the transaction price or for disclosure purposes. We have contracts which have payment terms dictated by daily or hourly rates where some contracts may have mixed pricing terms which include a fixed fee portion. For contracts in which we charge the customer a fixed rate based on the time or materials spent during the project that correspond to the value transferred to the customer, we recognize revenue in the amount to which we have the right to invoice.

Contract modifications - Contracts are often modified to account for changes in contract specifications and requirements. We consider contract modifications to exist when the modification either creates new, or changes the existing, enforceable rights and obligations. Most of our contract modifications are for goods or services that are not distinct from the existing contract due to the significant integration service provided in the context of the contract and are accounted for as if they were part of that existing contract. The effect of a contract modification on the transaction price and our measure of progress for the performance obligation to which it relates is recognized as an adjustment to revenue (either as an increase in or a reduction of revenue) on a cumulative catch-up basis.

Revenue Recognition by Segment

The following is a description of principal activities separated by reportable segments from which TechnipFMC generates its revenue. See Note 7 for more detailed information about reportable segments.

Subsea

Our Subsea segment manufactures and designs products and systems, performs engineering, procurement and project management and provides services used by oil and gas companies involved in offshore exploration and production of crude oil and natural gas. Systems and services may be sold separately or as combined integrated systems and services offered within one contract. Many of the systems and products TechnipFMC supplies for subsea applications are highly engineered to meet the unique demands of our customers’ field properties and are typically ordered one to two years prior to installation. We often receive advance payments and progress billings from our customers in order to fund initial development and working capital requirements.

Under Subsea engineering, procurement, construction and installation contracts, revenue is principally generated from long-term contracts with customers. We have determined these contracts generally have one performance obligation as the delivered product is highly customized to customer and field specifications. We generally recognize revenue over time for such contracts as the customized products do not have an alternative use for TechnipFMC and we have an enforceable right to payment plus a reasonable profit for performance completed to date.

Our Subsea segment also performs an array of subsea services including (i) installation services, (ii) asset management services (iii) product optimization, (iv) inspection, maintenance and repair services, and (v) well access and intervention services, where revenue is generally earned through the execution of either installation-type or maintenance-type contracts. For either contract-type, management has determined that the performance of the service generally represents one single performance obligation. We have determined that revenue from these contracts is recognized over time as the customer simultaneously receives and consumes the benefit of the services.

Surface Technologies

Our Surface Technologies segment designs, manufactures and supplies technologically advanced wellhead systems and high pressure valves and pumps used in stimulation activities for oilfield service companies and provides installation, flowback and other services for exploration and production companies.

We provide a full range of drilling, completion and production wellhead systems for both standard and custom-engineered applications. Under pressure control product contracts, we design and manufacture flowline products, under the Weco®/Chiksan® trademarks, articulating frac arm manifold trailers, well service pumps, compact valves and reciprocating pumps used in well completion and stimulation activities by major oilfield service companies. Performance obligations within these systems are satisfied either through delivery of a standardized product or equipment or the delivery of a customized product or equipment.

For contracts with a standardized product or equipment performance obligation, management has determined that because there is limited customization to products sold within such contracts and the asset delivered can be resold to another customer, revenue should be recognized as of a point in time, upon transfer of control to the customer and after the customer acceptance provisions have been met.

For contracts with a customized product or equipment performance obligation, the revenue is recognized over time, as the manufacturing of our product does not create an asset with an alternative use for us and we have an enforceable right to payment plus a reasonable profit for performance completed to date.

This segment also designs, manufactures and services measurement products globally. Contract-types include standard product or equipment and maintenance-type services where we have determined that each contract under this product line represents one performance obligation.

Revenue from standard measurement equipment contracts is recognized at a point in time, while maintenance-type contracts are typically priced at a daily or hourly rate. We have determined that revenue for these contracts is recognized over time because the customer simultaneously receives and consumes the benefit of the services.

Disaggregation of Revenue

We disaggregate revenue by geographic location and contract type. The following table presents total revenue by geography for each reportable segment for the years ended December 31, 2021, 2020 and 2019:

	Reportable Segments
	Year Ended December 31,
	2021				2020				2019
(In millions)	Subsea		Surface Technologies		Subsea		Surface Technologies		Subsea		Surface Technologies
Europe, Central Asia	$	1,404.4	$	191.5	$	1,664.1	$	192.7	1,690.2		160.1
North America	753.6		372.7		899.7		367.9		660.8		751.9
Latin America	1,157.7		86.7		1,042.4		76.6		1,139.5		108.6
Asia Pacific	927.4		104.2		772.1		131.0		673.3		195.4
Africa	1,057.3		44.0		908.6		46.9		836.4		62.7
Middle East	28.7		275.3		184.5		244.1		419.3		252.0
Total revenue	$	5,329.1	$	1,074.4	$	5,471.4	$	1,059.2	$	5,419.5	$	1,530.7

The following table represents revenue by contract type for each reportable segment for the years ended December 31, 2021, 2020 and 2019:

	Reportable Segments
	Year Ended December 31,
	2021				2020				2019
(In millions)	Subsea		Surface Technologies		Subsea		Surface Technologies		Subsea		Surface Technologies
Services	$	3,282.0	$	158.7	$	3,121.1	$	150.2	$	3,141.0	$	271.0
Products	2,002.5		801.9		2,295.4		821.9		2,162.5		1,109.2
Lease(a)	44.6		113.8		54.9		87.1		116.0		150.5
Total revenue	$	5,329.1	$	1,074.4	$	5,471.4	$	1,059.2	$	5,419.5	$	1,530.7

(a)Represents revenue not subject to ASC Topic 606.

Contract Balances

The timing of revenue recognition, billings and cash collections results in billed accounts receivable, costs and estimated earnings in excess of billings on uncompleted contracts (contract assets), and billings in excess of costs and estimated earnings on uncompleted contracts (contract liabilities) in the consolidated balance sheets. Any expected contract losses are recorded in the period in which they become probable.

Contract Assets - Contract Assets include unbilled amounts typically resulting from sales under long-term contracts when revenue is recognized over time and revenue recognized exceeds the amount billed to the customer, and right to payment is not just subject to the passage of time. Amounts may not exceed their net realizable value. Costs and estimated earnings in excess of billings on uncompleted contracts are generally classified as current.

Contract Liabilities - We sometimes receive advances or deposits from our customers, before revenue is recognized, resulting in contract liabilities.

The following table provides information about net contract assets (liabilities) as of December 31, 2021 and 2020:

	December 31,
(In millions)	2021		2020		$ change		% change
Contract assets	$	966.0	$	886.8	$	79.2	8.9
Contract (liabilities)	(1,012.9)		(1,046.8)		33.9		3.2
Net contract (liabilities)	$	(46.9)	$	(160.0)	$	113.1	70.7

The increase in our contract assets from December 31, 2020 to December 31, 2021 was primarily due to the timing of project milestones.

The decrease in our contract liabilities was primarily due to completion of performance obligations for contracts, for which consideration was received in advance of the work performed during the period.

In order to determine revenue recognized in the period from contract liabilities, we first allocate revenue to the individual contract liability balance outstanding at the beginning of the period until the revenue exceeds that balance. Any subsequent revenue we recognize increases contract asset balance. Revenue recognized for the years ended December 31, 2021 and 2020 that were included in the contract liabilities balance as of December 31, 2020 and 2019 was $305.3 million and $484.3 million, respectively.

In addition, net revenue recognized for the years ended December 31, 2021 and 2020 from our performance obligations satisfied in previous periods had favorable (unfavorable) impacts of $25.9 million and $(21.7) million, respectively. This primarily relates to the changes in the estimate of the stage of completion that impacted revenue.

Transaction Price Allocated to the Remaining Unsatisfied Performance Obligations

Remaining unsatisfied performance obligations (“RUPO” or “order backlog”) represent the transaction price for products and services for which we have a material right, but work has not been performed. Transaction price of the order backlog includes the base transaction price, variable consideration and changes in transaction price. The order backlog table does not include contracts for which we recognize revenue at the amount to which we have the right to invoice for services performed. The transaction price of order backlog related to unfilled, confirmed customer orders is estimated at each reporting date. As of December 31, 2021, the aggregate amount of the transaction price allocated to order backlog was $7,657.7 million. TechnipFMC expects to recognize revenue on approximately 49.0% of the order backlog through 2022 and 51.0% thereafter.

The following table details the order backlog for each business segment as of December 31, 2021:

(In millions)	2022		2023		Thereafter
Subsea	$	3,372.8	$	2,227.5	$	932.7
Surface Technologies	376.8		95.2		652.7
Total remaining unsatisfied performance obligations	$	3,749.6	$	2,322.7	$	1,585.4

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BUSINESS SEGMENTS

12 Months Ended

Dec. 31, 2021

Segment Reporting, Measurement Disclosures [Abstract]

BUSINESS SEGMENTS

BUSINESS SEGMENTS

Management’s determination of our reporting segments was made on the basis of our strategic priorities within each segment and the differences in the products and services we provide, which corresponds to the manner in which our Chair and Chief Executive Officer, as our chief operating decision maker, reviews and evaluates operating performance to make decisions about resources to be allocated to the segment. We now operate under two reportable segments: Subsea and Surface Technologies.

•Subsea - designs and manufactures products and systems, performs engineering, procurement and project management, and provides services used by oil and gas companies involved in offshore exploration and production of crude oil and natural gas.

•Surface Technologies - designs and manufactures products and systems and provides services used by oil and gas companies involved in land and shallow water exploration and production of crude oil and natural gas; designs, manufactures, and supplies technologically advanced high-pressure valves and fittings for oilfield service companies; and also provides flowback and well testing services.

Segment operating profit (loss) is defined as total segment revenue less segment operating expenses. Income (loss) from equity method investments is included in computing segment operating profit. The following items have been excluded in computing segment operating profit (loss): corporate staff expense, foreign exchange gains (losses), income from investment in Technip Energies, net interest income (expense) associated with corporate debt facilities and income taxes.

Information by business segment

Segment revenue and segment operating profit (loss) were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Segment revenue
Subsea	$	5,329.1	$	5,471.4	$	5,419.5
Surface Technologies	1,074.4		1,059.2		1,530.7
Total revenue	$	6,403.5	$	6,530.6	$	6,950.2
Segment operating profit (loss)
Subsea	$	141.4	$	(2,815.5)	$	(1,442.7)
Surface Technologies	42.0		(429.3)		(662.7)
Total segment operating profit (loss)	183.4		(3,244.8)		(2,105.4)
Corporate items
Merger transaction and integration costs	—		—		(14.2)
Legal expenses	—		—		(33.0)
Other corporate expenses (a)	(118.1)		(131.9)		(191.7)
Net interest expense	(143.3)		(81.8)		(91.3)
Loss on early extinguishment of debt	(61.9)		—		—
Income from investment in Technip Energies	322.2		—		—
Foreign exchange gains (losses)	15.8		(40.2)		(135.5)
Total corporate items	14.7		(253.9)		(465.7)
Income (loss) before income taxes(b)	$	198.1	$	(3,498.7)	$	(2,571.1)

(a)Other corporate expenses primarily include corporate staff expenses, share-based compensation expenses, certain long-lived assets impairments, restructuring and other expenses and other employee benefits.

(b)Includes amounts attributable to non-controlling interests.

Segment assets were as follows:

	December 31,
(In millions)	2021		2020
Segment assets
Subsea	$	6,532.5	$	6,796.6
Surface Technologies	1,420.0		1,758.3
Total segment assets	7,952.5		8,554.9
Corporate (a)	2,067.6		2,129.1
Assets from discontinued operations	—		9,008.6
Total assets	$	10,020.1	$	19,692.6

(a)Corporate includes cash, investment in Technip Energies, LIFO adjustments, deferred income tax balances, property, plant and equipment and intercompany eliminations not associated with a specific segment, pension assets and the fair value of derivative financial instruments.

Other business segment information is as follows:

	Capital Expenditures						Depreciation and Amortization						Research and Development Expense
	Year Ended December 31,						Year Ended December 31,						Year Ended December 31,
(In millions)	2021		2020		2019		2021		2020		2019		2021		2020		2019
Subsea	$	149.4	$	213.6	$	287.5	$	317.2	$	324.9	$	345.0	$	73.2	$	66.5	$	134.2
Surface Technologies	36.8		38.5		96.0		64.8		70.1		107.1		5.2		8.8		15.3
Corporate	5.5		4.0		29.2		3.4		17.1		15.6		—		—		—
Total	$	191.7	$	256.1	$	412.7	$	385.4	$	412.1	$	467.7	$	78.4	$	75.3	$	149.5

Information by geography

Revenue by geography was identified based on the country where our products and services were delivered, and is as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Revenue
United States	$	1,137.2	$	1,320.1	$	1,458.6
Norway	979.9		1,216.6		1,352.6
Brazil	767.8		600.6		1,086.2
United Kingdom	542.5		489.0		535.8
Mozambique	472.0		320.4		80.0
Australia	419.8		122.5		133.4
Angola	406.3		482.8		498.1
Guyana	314.7		330.1		7.2
Indonesia	224.9		280.0		262.6
Singapore	216.3		219.9		190.5
Malaysia	206.9		190.0		197.2
India	109.8		26.8		—
Trinidad	78.1		106.3		42.8
Israel	26.8		179.3		319.6
All other countries	500.5		646.2		785.6
Total revenue	$	6,403.5	$	6,530.6	$	6,950.2

Long-lived assets by geography represent property, plant and equipment, net, and are as follows:

	December 31,
(In millions)	2021		2020
Long-lived assets
United Kingdom	$	882.9	$	928.8
Netherlands	414.7		417.6
United States	383.4		439.1
Norway	271.9		312.1
Brazil	265.5		259.9
All other countries	378.8		398.7
Total long-lived assets	$	2,597.2	$	2,756.2

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EARNINGS (LOSS) PER SHARE

12 Months Ended

Dec. 31, 2021

Earnings Per Share [Abstract]

EARNINGS (LOSS) PER SHARE

EARNINGS (LOSS) PER SHARE

A reconciliation of the number of shares used for the basic and diluted earnings (loss) per share calculation was as follows:

	Year Ended December 31,
(In millions, except per share data)	2021		2020		2019
Income (loss) from continuing operations attributable to TechnipFMC plc	$	87.8	$	(3,552.6)	$	(2,645.5)
Income (loss) from discontinued operations attributable to TechnipFMC plc	(74.5)		265.0		230.3
Net income (loss) attributable to TechnipFMC plc	$	13.3	$	(3,287.6)	$	(2,415.2)
Weighted average number of shares outstanding	450.5		448.7		448.0
Dilutive effect of restricted stock units	4.1		—		—
Total shares and dilutive securities	454.6		448.7		448.0
Basic and diluted earnings (loss) per share attributable to TechnipFMC plc:
Earnings (loss) per share from continuing operations attributable to TechnipFMC plc
Basic	$	0.19	$	(7.92)	$	(5.91)
Diluted	$	0.19	$	(7.92)	$	(5.91)
Earnings (loss) per share from discontinued operations attributable to TechnipFMC plc
Basic	$	(0.17)	$	0.59	$	0.51
Diluted	$	(0.16)	$	0.59	$	0.51
Total earnings (loss) per share attributable to TechnipFMC plc
Basic and diluted	$	0.03	$	(7.33)	$	(5.39)

For the years ended December 31, 2020 and 2019, we incurred net losses; therefore, the impact of any incremental shares from our share-based compensation awards would be anti-dilutive. For the years ended December 31, 2020 and 2019, 3.8 million shares and 4.3 million shares, respectively, were anti-dilutive due to a net loss position.

Weighted average shares of the following share-based compensation awards were excluded from the calculation of diluted weighted average number of shares where the assumed proceeds exceed the average market price from the calculation of diluted weighted average number of shares, because their effect would be anti-dilutive:

	Year Ended December 31,
(millions of shares)	2021	2020	2019
Share option awards	1.7	4.6	4.0
Restricted share units	0.1	1.8	—
Performance shares	—	1.9	1.6
Total	1.8	8.3	5.6

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RECEIVABLES

12 Months Ended

Dec. 31, 2021

Receivables [Abstract]

RECEIVABLES

RECEIVABLES

We manage our receivables portfolios using published default risk as a key credit quality indicator for our loans and receivables. Our loans receivable and security deposits were related to sales of long-lived assets or businesses, loans to related parties for capital expenditure purposes, or security deposits for lease arrangements.

We manage our held-to-maturity debt securities using published credit ratings as a key credit quality indicator as our held-to-maturity debt securities consist of government bonds.

The table below summarizes the amortized cost basis of financial assets by years of origination and credit quality. The key credit quality indicator is updated as of December 31, 2021.

(In millions)	Year of origination	Balance as of December 31, 2021		Balance as of December 31, 2020
Loans receivables, security deposits and other
Moody’s rating Ba2	2019	$	50.9	$	107.6
Debt securities at amortized cost
Moody’s rating B3	2019	24.0		23.7
Total financial assets		$	74.9	$	131.3

Credit Losses

For contract assets, trade receivables, loans receivable, and security deposits and other, we have elected to calculate an expected credit loss based on loss rates from historical data. We develop loss-rate statistics on the basis of the amount written-off over the life of the financial assets and contract assets and adjust these historical credit loss trends for forward-looking factors specific to the debtors and the economic environment to determine lifetime expected losses.

For held-to-maturity debt securities at amortized cost, we evaluate whether the debt securities are considered to have low credit risk at the reporting date using available, reasonable and supportable information.

The table below shows the roll-forward of allowance for credit losses as of December 31, 2021 and 2020, respectively.

	Balance as of December 31, 2021
(In millions)	Trade receivables		Contract assets		Loans receivable		Security deposit and other		Held-to-maturity debt securities
Allowance for credit losses at December 31, 2020	$	40.2	$	2.4	$	7.5	$	0.4	$	0.5
Current period provision (release) for expected credit losses	3.5		(1.3)		(7.2)		(0.1)		2.2
Recoveries	(5.6)		—		—		—		—
Allowance for credit losses at December 31, 2021	$	38.1	$	1.1	$	0.3	$	0.3	$	2.7

	Balance as of December 31, 2020
(In millions)	Trade receivables		Contract assets		Loans receivable		Security deposit and other		Held-to-maturity debt securities
Allowance for credit losses at December 31, 2019	$	59.4	$	4.5	$	9.5	$	0.7	$	1.1
Current period provision for expected credit losses	27.2		0.5		(0.2)		(0.3)		(0.6)
Write-offs charged against the allowance	(43.0)		—		—		—		—
Recoveries	(3.4)		(2.6)		(1.8)		—		—
Allowance for credit losses at December 31, 2020	$	40.2	$	2.4	$	7.5	$	0.4	$	0.5

Certain trade receivables are due in one year or less.

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INVENTORIES

12 Months Ended

Dec. 31, 2021

Inventory, Finished Goods and Work in Process, Gross [Abstract]

INVENTORIES

INVENTORIES

Inventories consisted of the following:

	December 31,
(In millions)	2021		2020
Raw materials	$	250.1	$	270.3
Work in process	178.7		242.7
Finished goods	603.1		739.8
Inventories, net	$	1,031.9	$	1,252.8

All amounts in the table above are reported net of obsolescence reserves of $116.6 million and $155.7 million as of December 31, 2021 and 2020, respectively.

Net inventories accounted for under the LIFO method totaled $350.1 million and $408.5 million as of December 31, 2021 and 2020, respectively. The current replacement costs of LIFO inventories exceeded their recorded values by $10.9 million and $11.6 million as of December 31, 2021 and 2020, respectively.

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OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES

12 Months Ended

Dec. 31, 2021

Other Current Assets & Other Current Liabilities [Abstract]

OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES

OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES

Other current assets consisted of the following:

	December 31,
(In millions)	2021		2020
Value - added tax receivables	$	222.4	$	256.9
Sundry receivables	106.1		138.4
Other taxes receivables	70.6		73.8
Prepaid expenses	50.7		78.1
Current financial assets at amortized cost	21.9		40.6
Held-to-maturity investments	8.8		24.2
Assets held for sale	5.0		47.3
Other	26.8		24.1
Total other current assets	$	512.3	$	683.4

Other current liabilities consisted of the following:

	December 31,
(In millions)	2021		2020
Warranty accruals and project contingencies	$	119.5	$	168.8
Legal provisions	121.7		127.6
Value - added tax and other taxes payable	71.0		109.6
Compensation accrual	85.7		54.3
Social security liability	70.4		67.9
Provisions	23.6		53.0
Current portion of accrued pension and other post-retirement benefits	5.2		6.9
Other accrued liabilities	163.3		230.2
Total other current liabilities	$	660.4	$	818.3

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WARRANTY OBLIGATIONS

12 Months Ended

Dec. 31, 2021

Product Warranties Disclosures [Abstract]

WARRANTY OBLIGATIONS

WARRANTY OBLIGATIONS

Warranty obligations are included within other current liabilities in our consolidated balance sheets as of December 31, 2021 and 2020. A reconciliation of warranty obligations for the years ended December 31, 2021 and 2020 is as follows:

	Year Ended December 31,
(In millions)	2021		2020
Balance at beginning of period	$	109.6	$	121.7
Warranty expenses	54.0		52.0
Adjustment to existing accruals	(56.5)		(48.2)
Claims paid	(20.9)		(15.9)
Balance at end of period	$	86.2	$	109.6

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INVESTMENTS

12 Months Ended

Dec. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

INVESTMENTS

INVESTMENTS

Equity Method Investments

The equity method of accounting is used to account for investments in unconsolidated affiliates where we can have the ability to exert significant influence over the affiliates operating and financial policies.

Our equity investments were as follows as of December 31, 2021 and 2020:

			December 31,
			2021		2020
(In millions, except %)	Percentage Owned		Carrying Value
Dofcon Brasil AS	50.0	%	276.9		234.7
Magma Global Limited	—	%	—		51.4
Serimax Holdings SAS	20.0	%	15.0		18.8
Other			0.5		0.6
Investments in equity affiliates			$	292.4	$	305.5

Our income from equity affiliates for the years ended December 31, 2021, 2020 and 2019, was $0.6 million, $64.6 million and $59.8 million, respectively and included within our Subsea segment.

Our major equity method investments are as follows:

Dofcon Brasil AS (“Dofcon”) - is an affiliated company in the form of a joint venture between TechnipFMC and DOF Subsea and was founded in 2006. Dofcon provides Pipe-Laying Support Vessels (PLSVs) for work in oil and gas fields offshore Brazil. Dofcon is considered a VIE because it does not have sufficient equity to finance its activities without additional subordinated financial support from other parties. We are not the primary beneficiary of the VIE. As such, we have accounted for our 50% investment using the equity method of accounting with results reported in our Subsea segment.

Magma Global Limited (“Magma Global”) - In 2018, we entered into a collaboration agreement with Magma Global to develop a new generation of hybrid flexible pipe for use in the traditional and new energy industries. As part of the collaboration, we purchased a 25% ownership interest in Magma Global. In October 2021, we purchased the remaining ownership interest in Magma Global for $64.0 million. See Note 3 for further details.

Serimax Holdings SAS (“Serimax”) - is an affiliated company in the form of a joint venture between TechnipFMC and Vallourec SA and was founded in 2016. Serimax is headquartered in Paris, France and provides rigid pipes welding services for work in oil and gas fields around the world. We have accounted for our 20% investment using the equity method of accounting with results reported in our Subsea segment.

Investment in Technip Energies

As discussed in Note 2, immediately following the completion of the Spin-off, we owned 49.9% of the outstanding shares of Technip Energies. At the Spin-off date, on initial recognition of the investment, we elected to account for our investment in Technip Energies at fair value with all subsequent changes in fair value for the investment reported in our consolidated statement of income.

On January 7, 2021, Bpifrance Participations SA (“BPI”) entered into the Share Purchase Agreement with us pursuant to which BPI agreed to purchase a portion of our retained stake in Technip Energies N.V. (the “BPI Investment”) for $200.0 million (the “Purchase Price”), subject to certain adjustments. On March 31, 2021, BPI ultimately purchased 7.5 million shares in Technip Energies from us for $100.0 million. Accordingly, on April 8, 2021, we refunded $100.0 million to BPI as a result of their revised level of investment.

On April 27, 2021 we sold 25.0 million Technip Energies shares, representing 14% of Technip Energies’ share capital, through a private placement by way of an accelerated bookbuild offering (the “April Placement”). The sale price of the shares in the April Placement was set at €11.10 per share, yielding total gross proceeds of €277.5 million, or $335.2 million.

Concurrently with the April Placement, Technip Energies purchased from us 1.8 million shares of Technip Energies (equivalent to 1% of share capital) at €11.10 per share, corresponding to the price of the April Placement (the “Concurrent Sale to Technip Energies”). The sale of shares to Technip Energies yielded total gross proceeds of €20.0 million or $24.2 million. This purchase was separate from the April Placement.

On July 29, 2021 we announced the sale of 16.0 million Technip Energies shares, representing approximately 9% of Technip Energies’ issued and outstanding share capital, through a private placement by way of an accelerated bookbuild offering (the “July Placement”). The sale price of the shares in the July Placement was set at €11.20 per share, yielding total gross proceeds of €179.2 million, or $213.1 million. We agreed to a 60-day lock-up for our remaining shares in Technip Energies, subject to waiver from the Joint Global Coordinators and certain other customary exceptions.

On September 2, 2021 we announced the sale of 17.6 million Technip Energies shares, representing approximately 10% of Technip Energies’ issued and outstanding share capital, through a private sale transaction with HAL Investments, the Dutch investment subsidiary of HAL Holding, N.V. (the “September Sale”). The sale price of the shares in the September Sale was set at €11.15 per share, yielding total gross proceeds of €196.2 million, or $231.5 million. The Joint Global Coordinators from the July Placement granted a waiver of the 60-day lock-up solely for the purpose of the September Sale.

The September Sale was completed in two tranches. The first tranche of 8.6 million shares was sold and settled in September for gross proceeds of €96.3 million, or $114.4 million. The second tranche of 9.0 million shares was settled on October 22, 2021 for gross proceeds of €99.9 million, or $116.4 million.

As a result of the reduced ownership interest in Technip Energies and related loss of significant influence, we discontinued the use of equity method of accounting for our interest in Technip Energies. Following the September sale, we account for our remaining ownership interest in Technip Energies as equity security at fair value.

As of December 31, 2021, we retained a direct stake of 21.9 million shares, representing 12.2% of Technip Energies’ issued and outstanding share capital. There is no lock-up associated with our remaining stake in Technip Energies. The carrying amount of our investment in Technip Energies as of December 31, 2021 was $317.3 million.

For the year ended December 31, 2021, we recognized $322.2 million of income related to our investment in Technip Energies. The amounts recognized include purchase price discounts on the sales of shares and a fair value revaluation gains and losses of our investment.

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RELATED PARTY TRANSACTIONS

12 Months Ended

Dec. 31, 2021

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS

Receivables, payables, revenues and expenses which are included in our consolidated financial statements for all transactions with related parties, defined as entities related to our directors and main shareholders as well as the partners of our consolidated joint ventures, were as follows.

Trade receivables consisted of trade receivables due from the following related parties:

	December 31,
(In millions)	2021		2020
Equinor ASA	$	—	$	24.1
Dofcon Navegacao	22.7		4.2
Techdof Brasil AS	4.5		8.0
Others	2.5		1.7
Total trade receivables	$	29.7	$	38.0

Dofcon Navegacao and Dofcon Brasil AS are our equity method investments and Techdof Brasil AS is a wholly owned subsidiary of Dofcon Brasil AS. In October 2020, we added a new member to our Board of Directors who was an executive of Equinor ASA up through January 2021.

Payables consisted of payables due to the following related parties:

	December 31,
(In millions)	2021		2020
Crescent Energy	$	2.7	$	—
Dofcon Navegacao	$	—	$	1.5
Arkema S.A.	0.9		0.5
Others	1.9		2.6
Total trade payables	$	5.5	$	4.6

Additionally, we have a note receivable balance of $12.6 million and $37.6 million with Dofcon Brasil AS as of December 31, 2021 and 2020, respectively. These are included in other assets in our consolidated balance sheets.

Revenue consisted of amount from following related parties:

	Year Ended December 31,
(In millions)	2021		2020		2019
Equinor ASA	$	—	$	119.6	$	—
Anadarko Petroleum Company	—		—		67.1
TOP CV	—		—		11.9
Dofcon Navegacao	9.9		3.4		8.4
Techdof Brasil AS	15.8		11.2		8.3
Others	14.0		18.5		14.4
Total revenue	$	39.7	$	152.7	$	110.1

A member of our Board of Directors (the “Director”) served on the Board of Directors of Anadarko Petroleum Company (“Anadarko”) until August 2019. In August 2019, Anadarko was acquired by Occidental Petroleum Corporation (“Occidental”). As a result, the Director no longer serves as a member of the Board of Directors of Anadarko. The Director is not an officer or director of Occidental.

TOP CV was previously an equity method affiliate that became a fully consolidated subsidiary on December 30, 2019. See Note 3 for further details.

Expenses consisted of amounts to following related parties:

	Year Ended December 31,
(In millions)	2021		2020		2019
Arkema S.A.	$	3.8	$	1.5	$	3.8
Serimax Holdings SAS	7.6		0.4		17.7
Magma Global Limited	8.8		14.0		7.3
Jumbo Shipping	—		16.0		4.5
Dofcon Navegacao	26.7		24.0		1.8
Altus Intervention	—		3.6		1.8
Others	18.5		17.6		17.8
Total expenses	$	65.4	$	77.1	$	54.7

Serimax Holdings SAS is an equity method affiliate. Members of our Board of Directors served on the Board of Directors for Jumbo Shipping. Magma Global Limited was an equity method affiliate through September 30, 2021. In October 2021, we purchased the remaining ownership interest in Magma Global, see Note 3 for further details.

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PROPERTY, PLANT AND EQUIPMENT

12 Months Ended

Dec. 31, 2021

Property, Plant and Equipment [Abstract]

PROPERTY, PLANT AND EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment consisted of the following: 

	December 31,
(In millions)	2021		2020
Land and land improvements	$	79.4	$	80.0
Buildings	471.6		514.6
Vessels	1,979.0		1,968.1
Machinery and equipment	1,849.0		1,871.8
Office fixtures and furniture	121.9		125.4
Construction in process	110.5		147.3
Other	189.8		203.2
	4,801.2		4,910.4
Accumulated depreciation	(2,204.0)		(2,154.2)
Property, plant and equipment, net	$	2,597.2	$	2,756.2

Depreciation expense was $291.3 million, $308.7 million and $363.0 million in 2021, 2020 and 2019, respectively. The amount of interest cost capitalized was not material for the years presented.

During 2021 and 2020, we determined the carrying amount of certain of our long-lived assets exceeded their fair value and recorded impairments. See Note 20 for further details.

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GOODWILL AND INTANGIBLE ASSETS

12 Months Ended

Dec. 31, 2021

Goodwill and Intangible Assets Disclosure [Abstract]

GOODWILL AND INTANGIBLE ASSETS

GOODWILL AND INTANGIBLE ASSETS

Goodwill - We record goodwill as the excess of the purchase price over the fair value of the net assets acquired in acquisitions accounted for under the purchase method of accounting. We test goodwill for impairment annually as of October 31 of each year, or more frequently if circumstances indicate possible impairment. We identify a potential impairment by comparing the fair value of the applicable reporting unit (which is consistent with our business segments) to its net book value, including goodwill. If the net book value exceeds the fair value of the reporting unit, we measure the impairment by comparing the carrying value of the reporting unit to its fair value.

We test our goodwill for impairment by comparing the fair value of each of our reporting units to their net carrying value. Our impairment analysis is quantitative; however, it includes subjective estimates based on assumptions regarding future growth rates, interest rates and operating expenses.

The income approach estimates fair value by discounting each reporting unit’s estimated future cash flows using a weighted-average cost of capital that reflects current market conditions and the risk profile of the reporting unit. To arrive at our future cash flows, we use estimates of economic and market assumptions, including growth rates in revenues, costs, estimates of future expected changes in operating margins, tax rates and capital expenditures. Future revenues are also adjusted to match changes in our business strategy. We believe this approach is an appropriate valuation method. Under the market multiple approach, we determine the estimated fair value of each of our reporting units by applying transaction multiples to each reporting unit’s projected EBITDA and then averaging that estimate with similar historical calculations using either a one, two or three year average. Our reporting unit valuations were determined primarily by utilizing the income approach and the market multiple approach.

During the first quarter of 2020, triggering events were identified which led to performing interim goodwill impairment testing in our reporting units as of March 31, 2020. These events included the COVID-19 pandemic breakout, commodity price declines, and a significant decrease in our market capitalization as well as those of our peers and customers. The fair value for our reporting units for the interim testing was valued using a market approach. An appropriate control premium was considered for each of the reporting units and applied to the output of the market approach. An interim impairment test during the first quarter of 2020 resulted in $2,747.5 million and $335.9 million of goodwill impairment charges recorded in our Subsea and Surface Technologies segments, respectively. Subsequent to the charges, we do not have any goodwill recorded in either of our segment.

The carrying amount of goodwill by reporting segment was as follows:

(In millions)	Subsea		Surface Technologies		Total
December 31, 2019	$	2,792.8	$	335.7	$	3,128.5
Impairments	(2,747.5)		(335.9)		(3,083.4)
Translation	(45.3)		0.2		(45.1)
December 31, 2020	$	—	$	—	$	—

Intangible assets - The components of intangible assets were as follows:

	December 31,
	2021				2020
(In millions)	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
Acquired technology	$	247.0	$	122.4	$	247.1	$	98.1
Customer relationships	285.4		142.9		285.3		114.4
Licenses, patents and trademarks	694.6		220.7		690.3		189.3
Software	108.2		84.8		111.3		81.1
Other	54.0		4.7		10.4		10.2
Total intangible assets	$	1,389.2	$	575.5	$	1,344.4	$	493.1

We recorded $94.1 million, $103.4 million and $104.7 million in amortization expense related to intangible assets during the years ended December 31, 2021, 2020 and 2019, respectively. During the years 2022 through 2026, annual amortization expense is expected to be $87 million in each of the five years and $351 million thereafter in the aggregate.

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DEBT

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

DEBT

DEBT

Overview

Long-term debt consisted of the following:

	December 31,
(In millions)	2021		2020
Commercial paper	$	—	$	1,043.7
Synthetic bonds due 2021	—		551.2
3.45% Senior Notes due 2022	—		500.0
3.40% 2012 Private placement notes due 2022	169.9		184.0
3.15% 2013 Private placement notes due 2023	288.8		312.9
5.75% 2020 Private placement notes due 2025	226.5		245.4
6.50% Senior notes due 2026	633.1		—
4.00% 2012 Private placement notes due 2027	84.9		92.0
4.00% 2012 Private placement notes due 2032	113.3		122.7
3.75% 2013 Private placement notes due 2033	113.3		122.7
Bank borrowings and other	397.4		298.4
Unamortized debt issuance costs and discounts	(22.3)		(12.8)
Total debt	2,004.9		3,460.2
Less: current borrowings	277.6		624.7
Long-term debt	$	1,727.3	$	2,835.5

Debt maturities as of December 31, 2021, are as follows:

	Payments Due by Period
(In millions)	Total payments		Less than 1 year		1-3 years		3-5 years		After 5 years
Total debt	$	2,004.9	$	277.6	$	402.1	$	942.9	$	382.3

Debt Financing Transactions in Connection with the Spin-off

In connection with the Spin-off, we executed a series of refinancing transactions, in order to provide a capital structure with sufficient cash resources to support future operating and investment plans.

Debt Issuance

•On February 16, 2021, we entered into a credit agreement, which provides for a $1.0 billion three-year senior secured multi-currency revolving credit facility (“Revolving Credit Facility”) including a $450.0 million letter of credit sub-facility; and

•On January 29, 2021, we issued $1.0 billion of 6.50% senior notes due 2026 (the “2021 Notes”).

Repayment of Debt

The proceeds from the debt issuance described above along with the available cash on hand, were used to fund:

•the repayment of all $542.4 million of the outstanding Synthetic Convertible Bonds that matured in January 2021;

•the repayment of all $500.0 million aggregate principal amount of outstanding 3.45% Senior Notes due 2022. In connection with the repayment, we recorded a loss on extinguishment of debt of $23.5 million related to the difference between the amount paid and the net carrying value of the debt; and

•the termination of the $2.5 billion senior unsecured revolving credit facility entered into on January 17, 2017; the termination of the €500.0 million Euro Facility entered into on May 19, 2020, and the termination of the CCFF Program entered into on May 19, 2020. In connection with the termination of these credit facilities, we repaid $830.9 million of the outstanding commercial paper borrowings.

Credit Facilities and Debt

Revolving Credit Facility - On February 16, 2021, we entered into a credit agreement, which provides for a $1.0 billion three-year senior secured multi-currency Revolving Credit Facility including a $450.0 million letter of credit sub-facility. We incurred $34.8 million of debt issuance costs in connection with the Revolving Credit Facility. These debt issuance costs are deferred and are included in other assets in our consolidated balance sheet as of December 31, 2021. The deferred debt issuance costs are amortized to interest expense over the term of the Revolving Credit Facility.

Availability of borrowings under the Revolving Credit Facility is reduced by the outstanding letters of credit issued against the facility. As of December 31, 2021, there were $16.7 million letters of credit outstanding and availability of borrowings under the Revolving Credit Facility was $983.3 million.

Borrowings under the Revolving Credit Facility bear interest at the following rates, plus an applicable margin, depending on currency:

•U.S. dollar-denominated loans bear interest, at the Company’s option, at a base rate or an adjusted rate linked to the London interbank offered rate (“Adjusted LIBOR”); and

•Euro-denominated loans bear interest on an adjusted rate linked to the Euro interbank offered rate.

The applicable margin for borrowings under the Revolving Credit Facility ranges from 2.50% to 3.50% for Eurocurrency loans and 1.50% to 2.50% for base rate loans, depending on a total leverage ratio. The Revolving Credit Facility is subject to customary representations and warranties, covenants, events of default, mandatory repayment provisions and financial covenants.

2021 Notes - On January 29, 2021, we issued $1.0 billion of 6.50% senior notes due 2026. The interest on the 2021 Notes is paid semi-annually on February 1 and August 1 of each year, beginning on August 1, 2021. The 2021 Notes are senior unsecured obligations and are guaranteed on a senior unsecured basis by substantially all of our wholly-owned U.S. subsidiaries and non-U.S. subsidiaries in Brazil, the Netherlands, Norway, Singapore and the United Kingdom. We incurred $25.7 million of debt issuance costs in connection with issuance of the 2021 Notes. These debt issuance costs are deferred and are included in long-term debt in our consolidated balance sheet as of December 31, 2021. The deferred debt issuance costs are amortized to interest expense over the term of the 2021 Notes, which approximates the effective interest method.

During 2021, we completed two tender offers and purchased for cash $366.9 million of the outstanding 2021 Notes. We paid a cash premium of $29.5 million to the note holders who tendered and wrote-off $8.9 million of bond issuance costs.

As of December 31, 2021, we were in compliance with all debt covenants.

Commercial paper - As of December 31, 2021, we had no commercial paper outstanding. In accordance with the terms of the new Revolving Credit Facility, we do not have an ability to issue any new commercial paper notes going forward. As of December 31, 2020, our commercial paper borrowings had a weighted average interest rate of 0.34% on the U.S. dollar denominated borrowings. Commercial paper borrowings were issued at market interest rates. As of December 31, 2020, we had $225.8 million of outstanding commercial paper borrowings under this program.

Synthetic bonds - In 2016, we issued €450.0 million principal amount of 0.875% convertible bonds. Interest on the synthetic bonds was payable semi-annually in arrears on January 25 and July 25 of each year, beginning July 26, 2016. The synthetic bonds were repaid during the first quarter of 2021.

Senior Notes - As of December 31, 2020, we had outstanding 3.45% $500.0 million senior notes due October 1, 2022. The senior notes were redeemed during the first quarter of 2021.

Private Placement Notes

2020 Issuance:

During 2020, we completed the private placement of €200 million aggregate principal amount of the 2020 Private Placement Notes. The 2020 Private Placement Notes bear interest of 5.75% and are due June 2025. Prior to 2021, these notes had an interest of 4.50%. Interest on the notes is payable annually in arrears on June 30 of each year beginning June 30, 2020. The 2020 Private Placement Notes contain usual and customary covenants and events of default for notes of this type.

2013 Issuances:

In October 2013, we completed the private placement of €355.0 million aggregate principal amount of senior notes. The notes were issued in three tranches with €100.0 million bearing interest at 3.75% and due October 2033 (the “Tranche A 2033 Notes”), €130.0 million bearing interest of 3.15% and due October 2023 (the “Tranche B 2023 Notes) and €125.0 million bearing interest of 3.15% and due October 2023 (the “Tranche C 2023 Notes” and, collectively with the “Tranche A 2033 Notes and the “Tranche B 2023 Notes”, the “2013 Private Placement Notes”).

Interest on the Tranche A 2033 Notes is payable annually in arrears on October 7 each year, beginning October 7, 2014. Interest on the Tranche B 2023 Notes is payable annually in arrears on October 16 of each year beginning October 16, 2014. Interest on the Tranche C 2023 Notes is payable annually in arrears on October 18 of each year, beginning October 18, 2014.

2012 Issuances:

In June 2012, we completed the private placement of €325.0 million aggregate principal amount of notes. The notes were issued in three tranches with €150.0 million bearing interest at 3.40% and due June 2022 (the “Tranche A 2022 Notes”), €75.0 million bearing interest of 4.0% and due June 2027 (the “Tranche B 2027 Notes”) and €100.0 million bearing interest of 4.0% and due June 2032 (the “Tranche C 2032 Notes” and, collectively with the “Tranche A 2022 Notes and the “Tranche B 2027 Notes,” the “2012 Private Placement Notes”). Interest on the Tranche A 2022 Notes and the Tranche C 2032 Notes is payable annually in arrears on June 14 of each year beginning June 14, 2013. Interest on the Tranche B 2027 Notes is payable annually in arrears on June 15 of each year, beginning June 15, 2013.

The 2013 and 2012 Private Placement Notes contain usual and customary covenants and events of default for notes of this type. In the event of a change of control resulting in a downgrade in the rating of the notes below BBB-, the 2013 and 2012 Private Placement Notes may be redeemed early at the request of any bondholder, at its sole discretion. The 2013 and 2012 Private Placement Notes are our unsecured obligations. The 2013 and 2012 Private Placement Notes will rank equally in right of payment with all of our existing and future unsubordinated debt.

Term loan - In December 2016, we entered into a £160.0 million term loan agreement to finance the Deep Explorer, a diving support vessel (“DSV”), maturing December 2028. Under the loan agreement, interest accrues at an annual rate of 2.813%. This loan agreement contains usual and customary covenants and events of default for loans of this type.

Bank borrowings - In January 2019, we executed a sale-leaseback transaction to finance the purchase of a deepwater dive support vessel, Deep Discoverer (the “Vessel”) for the full transaction price of $116.8 million. The sale-leaseback agreement (“Charter”) was entered into with a French joint-stock company, owned by Credit Industrial et Commercial (“CIC”) which was formed for the sole purpose to purchase and act as the lessor of the Vessel. It is a variable interest entity, which is fully consolidated in our consolidated financial statements. The transaction was funded through debt of $96.2 million which is primarily long-term, expiring on January 8, 2031.

Foreign committed credit - We have committed credit lines at many of our international subsidiaries for immaterial amounts. We utilize these facilities for asset financing and to provide a more efficient daily source of liquidity. The effective interest rates depend upon the local national market.

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STOCKHOLDERS’ EQUITY

12 Months Ended

Dec. 31, 2021

Stockholders' Equity Note [Abstract]

STOCKHOLDERS' EQUITY

STOCKHOLDERS’ EQUITY

Cash dividends paid during the years ended December 31, 2021, 2020 and 2019 were nil, $59.2 million and $232.8 million, respectively.

As an English public limited company, we are required under U.K. law to have available “distributable reserves” to conduct share repurchases or pay dividends to shareholders. Distributable reserves are a statutory requirement and are not linked to a GAAP reported amount (e.g., retained earnings). The declaration and payment of dividends require the authorization of our Board of Directors, provided that such dividends on issued share capital may be paid only out of our “distributable reserves” on our statutory balance sheet. Therefore, we are not permitted to pay dividends out of share capital, which includes share premium. On November 27, 2019, we redeemed 50,000 redeemable shares of £1 each and cancelled one deferred ordinary share of £1 in the capital of TechnipFMC.

The following is a summary of our capital stock activity for the years ended December 31, 2021, 2020 and 2019:

(Number of shares in millions)	Ordinary Shares Issued	Ordinary Shares Held in  Employee Benefit Trust	Treasury Stock
December 31, 2018	450.5	0.1	—
Stock awards	0.6	—	—
Treasury stock purchases	—	—	4.0
Treasury stock cancellation	(4.0)	—	(4.0)
Net stock purchased for employee benefit trust	—	(0.1)	—
December 31, 2019	447.1	—	—
Stock awards	2.4	—	—
December 31, 2020	449.5	—	—
Stock awards	1.2	—	—
December 31, 2021	450.7	—	—

In 2017, the Board of Directors authorized a share repurchase program of up to $500.0 million in ordinary shares and in December 2018, the Board of Directors authorized an extension of the share repurchase program of up to $300.0 million of additional shares. During the years ended December 31, 2021, 2020 and 2019, we repurchased nil, nil and $92.7 million of shares, respectively. As of December 31, 2021, we had $207.8 million of shares authorized for repurchase. Repurchased shares are canceled and not held in treasury. Canceled treasury shares are accounted for using the constructive retirement method.

Accumulated other comprehensive income (loss) - Accumulated other comprehensive income (loss) consisted of the following:

(In millions)	Foreign Currency Translation		Hedging		Defined Pension  and Other Post-Retirement Benefits		Accumulated Other Comprehensive  Loss Attributable to TechnipFMC plc		Accumulated Other Comprehensive  Loss Attributable to Non-Controlling Interest
December 31, 2019	$	(1,230.1)	$	(5.8)	$	(171.6)	$	(1,407.5)	$	(4.7)
Other comprehensive income (loss) before reclassifications, net of tax	(171.1)		26.8		(92.9)		(237.2)		0.6
Reclassification adjustment for net (gains) losses included in net income, net of tax	—		13.0		9.2		22.2		—
Other comprehensive income (loss), net of tax	(171.1)		39.8		(83.7)		(215.0)		0.6
December 31, 2020	$	(1,401.2)	$	34.0	$	(255.3)	$	(1,622.5)	$	(4.1)
Other comprehensive income (loss) before reclassifications, net of tax	29.2		(19.8)		70.8		80.2		(1.6)
Reclassification adjustment for net (gains) losses included in net income, net of tax	—		(11.8)		18.0		6.2		—
Other comprehensive income (loss), net of tax	29.2		(31.6)		88.8		86.4		(1.6)
Spin-off of Technip Energies	213.6		(19.7)		37.2		231.1		—
December 31, 2021	$	(1,158.4)	$	(17.3)	$	(129.3)	$	(1,305.0)	$	(5.7)

Reclassifications out of accumulated other comprehensive income (loss) - Reclassifications out of accumulated other comprehensive income (loss) consisted of the following:

	Year Ended December 31,
(In millions)	2021		2020		2019
Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified out of Accumulated Other Comprehensive Loss						Affected Line Item in the Consolidated Statement of Income
Gains on foreign currency translation	$	—	$	—	$	12.0	Other income (expense), net
Gains (losses) on hedging instruments
Foreign exchange contracts	$	(29.7)	$	(83.7)	$	(26.6)	Revenue
	10.7		68.5		12.0		Costs of sales
	0.2		(0.4)		—		Selling, general and administrative expense
	32.9		(4.4)		(9.1)		Other Income (expense), net
	14.1		(20.0)		(23.7)		Income (loss) before income taxes
	2.3		(7.0)		(5.5)		Provision (benefit) for income taxes
	$	11.8	$	(13.0)	$	(18.2)	Net income (loss)
Pension and other post-retirement benefits
Settlements and curtailments	$	(3.3)	$	(2.2)	$	(0.3)	(a)
Amortization of actuarial gain (loss)	(18.2)		(9.0)		(2.5)		(a)
Amortization of prior service credit (cost)	(0.5)		(1.2)		(1.0)		(a)
	(22.0)		(12.4)		(3.8)		Income (loss) before income taxes
	(4.0)		(3.2)		(0.8)		Provision (benefit) for income taxes
	$	(18.0)	$	(9.2)	$	(3.0)	Net income (loss)

(a)    These accumulated other comprehensive income components are included in the computation of net periodic pension cost (See Note 23 for further details).

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SHARE-BASED COMPENSATION

12 Months Ended

Dec. 31, 2021

Share-based Payment Arrangement [Abstract]

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION

Incentive compensation and award plan - On January 11, 2017, we adopted the TechnipFMC plc Incentive Award Plan (the “Plan”). The Plan provides certain incentives and awards to officers, employees, non-employee directors and consultants of TechnipFMC and its subsidiaries. The Plan allows our Board of Directors to make various types of awards to non-employee directors and the Compensation Committee (the “Committee”) of the Board of Directors to make various types of awards to other eligible individuals. Awards may include share options, share appreciation rights, performance share units, restricted share units, restricted shares or other awards authorized under the Plan. All awards are subject to the Plan’s provisions, including all share-based grants previously issued prior to consummation of the merger of FMC Technologies and Technip S.A. (the “Merger”). Under the Plan, 24.1 million ordinary shares were authorized for awards in 2017. On the record date of the Spin-off, 11.9 million shares remained available under the Plan, which were adjusted to reflect the Spin-off using an adjustment ratio, calculated as the ratio of the closing price of shares of TechnipFMC on the NYSE on the date immediately after the Spin-off. After this adjustment, 15.2 million ordinary shares remained authorized for awards under the Plan as of February 17, 2021. As of  December 31, 2021, 7.8 million ordinary shares were available for future grant

The exercise price for options is determined by the Committee but cannot be less than the fair market value of our ordinary shares at the grant date. Restricted share and performance share unit grants generally vest after three years of service.

Under the Plan, our Board of Directors has the authority to grant non-employee directors share options, restricted shares, restricted share units and performance shares. Unless otherwise determined by our Board of Directors, awards to non-employee directors generally vest one year from the date of grant. All restricted share units awarded prior to 2020 will be settled when a non-executive director ceases services on the Board of Directors. Beginning with the 2020 equity award, non-executive directors now have the opportunity to elect the year in which they will take receipt of the equity grants from either (a) a period of 1 to 10 years from the grant date or (b) upon their separation from Board service. The elections are made prior to the beginning of the grant year and are irrevocable after December 31 of the year prior to grant. Restricted share units are settled when a director ceases services to the Board of Directors. As of December 31, 2021, outstanding awards to active and retired non-employee directors included 184.6 thousand of share units.

The measurement of share-based compensation expense on restricted share awards is based on the market price and fair value at the grant date and the number of shares awarded. The fair value of performance shares is estimated using a combination of the closing stock price on the grant date and the Monte Carlo simulation model. We use Black-Scholes options pricing model to measure the fair value of stock options granted on or after January 1, 2017.

The share-based compensation expense for each award is recognized ratably over the applicable service period or the period beginning at the start of the service period and ending when an employee becomes eligible for retirement (currently age 62 under the Plan), after taking into account estimated forfeitures.

We recognize compensation expense and the corresponding tax benefits for awards under the Plan. The compensation expense under the Plan for continuing operations was as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Share-based compensation expense	$	26.8	$	38.3	$	44.4
Income tax benefits related to share-based compensation expense	7.2		10.3		12.0

In connection with the Spin-off and in accordance with the employee matters agreement, TechnipFMC has made certain adjustments to the exercise price and the number of share-based compensation awards. Share options and restricted share units were modified and converted into similar awards of the entity where the employee is working post the Spin-off using an adjustment ratio with the intention of preserving the intrinsic value of the awards prior to the Spin-off. Performance share units have been modified and converted to restricted share units at the target value using the adjustment ratio. The pre-tax share-based compensation expense due to the adjustments was $5.2 million in fiscal year 2021. All outstanding share awards and share options for employees transferred to Technip Energies were cancelled in connection with the Spin-off.

Additionally, in connection with the Spin-off, the Board of Directors approved amendments to certain outstanding long-term incentive awards on January 28, 2021. The amendments provided for the accelerated vesting on February 2, 2021 of certain stock-based awards that were otherwise scheduled to vest between June 1, 2021 and November 31, 2021.

As of December 31, 2021, the portion of share-based compensation expense related to outstanding awards to be recognized in future periods is as follows:

	December 31, 2021
Share-based compensation expense not yet recognized (in millions)	$	51.6
Weighted-average recognition period (in years)	1.4

Restricted Share Units

A summary of the non-vested restricted share units’ activity is as follows:

(Shares in thousands)	Shares	Weighted-Average  Grant Date  Fair Value
Non-vested as of December 31, 2020	6,121.9	$	18.43
Granted	2,893.0	$	7.97
Vested	(667.1)	$	37.57
Cancelled/forfeited	(882.6)	$	13.75
Adjustment due to the Spin-off	2,124.3	$	12.37
Non-vested as of December 31, 2021	9,589.5	$	11.35

The total grant date fair value of restricted stock share units vested during the years ended December 31, 2021, 2020 and 2019 was $25.1 million, $51.8 million and $10.2 million, respectively.

Performance Share Units

The Board of Directors has granted certain employees, senior executives and directors performance share units that vest subject to achieving satisfactory performances. For performance share units issued on or after January 1, 2017, performance is based on results of return on invested capital and total shareholder return (“TSR”).

For the performance share units which vest based on TSR, the fair value of performance shares is estimated using a combination of the closing stock price on the grant date and the Monte Carlo simulation model. The weighted-average fair value and the assumptions used to measure the fair value of performance share units subject to performance-adjusted vesting conditions in the Monte Carlo simulation model were as follows:

	Year Ended December 31,
	2021		2020		2019
Weighted-average fair value (a)	$11.50		$10.02		$29.04
Expected volatility (b)	62.70	%	38.30	%	34.00	%
Risk-free interest rate (c)	0.35	%	0.40	%	2.42	%
Expected performance period in years (d)	2.9		3.0		3.0

(a) The weighted-average fair value was based on performance share units granted during the period.

(b) Expected volatility is based on normalized historical volatility of our shares over a preceding period commensurate with the expected term of the performance share units.

(c) The risk-free rate for the expected term of the performance share units is based on the U.S. Treasury yield curve in effect at the time of grant.

(d) For awards subject to service-based vesting, due to the lack of historical exercise and post-vesting termination patterns of the post-Merger employee base, the expected term was estimated using a simplified method for all awards granted in 2021, 2020 and 2019.

A summary of the non-vested performance share units’ activity is as follows:

(Shares in thousands)	Shares	Weighted-Average  Grant Date  Fair Value
Non-vested as of December 31, 2020	4,840.7	$	17.55
Granted	2,426.2	$	11.50
Vested	(111.3)	$	30.42
Cancelled/forfeited	(1,723.2)	$	16.03
Adjustment due to the Spin-off	(3,122.8)	$	12.37
Non-vested as of December 31, 2021	2,309.6	$	13.26

The total grant date fair value of performance share units vested during years ended December 31, 2021, 2020 and 2019 was $3.4 million, $43.2 million and $13.3 million, respectively.

Share Option Awards

The fair value of each share option award is estimated as of the date of grant using the Black-Scholes options pricing model.

Share options awarded prior to 2017 were granted subject to performance criteria based upon certain targets, such as TSR, return on capital employed, and operating income from recurring activities. Subsequent share options granted are time-based awards vesting over three years.

There were no share option awards granted in 2021 or 2020. The weighted-average fair value and the assumptions used to measure fair value of 2019 grant were as follows:

	December 31, 2019
Weighted-average fair value (a)	$	5.64
Expected volatility (b)	32.5		%
Risk-free interest rate (c)	2.5		%
Expected dividend yield	2.6		%
Expected term in years (d)	6.5

(a)The weighted-average fair value was based on stock options granted during the period.

(b)Expected volatility is based on normalized historical volatility of our shares over a preceding period commensurate with the expected term of the option.

(c)The risk-free rate for the expected term of the option is based on the U.S. Treasury yield curve in effect at the time of grant.

(d)For awards subject to service-based vesting, due to the lack of historical exercise and post-vesting termination patterns of the post-Merger employee base, the expected term was estimated using a simplified method for all awards granted in 2019.

The following is a summary of share option transactions during the year ended December 31, 2021:

	Number of Shares	Weighted average exercise price		Weighted average remaining life (in years)
Balance as of December 31, 2020	4,598.4	$	29.77	4.2
Granted	—	$	—
Exercised	—	$	—
Cancelled	(532.0)	$	24.10
Adjustment due to the Spin-off	(2,490.3)	$	—
Balance as of December 31, 2021	1,576.1	$	20.17	6.3
Exercisable as of December 31, 2021	939.3	$	22.99	5.6

The aggregate intrinsic value of stock options outstanding and stock options exercisable as of December 31, 2021 was nil and nil, respectively.

Cash received from the share option exercises was nil, during each of the years ended December 31, 2021, 2020 and 2019. The total intrinsic value of share options exercised during each of the years ended December 31, 2021, 2020 and 2019 was nil. To exercise share options, an employee may choose (1) to pay, either directly or by way of the group savings plan, the share option strike price to obtain shares, or (2) to sell the shares immediately after having exercised the share option (in this case, the employee does not pay the strike price but instead receives the intrinsic value of the share options in cash).

The following summarizes significant ranges of outstanding and exercisable share options as of December 31, 2021:

	Options Outstanding				Options Exercisable
Exercise Price Range	Number of options (in thousands)	Weighted average remaining life (in years)	Weighted average exercise price		Number of options (in thousands)	Weighted average exercise price
$16.00-$19.00	636.7	7.2	$	16.46	—	$	—
$20.00-$24.00	721.2	5.6	$	22.28	721.2	$	22.28
$25.00-$26.00	218.2	5.6	$	25.32	218.1	$	25.32
Total	1,576.1	6.3	$	20.17	939.3	$	22.99

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IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES

12 Months Ended

Dec. 31, 2021

Restructuring and Related Activities [Abstract]

IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSE

IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES

Impairment, restructuring and other expenses were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Subsea	$	53.5	$	2,957.5	$	1,748.4
Surface Technologies	7.6		440.2		704.2
Corporate and other	5.6		4.3		4.1
Total impairment, restructuring and other expenses	$	66.7	$	3,402.0	$	2,456.7

Goodwill and Long-Lived Assets Impairments

Goodwill and long-lived assets impairments were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Subsea	$	44.2	$	2,854.5	$	1,794.8
Surface Technologies	1.9		419.3		685.5
Corporate and other	3.0		—		—
Total impairments	$	49.1	$	3,273.8	$	2,480.3

Subsequent to the Spin-off, certain real estate rationalization actions were taken, and as a result, we recorded $24.2 million of impairment charges relating to our operating lease right-of-use assets and $24.9 million of impairment of property, plant and equipment during the year ended December 31, 2021.

Due to the substantial decline in global demand for oil caused by the COVID-19 pandemic in 2020 we reviewed the future utilization of our vessels and service potential of our subsea service and surface equipment and determined that the carrying amount of our goodwill and some of our long-lived assets exceeded their respective fair values. We recorded $3,083.4 million and $190.4 million, respectively, related to goodwill and long-lived assets impairments. The $190.4 million of long-lived asset impairments during the year ended December 31, 2020 consisted of $88.4 million attributable to plant, equipment and various machinery infrastructure in our Subsea operating segment; $82.0 million mainly related to building and surface equipment in our Surface Technologies reportable segment; and $20.0 million of operating lease right-of-use assets impairments.

The prolonged downturn in the energy market and its corresponding impact on our business outlook in 2019 led us to conclude the carrying amount of certain of our assets in our Subsea and Surface Technologies segments exceeded their fair value as of December 31, 2019. During the 2019 year we recorded $1,988.7 million and $491.6 million, respectively, related to goodwill and long-lived assets impairments. The $491.6 million of long-lived asset impairments during the year ended December 31, 2019, primarily consisted of $153.8 million related to vessels in our Subsea operating segment and $168.9 million related to our flexible pipe and umbilical manufacturing facilities in our Surface Technologies reportable segment due to the prolonged downturn in the energy market and its corresponding impact on our business outlook.

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that carrying amounts of such assets may not be recoverable. Assessing the recoverability of assets to be held and used requires the use of unobservable inputs, which involves significant judgment. Such judgments include expected future asset utilization while taking into account reduced future capital spending by certain customers in response to market conditions.

Restructuring and Other Expenses

Restructuring and other charges primarily consisted of severance and other employee related costs and COVID-19 related expenses across all segments. Restructuring and other expenses were as follows:

	Year Ended December 31,
	2021		2020				2019
(In millions)	Restructuring and other charges		Restructuring and other charges		COVID-19 expenses		Restructuring and other charges
Subsea	$	9.3	$	52.9	$	50.1	$	(46.4)
Surface Technologies	5.7		13.2		7.7		18.7
Corporate and other	2.6		4.3		—		4.1
Total	$	17.6	$	70.4	$	57.8	$	(23.6)

COVID-19 related expenses represent unplanned, one-off, incremental and non-recoverable costs incurred solely as a result of the COVID-19 pandemic situation, which would not have been incurred otherwise. COVID-19 related expenses primarily included (a) employee payroll and travel, operational disruptions associated with quarantining, personnel travel restrictions to job sites, and shutdown of manufacturing plants and sites; (b) supply chain and related expediting costs of accelerated shipments for previously ordered and undelivered products; (c) costs associated with implementing additional information technology to support remote working environments; and (d) facilities-related expenses to ensure safe working environments.

Prolonged uncertainty in energy markets could lead to further future reductions in capital spending from our customer base. In turn, this may lead to changes in our strategy. We will continue to take actions designed to mitigate the adverse effects of the rapidly changing market environment and expect to continue to adjust our cost structure to market conditions. If market conditions continue to deteriorate, we may record additional restructuring charges and additional impairments of our long-lived assets, operating lease right-of-use assets and equity method investments.

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COMMITMENTS AND CONTINGENT LIABILITIES

12 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENT LIABILITIES

COMMITMENTS AND CONTINGENT LIABILITIES

Contingent liabilities associated with guarantees - In the ordinary course of business, we enter into standby letters of credit, performance bonds, surety bonds, and other guarantees with financial institutions for the benefit of our customers, vendors, and other parties. The majority of these financial instruments expire within five years. Management does not expect any of these financial instruments to result in losses that, if incurred, would have a material adverse effect on our consolidated financial position, results of operations, or cash flows.

Guarantees made by our consolidated subsidiaries consisted of the following:

(In millions)	December 31, 2021
Financial guarantees (a)	$	177.4
Performance guarantees (b)	1,069.0
Maximum potential undiscounted payments	$	1,246.4

(a)Financial guarantees represent contracts that contingently require a guarantor to make payments to a guaranteed party based on changes in an underlying agreement that is related to an asset, a liability or an equity security of the guaranteed party. These tend to be drawn down only if there is a failure to fulfill our financial obligations.

(b)Performance guarantees represent contracts that contingently require a guarantor to make payments to a guaranteed party based on another entity's failure to perform under a nonfinancial obligating agreement. Events that trigger payment are performance-related, such as failure to ship a product or provide a service.

We believe the ultimate resolution of our known contingencies will not materially adversely affect our consolidated financial position, results of operations, or cash flows.

Contingent liabilities associated with legal and tax matters - We are involved in various pending or potential legal and tax actions or disputes in the ordinary course of our business. These actions and disputes can involve our agents, suppliers, clients, and venture partners, and can include claims related to payment of fees, service quality, and ownership arrangements, including certain put or call options. We are unable to predict the ultimate outcome of these actions because of their inherent uncertainty. However, we believe that the most probable, ultimate resolution of these matters will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.

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 U.S. Foreign Corrupt Practices Act (“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 we have also raised with the DOJ certain other projects performed by Technip S.A. subsidiaries in Brazil between 2002 and 2013. The DOJ has 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.

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 will not be required to have a monitor and will, instead, provide 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 will also provide the DOJ reports on our anti-corruption program during the term of the DPA.

In Brazil, 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 have committed, as part of those agreements, to make certain enhancements to their compliance programs in Brazil during a two-year self-reporting period, which aligns 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.

To date, the investigation by 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 recently 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, 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 anticorruption 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.

Contingent liabilities associated with liquidated damages - Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a conforming claim under these provisions. These contracts define the conditions under which our customers may make claims against us for liquidated damages. Based upon the evaluation of our performance and other commercial and legal analysis, management believes we have appropriately recognized probable liquidated damages as of December 31, 2021 and 2020, and that the ultimate resolution of such matters will not materially affect our consolidated financial position, results of operations, or cash flows.

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INCOME TAXES

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

Components of income (loss) from continuing operations before income taxes - U.S. and outside U.S. components of income (loss) from continuing operations before income taxes were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
United States	$	(288.2)	$	(2,169.3)	$	(2,376.4)
Outside United States	486.3		(1,329.4)		(194.7)
Income (loss) from continuing operations before income taxes	$	198.1	$	(3,498.7)	$	(2,571.1)

Provision (benefit) for income tax - The provision for income taxes consisted of:

	Year Ended December 31,
(In millions)	2021		2020		2019
Current
United States	$	0.2	$	(18.3)	$	39.1
Outside United States	206.0		69.5		12.0
Total current income taxes	206.2		51.2		51.1
Deferred
United States	—		(2.8)		3.8
Outside United States	(95.1)		(29.0)		24.1
Total deferred income taxes	(95.1)		(31.8)		27.9
Provision for income taxes	$	111.1	$	19.4	$	79.0

Deferred tax assets and liabilities - Significant components of deferred tax assets and liabilities were as follows: 

	December 31,
(In millions)	2021		2020
Deferred tax assets attributable to
Accrued expenses	$	173.0	$	133.0
Capital loss	21.1		21.1
Non-deductible interest	95.4		77.0
Foreign tax credit carryforwards	136.5		134.4
Other tax credits	146.0		163.8
Net operating loss carryforwards	455.5		383.5
Inventories	1.2		16.6
Research and development credit	3.8		2.9
Foreign exchange	17.2		—
Provisions for pensions and other long-term employee benefits	31.9		66.1
Contingencies	38.3		2.9
Margin recognition on construction contracts	18.0		20.6
Leases	183.4		170.4
Other	5.4		0.6
Deferred tax assets	1,326.7		1,192.9
Valuation allowance	(935.5)		(815.1)
Deferred tax assets, net of valuation allowance	391.2		377.8
Deferred tax liabilities attributable to
Revenue in excess of billings on contracts accounted for under the percentage of completion method	32.2		33.6
U.S. tax on foreign subsidiaries’ undistributed earnings not indefinitely reinvested	—		4.2
Property, plant and equipment, intangibles and other assets	162.8		180.1
Foreign exchange	—		43.9
Leases	169.4		161.1
Deferred tax liabilities	364.4		422.9
Net deferred tax assets/(liabilities)	$	26.8	$	(45.1)

At December 31, 2021 and 2020, the carrying amount of net deferred tax assets and the related valuation allowance included the impact of foreign currency translation adjustments.

Non-deductible interest. At December 31, 2021, deferred tax assets include tax benefits related to certain intercompany interest costs which are not currently deductible, but which may be deductible in future periods. If not utilized, these costs will become permanently non-deductible beginning in 2025. Management believes that it is more likely than not that we will not be able to deduct these costs before expiration of the carry forward period; therefore, we have established an uncertain tax position and valuation allowance against the related deferred tax assets.

Foreign tax credit carryforwards. At December 31, 2021, deferred tax assets included U.S. foreign tax credit carryforwards of $136.5 million, which, if not utilized, will begin to expire in 2023. Realization of these deferred tax assets is dependent on the generation of sufficient U.S. taxable income prior to the above date. Based on long-term forecasts of operating results, management believes that it is more likely than not that our U.S. earnings over the forecast period will not result in sufficient U.S. taxable income to fully realize these deferred tax assets; therefore, we have established a valuation allowance against the related deferred tax assets. In its analysis, management has considered the effect of deemed dividends and other expected adjustments to U.S. earnings that are required in determining U.S. taxable income. Non-U.S. earnings subject to U.S. tax, including deemed dividends for U.S. tax purposes, were $19.5 million in 2021, $0.1 million in 2020 and $21.4 million in 2019.

Net operating loss carryforwards. At December 31, 2021, we had $455.5 million of tax-effected net operating loss carryforwards, with approximately $23.5 million estimated to be utilized against our unrecognized tax benefits. The ultimate realization of these deferred tax assets depends on our ability to generate sufficient taxable income in the appropriate taxing jurisdiction. Our deferred tax assets from net operating losses will expire as follows:

(In millions)	Net Operating Loss
2022 – 2026	$	55.4
2027 – 2031	42.0
2032 – 2042	70.1
Non-Expiring	288.0
	$	455.5

Unrecognized tax benefits - The following table presents a summary of changes in our unrecognized tax benefits: 

(In millions)	Federal, State and Foreign Tax
Balance at December 31, 2019	$	57.6
Reductions for tax positions related to prior years	(7.9)
Reductions for tax positions related to current year	(2.9)
Reductions for tax positions due to settlements	(0.6)
Balance at December 31, 2020	46.2
Reductions for tax positions related to prior years	(15.2)
Additions for tax positions related to current year	39.9
Reductions for tax positions due to settlements	(2.1)
Balance at December 31, 2021	$	68.8

The amounts reported above for uncertain tax positions excludes interest and penalties of $0.2 million, $0.6 million, and nil for the years ended December 31, 2021, 2020, and 2019, respectively. Interest and penalties relating to these uncertain tax positions were included in income tax expense in our consolidated statements of income. It is reasonably possible that within twelve months, $14.3 million of assets for unrecognized tax benefits will be settled. This amount is reflected in income taxes payable, the remaining balance of the unrecognized tax benefit is recorded in other long term liabilities. As of December 31, 2021, a net $32.5 million unrecognized tax benefit, without a net operating loss carryforward or other deferred tax asset to offset, would positively impact the effective tax rate and be recognized as additional tax benefits in our statement of operations if resolved in our favor.

We operate in numerous jurisdictions around the world and could be subject to multiple tax audits at any given time. Most notably, the following tax years and thereafter remain subject to examination: 2012 for Norway, 2016 for Nigeria, 2017 for Brazil, 2019 for France, and 2018 for the United States.

TechnipFMC plc is a public limited company incorporated under the laws of England and Wales. Therefore, our earnings are subject to the U.K. statutory rate which is 19.0% for 2021, 2020, and 2019.

Effective income tax rate reconciliation - The effective income tax rate was different from the statutory U.K. income tax rate due to the following:

	Year Ended December 31,
	2021		2020		2019
Statutory income tax rate	19.0	%	19.0	%	19.0	%
Net difference resulting from
Foreign earnings subject to different tax rates	24.4	%	1.3	%	3.4	%
Adjustments to prior year taxes	(52.4)	%	(1.2)	%	0.8	%
Net change in unrecognized tax benefits	12.3	%	—	%	—	%
Changes in valuation allowance	65.4	%	(0.9)	%	(7.2)	%
Deferred tax asset/liability revaluation for tax rate change	(12.2)	%	0.3	%	(0.4)	%
Impairments	—	%	(19.5)	%	(19.7)	%
Non-deductible legal provision	—	%	0.3	%	1.1	%
Other	(0.4)	%	0.1	%	(0.1)	%
Effective income tax rate	56.1	%	(0.6)	%	(3.1)	%

Income tax holidays. We did not benefit from income tax holidays in 2021.

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS

12 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]

PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS

PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS

We have funded and unfunded defined benefit pension plans, which provide defined benefits based on years of service and final average salary.

On December 31, 2017, we amended the U.S. retirement plans (the “Plans”) to freeze benefit accruals for all participants of the Plans as of December 31, 2017. After that date, participants in the Plans will no longer accrue any further benefits and participants’ benefits under the Plans will be determined based on credited service and eligible earnings as of December 31, 2017.

Foreign-based employees are eligible to participate in TechnipFMC-sponsored or government-sponsored benefit plans to which we contribute. Several of the foreign defined benefit pension plans sponsored by us provide for employee contributions; the remaining plans are noncontributory. The most significant of these plans are in the Netherlands, France, and the United Kingdom.

We have other post-retirement benefit plans covering substantially all of our U.S. unionized employees. The post-retirement health care plans are contributory; the post-retirement life insurance plans are noncontributory.

We are required to recognize the funded status of defined benefit post-retirement plans as an asset or liability in the consolidated balance sheet and recognize changes in that funded status in comprehensive income (loss) in the year in which the changes occur. Further, we are required to measure the plan’s assets and its obligations that determine its funded status as of the date of the consolidated balance sheet. We have applied this guidance to our domestic pension and other post-retirement benefit plans as well as for many of our non-U.S. plans, including those in the United Kingdom, Germany, France and Canada. Pension expense measured in compliance with GAAP for the other non-U.S. pension plans is not materially different from the locally reported pension expense.

In connection with the Spin-off, certain international plans were transferred to Technip Energies and reported as discontinued operations for the years ended December 31, 2020 and 2019.

The funded status of our U.S. Pension Plans, certain foreign pension plans and U.S. post-retirement health care and life insurance benefit plans, together with the associated balances recognized in our consolidated balance sheets as of December 31, 2021 and 2020, were as follows:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Accumulated benefit obligation	$	653.6	$	589.1	$	684.7	$	598.1
Projected benefit obligation at January 1	$	684.7	$	656.4	$	669.7	$	585.1	$	9.4	$	10.2
Service cost	—		10.0		—		10.4		—		—
Interest cost	18.0		9.8		22.2		11.3		0.3		0.4
Actuarial (gain) loss	7.1		(32.5)		53.9		30.4		(0.7)		(0.2)
Settlements	(22.6)		—		(25.6)		(2.6)		—		—
Foreign currency exchange rate changes	—		(11.9)		—		23.6		(0.2)		(0.6)
Plan participants’ contributions	—		0.9		—		1.1		—		—
Benefits paid	(33.6)		(22.0)		(35.5)		(17.8)		(0.4)		(0.4)
Other	—		(9.1)		—		14.9		—		—
Projected benefit obligation as of December 31	653.6		601.6		684.7		656.4		8.4		9.4
Fair value of plan assets at January 1	483.7		591.5		520.0		521.2		—		—
Actual return on plan assets	61.1		46.4		14.3		40.1		—		—
Company contributions	28.9		19.6		—		27.1		—		—
Foreign currency exchange rate changes	—		(8.9)		—		20.4		—		—
Settlements	(22.6)		—		(19.6)		(1.9)		—		—
Plan participants’ contributions	—		0.9		—		1.1		—		—
Benefits paid	(33.6)		(22.0)		(31.0)		(15.8)		—		—
Other	—		—		—		(0.7)		—		—
Fair value of plan assets as of December 31	517.5		627.5		483.7		591.5		—		—
Funded status of the plans (liability) as of December 31	$	(136.1)	$	25.9	$	(201.0)	$	(64.9)	$	(8.4)	$	(9.4)

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Current portion of accrued pension and other post-retirement benefits	$	(2.9)	$	(1.7)	$	(4.6)	$	(1.6)	$	(0.6)	$	(0.7)
Accrued pension and other post-retirement benefits, net of current portion	(133.2)		27.6		(196.4)		(63.3)		(7.8)		(8.7)
Funded status as of December 31	$	(136.1)	$	25.9	$	(201.0)	$	(64.9)	$	(8.4)	$	(9.4)

The following table summarizes the pre-tax amounts in accumulated other comprehensive (income) loss as of December 31, 2021 and 2020 that have not been recognized as components of net periodic benefit cost:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Pre-tax amounts recognized in accumulated other comprehensive (income) loss
Unrecognized actuarial loss	$	156.6	$	15.9	$	198.4	$	79.1	$	0.4	$	1.3
Unrecognized prior service cost	—		3.4		—		3.9		—		—
Accumulated other comprehensive (income) loss as of December 31	$	156.6	$	19.3	$	198.4	$	83.0	$	0.4	$	1.3

The following tables summarize the projected and accumulated benefit obligations and fair values of plan assets where the projected or accumulated benefit obligation exceeds the fair value of plan assets as of December 31, 2021 and 2020:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Plans with underfunded or non-funded projected benefit obligation
Aggregate projected benefit obligation	$	652.2	$	57.9	$	684.7	$	513.1	$	8.4	$	9.4
Aggregate fair value of plan assets	$	516.0	$	—	$	483.7	$	442.7	$	—	$	—

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Plans with underfunded or non-funded accumulated benefit obligation
Aggregate accumulated benefit obligation	$	652.2	$	46.7	$	684.7	$	50.8	$	—	$	—
Aggregate fair value of plan assets	$	516.0	$	—	$	483.7	$	—	$	—	$	—

The following table summarizes the components of net periodic benefit cost (income) for the years ended December 31, 2021, 2020 and 2019:

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
(In millions)	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Components of net periodic benefit cost (income)
Service cost	$	—	$	10.0	$	—	$	10.4	$	—	$	7.0	$	—	$	—	$	—
Interest cost	18.0		9.8		22.2		11.3		25.6		13.7		0.3		0.4		0.5
Expected return on plan assets	(31.9)		(25.0)		(45.4)		(36.5)		(41.6)		(31.3)		—		—		—
Settlement cost	2.8		—		1.4		0.5		—		—		—		—		—
Curtailment benefit	—		0.4		—		—		—		—		—		—		—
Amortization of net actuarial loss (gain)	16.8		1.4		6.9		0.6		1.8		0.3		0.1		0.1		—
Amortization of prior service cost (credit)	—		0.5		—		0.6		—		0.4		—		—		—
Net periodic benefit cost (income)	$	5.7	$	(2.9)	$	(14.9)	$	(13.1)	$	(14.2)	$	(9.9)	$	0.4	$	0.5	$	0.5

The following table summarizes changes in plan assets and benefit obligations recognized in other comprehensive income (loss) for the years ended December 31, 2021, 2020 and 2019:

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
(In millions)	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Changes in plan assets and benefit obligations recognized in other comprehensive income (loss)
Net actuarial gain (loss) arising during period	$	(22.1)	$	(58.4)	$	(85.1)	$	(26.8)	$	(50.2)	$	(37.5)	$	—	$	—	$	—
Prior service (cost) credit arising during period	—		0.6		—		—		—		(0.9)		—		—		—
Settlements and curtailments	(2.8)		(0.4)		1.4		0.4		—		—		—		—		—
Amortization of net actuarial loss (gain)	(16.8)		(1.4)		6.9		0.6		1.8		0.3		—		(0.1)		—
Amortization of prior service cost (credit)	—		(0.5)		—		0.6		—		0.4		—		—		—
Other	—		—		—		(7.5)		—		(1.5)		(0.9)		(0.6)		1.5
Total recognized in other comprehensive income (loss)	$	(41.7)	$	(60.1)	$	(76.8)	$	(32.7)	$	(48.4)	$	(39.2)	$	(0.9)	$	(0.7)	$	1.5

Included in accumulated other comprehensive income (loss) as of December 31, 2021, are noncash, pre-tax charges which have not yet been recognized in net periodic benefit cost (income). The estimated amounts expected to be amortized from the portion of each component of accumulated other comprehensive income (loss) as a component of net period benefit cost (income), during the next fiscal year are as follows:

	Pensions				Other Post-retirement Benefits
(In millions)	U.S.		Int’l
Net actuarial losses	$	12.0	$	—	$	—
Prior service cost	$	—	$	0.4	$	—

Key assumptions - The following weighted-average assumptions were used to determine the benefit obligations: 

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
	U.S.		Int’l		U.S.		Int’l
Discount rate	2.90	%	1.99	%	2.70	%	1.48	%	5.26	%	3.63	%
Rate of compensation increase	N/A		3.15	%	N/A		2.93	%	4.00	%	4.00	%

The following weighted-average assumptions were used to determine net periodic benefit cost: 

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Discount rate	2.70	%	3.09	%	3.40	%	2.01	%	4.40	%	2.89	%	4.46	%	4.48	%	5.32	%
Rate of compensation increase	N/A		3.15	%	N/A		3.84	%	N/A		3.80	%	4.00	%	4.00	%	4.00	%
Expected rate of return on plan assets	6.75	%	2.22	%	7.75	%	7.27	%	8.65	%	7.15	%	N/A		N/A		N/A

Our estimate of expected rate of return on plan assets is primarily based on the historical performance of plan assets, current market conditions, our asset allocation and long-term growth expectations.

Plan assets - We actively monitor how the duration and the expected yield of the investments are matching the expected cash outflows arising from the pension obligations. We have not changed the processes used to manage its risks from previous periods. Investments are well diversified, such that the failure of any single investment would not have a material impact on the overall level of assets. Our pension investment strategy emphasizes maximizing returns consistent with balancing risk. Excluding our international plans with insurance-based investments, 98.8% of our total pension plan assets represent the U.S. qualified plan and the U.K. plan. These plans are primarily invested in equity securities to maximize the long-term returns of the plans. The investment managers of these assets, including the hedge funds and limited partnerships, use Graham and Dodd fundamental investment analysis to select securities that have a margin of safety between the price of the security and the estimated value of the security. This value-oriented approach tends to mitigate the risk of a large equity allocation.

The following is a description of the valuation methodologies used for the pension plan assets. There have been no changes in the methodologies used as of December 31, 2021 and 2020.

•Cash is valued at cost, which approximates fair value.

•Equity securities are comprised of common stock and preferred stock. The fair values of equity securities are valued at the closing price reported on the active market on which the securities are traded.

•Fair values of registered investment companies and common/collective trusts are valued based on quoted market prices, which represent the net asset value (“NAV”) of shares held. Registered investment companies primarily include investments in emerging market bonds. Common/collective trusts primarily includes money market instruments with short maturities.

•Insurance contracts are valued at book value, which approximates fair value, and is calculated using the prior-year balance plus or minus investment returns and changes in cash flows.

•The fair values of hedge funds are valued using the NAV as determined by the administrator or custodian of the fund. The funds primarily invest in U.S. and international equities, debt securities and other hedge funds.

•The fair values of limited partnerships are valued using the NAV as determined by the administrator or custodian of the fund. The partnerships primarily invest in U.S. and international equities and debt securities.

•Real estate and other investments primarily consist of real estate investment trusts and other investments. These investments are measured at quoted market prices, which represent the NAV of the securities held in such funds at year end.

Our pension plan assets measured at fair value on a recurring basis are as follows as of December 31, 2021 and 2020. Refer to “Fair value measurements” in Note 1 to these consolidated financial statements for a description of the levels.

(In millions)	U.S.										International
December 31, 2021	Total		Level 1		Level 2		Level 3		Net Asset Value (a)		Total		Level 1		Level 2		Level 3		Net Asset Value (a)
Cash and cash equivalents	$	43.4	$	43.4	$	—	$	—	$	—	$	40.5	$	40.5	$	—	$	—	$	—
Equity securities
U.S. companies	102.1		102.1		—		—		—		45.5		45.5		—		—		—
International companies	2.1		2.1		—		—		—		143.4		143.4		—		—		—
Registered investment companies	37.9		—		—		—		37.9		36.0		—		—		—		36.0
Insurance contracts	—		—		—		—		—		—		—		—		—		—
Hedge funds	138.8		—		—		—		138.8		291.0		—		—		—		291.0
Limited partnerships	192.5		—		—		—		192.5		3.6		—		—		—		3.6
Real estate and other investments	0.6		0.6		—		—		—		69.7		69.7		—		—		—
Total assets	$	517.4	$	148.2	$	—	$	—	$	369.2	$	629.7	$	299.1	$	—	$	—	$	330.6
December 31, 2020
Cash and cash equivalents	$	38.1	$	38.1	$	—	$	—	$	—	$	66.3	$	66.3	$	—	$	—	$	—
Equity securities
U.S. companies	83.3		83.3		—		—		—		96.3		96.3		—		—		—
International companies	1.1		1.1		—		—		—		208.4		208.4		—		—		—
Registered investment companies	38.4		—		—		—		38.4		68.2		—		—		—		68.2
Hedge funds	160.9		—		—		—		160.9		98.3		—		—		—		98.3
Limited partnerships	160.9		—		—		—		160.9		14.5		—		—		—		14.5
Real estate and other investments	1.0		1.0		—		—		—		39.5		39.5		—		—		—
Total assets	$	483.7	$	123.5	$	—	$	—	$	360.2	$	591.5	$	410.5	$	—	$	—	$	181.0

(a)Certain investments that are measured at fair value using net asset value per share (or its equivalent) have not been classified in the fair value hierarchy.

Contributions - We expect to contribute approximately $12.3 million to our international pension plans, representing primarily the U.K. qualified pension plans in 2022. We do not expect to make any contributions to our U.S. Qualified Pension Plan and our U.S. Non-Qualified Defined Benefit Pension Plan in 2022. All of the contributions are expected to be in the form of cash. In 2021 and 2020, we contributed $34.3 million and $27.1 million to all pension plans, respectively.

Estimated future benefit payments - The following table summarizes expected benefit payments from our various pension and post-retirement benefit plans through 2031. Actual benefit payments may differ from expected benefit payments.

	Pensions				Other Post-retirement Benefits
(In millions)	U.S.		International
2022	$	33.3	$	22.0	$	0.6
2023	31.4		22.4		0.6
2024	31.7		23.8		0.6
2025	32.3		24.4		0.5
2026	32.7		25.6		0.5
2027-2031	165.9		149.9		2.3

Savings plans - The TechnipFMC Retirement Savings Plan (“Qualified Plan”), a qualified salary reduction plan under Section 401(k) of the Internal Revenue Code, is a defined contribution plan. Additionally, we have a non-qualified deferred compensation plan, the Non-Qualified Plan, which allows certain highly compensated employees the option to defer the receipt of a portion of their salary. We match a portion of the participants’ deferrals to both plans. Both plans relate to FMC Technologies, Inc.

Participants in the Non-Qualified Plan earn a return based on hypothetical investments in the same options as our 401(k) plan. Changes in the market value of these participant investments are reflected as an adjustment to the deferred compensation liability with an offset to other income (expense), net. As of December 31, 2021 and 2020, our liability for the Non-Qualified Plan was $24.1 million and $22.8 million, respectively, and was recorded in other liabilities in our consolidated balance sheets. We hedge the financial impact of changes in the participants’ hypothetical investments by purchasing the investments that the participants have chosen. Changes in the fair value of these investments are recognized as an offset to other income (expense), net in our consolidated statements of income. As of December 31, 2021 and 2020, we had investments for the Non-Qualified Plan totaling $24.1 million and $22.8 million at fair market value, respectively.

During the years ended December 31, 2021, and 2020 we recognized expense of $21.5 million and $21.3 million, respectively for matching contributions to these plans in 2021 and 2020, respectively. Additionally, during the years ended December 31, 2021 and 2020, we recognized expense of $9.0 million and $8.3 million, respectively, for non-elective contributions.

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DERIVATIVE FINANCIAL INSTRUMENTS

12 Months Ended

Dec. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS

DERIVATIVE FINANCIAL INSTRUMENTS

For purposes of mitigating the effect of changes in exchange rates, we hold derivative financial instruments to hedge the risks of certain identifiable and anticipated transactions and recorded assets and liabilities in our consolidated balance sheets. The types of risks hedged are those relating to the variability of future earnings and cash flows caused by movements in foreign currency exchange rates. Our policy is to hold derivatives only for the purpose of hedging risks associated with anticipated foreign currency purchases and sales created in the normal course of business, and not for speculative purposes.

Generally, we enter into hedging relationships such that changes in the fair values or cash flows of the transactions being hedged are expected to be offset by corresponding changes in the fair value of the derivatives. For derivative instruments that qualify as a cash flow hedge, the effective portion of the gain or loss of the derivative, which does not include the time value component of a forward currency rate, is reported as a component of other comprehensive income (“OCI”) and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings. For derivative instruments not designated as hedging instruments, any change in the fair value of those instruments is reflected in earnings in the period such change occurs.

We hold the following types of derivative instruments:

Foreign exchange rate forward contracts – The purpose of these instruments is to hedge the risk of changes in future cash flows of anticipated purchase or sale commitments denominated in foreign currencies and recorded assets and liabilities in our consolidated balance sheets. As of December 31, 2021, we held the following material net positions: 

	Net Notional Amount Bought (Sold)
(In millions)		USD Equivalent
Euro	775.4	878.2
British pound	(197.2)	(265.9)
Malaysian ringgit	(627.4)	(150.5)
Norwegian krone	967.9	109.8
Brazilian real	1,299.8	232.9
Singapore dollar	125.4	92.9
Mexican peso	(116.7)	(5.7)
Australian dollar	182.4	132.2
Indian rupee	881.4	11.8
Kuwaiti Dinar	(3.3)	(10.9)
Russian Ruble	925.0	12.5
Canadian dollar	19.2	15.1
Indonesian rupiah	(45,656.9)	(3.2)
U.S. dollar	(1,119.9)	(1,119.9)

Foreign exchange rate instruments embedded in purchase and sale contracts – The purpose of these instruments is to match offsetting currency payments and receipts for particular projects, or comply with government restrictions on the currency used to purchase goods in certain countries. As of December 31, 2021, our portfolio of these instruments included the following material net positions: 

	Net Notional Amount Bought (Sold)
(In millions)		USD Equivalent
Brazilian real	52.5	9.4
Euro	(7.3)	(8.3)
Norwegian krone	6.1	0.7
U.S. dollar	(1.2)	(1.2)

Fair value amounts for all outstanding derivative instruments have been determined using available market information and commonly accepted valuation methodologies. See Note 25 for further details. Accordingly, the estimates presented may not be indicative of the amounts that we would realize in a current market exchange and may not be indicative of the gains or losses we may ultimately incur when these contracts are settled.

The following table presents the location and fair value amounts of derivative instruments reported in the consolidated balance sheets:

	December 31, 2021				December 31, 2020
(In millions)	Assets		Liabilities		Assets		Liabilities
Derivatives designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments	$	106.4	$	139.5	$	189.5	$	141.9
Long-term - Derivative financial instruments	10.5		15.5		28.9		18.8
Total derivatives designated as hedging instruments	116.9		155.0		218.4		160.7
Derivatives not designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments	3.9		21.5		79.2		15.6
Long-term - Derivative financial instruments	—		—		0.3		—
Total derivatives not designated as hedging instruments	3.9		21.5		79.5		15.6
Total derivatives	$	120.8	$	176.5	$	297.9	$	176.3

Cash flow hedges of forecasted transactions, net of tax, which qualify for hedge accounting, resulted in accumulated other comprehensive gains (losses) of $(18.7) million and $12.9 million as of December 31, 2021 and 2020, respectively. We expect to transfer an approximately $3.4 million gain from accumulated OCI to earnings during the next 12 months when the anticipated transactions actually occur. All anticipated transactions currently being hedged are expected to occur by the second half of 2024.

The following tables present the location of gains (losses) in the consolidated statements of income related to derivative instruments designated as cash flow hedges. 

	Gain (Loss) Recognized in OCI
	Year Ended December 31,
(In millions)	2021		2020		2019
Foreign exchange contracts	$	(26.3)	$	3.8	$	12.2

The following represents the effect of cash flow hedge accounting on the consolidated statements of income for the year ended December 31, 2021, 2020 and 2019:

	Year Ended December 31,
(In millions)	2021								2020								2019
Total amount of income (expense) presented in the consolidated statements of income associated with hedges and derivatives	Revenue		Cost of sales		Selling, general and administrative expense		Other income (expense), net		Revenue		Cost of sales		Selling, general and administrative expense		Other income (expense), net		Revenue		Cost of sales		Other income (expense), net
Amounts reclassified from accumulated OCI to income (loss)	$	(29.7)	$	10.7	$	0.2	$	32.9	$	(83.7)	$	68.5	$	(0.4)	$	(0.2)	$	(26.6)	$	12.0	$	(1.3)
Amounts excluded from effectiveness testing	(1.8)		(3.3)		—		3.8		7.7		(9.8)		(0.2)		0.3		0.6		(7.6)		(7.2)
Total cash flow hedge gain (loss) recognized in income	(31.5)		7.4		0.2		36.7		(76.0)		58.7		(0.6)		0.1		(26.0)		4.4		(8.5)
Gain (loss) recognized in income on derivatives not designated as hedging instruments	1.3		0.3		—		(13.3)		(0.8)		3.4		—		35.9		(1.6)		0.2		(21.4)
Total	$	(30.2)	$	7.7	$	0.2	$	23.4	$	(76.8)	$	62.1	$	(0.6)	$	36.0	$	(27.6)	$	4.6	$	(29.9)

Balance Sheet Offsetting - We execute derivative contracts with counterparties that consent to a master netting agreement which permits net settlement of the gross derivative assets against gross derivative liabilities. Each instrument is accounted for individually and assets and liabilities are not offset. As of December 31, 2021 and 2020, we had no collateralized derivative contracts. The following tables present both gross information and net information of recognized derivative instruments:

	December 31, 2021						December 31, 2020
(In millions)	Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount		Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount
Derivative assets	$	120.8	$	(78.6)	$	42.2	$	297.9	$	(128.7)	$	169.2
Derivative liabilities	$	176.5	$	(78.6)	$	97.9	$	176.3	$	(128.7)	$	47.6

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FAIR VALUE MEASUREMENTS

12 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

Recurring Fair Value Measurements

Assets and liabilities measured at fair value on a recurring basis were as follows: 

	December 31, 2021								December 31, 2020
(In millions)	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Assets
Investments
Investment in Technip Energies	$	317.3	$	317.3	$	—	$	—	$	—	$	—	$	—	$	—
Equity securities(a)	25.0		25.0		—		—		23.4		23.4		—		—
Money market fund	2.4		—		2.4		—		1.7		—		1.7		—
Stable value fund(b)	0.3		—		—		—		0.9		—		—		—
Held-to-maturity debt securities	24.0		—		24.0		—		24.2		—		24.2		—
Derivative financial instruments
Foreign exchange contracts	120.8		—		120.8		—		297.9		—		297.9		—
Assets held for sale	5.0		—		—		5.0		47.3		—		—		47.3
Total assets	$	494.8	$	342.3	$	147.2	$	5.0	$	395.4	$	23.4	$	323.8	$	47.3
Liabilities
Derivative financial instruments
Foreign exchange contracts	176.5		—		176.5		—		176.3		—		176.3		—
Total liabilities	$	176.5	$	—	$	176.5	$	—	$	176.3	$	—	$	176.3	$	—

(a)Includes fixed income and other investments measured at fair value.

(b)Certain investments that are measured at fair value using net asset value per share (or its equivalent) have not been classified in the fair value hierarchy.

Investment in Technip Energies - The fair value of our investment in Technip Energies is based on quoted prices that we have the ability to access in public markets, see Note 13 for further details.

Equity securities and Available-for-sale Securities - The fair value measurement of our traded securities and Available-for-sale-Securities is based on quoted prices that we have the ability to access in public markets.

Stable value fund and Money market fund - Stable value fund and money market fund are valued at the net asset value of the shares held at the end of the quarter, which is based on the fair value of the underlying investments using information reported by our investment advisor at quarter-end.

Held-to-maturity debt securities - Held-to-maturity debt securities consist of government bonds. These investments are stated at amortized cost, which approximates fair value.

Assets held for sale - The fair value of our assets held for sale was determined using a market approach that took into consideration the expected sales price. As of December 31, 2020, our G1200 vessel is classified as held for sale. In March 2021, we entered into a Memorandum of Agreement to sell the vessel. We completed the sale and received $48.0 million in cash proceeds during the second quarter of 2021.

Redeemable non-controlling interest - In accordance with the Share Purchase Agreement between Technip-Coflexip UK Holdings Limited (“TUK”) and Island Offshore Management AS (“Island Offshore”) that was executed on March 12, 2018, whereby TUK initially purchased 51% of the shares of TIOS AS, a joint venture between TUK and Island Offshore, TUK acquired the remaining 49% interest in TIOS at a total price of $48.6 million during the third quarter of 2021. As of December 31, 2020, we owned a 51% share in TIOS and the redeemable non-controlling interest was recorded as mezzanine equity at fair value of $43.7 million.

Derivative financial instruments - We use the income approach 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 by using the spread of similar companies in the same industry, of similar size and with the same credit rating.

We currently 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. See Note 24 for further details.

Nonrecurring Fair Value Measurements

Fair value of long-lived, non-financial assets - Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that carrying amounts of such assets may not be recoverable.

The following summarizes impairments of long-lived assets and related post-impairment fair value for the years ended December 31, 2021 and 2020:

	Year Ended December 31,
	2021				2020
(In millions)	Impairment		Fair Value		Impairment		Fair Value
Long-lived assets(a)	$	49.1	$	25.5	$	190.4	$	452.5

(a)Measuring these asset groups for recoverability required the use of unobservable inputs that require significant judgment. Such judgments include expected future asset utilization while taking into account reduced future capital spending by certain customers in response to market conditions.

Other fair value disclosures

The carrying amounts of cash and cash equivalents, trade receivables, accounts payable, short-term debt, commercial paper, debt associated with our bank borrowings, credit facilities, as well as amounts included in other current assets and other current liabilities that meet the definition of financial instruments, approximate fair value.

Fair value of debt - We use a market approach to determine the fair value of our fixed-rate debt using observable market data, which results in a Level 2 fair value measurement. The estimated fair value of our private placement notes, senior notes and synthetic bonds was $1,706.1 million and $2,199.2 million as of December 31, 2021 and December 31, 2020, respectively.

Credit risk - By their nature, financial instruments involve risk, including credit risk, for non-performance by counterparties. Financial instruments that potentially subject us to credit risk primarily consist of trade receivables and derivative contracts. We manage the credit risk on financial instruments by transacting only with what management believes are financially secure counterparties, requiring credit approvals and credit limits and monitoring counterparties’ financial condition. Our maximum exposure to credit loss in the event of non-performance by the counterparty is limited to the amount drawn and outstanding on the financial instrument. Allowances for losses on trade receivables are established based on collectability assessments. We mitigate credit risk on derivative contracts by executing contracts only with counterparties that consent to a master netting agreement, which permits the net settlement of gross derivative assets against gross derivative liabilities.

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SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2021
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTSOn January 10, 2022 we announced the sale of 9.0 million Technip Energies shares, representing approximately 5% of Technip Energies’ issued and outstanding share capital, through a private sale transaction (the “January Sale”). The sale price of the shares in the January Sale was set at €13.15 per share, yielding total net proceeds of €118.4 million, or $135.1 million. Upon completion of the January Sale, we retain a direct stake of 12.9 million shares, representing 7.1% of Technip Energies’ issued and outstanding share capital. As of February 25, 2022, the value of our investment in Technip Energies was $155.3 million. On January 14, 2022 we paid £6 million, or $8.3 million for 750,000 ordinary shares in Orbital Marine Power (Orbital) to complete the investment in accordance with the Memorandum of Understanding between Technip Holding Benelux B.V. and Orbital. Orbital is a Scotland-based renewable energy company focused on the development and global application of its floating turbine technology. Upon completion of the investment, we will hold approximately 10.2% of the ordinary shares in Orbital

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Schedule II - Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2021

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

SCHEDULE OF VALUATION AND QUALIFYING ACCOUNTS

Schedule II—Valuation and Qualifying Accounts

(In millions)			Additions
Description	Balance at Beginning of  Period		Charged to  Costs and Expenses		Charged to Other Accounts (a)		Deductions and Adjustments (b)		Balance at End of Period
Year Ended December 31, 2019
Trade receivables allowance for doubtful accounts	$	58.7	$	27.7	$	3.5	$	(32.5)	$	57.4
Valuation allowance for deferred tax assets	$	496.6	$	184.9	$	—	$	47.6	$	729.1
Year Ended December 31, 2020
Trade receivables allowance for doubtful accounts (c)	$	57.4	$	38.0	$	1.3	$	(56.5)	$	40.2
Valuation allowance for deferred tax assets	$	729.1	$	104.4	$	(11.3)	$	(7.1)	$	815.1
Year Ended December 31, 2021
Trade receivables allowance for doubtful accounts	$	40.2	$	17.0	$	(10.8)	$	(8.3)	$	38.1
Valuation allowance for deferred tax assets	$	815.1	$	129.7	$	(12.0)	$	2.7	$	935.5

(a)"Additions charged to other accounts” includes translation adjustments.

(b)“Deductions and adjustments” includes write-offs, net of recoveries, increases in allowances offset by increases to deferred tax assets, and reductions in the allowances credited to expense.

(c)On January 1, 2020, we adopted ASU 2016-13, resulting in a $2.0 million increase to our trade receivables allowance for credit losses.

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BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policy)

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Basis of presentation

Basis of presentation - Our consolidated financial statements were prepared in U.S. dollars and in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and rules and regulations of the Securities and Exchange Commission (“SEC”) pertaining to annual financial information. The preparation of financial statements in conformity with these accounting principles requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Ultimate results could differ from our estimates.

Principles of consolidation

Principles of consolidation - The consolidated financial statements include the accounts of TechnipFMC and its majority-owned subsidiaries and affiliates. Intercompany accounts and transactions are eliminated in consolidation.

Use of estimates

Use of estimates - The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. Such estimates include, but are not limited to, estimates of total contract profit or loss on long-term construction-type contracts; estimated realizable value on excess and obsolete inventory; estimates related to pension accounting; estimates related to fair value for purposes of assessing goodwill, long-lived assets and intangible assets for impairment; estimates of fair value in business combinations and estimates related to income taxes.

Investments in the common stock of unconsolidated affiliates

Investments in the common stock of unconsolidated affiliates - The equity method of accounting is used to account for investments in unconsolidated affiliates where we have the ability to exert significant influence over the affiliates’ operating and financial policies. We measure equity investments not accounted for under the equity method at fair value and recognize any changes in fair value in net income. For certain construction joint ventures, we use the proportionate consolidation method, whereby our proportionate share of each entity’s assets, liabilities, revenues and expenses are included in the appropriate classifications in the consolidated financial statements. Intercompany balances and transactions have been eliminated in preparing the consolidated financial statements.

Investments in unconsolidated affiliates are assessed for impairment whenever events or changes in facts and circumstances indicate the carrying value of the investments may not be fully recoverable. When such a condition is subjectively determined to be other than temporary, the carrying value of the investment is written down to fair value. Management’s assessment as to whether any decline in value is other than temporary is based on our ability and intent to hold the investment and whether evidence indicating the carrying value of the investment is recoverable within a reasonable period of time outweighs evidence to the contrary. Management generally considers our investments in equity method investees to be strategic, long-term investments and completes its assessments for impairment with a long-term viewpoint.

Investments in which ownership is less than 20% or that do not represent significant investments are reported in other assets in the consolidated balance sheets. Where no active market exists and where no other valuation method can be used, these financial assets are maintained at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer.

Variable interest entity

We determine whether investments involve a variable interest entity (“VIE”) based on the characteristics of the subject entity. If the entity is determined to be a VIE, then management determines if we are the primary beneficiary of the entity and whether or not consolidation of the VIE is required. The primary beneficiary consolidating the VIE must normally have both (i) the power to direct the activities that most significantly affect the VIE’s economic performance and (ii) the obligation to absorb significant losses of or the right to receive significant benefits from the VIE. If we are deemed to be the primary beneficiary, the VIE is consolidated and the other party’s equity interest in the VIE is accounted for as a non-controlling interest. Our unconsolidated VIEs are accounted for using the equity method of accounting.

Business combinations

Business combinations - Business combinations are accounted for using the acquisition method of accounting. Under the acquisition method, assets acquired and liabilities assumed are recorded at their respective fair values as of the acquisition date. Determining the fair value of assets and liabilities involves significant judgment regarding methods and assumptions used to calculate estimated fair values. The purchase price is allocated to the acquired assets, assumed liabilities and identifiable intangible assets based on their estimated fair values. Any excess of the purchase price over the estimated fair values of the net assets acquired is recorded as goodwill. Transaction related costs are expensed as incurred.

Lessor, Leases

Leases - The majority of our leases are operating leases. We account for leases in accordance with Accounting Standard Codification (“ASC”)Topic 842, Leases, which we adopted on January 1, 2019 using the modified retrospective method. See Note 5 for further details.

Revenue recognition

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 ASC Topic 606, Revenue from Contracts with Customers. See Note 6 for further details.

Contract costs to obtain a contract - Our incremental direct costs of obtaining a contract are deferred and amortized over the period of contract performance or a longer period, generally the estimated life of the customer relationship, if renewals are expected and the renewal commission is not commensurate with the initial commission. We classify deferred commissions as current or non-current based on the timing of when we expect to recognize the expense. The current and non-current portions of deferred commissions are included in other current assets and other assets, respectively, in our consolidated balance sheets.

Amortization of deferred commissions is included in selling, general and administrative expenses in our consolidated statements of income.

Cash equivalents

Cash equivalents - Cash equivalents are highly-liquid, short-term investments with original maturities of three months or less from their date of purchase.

Trade receivables, net of allowances

Trade receivables, net of allowances - An allowance for doubtful accounts is provided on receivables equal to the estimated uncollectible amounts and is calculated based on loss rates from historical data. We develop loss-rate statistics on the basis of the amount written off over the life of the receivable and adjust these historical credit loss trends for forward-looking factors specific to the debtors and the economic environment to determine lifetime expected losses.

Inventories

Inventories - Inventories are stated at the lower of cost or net realizable value, except as it relates to inventory measured using the last-in, first-out (“LIFO”) method, for which the inventories are stated at the lower of cost or market. Inventory costs include those costs directly attributable to products, including all manufacturing overhead, but excluding costs to distribute. Cost for a significant portion of the U.S. domiciled inventories is determined on the LIFO method. The first-in, first-out (“FIFO”) or weighted average methods are used to determine the cost for the remaining inventories. Write-down of inventories is recorded when the net realizable value of inventories is lower than their net book value.

Property, plant and equipment

Property, plant and equipment - Property, plant, and equipment is recorded at cost. Depreciation is principally provided on the straight-line basis over the estimated useful lives of the assets (vessels - 10 to 30 years; buildings - 10 to 50 years; and machinery and equipment - 3 to 20 years). Gains and losses are realized upon the sale or retirement of assets and are recorded in other income (expense), net on our consolidated statements of income. Maintenance and repair costs are expensed as incurred. Expenditures that extend the useful lives of property, plant and equipment are capitalized and depreciated over the estimated new remaining life of the asset.

Impairment of property, plant, and equipment

Impairment of property, plant and equipment - Property, plant and equipment are reviewed for impairment whenever events or changes in circumstances indicate the carrying value of the long-lived asset may not be recoverable. The carrying value of an asset group 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 impairment loss is measured as the amount by which the carrying value of the long-lived asset exceeds its fair value.

Long-lived assets classified as held for sale are reported at the lower of carrying value or fair value less cost to sell.

Goodwill

Goodwill - Goodwill is not subject to amortization but is tested for impairment on an annual basis (or more frequently if impairment indicators arise) by comparing the estimated fair value of each reporting unit to its carrying value, including goodwill. A reporting unit is defined as an operating segment or one level below the operating segment. We have established October 31 as the date of our annual test for impairment of goodwill. Reporting units with goodwill are tested for impairment using a quantitative impairment test known as the income approach, which estimates fair value by discounting each reporting unit’s estimated future cash flows using a weighted-average cost of capital that reflects current market conditions and the risk profile of the reporting unit. To arrive at our future cash flows, we use estimates of economic and market assumptions, including growth rates in revenues, costs, estimates of future expected changes in operating margins, tax rates and cash expenditures. Future revenues are also adjusted to match changes in our business strategy. If the fair value of the reporting unit is less than its carrying amount as a result of this method, then an impairment loss is recorded.

A lower fair value estimate in the future for any of our reporting units could result in goodwill impairments. Factors that could trigger a lower fair value estimate include sustained price declines of the reporting unit’s products and services, cost increases, regulatory or political environment changes, changes in customer demand, and other changes in market conditions, which may affect certain market participant assumptions used in the discounted future cash flow model. As of December 31, 2021, we did not have any goodwill outstanding.

Intangible assets

Intangible assets - Our acquired intangible assets are generally amortized on a straight-line basis over their estimated useful lives, which generally range from 2 to 20 years. Our acquired intangible assets do not have indefinite lives. Intangible assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of the intangible asset may not be recoverable. The carrying amount of an intangible 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 intangible asset exceeds its fair value.

Capitalized software costs are recorded at cost. Capitalized software costs include purchases of software and internal and external costs incurred during the application development stage of software projects. These costs are amortized on a straight-line basis over the estimated useful lives. For internal use software, the useful lives range from 3 to 10 years. For Internet website costs, the estimated useful lives do not exceed 3 years.

Research and development expense is expensed as incurred. Research and development expense includes improvement of existing products and services, design and development of new products and services and test of new technologies.

Debt instruments

Debt instruments - Debt instruments include senior and private placement notes and other borrowings. Issuance fees and redemption premium on debt instruments are included in the cost of debt in the consolidated balance sheets, as an adjustment to the nominal amount of the debt. Loan origination costs for revolving credit facilities are recorded as an asset and amortized over the life of the underlying debt.

Fair value measurements

Fair value measurements - Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the reporting date. The fair value framework requires the categorization of assets and liabilities measured at fair value into three levels based upon the assumptions (inputs) used to price the assets or liabilities, with the exception of certain assets and liabilities measured using the net asset value practical expedient, which are not required to be leveled. Level 1 provides the most reliable measure of fair value, whereas Level 3 generally requires significant management judgment. The three levels are defined as follows:

•Level 1: Unadjusted quoted prices in active markets for identical assets and liabilities.

•Level 2: Observable inputs other than quoted prices included in Level 1. For example, quoted prices for similar assets or liabilities in active markets or quoted prices for identical assets or liabilities in inactive markets.

•Level 3: Unobservable inputs reflecting management’s own assumptions about the assumptions market participants would use in pricing the asset or liability.

Income taxes

Income taxes - Current income taxes are provided on income reported for financial statement purposes, adjusted for transactions that do not enter into the computation of income taxes payable in the same year. Deferred tax assets and liabilities are measured using enacted tax rates for the expected future tax consequences of temporary differences between the carrying amounts and the tax basis of assets and liabilities. A valuation allowance is established whenever management believes that it is more likely than not that deferred tax assets may not be realizable.

Income taxes are not provided on our equity in undistributed earnings of foreign subsidiaries or affiliates to the extent we have determined that the earnings are indefinitely reinvested. Income taxes are provided on such earnings in the period in which we can no longer support that such earnings are indefinitely reinvested.

Tax benefits related to uncertain tax positions are recognized when it is more likely than not, based on the technical merits, that the position will be sustained upon examination.

We classify interest expense and penalties recognized on underpayments of income taxes as income tax expense.

Stock-based employee compensation

Share-based compensation - The measurement of share-based compensation expense on restricted share awards and performance share awards is based on the market price at the grant date and the number of shares awarded. We use Black-Scholes options pricing model to measure the fair value of stock options granted on or after January 1, 2017. The stock-based compensation expense for each award is recognized ratably over the applicable service period or the period beginning at the start of the service period and ending when an employee becomes eligible for retirement, after taking into account estimated forfeitures.

Earnings per common share (“EPS”)

Earnings per ordinary share (“EPS”) - Basic EPS is computed using the weighted-average number of ordinary shares outstanding during the year. We use the treasury stock method to compute diluted EPS which gives effect to the potential dilution of earnings that could have occurred if additional shares were issued for awards granted under our incentive compensation and stock plan. The treasury stock method assumes proceeds that would be obtained upon exercise of awards granted under our incentive compensation and stock plan are used to purchase outstanding ordinary shares at the average market price during the period.

Foreign currency

Foreign currency - Financial statements of operations for which the U.S. dollar is not the functional currency, and which are located in non-highly inflationary countries, are translated into U.S. dollars prior to consolidation. Assets and liabilities are translated at the exchange rate in effect at the balance sheet date, while income statement accounts are translated at the average exchange rate for each period. For these operations, translation gains and losses are recorded as a component of accumulated other comprehensive income (loss) in stockholders’ equity until the foreign entity is sold or liquidated. For operations in highly inflationary countries and where the local currency is not the functional currency, inventories, property, plant and equipment, and other non-current assets are converted to U.S. dollars at historical exchange rates, and all gains or losses from conversion are included in net income. Foreign currency effects on cash, cash equivalents and debt in highly inflationary economies are included in interest income or expense.

For certain committed and anticipated future cash flows and recognized assets and liabilities which are denominated in a foreign currency, we may choose to manage our risk against changes in the exchange rates, when compared against the functional currency, through the economic netting of exposures instead of derivative instruments. Cash outflows or liabilities in a foreign currency are matched against cash inflows or assets in the same currency, such that movements in exchange rates will result in offsetting gains or losses. Due to the inherent unpredictability of the timing of cash flows, gains and losses in the current period may be economically offset by gains and losses in a future period. All gains and losses are recorded in our consolidated statements of income in the period in which they are incurred. Gains and losses from the remeasurement of assets and liabilities are recognized in other income (expense), net.

Derivative instruments

Derivative instruments - Derivatives are recognized on the consolidated balance sheets at fair value, with classification as current or non-current based upon the maturity of the derivative instrument. Changes in the fair value of derivative instruments are recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on the type of hedging transaction and whether a derivative is designated as, and is effective as, a hedge. Each instrument is accounted for individually and assets and liabilities are not offset.

Hedge accounting is only applied when the derivative is deemed to be highly effective at offsetting changes in anticipated cash flows of the hedged item or transaction. Changes in fair value of derivatives that are designated as cash flow hedges are deferred in accumulated other comprehensive income (loss) until the underlying transactions are recognized in earnings. At such time, related deferred hedging gains or losses are recorded in earnings on the same line as the hedged item. Effectiveness is assessed at the inception of the hedge and on a quarterly basis. Effectiveness of forward contract cash flow hedges are assessed based solely on changes in fair value attributable to the change in the spot rate. The change in the fair value of the contract related to the change in forward rates is excluded from the assessment of hedge effectiveness. Changes in this excluded component of the derivative instrument, along with any ineffectiveness identified, are recorded in earnings as incurred. We document our risk management strategy and hedge effectiveness at the inception of, and during the term of, each hedge.

We also use forward contracts to hedge foreign currency assets and liabilities, for which we do not apply hedge accounting. The changes in fair value of these contracts are recognized in other income (expense), net on our consolidated statements of income, as they occur and offset gains or losses on the remeasurement of the related asset or liability.

Reclassification

Reclassifications - Certain prior-year amounts have been reclassified to conform to the current year’s presentation.

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DISCONTINUED OPERATIONS (Tables)

12 Months Ended

Dec. 31, 2021

Discontinued Operations and Disposal Groups [Abstract]

Income, Assets and liabilities of discontinued operations

The following table summarizes the components of income from discontinued operations, net of tax:

	Year Ended
(In millions)	2021		2020		2019
Revenue	$	906.0	$	6,520.0	$	6,458.9
Costs and expenses	(932.0)		(5,899.0)		(5,627.6)
Other income and (expense), net	(18.6)		(206.8)		(396.0)
Income (loss) from discontinued operations before income taxes	$	(44.6)	$	414.2	$	435.3
Income (loss) from discontinued operations, net of income taxes	$	(72.6)	$	280.2	$	238.0

Supplemental information:

	Year Ended
(In millions)	2021		2020		2019
Capital expenditures	$	5.1	$	35.7	$	41.7
Depreciation and amortization expense	17.1		35.1		41.9
Research and development expense	4.4		44.5		13.4

Assets and liabilities of discontinued operations are summarized below:

	December 31,
(In millions)	2020
Assets
Cash and cash equivalents	$	3,538.6
Trade receivables, net of allowances	1,302.1
Contract assets	380.8
Other current assets	503.6
Total current assets of discontinued operations	5,725.1
Property, plant and equipment, net of accumulated depreciation	105.6
Goodwill	2,512.5
Other assets	665.4
Total non-current assets of discontinued operations	3,283.5
Total assets of discontinued operations	$	9,008.6
Liabilities
Accounts payable, trade	$	1,539.5
Contract liabilities	3,689.3
Other current liabilities	867.7
Total current liabilities of discontinued operations	6,096.5
Long-term debt, less current portion	482.2
Operating lease liabilities	248.2
Other liabilities	350.9
Total non-current liabilities of discontinued operations	1,081.3
Total liabilities of discontinued operations	$	7,177.8

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LEASES (Tables)

12 Months Ended

Dec. 31, 2021

Leases [Abstract]

Lease, cost

The following table is a summary of the Company’s components of net lease cost for the years ended December 31, 2021 and 2020:

	Year Ended December 31,
(In millions)	2021		2020
Operating lease costs including variable costs	$	175.9	$	195.6
Short-term lease costs	5.2		11.0
Less: sublease income	2.4		2.8
Net lease cost	$	178.7	$	203.8

Schedule of supplemental cash flow information related to leases

Supplemental cash flow information related to leases for the years ended December 31, 2021 and 2020 is as follows:

	Year Ended December 31,
(In millions)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	176.5	$	206.5
Right-of-use assets obtained in exchange for lease liabilities
Operating leases	$	114.9	$	421.3
Finance leases	$	24.6	$	26.9

Schedule of supplemental balance sheet information related to leases

Supplemental balance sheet information related to leases as of December 31, 2021 and 2020 is as follows:

	December 31,
(In millions, except lease term and discount rate)	2021		2020
Weighted average remaining lease term
Operating leases	13.3 years		13.6 years
Finance leases	1.1 years		0.6 years
Weighted average discount rate
Operating leases	5.86	%	5.35	%
Finance leases	1.2	%	2.1	%

Schedule of maturities of operating and finance leases liabilities

Maturities of operating and finance lease liabilities as of December 31, 2021 are as follows:

(In millions)	Maturity of Operating Lease Liabilities		Maturity of Finance Lease Liabilities
2022	$	150.2	$	1.0
2023	108.3		103.0
2024	102.3		—
2025	83.1		—
2026	74.7		—
Thereafter	675.9		—
Total lease payments	1,194.5		104.0
Less: Imputed interest (a)	421.5		52.2
Total lease liabilities (b)	$	773.0	$	51.8

Note: For leases that commenced prior to 2019, minimum lease payments exclude payments to landlords for real estate taxes and common area maintenance.

(a)Calculated using the interest rate for each lease.

(b)Includes the current portion of $126.9 million.

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REVENUE (Tables)

12 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

Schedule of disaggregation of revenue

The following table presents total revenue by geography for each reportable segment for the years ended December 31, 2021, 2020 and 2019:

	Reportable Segments
	Year Ended December 31,
	2021				2020				2019
(In millions)	Subsea		Surface Technologies		Subsea		Surface Technologies		Subsea		Surface Technologies
Europe, Central Asia	$	1,404.4	$	191.5	$	1,664.1	$	192.7	1,690.2		160.1
North America	753.6		372.7		899.7		367.9		660.8		751.9
Latin America	1,157.7		86.7		1,042.4		76.6		1,139.5		108.6
Asia Pacific	927.4		104.2		772.1		131.0		673.3		195.4
Africa	1,057.3		44.0		908.6		46.9		836.4		62.7
Middle East	28.7		275.3		184.5		244.1		419.3		252.0
Total revenue	$	5,329.1	$	1,074.4	$	5,471.4	$	1,059.2	$	5,419.5	$	1,530.7

The following table represents revenue by contract type for each reportable segment for the years ended December 31, 2021, 2020 and 2019:

	Reportable Segments
	Year Ended December 31,
	2021				2020				2019
(In millions)	Subsea		Surface Technologies		Subsea		Surface Technologies		Subsea		Surface Technologies
Services	$	3,282.0	$	158.7	$	3,121.1	$	150.2	$	3,141.0	$	271.0
Products	2,002.5		801.9		2,295.4		821.9		2,162.5		1,109.2
Lease(a)	44.6		113.8		54.9		87.1		116.0		150.5
Total revenue	$	5,329.1	$	1,074.4	$	5,471.4	$	1,059.2	$	5,419.5	$	1,530.7

(a)Represents revenue not subject to ASC Topic 606.

Schedule of contract balances

The following table provides information about net contract assets (liabilities) as of December 31, 2021 and 2020:

	December 31,
(In millions)	2021		2020		$ change		% change
Contract assets	$	966.0	$	886.8	$	79.2	8.9
Contract (liabilities)	(1,012.9)		(1,046.8)		33.9		3.2
Net contract (liabilities)	$	(46.9)	$	(160.0)	$	113.1	70.7

Schedule of remaining revenue performance obligations

The following table details the order backlog for each business segment as of December 31, 2021:

(In millions)	2022		2023		Thereafter
Subsea	$	3,372.8	$	2,227.5	$	932.7
Surface Technologies	376.8		95.2		652.7
Total remaining unsatisfied performance obligations	$	3,749.6	$	2,322.7	$	1,585.4

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BUSINESS SEGMENTS (Tables)

12 Months Ended

Dec. 31, 2021

Segment Reporting, Measurement Disclosures [Abstract]

Segment revenue, segment operating profit and corporate items

Segment revenue and segment operating profit (loss) were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Segment revenue
Subsea	$	5,329.1	$	5,471.4	$	5,419.5
Surface Technologies	1,074.4		1,059.2		1,530.7
Total revenue	$	6,403.5	$	6,530.6	$	6,950.2
Segment operating profit (loss)
Subsea	$	141.4	$	(2,815.5)	$	(1,442.7)
Surface Technologies	42.0		(429.3)		(662.7)
Total segment operating profit (loss)	183.4		(3,244.8)		(2,105.4)
Corporate items
Merger transaction and integration costs	—		—		(14.2)
Legal expenses	—		—		(33.0)
Other corporate expenses (a)	(118.1)		(131.9)		(191.7)
Net interest expense	(143.3)		(81.8)		(91.3)
Loss on early extinguishment of debt	(61.9)		—		—
Income from investment in Technip Energies	322.2		—		—
Foreign exchange gains (losses)	15.8		(40.2)		(135.5)
Total corporate items	14.7		(253.9)		(465.7)
Income (loss) before income taxes(b)	$	198.1	$	(3,498.7)	$	(2,571.1)

(a)Other corporate expenses primarily include corporate staff expenses, share-based compensation expenses, certain long-lived assets impairments, restructuring and other expenses and other employee benefits.

(b)Includes amounts attributable to non-controlling interests.

Segment operating capital employed and segment assets

Segment assets were as follows:

	December 31,
(In millions)	2021		2020
Segment assets
Subsea	$	6,532.5	$	6,796.6
Surface Technologies	1,420.0		1,758.3
Total segment assets	7,952.5		8,554.9
Corporate (a)	2,067.6		2,129.1
Assets from discontinued operations	—		9,008.6
Total assets	$	10,020.1	$	19,692.6

(a)Corporate includes cash, investment in Technip Energies, LIFO adjustments, deferred income tax balances, property, plant and equipment and intercompany eliminations not associated with a specific segment, pension assets and the fair value of derivative financial instruments.

Reconciliation of other significant reconciling items from segments to consolidated

Other business segment information is as follows:

	Capital Expenditures						Depreciation and Amortization						Research and Development Expense
	Year Ended December 31,						Year Ended December 31,						Year Ended December 31,
(In millions)	2021		2020		2019		2021		2020		2019		2021		2020		2019
Subsea	$	149.4	$	213.6	$	287.5	$	317.2	$	324.9	$	345.0	$	73.2	$	66.5	$	134.2
Surface Technologies	36.8		38.5		96.0		64.8		70.1		107.1		5.2		8.8		15.3
Corporate	5.5		4.0		29.2		3.4		17.1		15.6		—		—		—
Total	$	191.7	$	256.1	$	412.7	$	385.4	$	412.1	$	467.7	$	78.4	$	75.3	$	149.5

Geographic segment information

Revenue by geography was identified based on the country where our products and services were delivered, and is as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Revenue
United States	$	1,137.2	$	1,320.1	$	1,458.6
Norway	979.9		1,216.6		1,352.6
Brazil	767.8		600.6		1,086.2
United Kingdom	542.5		489.0		535.8
Mozambique	472.0		320.4		80.0
Australia	419.8		122.5		133.4
Angola	406.3		482.8		498.1
Guyana	314.7		330.1		7.2
Indonesia	224.9		280.0		262.6
Singapore	216.3		219.9		190.5
Malaysia	206.9		190.0		197.2
India	109.8		26.8		—
Trinidad	78.1		106.3		42.8
Israel	26.8		179.3		319.6
All other countries	500.5		646.2		785.6
Total revenue	$	6,403.5	$	6,530.6	$	6,950.2

Long-lived assets by geography represent property, plant and equipment, net, and are as follows:

	December 31,
(In millions)	2021		2020
Long-lived assets
United Kingdom	$	882.9	$	928.8
Netherlands	414.7		417.6
United States	383.4		439.1
Norway	271.9		312.1
Brazil	265.5		259.9
All other countries	378.8		398.7
Total long-lived assets	$	2,597.2	$	2,756.2

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EARNINGS (LOSS) PER SHARE (Tables)

12 Months Ended

Dec. 31, 2021

Earnings Per Share [Abstract]

Reconciliation of the number of shares used for the basic and diluted earnings per share

A reconciliation of the number of shares used for the basic and diluted earnings (loss) per share calculation was as follows:

	Year Ended December 31,
(In millions, except per share data)	2021		2020		2019
Income (loss) from continuing operations attributable to TechnipFMC plc	$	87.8	$	(3,552.6)	$	(2,645.5)
Income (loss) from discontinued operations attributable to TechnipFMC plc	(74.5)		265.0		230.3
Net income (loss) attributable to TechnipFMC plc	$	13.3	$	(3,287.6)	$	(2,415.2)
Weighted average number of shares outstanding	450.5		448.7		448.0
Dilutive effect of restricted stock units	4.1		—		—
Total shares and dilutive securities	454.6		448.7		448.0
Basic and diluted earnings (loss) per share attributable to TechnipFMC plc:
Earnings (loss) per share from continuing operations attributable to TechnipFMC plc
Basic	$	0.19	$	(7.92)	$	(5.91)
Diluted	$	0.19	$	(7.92)	$	(5.91)
Earnings (loss) per share from discontinued operations attributable to TechnipFMC plc
Basic	$	(0.17)	$	0.59	$	0.51
Diluted	$	(0.16)	$	0.59	$	0.51
Total earnings (loss) per share attributable to TechnipFMC plc
Basic and diluted	$	0.03	$	(7.33)	$	(5.39)

Schedule of antidilutive securities excluded from computation of earnings per share

Weighted average shares of the following share-based compensation awards were excluded from the calculation of diluted weighted average number of shares where the assumed proceeds exceed the average market price from the calculation of diluted weighted average number of shares, because their effect would be anti-dilutive:

	Year Ended December 31,
(millions of shares)	2021	2020	2019
Share option awards	1.7	4.6	4.0
Restricted share units	0.1	1.8	—
Performance shares	—	1.9	1.6
Total	1.8	8.3	5.6

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RECEIVABLES (Tables)

12 Months Ended

Dec. 31, 2021

Receivables [Abstract]

Financing receivable credit quality indicators

The table below summarizes the amortized cost basis of financial assets by years of origination and credit quality. The key credit quality indicator is updated as of December 31, 2021.

(In millions)	Year of origination	Balance as of December 31, 2021		Balance as of December 31, 2020
Loans receivables, security deposits and other
Moody’s rating Ba2	2019	$	50.9	$	107.6
Debt securities at amortized cost
Moody’s rating B3	2019	24.0		23.7
Total financial assets		$	74.9	$	131.3

Financing receivable, allowance for credit loss

The table below shows the roll-forward of allowance for credit losses as of December 31, 2021 and 2020, respectively.

	Balance as of December 31, 2021
(In millions)	Trade receivables		Contract assets		Loans receivable		Security deposit and other		Held-to-maturity debt securities
Allowance for credit losses at December 31, 2020	$	40.2	$	2.4	$	7.5	$	0.4	$	0.5
Current period provision (release) for expected credit losses	3.5		(1.3)		(7.2)		(0.1)		2.2
Recoveries	(5.6)		—		—		—		—
Allowance for credit losses at December 31, 2021	$	38.1	$	1.1	$	0.3	$	0.3	$	2.7

	Balance as of December 31, 2020
(In millions)	Trade receivables		Contract assets		Loans receivable		Security deposit and other		Held-to-maturity debt securities
Allowance for credit losses at December 31, 2019	$	59.4	$	4.5	$	9.5	$	0.7	$	1.1
Current period provision for expected credit losses	27.2		0.5		(0.2)		(0.3)		(0.6)
Write-offs charged against the allowance	(43.0)		—		—		—		—
Recoveries	(3.4)		(2.6)		(1.8)		—		—
Allowance for credit losses at December 31, 2020	$	40.2	$	2.4	$	7.5	$	0.4	$	0.5

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INVENTORIES (Tables)

12 Months Ended

Dec. 31, 2021

Inventory, Finished Goods and Work in Process, Gross [Abstract]

Schedule of components of inventories

Inventories consisted of the following:

	December 31,
(In millions)	2021		2020
Raw materials	$	250.1	$	270.3
Work in process	178.7		242.7
Finished goods	603.1		739.8
Inventories, net	$	1,031.9	$	1,252.8

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OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES (Tables)

12 Months Ended

Dec. 31, 2021

Other Current Assets & Other Current Liabilities [Abstract]

Schedule of other current assets

Other current assets consisted of the following:

	December 31,
(In millions)	2021		2020
Value - added tax receivables	$	222.4	$	256.9
Sundry receivables	106.1		138.4
Other taxes receivables	70.6		73.8
Prepaid expenses	50.7		78.1
Current financial assets at amortized cost	21.9		40.6
Held-to-maturity investments	8.8		24.2
Assets held for sale	5.0		47.3
Other	26.8		24.1
Total other current assets	$	512.3	$	683.4

Other current liabilities

Other current liabilities consisted of the following:

	December 31,
(In millions)	2021		2020
Warranty accruals and project contingencies	$	119.5	$	168.8
Legal provisions	121.7		127.6
Value - added tax and other taxes payable	71.0		109.6
Compensation accrual	85.7		54.3
Social security liability	70.4		67.9
Provisions	23.6		53.0
Current portion of accrued pension and other post-retirement benefits	5.2		6.9
Other accrued liabilities	163.3		230.2
Total other current liabilities	$	660.4	$	818.3

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WARRANTY OBLIGATIONS (Tables)

12 Months Ended

Dec. 31, 2021

Product Warranties Disclosures [Abstract]

Warranty cost and accrual information

A reconciliation of warranty obligations for the years ended December 31, 2021 and 2020 is as follows:

	Year Ended December 31,
(In millions)	2021		2020
Balance at beginning of period	$	109.6	$	121.7
Warranty expenses	54.0		52.0
Adjustment to existing accruals	(56.5)		(48.2)
Claims paid	(20.9)		(15.9)
Balance at end of period	$	86.2	$	109.6

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INVESTMENTS (Tables)

12 Months Ended

Dec. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Equity method investments (percentage owned and carrying value)

Our equity investments were as follows as of December 31, 2021 and 2020:

			December 31,
			2021		2020
(In millions, except %)	Percentage Owned		Carrying Value
Dofcon Brasil AS	50.0	%	276.9		234.7
Magma Global Limited	—	%	—		51.4
Serimax Holdings SAS	20.0	%	15.0		18.8
Other			0.5		0.6
Investments in equity affiliates			$	292.4	$	305.5

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RELATED PARTY TRANSACTIONS (Tables)

12 Months Ended

Dec. 31, 2021

Related Party Transactions [Abstract]

Related Party Transactions Receivables

Trade receivables consisted of trade receivables due from the following related parties:

	December 31,
(In millions)	2021		2020
Equinor ASA	$	—	$	24.1
Dofcon Navegacao	22.7		4.2
Techdof Brasil AS	4.5		8.0
Others	2.5		1.7
Total trade receivables	$	29.7	$	38.0

Related Party Transactions Payables

Payables consisted of payables due to the following related parties:

	December 31,
(In millions)	2021		2020
Crescent Energy	$	2.7	$	—
Dofcon Navegacao	$	—	$	1.5
Arkema S.A.	0.9		0.5
Others	1.9		2.6
Total trade payables	$	5.5	$	4.6

Related Party Transactions Revenue and Expenses, Details

Revenue consisted of amount from following related parties:

	Year Ended December 31,
(In millions)	2021		2020		2019
Equinor ASA	$	—	$	119.6	$	—
Anadarko Petroleum Company	—		—		67.1
TOP CV	—		—		11.9
Dofcon Navegacao	9.9		3.4		8.4
Techdof Brasil AS	15.8		11.2		8.3
Others	14.0		18.5		14.4
Total revenue	$	39.7	$	152.7	$	110.1

A member of our Board of Directors (the “Director”) served on the Board of Directors of Anadarko Petroleum Company (“Anadarko”) until August 2019. In August 2019, Anadarko was acquired by Occidental Petroleum Corporation (“Occidental”). As a result, the Director no longer serves as a member of the Board of Directors of Anadarko. The Director is not an officer or director of Occidental.

TOP CV was previously an equity method affiliate that became a fully consolidated subsidiary on December 30, 2019. See Note 3 for further details.

Expenses consisted of amounts to following related parties:

	Year Ended December 31,
(In millions)	2021		2020		2019
Arkema S.A.	$	3.8	$	1.5	$	3.8
Serimax Holdings SAS	7.6		0.4		17.7
Magma Global Limited	8.8		14.0		7.3
Jumbo Shipping	—		16.0		4.5
Dofcon Navegacao	26.7		24.0		1.8
Altus Intervention	—		3.6		1.8
Others	18.5		17.6		17.8
Total expenses	$	65.4	$	77.1	$	54.7

Serimax Holdings SAS is an equity method affiliate. Members of our Board of Directors served on the Board of Directors for Jumbo Shipping. Magma Global Limited was an equity method affiliate through September 30, 2021. In October 2021, we purchased the remaining ownership interest in Magma Global, see Note 3 for further details.

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PROPERTY, PLANT AND EQUIPMENT (Tables)

12 Months Ended

Dec. 31, 2021

Property, Plant and Equipment [Abstract]

Schedule of property, plant and equipment

Property, plant and equipment consisted of the following: 

	December 31,
(In millions)	2021		2020
Land and land improvements	$	79.4	$	80.0
Buildings	471.6		514.6
Vessels	1,979.0		1,968.1
Machinery and equipment	1,849.0		1,871.8
Office fixtures and furniture	121.9		125.4
Construction in process	110.5		147.3
Other	189.8		203.2
	4,801.2		4,910.4
Accumulated depreciation	(2,204.0)		(2,154.2)
Property, plant and equipment, net	$	2,597.2	$	2,756.2

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GOODWILL AND INTANGIBLE ASSETS (Tables)

12 Months Ended

Dec. 31, 2021

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of goodwill

The carrying amount of goodwill by reporting segment was as follows:

(In millions)	Subsea		Surface Technologies		Total
December 31, 2019	$	2,792.8	$	335.7	$	3,128.5
Impairments	(2,747.5)		(335.9)		(3,083.4)
Translation	(45.3)		0.2		(45.1)
December 31, 2020	$	—	$	—	$	—

Schedule of finite-lived intangible assets

Intangible assets - The components of intangible assets were as follows:

	December 31,
	2021				2020
(In millions)	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
Acquired technology	$	247.0	$	122.4	$	247.1	$	98.1
Customer relationships	285.4		142.9		285.3		114.4
Licenses, patents and trademarks	694.6		220.7		690.3		189.3
Software	108.2		84.8		111.3		81.1
Other	54.0		4.7		10.4		10.2
Total intangible assets	$	1,389.2	$	575.5	$	1,344.4	$	493.1

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DEBT (Tables)

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Schedule of long-term debt

Long-term debt consisted of the following:

	December 31,
(In millions)	2021		2020
Commercial paper	$	—	$	1,043.7
Synthetic bonds due 2021	—		551.2
3.45% Senior Notes due 2022	—		500.0
3.40% 2012 Private placement notes due 2022	169.9		184.0
3.15% 2013 Private placement notes due 2023	288.8		312.9
5.75% 2020 Private placement notes due 2025	226.5		245.4
6.50% Senior notes due 2026	633.1		—
4.00% 2012 Private placement notes due 2027	84.9		92.0
4.00% 2012 Private placement notes due 2032	113.3		122.7
3.75% 2013 Private placement notes due 2033	113.3		122.7
Bank borrowings and other	397.4		298.4
Unamortized debt issuance costs and discounts	(22.3)		(12.8)
Total debt	2,004.9		3,460.2
Less: current borrowings	277.6		624.7
Long-term debt	$	1,727.3	$	2,835.5

Schedule of maturities of long-term debt

Debt maturities as of December 31, 2021, are as follows:

	Payments Due by Period
(In millions)	Total payments		Less than 1 year		1-3 years		3-5 years		After 5 years
Total debt	$	2,004.9	$	277.6	$	402.1	$	942.9	$	382.3

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STOCKHOLDERS’ EQUITY (Tables)

12 Months Ended

Dec. 31, 2021

Stockholders' Equity Note [Abstract]

Schedule of capital stock activity

The following is a summary of our capital stock activity for the years ended December 31, 2021, 2020 and 2019:

(Number of shares in millions)	Ordinary Shares Issued	Ordinary Shares Held in  Employee Benefit Trust	Treasury Stock
December 31, 2018	450.5	0.1	—
Stock awards	0.6	—	—
Treasury stock purchases	—	—	4.0
Treasury stock cancellation	(4.0)	—	(4.0)
Net stock purchased for employee benefit trust	—	(0.1)	—
December 31, 2019	447.1	—	—
Stock awards	2.4	—	—
December 31, 2020	449.5	—	—
Stock awards	1.2	—	—
December 31, 2021	450.7	—	—

Schedule of accumulated other comprehensive loss

Accumulated other comprehensive income (loss) - Accumulated other comprehensive income (loss) consisted of the following:

(In millions)	Foreign Currency Translation		Hedging		Defined Pension  and Other Post-Retirement Benefits		Accumulated Other Comprehensive  Loss Attributable to TechnipFMC plc		Accumulated Other Comprehensive  Loss Attributable to Non-Controlling Interest
December 31, 2019	$	(1,230.1)	$	(5.8)	$	(171.6)	$	(1,407.5)	$	(4.7)
Other comprehensive income (loss) before reclassifications, net of tax	(171.1)		26.8		(92.9)		(237.2)		0.6
Reclassification adjustment for net (gains) losses included in net income, net of tax	—		13.0		9.2		22.2		—
Other comprehensive income (loss), net of tax	(171.1)		39.8		(83.7)		(215.0)		0.6
December 31, 2020	$	(1,401.2)	$	34.0	$	(255.3)	$	(1,622.5)	$	(4.1)
Other comprehensive income (loss) before reclassifications, net of tax	29.2		(19.8)		70.8		80.2		(1.6)
Reclassification adjustment for net (gains) losses included in net income, net of tax	—		(11.8)		18.0		6.2		—
Other comprehensive income (loss), net of tax	29.2		(31.6)		88.8		86.4		(1.6)
Spin-off of Technip Energies	213.6		(19.7)		37.2		231.1		—
December 31, 2021	$	(1,158.4)	$	(17.3)	$	(129.3)	$	(1,305.0)	$	(5.7)

Reclassification out of accumulated other comprehensive income

Reclassifications out of accumulated other comprehensive income (loss) - Reclassifications out of accumulated other comprehensive income (loss) consisted of the following:

	Year Ended December 31,
(In millions)	2021		2020		2019
Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified out of Accumulated Other Comprehensive Loss						Affected Line Item in the Consolidated Statement of Income
Gains on foreign currency translation	$	—	$	—	$	12.0	Other income (expense), net
Gains (losses) on hedging instruments
Foreign exchange contracts	$	(29.7)	$	(83.7)	$	(26.6)	Revenue
	10.7		68.5		12.0		Costs of sales
	0.2		(0.4)		—		Selling, general and administrative expense
	32.9		(4.4)		(9.1)		Other Income (expense), net
	14.1		(20.0)		(23.7)		Income (loss) before income taxes
	2.3		(7.0)		(5.5)		Provision (benefit) for income taxes
	$	11.8	$	(13.0)	$	(18.2)	Net income (loss)
Pension and other post-retirement benefits
Settlements and curtailments	$	(3.3)	$	(2.2)	$	(0.3)	(a)
Amortization of actuarial gain (loss)	(18.2)		(9.0)		(2.5)		(a)
Amortization of prior service credit (cost)	(0.5)		(1.2)		(1.0)		(a)
	(22.0)		(12.4)		(3.8)		Income (loss) before income taxes
	(4.0)		(3.2)		(0.8)		Provision (benefit) for income taxes
	$	(18.0)	$	(9.2)	$	(3.0)	Net income (loss)

(a)    These accumulated other comprehensive income components are included in the computation of net periodic pension cost (See Note 23 for further details).

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SHARE-BASED COMPENSATION (Tables)

12 Months Ended

Dec. 31, 2021

Share-based Payment Arrangement [Abstract]

Schedule of compensation expense under stock based compensation plan

The compensation expense under the Plan for continuing operations was as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Share-based compensation expense	$	26.8	$	38.3	$	44.4
Income tax benefits related to share-based compensation expense	7.2		10.3		12.0

Schedule of unrecognized compensation cost, nonvested awards

As of December 31, 2021, the portion of share-based compensation expense related to outstanding awards to be recognized in future periods is as follows:

	December 31, 2021
Share-based compensation expense not yet recognized (in millions)	$	51.6
Weighted-average recognition period (in years)	1.4

Summary of changes in nonvested stock awards

A summary of the non-vested restricted share units’ activity is as follows:

(Shares in thousands)	Shares	Weighted-Average  Grant Date  Fair Value
Non-vested as of December 31, 2020	6,121.9	$	18.43
Granted	2,893.0	$	7.97
Vested	(667.1)	$	37.57
Cancelled/forfeited	(882.6)	$	13.75
Adjustment due to the Spin-off	2,124.3	$	12.37
Non-vested as of December 31, 2021	9,589.5	$	11.35

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Method Used

The weighted-average fair value and the assumptions used to measure the fair value of performance share units subject to performance-adjusted vesting conditions in the Monte Carlo simulation model were as follows:

	Year Ended December 31,
	2021		2020		2019
Weighted-average fair value (a)	$11.50		$10.02		$29.04
Expected volatility (b)	62.70	%	38.30	%	34.00	%
Risk-free interest rate (c)	0.35	%	0.40	%	2.42	%
Expected performance period in years (d)	2.9		3.0		3.0

(a) The weighted-average fair value was based on performance share units granted during the period.

(b) Expected volatility is based on normalized historical volatility of our shares over a preceding period commensurate with the expected term of the performance share units.

(c) The risk-free rate for the expected term of the performance share units is based on the U.S. Treasury yield curve in effect at the time of grant.

(d) For awards subject to service-based vesting, due to the lack of historical exercise and post-vesting termination patterns of the post-Merger employee base, the expected term was estimated using a simplified method for all awards granted in 2021, 2020 and 2019.

Schedule of Nonvested Performance-based Units Activity

A summary of the non-vested performance share units’ activity is as follows:

(Shares in thousands)	Shares	Weighted-Average  Grant Date  Fair Value
Non-vested as of December 31, 2020	4,840.7	$	17.55
Granted	2,426.2	$	11.50
Vested	(111.3)	$	30.42
Cancelled/forfeited	(1,723.2)	$	16.03
Adjustment due to the Spin-off	(3,122.8)	$	12.37
Non-vested as of December 31, 2021	2,309.6	$	13.26

Schedule of weighted average assumptions

The weighted-average fair value and the assumptions used to measure fair value of 2019 grant were as follows:

	December 31, 2019
Weighted-average fair value (a)	$	5.64
Expected volatility (b)	32.5		%
Risk-free interest rate (c)	2.5		%
Expected dividend yield	2.6		%
Expected term in years (d)	6.5

(a)The weighted-average fair value was based on stock options granted during the period.

(b)Expected volatility is based on normalized historical volatility of our shares over a preceding period commensurate with the expected term of the option.

(c)The risk-free rate for the expected term of the option is based on the U.S. Treasury yield curve in effect at the time of grant.

(d)For awards subject to service-based vesting, due to the lack of historical exercise and post-vesting termination patterns of the post-Merger employee base, the expected term was estimated using a simplified method for all awards granted in 2019.

Summary of option transactions

The following is a summary of share option transactions during the year ended December 31, 2021:

	Number of Shares	Weighted average exercise price		Weighted average remaining life (in years)
Balance as of December 31, 2020	4,598.4	$	29.77	4.2
Granted	—	$	—
Exercised	—	$	—
Cancelled	(532.0)	$	24.10
Adjustment due to the Spin-off	(2,490.3)	$	—
Balance as of December 31, 2021	1,576.1	$	20.17	6.3
Exercisable as of December 31, 2021	939.3	$	22.99	5.6

Summary of additional information concerning outstanding and exercisable options

The following summarizes significant ranges of outstanding and exercisable share options as of December 31, 2021:

	Options Outstanding				Options Exercisable
Exercise Price Range	Number of options (in thousands)	Weighted average remaining life (in years)	Weighted average exercise price		Number of options (in thousands)	Weighted average exercise price
$16.00-$19.00	636.7	7.2	$	16.46	—	$	—
$20.00-$24.00	721.2	5.6	$	22.28	721.2	$	22.28
$25.00-$26.00	218.2	5.6	$	25.32	218.1	$	25.32
Total	1,576.1	6.3	$	20.17	939.3	$	22.99

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IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES (Tables)

12 Months Ended

Dec. 31, 2021

Restructuring and Related Activities [Abstract]

Impairment, restructuring and other expenses

Impairment, restructuring and other expenses were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Subsea	$	53.5	$	2,957.5	$	1,748.4
Surface Technologies	7.6		440.2		704.2
Corporate and other	5.6		4.3		4.1
Total impairment, restructuring and other expenses	$	66.7	$	3,402.0	$	2,456.7

Schedule of Goodwill and Long-Lived Assets Impairment

Goodwill and long-lived assets impairments were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
Subsea	$	44.2	$	2,854.5	$	1,794.8
Surface Technologies	1.9		419.3		685.5
Corporate and other	3.0		—		—
Total impairments	$	49.1	$	3,273.8	$	2,480.3

Restructuring, other and COVID-19 expenses

Restructuring and other charges primarily consisted of severance and other employee related costs and COVID-19 related expenses across all segments. Restructuring and other expenses were as follows:

	Year Ended December 31,
	2021		2020				2019
(In millions)	Restructuring and other charges		Restructuring and other charges		COVID-19 expenses		Restructuring and other charges
Subsea	$	9.3	$	52.9	$	50.1	$	(46.4)
Surface Technologies	5.7		13.2		7.7		18.7
Corporate and other	2.6		4.3		—		4.1
Total	$	17.6	$	70.4	$	57.8	$	(23.6)

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COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

12 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Schedule of guarantor obligations

Guarantees made by our consolidated subsidiaries consisted of the following:

(In millions)	December 31, 2021
Financial guarantees (a)	$	177.4
Performance guarantees (b)	1,069.0
Maximum potential undiscounted payments	$	1,246.4

(a)Financial guarantees represent contracts that contingently require a guarantor to make payments to a guaranteed party based on changes in an underlying agreement that is related to an asset, a liability or an equity security of the guaranteed party. These tend to be drawn down only if there is a failure to fulfill our financial obligations.

(b)Performance guarantees represent contracts that contingently require a guarantor to make payments to a guaranteed party based on another entity's failure to perform under a nonfinancial obligating agreement. Events that trigger payment are performance-related, such as failure to ship a product or provide a service.

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INCOME TAXES (Tables)

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

Schedule of domestic and foreign components of income before taxes

Components of income (loss) from continuing operations before income taxes - U.S. and outside U.S. components of income (loss) from continuing operations before income taxes were as follows:

	Year Ended December 31,
(In millions)	2021		2020		2019
United States	$	(288.2)	$	(2,169.3)	$	(2,376.4)
Outside United States	486.3		(1,329.4)		(194.7)
Income (loss) from continuing operations before income taxes	$	198.1	$	(3,498.7)	$	(2,571.1)

Provision for income taxes

Provision (benefit) for income tax - The provision for income taxes consisted of:

	Year Ended December 31,
(In millions)	2021		2020		2019
Current
United States	$	0.2	$	(18.3)	$	39.1
Outside United States	206.0		69.5		12.0
Total current income taxes	206.2		51.2		51.1
Deferred
United States	—		(2.8)		3.8
Outside United States	(95.1)		(29.0)		24.1
Total deferred income taxes	(95.1)		(31.8)		27.9
Provision for income taxes	$	111.1	$	19.4	$	79.0

Deferred tax assets and liabilities

Deferred tax assets and liabilities - Significant components of deferred tax assets and liabilities were as follows: 

	December 31,
(In millions)	2021		2020
Deferred tax assets attributable to
Accrued expenses	$	173.0	$	133.0
Capital loss	21.1		21.1
Non-deductible interest	95.4		77.0
Foreign tax credit carryforwards	136.5		134.4
Other tax credits	146.0		163.8
Net operating loss carryforwards	455.5		383.5
Inventories	1.2		16.6
Research and development credit	3.8		2.9
Foreign exchange	17.2		—
Provisions for pensions and other long-term employee benefits	31.9		66.1
Contingencies	38.3		2.9
Margin recognition on construction contracts	18.0		20.6
Leases	183.4		170.4
Other	5.4		0.6
Deferred tax assets	1,326.7		1,192.9
Valuation allowance	(935.5)		(815.1)
Deferred tax assets, net of valuation allowance	391.2		377.8
Deferred tax liabilities attributable to
Revenue in excess of billings on contracts accounted for under the percentage of completion method	32.2		33.6
U.S. tax on foreign subsidiaries’ undistributed earnings not indefinitely reinvested	—		4.2
Property, plant and equipment, intangibles and other assets	162.8		180.1
Foreign exchange	—		43.9
Leases	169.4		161.1
Deferred tax liabilities	364.4		422.9
Net deferred tax assets/(liabilities)	$	26.8	$	(45.1)

Schedule of net operating losses

Our deferred tax assets from net operating losses will expire as follows:

(In millions)	Net Operating Loss
2022 – 2026	$	55.4
2027 – 2031	42.0
2032 – 2042	70.1
Non-Expiring	288.0
	$	455.5

Unrecognized tax benefits and associated interest and penalties

Unrecognized tax benefits - The following table presents a summary of changes in our unrecognized tax benefits: 

(In millions)	Federal, State and Foreign Tax
Balance at December 31, 2019	$	57.6
Reductions for tax positions related to prior years	(7.9)
Reductions for tax positions related to current year	(2.9)
Reductions for tax positions due to settlements	(0.6)
Balance at December 31, 2020	46.2
Reductions for tax positions related to prior years	(15.2)
Additions for tax positions related to current year	39.9
Reductions for tax positions due to settlements	(2.1)
Balance at December 31, 2021	$	68.8

Reconciliation of effective tax rate

Effective income tax rate reconciliation - The effective income tax rate was different from the statutory U.K. income tax rate due to the following:

	Year Ended December 31,
	2021		2020		2019
Statutory income tax rate	19.0	%	19.0	%	19.0	%
Net difference resulting from
Foreign earnings subject to different tax rates	24.4	%	1.3	%	3.4	%
Adjustments to prior year taxes	(52.4)	%	(1.2)	%	0.8	%
Net change in unrecognized tax benefits	12.3	%	—	%	—	%
Changes in valuation allowance	65.4	%	(0.9)	%	(7.2)	%
Deferred tax asset/liability revaluation for tax rate change	(12.2)	%	0.3	%	(0.4)	%
Impairments	—	%	(19.5)	%	(19.7)	%
Non-deductible legal provision	—	%	0.3	%	1.1	%
Other	(0.4)	%	0.1	%	(0.1)	%
Effective income tax rate	56.1	%	(0.6)	%	(3.1)	%

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS (Tables)

12 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]

Schedule of funded status

The funded status of our U.S. Pension Plans, certain foreign pension plans and U.S. post-retirement health care and life insurance benefit plans, together with the associated balances recognized in our consolidated balance sheets as of December 31, 2021 and 2020, were as follows:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Accumulated benefit obligation	$	653.6	$	589.1	$	684.7	$	598.1
Projected benefit obligation at January 1	$	684.7	$	656.4	$	669.7	$	585.1	$	9.4	$	10.2
Service cost	—		10.0		—		10.4		—		—
Interest cost	18.0		9.8		22.2		11.3		0.3		0.4
Actuarial (gain) loss	7.1		(32.5)		53.9		30.4		(0.7)		(0.2)
Settlements	(22.6)		—		(25.6)		(2.6)		—		—
Foreign currency exchange rate changes	—		(11.9)		—		23.6		(0.2)		(0.6)
Plan participants’ contributions	—		0.9		—		1.1		—		—
Benefits paid	(33.6)		(22.0)		(35.5)		(17.8)		(0.4)		(0.4)
Other	—		(9.1)		—		14.9		—		—
Projected benefit obligation as of December 31	653.6		601.6		684.7		656.4		8.4		9.4
Fair value of plan assets at January 1	483.7		591.5		520.0		521.2		—		—
Actual return on plan assets	61.1		46.4		14.3		40.1		—		—
Company contributions	28.9		19.6		—		27.1		—		—
Foreign currency exchange rate changes	—		(8.9)		—		20.4		—		—
Settlements	(22.6)		—		(19.6)		(1.9)		—		—
Plan participants’ contributions	—		0.9		—		1.1		—		—
Benefits paid	(33.6)		(22.0)		(31.0)		(15.8)		—		—
Other	—		—		—		(0.7)		—		—
Fair value of plan assets as of December 31	517.5		627.5		483.7		591.5		—		—
Funded status of the plans (liability) as of December 31	$	(136.1)	$	25.9	$	(201.0)	$	(64.9)	$	(8.4)	$	(9.4)

Schedule of funded status recognized in the consolidated balance sheets

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Current portion of accrued pension and other post-retirement benefits	$	(2.9)	$	(1.7)	$	(4.6)	$	(1.6)	$	(0.6)	$	(0.7)
Accrued pension and other post-retirement benefits, net of current portion	(133.2)		27.6		(196.4)		(63.3)		(7.8)		(8.7)
Funded status as of December 31	$	(136.1)	$	25.9	$	(201.0)	$	(64.9)	$	(8.4)	$	(9.4)

Schedule of pre-tax amounts in accumulated other comprehensive (income) loss

The following table summarizes the pre-tax amounts in accumulated other comprehensive (income) loss as of December 31, 2021 and 2020 that have not been recognized as components of net periodic benefit cost:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Pre-tax amounts recognized in accumulated other comprehensive (income) loss
Unrecognized actuarial loss	$	156.6	$	15.9	$	198.4	$	79.1	$	0.4	$	1.3
Unrecognized prior service cost	—		3.4		—		3.9		—		—
Accumulated other comprehensive (income) loss as of December 31	$	156.6	$	19.3	$	198.4	$	83.0	$	0.4	$	1.3

Schedule of plans with underfunded or non-funded projected benefit obligation

The following tables summarize the projected and accumulated benefit obligations and fair values of plan assets where the projected or accumulated benefit obligation exceeds the fair value of plan assets as of December 31, 2021 and 2020:

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Plans with underfunded or non-funded projected benefit obligation
Aggregate projected benefit obligation	$	652.2	$	57.9	$	684.7	$	513.1	$	8.4	$	9.4
Aggregate fair value of plan assets	$	516.0	$	—	$	483.7	$	442.7	$	—	$	—

Schedule of plans with underfunded or non-funded accumulated benefit obligation

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
(In millions)	U.S.		Int’l		U.S.		Int’l
Plans with underfunded or non-funded accumulated benefit obligation
Aggregate accumulated benefit obligation	$	652.2	$	46.7	$	684.7	$	50.8	$	—	$	—
Aggregate fair value of plan assets	$	516.0	$	—	$	483.7	$	—	$	—	$	—

Schedule of components of net periodic benefit cost (income)

The following table summarizes the components of net periodic benefit cost (income) for the years ended December 31, 2021, 2020 and 2019:

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
(In millions)	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Components of net periodic benefit cost (income)
Service cost	$	—	$	10.0	$	—	$	10.4	$	—	$	7.0	$	—	$	—	$	—
Interest cost	18.0		9.8		22.2		11.3		25.6		13.7		0.3		0.4		0.5
Expected return on plan assets	(31.9)		(25.0)		(45.4)		(36.5)		(41.6)		(31.3)		—		—		—
Settlement cost	2.8		—		1.4		0.5		—		—		—		—		—
Curtailment benefit	—		0.4		—		—		—		—		—		—		—
Amortization of net actuarial loss (gain)	16.8		1.4		6.9		0.6		1.8		0.3		0.1		0.1		—
Amortization of prior service cost (credit)	—		0.5		—		0.6		—		0.4		—		—		—
Net periodic benefit cost (income)	$	5.7	$	(2.9)	$	(14.9)	$	(13.1)	$	(14.2)	$	(9.9)	$	0.4	$	0.5	$	0.5

Schedule of changes in plan assets and benefit obligations recognized in other comprehensive income (loss)

The following table summarizes changes in plan assets and benefit obligations recognized in other comprehensive income (loss) for the years ended December 31, 2021, 2020 and 2019:

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
(In millions)	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Changes in plan assets and benefit obligations recognized in other comprehensive income (loss)
Net actuarial gain (loss) arising during period	$	(22.1)	$	(58.4)	$	(85.1)	$	(26.8)	$	(50.2)	$	(37.5)	$	—	$	—	$	—
Prior service (cost) credit arising during period	—		0.6		—		—		—		(0.9)		—		—		—
Settlements and curtailments	(2.8)		(0.4)		1.4		0.4		—		—		—		—		—
Amortization of net actuarial loss (gain)	(16.8)		(1.4)		6.9		0.6		1.8		0.3		—		(0.1)		—
Amortization of prior service cost (credit)	—		(0.5)		—		0.6		—		0.4		—		—		—
Other	—		—		—		(7.5)		—		(1.5)		(0.9)		(0.6)		1.5
Total recognized in other comprehensive income (loss)	$	(41.7)	$	(60.1)	$	(76.8)	$	(32.7)	$	(48.4)	$	(39.2)	$	(0.9)	$	(0.7)	$	1.5

Included in accumulated other comprehensive income (loss) as of December 31, 2021, are noncash, pre-tax charges which have not yet been recognized in net periodic benefit cost (income). The estimated amounts expected to be amortized from the portion of each component of accumulated other comprehensive income (loss) as a component of net period benefit cost (income), during the next fiscal year are as follows:

	Pensions				Other Post-retirement Benefits
(In millions)	U.S.		Int’l
Net actuarial losses	$	12.0	$	—	$	—
Prior service cost	$	—	$	0.4	$	—

Schedule of weighted-average assumptions

The following weighted-average assumptions were used to determine the benefit obligations: 

	Pensions								Other Post-retirement Benefits
	2021				2020				2021		2020
	U.S.		Int’l		U.S.		Int’l
Discount rate	2.90	%	1.99	%	2.70	%	1.48	%	5.26	%	3.63	%
Rate of compensation increase	N/A		3.15	%	N/A		2.93	%	4.00	%	4.00	%

The following weighted-average assumptions were used to determine net periodic benefit cost: 

	Pensions												Other Post-retirement Benefits
	2021				2020				2019				2021		2020		2019
	U.S.		Int’l		U.S.		Int’l		U.S.		Int’l
Discount rate	2.70	%	3.09	%	3.40	%	2.01	%	4.40	%	2.89	%	4.46	%	4.48	%	5.32	%
Rate of compensation increase	N/A		3.15	%	N/A		3.84	%	N/A		3.80	%	4.00	%	4.00	%	4.00	%
Expected rate of return on plan assets	6.75	%	2.22	%	7.75	%	7.27	%	8.65	%	7.15	%	N/A		N/A		N/A

Schedule of pension plan assets

Our pension plan assets measured at fair value on a recurring basis are as follows as of December 31, 2021 and 2020. Refer to “Fair value measurements” in Note 1 to these consolidated financial statements for a description of the levels.

(In millions)	U.S.										International
December 31, 2021	Total		Level 1		Level 2		Level 3		Net Asset Value (a)		Total		Level 1		Level 2		Level 3		Net Asset Value (a)
Cash and cash equivalents	$	43.4	$	43.4	$	—	$	—	$	—	$	40.5	$	40.5	$	—	$	—	$	—
Equity securities
U.S. companies	102.1		102.1		—		—		—		45.5		45.5		—		—		—
International companies	2.1		2.1		—		—		—		143.4		143.4		—		—		—
Registered investment companies	37.9		—		—		—		37.9		36.0		—		—		—		36.0
Insurance contracts	—		—		—		—		—		—		—		—		—		—
Hedge funds	138.8		—		—		—		138.8		291.0		—		—		—		291.0
Limited partnerships	192.5		—		—		—		192.5		3.6		—		—		—		3.6
Real estate and other investments	0.6		0.6		—		—		—		69.7		69.7		—		—		—
Total assets	$	517.4	$	148.2	$	—	$	—	$	369.2	$	629.7	$	299.1	$	—	$	—	$	330.6
December 31, 2020
Cash and cash equivalents	$	38.1	$	38.1	$	—	$	—	$	—	$	66.3	$	66.3	$	—	$	—	$	—
Equity securities
U.S. companies	83.3		83.3		—		—		—		96.3		96.3		—		—		—
International companies	1.1		1.1		—		—		—		208.4		208.4		—		—		—
Registered investment companies	38.4		—		—		—		38.4		68.2		—		—		—		68.2
Hedge funds	160.9		—		—		—		160.9		98.3		—		—		—		98.3
Limited partnerships	160.9		—		—		—		160.9		14.5		—		—		—		14.5
Real estate and other investments	1.0		1.0		—		—		—		39.5		39.5		—		—		—
Total assets	$	483.7	$	123.5	$	—	$	—	$	360.2	$	591.5	$	410.5	$	—	$	—	$	181.0

(a)Certain investments that are measured at fair value using net asset value per share (or its equivalent) have not been classified in the fair value hierarchy.

Schedule of estimated future benefit payments

The following table summarizes expected benefit payments from our various pension and post-retirement benefit plans through 2031. Actual benefit payments may differ from expected benefit payments.

	Pensions				Other Post-retirement Benefits
(In millions)	U.S.		International
2022	$	33.3	$	22.0	$	0.6
2023	31.4		22.4		0.6
2024	31.7		23.8		0.6
2025	32.3		24.4		0.5
2026	32.7		25.6		0.5
2027-2031	165.9		149.9		2.3

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DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

12 Months Ended

Dec. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of notional amounts of outstanding derivative positions

As of December 31, 2021, we held the following material net positions: 

	Net Notional Amount Bought (Sold)
(In millions)		USD Equivalent
Euro	775.4	878.2
British pound	(197.2)	(265.9)
Malaysian ringgit	(627.4)	(150.5)
Norwegian krone	967.9	109.8
Brazilian real	1,299.8	232.9
Singapore dollar	125.4	92.9
Mexican peso	(116.7)	(5.7)
Australian dollar	182.4	132.2
Indian rupee	881.4	11.8
Kuwaiti Dinar	(3.3)	(10.9)
Russian Ruble	925.0	12.5
Canadian dollar	19.2	15.1
Indonesian rupiah	(45,656.9)	(3.2)
U.S. dollar	(1,119.9)	(1,119.9)

Foreign exchange rate instruments embedded in purchase and sale contracts – The purpose of these instruments is to match offsetting currency payments and receipts for particular projects, or comply with government restrictions on the currency used to purchase goods in certain countries. As of December 31, 2021, our portfolio of these instruments included the following material net positions: 

	Net Notional Amount Bought (Sold)
(In millions)		USD Equivalent
Brazilian real	52.5	9.4
Euro	(7.3)	(8.3)
Norwegian krone	6.1	0.7
U.S. dollar	(1.2)	(1.2)

Schedule of fair value of derivative instruments

The following table presents the location and fair value amounts of derivative instruments reported in the consolidated balance sheets:

	December 31, 2021				December 31, 2020
(In millions)	Assets		Liabilities		Assets		Liabilities
Derivatives designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments	$	106.4	$	139.5	$	189.5	$	141.9
Long-term - Derivative financial instruments	10.5		15.5		28.9		18.8
Total derivatives designated as hedging instruments	116.9		155.0		218.4		160.7
Derivatives not designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments	3.9		21.5		79.2		15.6
Long-term - Derivative financial instruments	—		—		0.3		—
Total derivatives not designated as hedging instruments	3.9		21.5		79.5		15.6
Total derivatives	$	120.8	$	176.5	$	297.9	$	176.3

Schedule of cash flow hedge

The following tables present the location of gains (losses) in the consolidated statements of income related to derivative instruments designated as cash flow hedges. 

	Gain (Loss) Recognized in OCI
	Year Ended December 31,
(In millions)	2021		2020		2019
Foreign exchange contracts	$	(26.3)	$	3.8	$	12.2

The following represents the effect of cash flow hedge accounting on the consolidated statements of income for the year ended December 31, 2021, 2020 and 2019:

	Year Ended December 31,
(In millions)	2021								2020								2019
Total amount of income (expense) presented in the consolidated statements of income associated with hedges and derivatives	Revenue		Cost of sales		Selling, general and administrative expense		Other income (expense), net		Revenue		Cost of sales		Selling, general and administrative expense		Other income (expense), net		Revenue		Cost of sales		Other income (expense), net
Amounts reclassified from accumulated OCI to income (loss)	$	(29.7)	$	10.7	$	0.2	$	32.9	$	(83.7)	$	68.5	$	(0.4)	$	(0.2)	$	(26.6)	$	12.0	$	(1.3)
Amounts excluded from effectiveness testing	(1.8)		(3.3)		—		3.8		7.7		(9.8)		(0.2)		0.3		0.6		(7.6)		(7.2)
Total cash flow hedge gain (loss) recognized in income	(31.5)		7.4		0.2		36.7		(76.0)		58.7		(0.6)		0.1		(26.0)		4.4		(8.5)
Gain (loss) recognized in income on derivatives not designated as hedging instruments	1.3		0.3		—		(13.3)		(0.8)		3.4		—		35.9		(1.6)		0.2		(21.4)
Total	$	(30.2)	$	7.7	$	0.2	$	23.4	$	(76.8)	$	62.1	$	(0.6)	$	36.0	$	(27.6)	$	4.6	$	(29.9)

Schedule of derivative assets, gross and net

The following tables present both gross information and net information of recognized derivative instruments:

	December 31, 2021						December 31, 2020
(In millions)	Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount		Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount
Derivative assets	$	120.8	$	(78.6)	$	42.2	$	297.9	$	(128.7)	$	169.2
Derivative liabilities	$	176.5	$	(78.6)	$	97.9	$	176.3	$	(128.7)	$	47.6

Schedule of derivative liabilities, gross and net

The following tables present both gross information and net information of recognized derivative instruments:

	December 31, 2021						December 31, 2020
(In millions)	Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount		Gross Amount Recognized		Gross Amounts Not Offset Permitted Under Master Netting Agreements		Net Amount
Derivative assets	$	120.8	$	(78.6)	$	42.2	$	297.9	$	(128.7)	$	169.2
Derivative liabilities	$	176.5	$	(78.6)	$	97.9	$	176.3	$	(128.7)	$	47.6

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FAIR VALUE MEASUREMENTS (Tables)

12 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

Schedule of assets and liabilities measured at fair value on a recurring basis

Assets and liabilities measured at fair value on a recurring basis were as follows: 

	December 31, 2021								December 31, 2020
(In millions)	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Assets
Investments
Investment in Technip Energies	$	317.3	$	317.3	$	—	$	—	$	—	$	—	$	—	$	—
Equity securities(a)	25.0		25.0		—		—		23.4		23.4		—		—
Money market fund	2.4		—		2.4		—		1.7		—		1.7		—
Stable value fund(b)	0.3		—		—		—		0.9		—		—		—
Held-to-maturity debt securities	24.0		—		24.0		—		24.2		—		24.2		—
Derivative financial instruments
Foreign exchange contracts	120.8		—		120.8		—		297.9		—		297.9		—
Assets held for sale	5.0		—		—		5.0		47.3		—		—		47.3
Total assets	$	494.8	$	342.3	$	147.2	$	5.0	$	395.4	$	23.4	$	323.8	$	47.3
Liabilities
Derivative financial instruments
Foreign exchange contracts	176.5		—		176.5		—		176.3		—		176.3		—
Total liabilities	$	176.5	$	—	$	176.5	$	—	$	176.3	$	—	$	176.3	$	—

(a)Includes fixed income and other investments measured at fair value.

(b)Certain investments that are measured at fair value using net asset value per share (or its equivalent) have not been classified in the fair value hierarchy.

Fair Value Measurements, Nonrecurring

The following summarizes impairments of long-lived assets and related post-impairment fair value for the years ended December 31, 2021 and 2020:

	Year Ended December 31,
	2021				2020
(In millions)	Impairment		Fair Value		Impairment		Fair Value
Long-lived assets(a)	$	49.1	$	25.5	$	190.4	$	452.5

(a)Measuring these asset groups for recoverability required the use of unobservable inputs that require significant judgment. Such judgments include expected future asset utilization while taking into account reduced future capital spending by certain customers in response to market conditions.

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BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	12 Months Ended
	Dec. 31, 2021
Minimum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Finite-lived intangible asset, useful life	2 years
Minimum | Vessels
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, estimated useful lives	10 years
Minimum | Buildings
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, estimated useful lives	10 years
Minimum | Machinery and equipment
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, estimated useful lives	3 years
Minimum | Software and software development costs
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Finite-lived intangible asset, useful life	3 years
Maximum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Finite-lived intangible asset, useful life	20 years
Maximum | Vessels
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, estimated useful lives	30 years
Maximum | Buildings
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, estimated useful lives	50 years
Maximum | Machinery and equipment
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, estimated useful lives	20 years
Maximum | Software and software development costs
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Finite-lived intangible asset, useful life	10 years
Maximum | Internet website costs
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Finite-lived intangible asset, useful life	3 years

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DISCONTINUED OPERATIONS - Narratives (Details) $ in Millions	Feb. 16, 2021	Dec. 31, 2021 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Exchange ratio	0.2
Accounts receivable		$ 84.4
Accounts payable		$ 72.2
Technip Energies N.V.
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Spin off, ownership interest percentage by parent	50.10%

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DISCONTINUED OPERATIONS - Income from discontinued operations, net of tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations, net of income taxes	$ (72.6)	$ 280.2	$ 238.0
Spinoff | Technip Energies N.V.
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenue	906.0	6,520.0	6,458.9
Costs and expenses	(932.0)	(5,899.0)	(5,627.6)
Other income and (expense), net	(18.6)	(206.8)	(396.0)
Income (loss) from discontinued operations before income taxes	(44.6)	414.2	435.3
Income (loss) from discontinued operations, net of income taxes	$ (72.6)	$ 280.2	$ 238.0

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DISCONTINUED OPERATIONS - Supplemental information (Details) - Assets from discontinued operations - TechnipFMC and Technip Energies - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Capital expenditures	$ 5.1	$ 35.7	$ 41.7
Depreciation and amortization expense	17.1	35.1	41.9
Research and development expense	$ 4.4	$ 44.5	$ 13.4

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DISCONTINUED OPERATIONS - Assets and liabilities of discontinued operations (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets
Trade receivables, net of allowances	$ 84.4
Total current assets of discontinued operations	0.0	$ 5,725.1
Total non-current assets of discontinued operations	0.0	3,283.5
Liabilities
Total current liabilities of discontinued operations	0.0	6,096.5
Total non-current liabilities of discontinued operations	$ 0.0	1,081.3
Spinoff | Technip Energies N.V.
Assets
Cash and cash equivalents		3,538.6
Trade receivables, net of allowances		1,302.1
Contract assets		380.8
Other current assets		503.6
Total current assets of discontinued operations		5,725.1
Property, plant and equipment, net of accumulated depreciation		105.6
Goodwill		2,512.5
Other assets		665.4
Total non-current assets of discontinued operations		3,283.5
Total assets of discontinued operations		9,008.6
Liabilities
Accounts payable, trade		1,539.5
Contract liabilities		3,689.3
Other current liabilities		867.7
Total current liabilities of discontinued operations		6,096.5
Long-term debt, less current portion		482.2
Operating lease liabilities		248.2
Other liabilities		350.9
Total non-current liabilities of discontinued operations		1,081.3
Total liabilities of discontinued operations		$ 7,177.8

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BUSINESS COMBINATION AND OTHER TRANSACTIONS - Narrative (Details)			1 Months Ended	3 Months Ended	12 Months Ended
	Oct. 12, 2021 USD ($)	Dec. 30, 2019 USD ($) vessel	Oct. 31, 2021 USD ($) installment	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Mar. 12, 2018
Business Acquisition [Line Items]
Acquisition of non-controlling interest				$ 48,600,000	$ 48,600,000	$ 0	$ 0
Island Offshore Management AS
Business Acquisition [Line Items]
Fair value					43,700,000	$ 43,700,000
Island Offshore Management AS | TIOS AS
Business Acquisition [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners						51.00%
Island Offshore Management AS | TIOS AS | Share Purchase Agreement
Business Acquisition [Line Items]
Purchased shares (percentage)								51.00%
Remaining interest (percentage)				49.00%
TOP CV
Business Acquisition [Line Items]
Acquired assets		$ 391,000,000
Number of acquired vessels | vessel		2
Vessels acquired		$ 335,200,000
Liability assumed		239,900,000
Business combination, long-term debt		203,100,000
Business combination, net loss		(900,000)
Impairment charge		84,200,000
Business combination, bargain purchase, gain recognized, amount		$ 83,300,000
Subsea | TOP CV
Business Acquisition [Line Items]
Purchased remaining ownership interest		50.00%
Magma Global Limited
Business Acquisition [Line Items]
Payments to acquire equity method investments	$ 23,900,000		$ 64,000,000
Number of annual installment payments | installment			3
Equity method investment impairment, Impairment				$ 36,700,000
Identifiable intangible assets acquired					$ 50,200,000
Finite-lived intangible asset, useful life					15 years

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LEASES - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Lease initial direct cost expense commencement	$ 1.8
Gain (loss) on termination of lease	3.1
Operating lease revenue including variable revenue	158.4	$ 142.0
Total undiscounted cash flows	19.3
2022	18.3
2023	$ 1.0
Commercial Real Estate Property
Lessee, Lease, Description [Line Items]
Renewal term	15 years
Land at Gremp Campus
Lessee, Lease, Description [Line Items]
Gain (loss) on sale of land	$ 0.0
Minimum
Lessee, Lease, Description [Line Items]
Renewal term	60 days
Maximum
Lessee, Lease, Description [Line Items]
Renewal term	5 years

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LEASES - Components of Lease Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease costs including variable costs	$ 175.9	$ 195.6
Short-term lease costs	5.2	11.0
Less: sublease income	2.4	2.8
Net lease cost	$ 178.7	$ 203.8

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LEASES - Supplemental Cash Flow Information Related to Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating cash flows from operating leases	$ 176.5	$ 206.5
Operating leases	114.9	421.3
Finance leases	$ 24.6	$ 26.9

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LEASES - Supplemental Balance Sheet Information Related to Leases (Details)	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating leases	13 years 3 months 18 days	13 years 7 months 6 days
Finance leases	1 year 1 month 6 days	7 months 6 days
Operating leases	5.86%	5.35%
Finance leases	1.20%	2.10%

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LEASES - Maturities of Lease Liabilities (Details) $ in Millions	Dec. 31, 2021 USD ($)
Maturity of Operating Lease Liabilities
2022	$ 150.2
2023	108.3
2024	102.3
2025	83.1
2026	74.7
Thereafter	675.9
Total lease payments	1,194.5
Less: Imputed interest	421.5
Total lease liabilities	773.0
Maturity of Finance Lease Liabilities
2022	1.0
2023	103.0
2024	0.0
2025	0.0
2026	0.0
Thereafter	0.0
Total lease payments	104.0
Less: Imputed interest	52.2
Finance Lease, Liability	51.8
Current portion of lease liability	$ 126.9

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REVENUE - Narrative (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Transferred over Time
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue Recognized, Percent	68.00%	72.00%	68.00%
Minimum
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue, performance obligation, warranty, term	18 years
Maximum
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue, performance obligation, warranty, term	36 months

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REVENUE - Disaggregation of Revenue, Geographical (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Lease	$ 158.4	$ 142.0	$ 266.5
Total revenue	6,403.5	6,530.6	6,950.2
Service revenue
Disaggregation of Revenue [Line Items]
Product and service revenue	3,440.7	3,266.8	3,412.0
Product revenue
Disaggregation of Revenue [Line Items]
Product and service revenue	2,804.4	3,121.8	3,271.7
Subsea
Disaggregation of Revenue [Line Items]
Product and service revenue	5,329.1	5,471.4	5,419.5
Lease	44.6	54.9	116.0
Total revenue	5,329.1	5,471.4	5,419.5
Subsea | Service revenue
Disaggregation of Revenue [Line Items]
Product and service revenue	3,282.0	3,121.1	3,141.0
Subsea | Product revenue
Disaggregation of Revenue [Line Items]
Product and service revenue	2,002.5	2,295.4	2,162.5
Subsea | Europe, Central Asia
Disaggregation of Revenue [Line Items]
Product and service revenue	1,404.4	1,664.1	1,690.2
Subsea | North America
Disaggregation of Revenue [Line Items]
Product and service revenue	753.6	899.7	660.8
Subsea | Latin America
Disaggregation of Revenue [Line Items]
Product and service revenue	1,157.7	1,042.4	1,139.5
Subsea | Asia Pacific
Disaggregation of Revenue [Line Items]
Product and service revenue	927.4	772.1	673.3
Subsea | Africa
Disaggregation of Revenue [Line Items]
Product and service revenue	1,057.3	908.6	836.4
Subsea | Middle East
Disaggregation of Revenue [Line Items]
Product and service revenue	28.7	184.5	419.3
Surface Technologies
Disaggregation of Revenue [Line Items]
Product and service revenue	1,074.4	1,059.2	1,530.7
Lease	113.8	87.1	150.5
Total revenue	1,074.4	1,059.2	1,530.7
Surface Technologies | Service revenue
Disaggregation of Revenue [Line Items]
Product and service revenue	158.7	150.2	271.0
Surface Technologies | Product revenue
Disaggregation of Revenue [Line Items]
Product and service revenue	801.9	821.9	1,109.2
Surface Technologies | Europe, Central Asia
Disaggregation of Revenue [Line Items]
Product and service revenue	191.5	192.7	160.1
Surface Technologies | North America
Disaggregation of Revenue [Line Items]
Product and service revenue	372.7	367.9	751.9
Surface Technologies | Latin America
Disaggregation of Revenue [Line Items]
Product and service revenue	86.7	76.6	108.6
Surface Technologies | Asia Pacific
Disaggregation of Revenue [Line Items]
Product and service revenue	104.2	131.0	195.4
Surface Technologies | Africa
Disaggregation of Revenue [Line Items]
Product and service revenue	44.0	46.9	62.7
Surface Technologies | Middle East
Disaggregation of Revenue [Line Items]
Product and service revenue	$ 275.3	$ 244.1	$ 252.0

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REVENUE - Contract Balances (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Contract assets	$ 966.0	$ 886.8
Contract (liabilities)	(1,012.9)	(1,046.8)
Net contract (liabilities)	(46.9)	(160.0)
Contract assets, increase (decrease)	$ 79.2
Contract with customer, asset, net, current, increase (decrease), (in percent)	8.90%
Contract (liabilities), (increase) decrease	$ 33.9
Contract with customer liability, current, increase (decrease), (in percent)	3.20%
Net contract assets (liabilities), increase (decrease)	$ 113.1
Contract assets (liabilities), current, net, increase (decrease), (in percent)	70.70%
Contract with customer, liability, revenue recognized		305.3	$ 484.3
Contract with customer, performance obligation satisfied in previous period	$ 25.9	$ (21.7)

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REVENUE - Performance Obligations (Details) $ in Millions	Dec. 31, 2021 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, total amount	$ 7,657.7
Revenue, remaining performance obligation, percentage	49.00%
Revenue, remaining performance obligation, amount	$ 3,749.6
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Subsea
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 3,372.8
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Technip Energies
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Surface Technologies
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 376.8
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, percentage	51.00%
Revenue, remaining performance obligation, amount	$ 2,322.7
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Subsea
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 2,227.5
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Technip Energies
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Surface Technologies
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 95.2
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 1,585.4
Revenue, remaining performance obligation, expected timing of satisfaction, period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Subsea
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 932.7
Revenue, remaining performance obligation, expected timing of satisfaction, period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Technip Energies
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Surface Technologies
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 652.7
Revenue, remaining performance obligation, expected timing of satisfaction, period	2 years

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BUSINESS SEGMENTS - Schedule Of Segment Revenue And Segment Operating Profit (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) segment	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment	2
Revenues	$ 6,403.5	$ 6,530.6	$ 6,950.2
Total segment operating profit	183.4	(3,244.8)	(2,105.4)
Merger transaction and integration costs	0.0	0.0	(14.2)
Legal expenses			(33.0)
Other corporate expenses	(118.1)	(131.9)	(191.7)
Net interest expense	(143.3)	(81.8)	(91.3)
Loss on early extinguishment of debt	(61.9)	0.0	0.0
Income from investment in Technip Energies	322.2	0.0	0.0
Foreign exchange gains (losses)	15.8	(40.2)	(135.5)
Loss before income taxes	198.1	(3,498.7)	(2,571.1)
Subsea
Segment Reporting Information [Line Items]
Revenues	5,329.1	5,471.4	5,419.5
Surface Technologies
Segment Reporting Information [Line Items]
Revenues	1,074.4	1,059.2	1,530.7
Operating segments | Subsea
Segment Reporting Information [Line Items]
Revenues	5,329.1	5,471.4	5,419.5
Total segment operating profit	141.4	(2,815.5)	(1,442.7)
Operating segments | Surface Technologies
Segment Reporting Information [Line Items]
Revenues	1,074.4	1,059.2	1,530.7
Total segment operating profit	42.0	(429.3)	(662.7)
Corporate
Segment Reporting Information [Line Items]
Total corporate items	$ 14.7	$ (253.9)	$ (465.7)

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BUSINESS SEGMENTS - Segment Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Total Assets	$ 10,020.1	$ 19,692.6
Assets from discontinued operations
Segment Reporting Information [Line Items]
Total Assets	0.0	9,008.6
Operating segments
Segment Reporting Information [Line Items]
Total Assets	7,952.5	8,554.9
Operating segments | Subsea
Segment Reporting Information [Line Items]
Total Assets	6,532.5	6,796.6
Operating segments | Surface Technologies
Segment Reporting Information [Line Items]
Total Assets	1,420.0	1,758.3
Corporate
Segment Reporting Information [Line Items]
Total Assets	$ 2,067.6	$ 2,129.1

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BUSINESS SEGMENTS - Other Business Segment Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Capital Expenditures	$ 191.7	$ 256.1	$ 412.7
Depreciation and Amortization	385.4	412.1	467.7
Research and Development Expense	78.4	75.3	149.5
Operating segments | Subsea
Segment Reporting Information [Line Items]
Capital Expenditures	149.4	213.6	287.5
Depreciation and Amortization	317.2	324.9	345.0
Research and Development Expense	73.2	66.5	134.2
Operating segments | Surface Technologies
Segment Reporting Information [Line Items]
Capital Expenditures	36.8	38.5	96.0
Depreciation and Amortization	64.8	70.1	107.1
Research and Development Expense	5.2	8.8	15.3
Corporate
Segment Reporting Information [Line Items]
Capital Expenditures	5.5	4.0	29.2
Depreciation and Amortization	$ 3.4	$ 17.1	$ 15.6

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BUSINESS SEGMENTS - Geographic Segment Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Revenues	$ 6,403.5	$ 6,530.6	$ 6,950.2
Property, plant and equipment, net	2,597.2	2,756.2
United States
Segment Reporting Information [Line Items]
Revenues	1,137.2	1,320.1	1,458.6
Property, plant and equipment, net	383.4	439.1
Norway
Segment Reporting Information [Line Items]
Revenues	979.9	1,216.6	1,352.6
Property, plant and equipment, net	271.9	312.1
Brazil
Segment Reporting Information [Line Items]
Revenues	767.8	600.6	1,086.2
Property, plant and equipment, net	265.5	259.9
United Kingdom
Segment Reporting Information [Line Items]
Revenues	542.5	489.0	535.8
Property, plant and equipment, net	882.9	928.8
Mozambique
Segment Reporting Information [Line Items]
Revenues	472.0	320.4	80.0
Australia
Segment Reporting Information [Line Items]
Revenues	419.8	122.5	133.4
Angola
Segment Reporting Information [Line Items]
Revenues	406.3	482.8	498.1
Guyana
Segment Reporting Information [Line Items]
Revenues	314.7	330.1	7.2
Indonesia
Segment Reporting Information [Line Items]
Revenues	224.9	280.0	262.6
Singapore
Segment Reporting Information [Line Items]
Revenues	216.3	219.9	190.5
Malaysia
Segment Reporting Information [Line Items]
Revenues	206.9	190.0	197.2
India
Segment Reporting Information [Line Items]
Revenues	109.8	26.8	0.0
Trinidad
Segment Reporting Information [Line Items]
Revenues	78.1	106.3	42.8
Israel
Segment Reporting Information [Line Items]
Revenues	26.8	179.3	319.6
All other countries
Segment Reporting Information [Line Items]
Revenues	500.5	646.2	$ 785.6
Property, plant and equipment, net	378.8	398.7
Netherlands
Segment Reporting Information [Line Items]
Property, plant and equipment, net	$ 414.7	$ 417.6

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EARNINGS (LOSS) PER SHARE - Reconciliation of Number of Shares Used For Basic and Diluted Earnings Per Share ("EPS") Calculation (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2017
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Income (loss) from continuing operations attributable to TechnipFMC plc	$ 87.8	$ (3,552.6)	$ (2,645.5)
Income (loss) from discontinued operations attributable to TechnipFMC plc	(74.5)	265.0	230.3
Net income (loss) attributable to TechnipFMC plc	$ 13.3	$ (3,287.6)	$ (2,415.2)
Weighted average number of shares outstanding (in shares)	450.5	448.7	448.0
Total shares and dilutive securities (in shares)	454.6	448.7	448.0	448.0
Earnings (loss) per share from continuing operations basic (usd per share)	$ 0.19	$ (7.92)	$ (5.91)
Earnings (loss) per share from continued operations diluted (usd per share)	0.19	(7.92)	(5.91)
Earnings (loss) per share from discontinued operations basic (usd per share)	(0.17)	0.59	0.51
Earnings (loss) per share from discontinued operations diluted (usd per share)	(0.16)	0.59	0.51
Earnings (loss) per share from continuing operations basic (usd per share)	0.03	(7.33)	(5.39)
Earnings (loss) per share from continuing operations diluted (usd per share)	$ 0.03	$ (7.33)	$ (5.39)
Antidilutive securities excluded from computation of earnings per share, amount (in shares)	1.8	8.3	5.6
Share option awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, amount (in shares)	1.7	4.6	4.0
Restricted share units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, amount (in shares)	0.1	1.8	0.0
Performance shares
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, amount (in shares)	0.0	1.9	1.6
Share option awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, amount (in shares)		3.8	4.3
Restricted share units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Dilutive effect of share-based payment arrangements (in shares)	4.1	0.0	0.0

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RECEIVABLES - Amortized cost basis of financial assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Financing Receivable, Allowance for Credit Loss [Line Items]
Financing receivable, originated in fiscal year before latest fiscal year	$ 74.9	$ 131.3
Moody’s rating Ba2
Financing Receivable, Allowance for Credit Loss [Line Items]
Financing receivable, originated in fiscal year before latest fiscal year	50.9	107.6
Moody’s rating B3
Financing Receivable, Allowance for Credit Loss [Line Items]
Financing receivable, originated in fiscal year before latest fiscal year	$ 24.0	$ 23.7

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RECEIVABLES - Roll-forward of allowance for credit losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Trade receivables
Accounts Receivable, Allowance for Credit Loss, Writeoff		$ (43.0)
Contract assets
Allowance for credit losses at December 31, 2020	$ 2.4
Write-offs charged against the allowance		0.0
Allowance for credit losses at December 31, 2021	1.1	2.4
Loans receivable
Write-offs charged against the allowance		0.0
Security deposit and other
Write-offs charged against the allowance		0.0
Held-to-maturity debt securities
Write-offs charged against the allowance		0.0
Trade receivables
Trade receivables
Allowance for credit losses at December 31, 2020	40.2	59.4
Current period provision (release) for expected credit losses	3.5	27.2
Recoveries	(5.6)	(3.4)
Allowance for credit losses at December 31, 2021	38.1	40.2
Contract assets
Contract assets
Allowance for credit losses at December 31, 2020	2.4	4.5
Current period provision (release) for expected credit losses	(1.3)	0.5
Recoveries	0.0	(2.6)
Allowance for credit losses at December 31, 2021	1.1	2.4
Loans receivable
Loans receivable
Allowance for credit losses at December 31, 2020	7.5	9.5
Current period provision (release) for expected credit losses	(7.2)	(0.2)
Recoveries	0.0	(1.8)
Allowance for credit losses at December 31, 2021	0.3	7.5
Security deposit and other
Security deposit and other
Allowance for credit losses at December 31, 2020	0.4	0.7
Current period provision (release) for expected credit losses	(0.1)	(0.3)
Recoveries	0.0	0.0
Allowance for credit losses at December 31, 2021	0.3	0.4
Held-to-maturity debt securities
Held-to-maturity debt securities
Allowance for credit losses at December 31, 2020	0.5	1.1
Current period provision (release) for expected credit losses	2.2	(0.6)
Recoveries	0.0	0.0
Allowance for credit losses at December 31, 2021	$ 2.7	$ 0.5

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INVENTORIES - Components Of Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Inventory, Finished Goods and Work in Process, Gross [Abstract]
Raw materials	$ 250.1	$ 270.3
Work in process	178.7	242.7
Finished goods	603.1	739.8
Inventories, net	$ 1,031.9	$ 1,252.8

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INVENTORIES - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Inventory Disclosure [Abstract]
Inventory Valuation Reserves	$ 116.6	$ 155.7
LIFO inventory amount	350.1	408.5
Replacement costs over stated LIFO value	$ 10.9	$ 11.6

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OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES - Other Current Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Other Current Assets & Other Current Liabilities [Abstract]
Value - added tax receivables	$ 222.4	$ 256.9
Sundry receivables	106.1	138.4
Other taxes receivables	70.6	73.8
Prepaid expenses	50.7	78.1
Current financial assets at amortized cost	21.9	40.6
Held-to-maturity investments	8.8	24.2
Assets held for sale	5.0	47.3
Other	26.8	24.1
Total other current assets	$ 512.3	$ 683.4

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OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES - Other Current Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Other Current Assets & Other Current Liabilities [Abstract]
Warranty accruals and project contingencies	$ 119.5	$ 168.8
Legal provisions	121.7	127.6
Value - added tax and other taxes payable	71.0	109.6
Compensation accrual	85.7	54.3
Social security liability	70.4	67.9
Provisions	23.6	53.0
Current portion of accrued pension and other post-retirement benefits	5.2	6.9
Other accrued liabilities	163.3	230.2
Total other current liabilities	$ 660.4	$ 818.3

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WARRANTY OBLIGATIONS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Warranty Obligations
Balance at beginning of period	$ 109.6	$ 121.7
Warranty expenses	54.0	52.0
Adjustment to existing accruals	(56.5)	(48.2)
Claims paid	(20.9)	(15.9)
Balance at end of period	$ 86.2	$ 109.6

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INVESTMENTS - Percentage Owned and Carrying Value (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Investment in Technip Energies	$ 292.4	$ 305.5
Techdof Brasil AS
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
Investment in Technip Energies	$ 276.9	234.7
Magma Global Limited
Schedule of Equity Method Investments [Line Items]
Ownership percentage	0.00%
Investment in Technip Energies	$ 0.0	51.4
Serimax Holdings SAS
Schedule of Equity Method Investments [Line Items]
Ownership percentage	20.00%
Investment in Technip Energies	$ 15.0	18.8
Other
Schedule of Equity Method Investments [Line Items]
Investment in Technip Energies	$ 0.5	$ 0.6
Magma Global Limited
Schedule of Equity Method Investments [Line Items]
Ownership percentage	25.00%
Serimax Holdings SAS
Schedule of Equity Method Investments [Line Items]
Ownership percentage	20.00%

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INVESTMENTS - Additional Information (Details) € / shares in Units, € in Millions, shares in Millions, $ in Millions										1 Months Ended	12 Months Ended
	Sep. 02, 2021 USD ($) shares	Sep. 02, 2021 EUR (€) tranche € / shares shares	Jul. 29, 2021 USD ($) shares	Jul. 29, 2021 EUR (€) € / shares shares	Apr. 27, 2021 USD ($) shares	Apr. 27, 2021 EUR (€) € / shares shares	Apr. 08, 2021 USD ($)	Mar. 31, 2021 USD ($) shares	Jan. 07, 2021 USD ($)	Oct. 31, 2021 USD ($)	Dec. 31, 2021 USD ($) shares	Dec. 31, 2021 EUR (€) shares	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Feb. 16, 2021
Schedule of Equity Method Investments [Line Items]
Income from equity affiliates											$ 0.6		$ 64.6	$ 59.8
Investment in Technip Energies											317.3		0.0
Income from investment in Technip Energies											$ 322.2		0.0	0.0
Private Placement
Schedule of Equity Method Investments [Line Items]
Sale, price per share (in Euro per share) | € / shares		€ 11.15		€ 11.20		€ 11.10
Private Placement | Share-based Payment Arrangement, Tranche One
Schedule of Equity Method Investments [Line Items]
Equity securities, number of shares sold (in shares) | shares											8.6	8.6
Proceeds from sale											$ 114.4	€ 96.3
Private Placement | Share-based Payment Arrangement, Tranche Two
Schedule of Equity Method Investments [Line Items]
Equity securities, number of shares sold (in shares) | shares											9.0	9.0
Proceeds from sale											$ 116.4	€ 99.9
BPI France
Schedule of Equity Method Investments [Line Items]
Business combination, consideration transferred									$ 200.0
Subsea
Schedule of Equity Method Investments [Line Items]
Income from equity affiliates													$ 64.6	$ 59.8
Serimax Holdings SAS
Schedule of Equity Method Investments [Line Items]
Ownership percentage											20.00%
Technip Energies
Schedule of Equity Method Investments [Line Items]
Ownership percentage															49.90%
Purchased shares (in shares) | shares								7.5
Purchased value							$ 100.0	$ 100.0
Equity securities, number of shares sold (in shares) | shares											21.9	21.9
Percentage of share capital											12.20%
Number of sale tranches | tranche		2
Technip Energies | Concurrent Sale To Technip Energies
Schedule of Equity Method Investments [Line Items]
Proceeds from sale					$ 24.2	€ 20.0
Technip Energies | Private Placement
Schedule of Equity Method Investments [Line Items]
Equity securities, number of shares sold (in shares) | shares	17.6	17.6	16.0	16.0	25.0	25.0
Proceeds from sale	$ 231.5	€ 196.2	$ 213.1	€ 179.2	$ 335.2	€ 277.5
Lock up period	60 days	60 days	60 days	60 days
Technip Energies | Technip Energies N.V. | Concurrent Sale To Technip Energies
Schedule of Equity Method Investments [Line Items]
Sale, price per share (in Euro per share) | € / shares						€ 11.10
Technip Energies | Technip Energies N.V. | Private Placement
Schedule of Equity Method Investments [Line Items]
Equity securities, number of shares sold (in shares) | shares					1.8	1.8
Technip Energies | Technip Energies N.V. | Private Placement
Schedule of Equity Method Investments [Line Items]
Percentage of share capital		10.00%		9.00%		14.00%
Technip Energies | Technip Energies N.V. | Technip Energies N.V. | Concurrent Sale To Technip Energies
Schedule of Equity Method Investments [Line Items]
Percentage of share capital						1.00%
Magma Global Limited
Schedule of Equity Method Investments [Line Items]
Ownership percentage											25.00%
Payments to acquire equity method investments										$ 64.0

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RELATED PARTY TRANSACTIONS - Trade Receivables (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Trade receivables	$ 29.7	$ 38.0
Equinor ASA | Director
Related Party Transaction [Line Items]
Trade receivables	0.0	24.1
Dofcon Navegacao | Equity Method Investee
Related Party Transaction [Line Items]
Trade receivables	22.7	4.2
Techdof Brasil AS | Equity Method Investee
Related Party Transaction [Line Items]
Trade receivables	4.5	8.0
Others | Others
Related Party Transaction [Line Items]
Trade receivables	$ 2.5	$ 1.7

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RELATED PARTY TRANSACTIONS - Trade Payables (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Trade payables	$ 5.5	$ 4.6
Crescent Energy | Director
Related Party Transaction [Line Items]
Trade payables	2.7	0.0
Dofcon Navegacao | Equity Method Investee
Related Party Transaction [Line Items]
Trade payables	0.0	1.5
Arkema S.A. | Equity Method Investee
Related Party Transaction [Line Items]
Trade payables	0.9	0.5
Others | Others
Related Party Transaction [Line Items]
Trade payables	$ 1.9	$ 2.6

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RELATED PARTY TRANSACTIONS - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Dofcon Brasil AS | Equity Method Investee
Related Party Transaction [Line Items]
Note receivables	$ 12.6	$ 37.6

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RELATED PARTY TRANSACTIONS - Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Revenue	$ 39.7	$ 152.7	$ 110.1
Equinor ASA | Director
Related Party Transaction [Line Items]
Revenue	0.0	119.6	0.0
Anadarko Petroleum Company | Director
Related Party Transaction [Line Items]
Revenue	0.0	0.0	67.1
TOP CV | Equity Method Investee
Related Party Transaction [Line Items]
Revenue	0.0	0.0	11.9
Dofcon Navegacao | Equity Method Investee
Related Party Transaction [Line Items]
Revenue	9.9	3.4	8.4
Techdof Brasil AS | Equity Method Investee
Related Party Transaction [Line Items]
Revenue	15.8	11.2	8.3
Others | Others
Related Party Transaction [Line Items]
Revenue	$ 14.0	$ 18.5	$ 14.4

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RELATED PARTY TRANSACTIONS - Expenses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Expenses	$ 65.4	$ 77.1	$ 54.7
Arkema S.A. | Director
Related Party Transaction [Line Items]
Expenses	3.8	1.5	3.8
Serimax Holdings SAS | Equity Method Investee
Related Party Transaction [Line Items]
Expenses	7.6	0.4	17.7
Magma Global Limited | Equity Method Investee
Related Party Transaction [Line Items]
Expenses	8.8	14.0	7.3
Jumbo Shipping | Director
Related Party Transaction [Line Items]
Expenses		16.0	4.5
Dofcon Navegacao | Equity Method Investee
Related Party Transaction [Line Items]
Expenses	26.7	24.0	1.8
Altus Intervention | Director
Related Party Transaction [Line Items]
Expenses		3.6	1.8
Others | Others
Related Party Transaction [Line Items]
Expenses	$ 18.5	$ 17.6	$ 17.8

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PROPERTY, PLANT AND EQUIPMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	$ 4,801.2	$ 4,910.4
Accumulated depreciation	(2,204.0)	(2,154.2)
Property, plant and equipment, net	2,597.2	2,756.2
Depreciation expense	291.3	308.7	$ 363.0
Land and land improvements
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	79.4	80.0
Buildings
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	471.6	514.6
Vessels
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	1,979.0	1,968.1
Machinery and equipment
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	1,849.0	1,871.8
Office fixtures and furniture
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	121.9	125.4
Construction in process
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	110.5	147.3
Other
Property, Plant and Equipment [Abstract]
Property, plant and equipment, gross	$ 189.8	$ 203.2

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GOODWILL AND INTANGIBLE ASSETS - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Goodwill [Line Items]
Goodwill, impairment charges			$ 3,083.4	$ 1,988.7
Amortization		$ 94.1	103.4	$ 104.7
Amortization expense, next 12 months		87.0
Amortization expense, year two		87.0
Amortization expense, year three		87.0
Amortization expense, year four		87.0
Amortization expense, year five		87.0
Amortization expense, Thereafter		$ 351.0
Subsea
Goodwill [Line Items]
Goodwill, impairment charges	$ 2,747.5		2,747.5
Surface Technologies
Goodwill [Line Items]
Goodwill, impairment charges	$ 335.9		$ 335.9

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GOODWILL AND INTANGIBLE ASSETS - Carrying Amount of Goodwill (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
Goodwill [Roll Forward]
Beginning balance	$ 3,128.5	$ 3,128.5
Impairments		(3,083.4)	$ (1,988.7)
Translation		(45.1)
Ending balance			3,128.5
Subsea
Goodwill [Roll Forward]
Beginning balance	2,792.8	2,792.8
Impairments	(2,747.5)	(2,747.5)
Translation		(45.3)
Ending balance			2,792.8
Surface Technologies
Goodwill [Roll Forward]
Beginning balance	335.7	335.7
Impairments	$ (335.9)	(335.9)
Translation		$ 0.2
Ending balance			$ 335.7

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GOODWILL AND INTANGIBLE ASSETS - Components Of Intangible Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Acquired Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 1,389.2	$ 1,344.4
Accumulated Amortization	575.5	493.1
Acquired technology
Acquired Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	247.0	247.1
Accumulated Amortization	122.4	98.1
Customer relationships
Acquired Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	285.4	285.3
Accumulated Amortization	142.9	114.4
Licenses, patents and trademarks
Acquired Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	694.6	690.3
Accumulated Amortization	220.7	189.3
Software
Acquired Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	108.2	111.3
Accumulated Amortization	84.8	81.1
Other
Acquired Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	54.0	10.4
Accumulated Amortization	$ 4.7	$ 10.2

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DEBT - Schedule Of Long-Term Debt (Details) € in Millions, $ in Millions	Dec. 31, 2021 USD ($)	Jan. 29, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2020 EUR (€)	Dec. 31, 2016	Oct. 31, 2013	Jun. 30, 2012
Debt Instrument [Line Items]
Interest rate, stated percentage			3.45%	3.45%	0.875%
Unamortized debt issuance costs and discounts	$ (22.3)		$ (12.8)
Total debt	2,004.9		3,460.2
Less: current borrowings	277.6		624.7
Long-term debt	1,727.3		$ 2,835.5
5.75% 2020 Private placement notes due 2025
Debt Instrument [Line Items]
Interest rate, stated percentage			5.75%	5.75%
Commercial paper
Debt Instrument [Line Items]
Long-term debt, gross	0.0		$ 1,043.7
Synthetic bonds due 2021
Debt Instrument [Line Items]
Long-term debt, gross	$ 0.0	$ 542.4	$ 551.2
Senior notes | 3.45% Senior Notes due 2022
Debt Instrument [Line Items]
Interest rate, stated percentage	3.45%	3.45%	3.45%	3.45%
Long-term debt, gross	$ 0.0	$ 500.0	$ 500.0
Senior notes | 6.50% Senior notes due 2026
Debt Instrument [Line Items]
Interest rate, stated percentage	6.50%		6.50%	6.50%
Long-term debt, gross	$ 633.1		$ 0.0
Unsecured debt | 3.40% 2012 Private placement notes due 2022
Debt Instrument [Line Items]
Interest rate, stated percentage	3.40%		3.40%	3.40%			3.40%
Long-term debt, gross	$ 169.9		$ 184.0
Unsecured debt | 3.15% 2013 Private placement notes due 2023
Debt Instrument [Line Items]
Interest rate, stated percentage	3.15%		3.15%	3.15%		3.15%
Long-term debt, gross	$ 288.8		$ 312.9
Unsecured debt | 5.75% 2020 Private placement notes due 2025
Debt Instrument [Line Items]
Interest rate, stated percentage	5.75%		5.75%	5.75%
Long-term debt, gross	$ 226.5		$ 245.4	€ 200
Unsecured debt | 4.00% 2012 Private placement notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	4.00%		4.00%	4.00%			4.00%
Long-term debt, gross	$ 84.9		$ 92.0
Unsecured debt | 4.00% 2012 Private placement notes due 2032
Debt Instrument [Line Items]
Interest rate, stated percentage	4.00%		4.00%	4.00%			4.00%
Long-term debt, gross	$ 113.3		$ 122.7
Unsecured debt | 3.75% 2013 Private placement notes due 2033
Debt Instrument [Line Items]
Interest rate, stated percentage	3.75%		3.75%	3.75%		3.75%
Long-term debt, gross	$ 113.3		$ 122.7
Bank borrowings and other
Debt Instrument [Line Items]
Long-term debt, gross	$ 397.4		$ 298.4

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DEBT - Maturities of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Disclosure [Abstract]
Total debt	$ 2,004.9	$ 3,460.2
Less than 1 year	277.6
1-3 years	402.1
3-5 years	942.9
After 5 years	$ 382.3

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DEBT - Debt Financing Transactions in Connection with the Spin-off (Details)			12 Months Ended
	Feb. 16, 2021 USD ($)	Jan. 29, 2021 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	May 19, 2020 EUR (€)	Jan. 17, 2017 USD ($)	Dec. 31, 2016 EUR (€)
Line of Credit Facility [Line Items]
Debt instrument, face amount | €								€ 450,000,000
Interest rate, stated percentage				3.45%				0.875%
Loss on early extinguishment of debt			$ (61,900,000)	$ 0	$ 0
Senior notes | Notes due 2026 6.50%
Line of Credit Facility [Line Items]
Debt instrument, face amount		$ 1,000,000,000
Interest rate, stated percentage		6.50%	6.50%	6.50%
Senior notes | 3.45% Senior Notes due 2022
Line of Credit Facility [Line Items]
Interest rate, stated percentage		3.45%	3.45%	3.45%
Long-term debt, gross		$ 500,000,000	$ 0	$ 500,000,000.0
Loss on early extinguishment of debt		23,500,000
Synthetic bonds due 2021
Line of Credit Facility [Line Items]
Long-term debt, gross		$ 542,400,000	0	551,200,000
Commercial paper
Line of Credit Facility [Line Items]
Long-term debt, gross			0	$ 1,043,700,000
Commercial paper | U.S. dollar
Line of Credit Facility [Line Items]
Maximum borrowing capacity			$ 830,900,000
Revolving Credit Facility | Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,000,000,000					€ 500,000,000	$ 2,500,000,000
Debt instrument, term	3 years
Revolving Credit Facility | Letter of credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 450,000,000

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DEBT - Credit Facilities and Debt (Details)		12 Months Ended
	Feb. 16, 2021 USD ($)	Dec. 31, 2021 USD ($) tender_offer	Jan. 29, 2021 USD ($)	Dec. 31, 2020 USD ($)	May 19, 2020 EUR (€)	Jan. 17, 2017 USD ($)	Dec. 31, 2016 EUR (€)
Line of Credit Facility [Line Items]
Debt instrument, face amount | €							€ 450,000,000
Interest rate, stated percentage				3.45%			0.875%
Commercial paper outstanding debt				$ 225,800,000
Senior notes | Note 2021
Line of Credit Facility [Line Items]
Debt issuance costs	$ 34,800,000	$ 8,900,000
Debt issuance costs			$ 25,700,000
Number of tender offers | tender_offer		2
Tender purchased for cash		$ 366,900,000
Cash paid premium to holders		$ 29,500,000
Senior notes | Notes due 2026 6.50%
Line of Credit Facility [Line Items]
Debt instrument, face amount			$ 1,000,000,000
Interest rate, stated percentage		6.50%	6.50%	6.50%
Senior notes | Notes due 2022 3.45%
Line of Credit Facility [Line Items]
Long-term debt, gross				$ 500,000,000
Commercial paper
Line of Credit Facility [Line Items]
Long-term debt, gross		$ 0		$ 1,043,700,000
Weighted average interest rate				0.34%
Revolving Credit Facility | Minimum | Euro loan
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate		2.50%
Revolving Credit Facility | Minimum | Base rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate		1.50%
Revolving Credit Facility | Maximum | Euro loan
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate		3.50%
Revolving Credit Facility | Maximum | Base rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate		2.50%
Revolving Credit Facility | Letter of credit
Line of Credit Facility [Line Items]
Letters of credit outstanding amount		$ 16,700,000
Line of credit facility borrowing capacity		$ 983,300,000
Revolving Credit Facility | Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,000,000,000				€ 500,000,000	$ 2,500,000,000
Debt instrument, term	3 years
Revolving Credit Facility | Letter of credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 450,000,000

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Debt - 2020 Issuance (Details) € in Millions, $ in Millions	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2020 EUR (€)	Dec. 31, 2016
Line of Credit Facility [Line Items]
Interest rate, stated percentage		3.45%	3.45%	0.875%
5.75% 2020 Private placement notes due 2025
Line of Credit Facility [Line Items]
Interest rate, stated percentage		5.75%	5.75%
5.75% 2020 Private placement notes due 2025 | Unsecured debt
Line of Credit Facility [Line Items]
Long-term debt, gross	$ 226.5	$ 245.4	€ 200
Interest rate, stated percentage	5.75%	5.75%	5.75%
4.50% Notes due
Line of Credit Facility [Line Items]
Interest rate, stated percentage		4.50%	4.50%

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Debt - 2013 Issuances (Details)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2016 EUR (€)	Oct. 31, 2013 EUR (€) tranche	Jun. 30, 2012 EUR (€) tranche
Line of Credit Facility [Line Items]
Debt instrument, face amount			€ 450,000,000
Interest rate, stated percentage		3.45%	0.875%
Unsecured debt
Line of Credit Facility [Line Items]
Debt instrument, face amount				€ 355,000,000	€ 325,000,000
Number of tranches | tranche				3	3
Unsecured debt | 3.75% 2013 Private placement notes due 2033
Line of Credit Facility [Line Items]
Debt instrument, face amount				€ 100,000,000
Interest rate, stated percentage	3.75%	3.75%		3.75%
Unsecured debt | 3.15% 2013 Private placement notes due 2023
Line of Credit Facility [Line Items]
Debt instrument, face amount				€ 130,000,000
Interest rate, stated percentage	3.15%	3.15%		3.15%
Unsecured debt | 3.15% 2013 Private placement notes due 2023
Line of Credit Facility [Line Items]
Debt instrument, face amount				€ 125,000,000
Interest rate, stated percentage				3.15%

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Debt - 2012 Issuances (Details) £ in Millions, $ in Millions	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Jan. 31, 2019 USD ($)	Dec. 31, 2017	Dec. 31, 2016 EUR (€)	Dec. 31, 2016 GBP (£)	Oct. 31, 2013 EUR (€) tranche	Jun. 30, 2012 EUR (€) tranche
Line of Credit Facility [Line Items]
Debt instrument, face amount | €					€ 450,000,000
Interest rate, stated percentage		3.45%			0.875%	0.875%
Sale Leaseback Transaction
Line of Credit Facility [Line Items]
Sale leaseback transaction, historical cost | $			$ 116.8
Long-term debt, gross | $			$ 96.2
Unsecured debt
Line of Credit Facility [Line Items]
Debt instrument, face amount | €							€ 355,000,000	€ 325,000,000
Number of tranches | tranche							3	3
Unsecured debt | 3.40% 2012 Private placement notes due 2022
Line of Credit Facility [Line Items]
Debt instrument, face amount | €								€ 150,000,000
Interest rate, stated percentage	3.40%	3.40%						3.40%
Long-term debt, gross | $	$ 169.9	$ 184.0
Unsecured debt | 4.00% 2012 Private placement notes due 2027
Line of Credit Facility [Line Items]
Debt instrument, face amount | €								€ 75,000,000
Interest rate, stated percentage	4.00%	4.00%						4.00%
Long-term debt, gross | $	$ 84.9	$ 92.0
Unsecured debt | 4.00% 2012 Private placement notes due 2032
Line of Credit Facility [Line Items]
Debt instrument, face amount | €								€ 100,000,000
Interest rate, stated percentage	4.00%	4.00%						4.00%
Long-term debt, gross | $	$ 113.3	$ 122.7
Term loan
Line of Credit Facility [Line Items]
Debt instrument, face amount | £						£ 160.0
Interest rate, stated percentage				2.813%

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STOCKHOLDERS’ EQUITY - Narrative (Details) € in Millions		12 Months Ended
	Nov. 27, 2019 £ / shares shares	Dec. 31, 2021 USD ($) shares	Dec. 31, 2020 USD ($) shares	Dec. 31, 2020 EUR (€) shares	Dec. 31, 2019 USD ($)	Dec. 31, 2019 EUR (€)	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Stockholders' Equity Note [Abstract]
Cash dividends declared		$ 0	$ 59,200,000	€ 59.2	$ 232,800,000	€ 232.8
Stock redeemed (shares) | shares	50,000
Shares redemption price (in Pound Sterling per share) | £ / shares	£ 1
Canceled shares (in shares) | shares	1	0	0	0
Price of deferred shares canceled (Pound Sterling per share) | £ / shares	£ 1
Stock repurchase program, authorized amount | $		$ 207,800,000					$ 300,000,000	$ 500,000,000
Issuance of ordinary shares | $		$ 0	$ 0		$ (92,700,000)

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STOCKHOLDERS’ EQUITY - Capital Stock Activity (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Number of shares beginning balance (in shares)	449.5
Number of shares ending balance (in shares)	450.7	449.5
Ordinary Shares Issued
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Number of shares beginning balance (in shares)	449.5	447.1	450.5
Stock awards (in shares)	1.2	2.4	0.6
Treasury stock purchases (in shares)			0.0
Treasury stock cancellation (in shares)			(4.0)
Net stock purchased for employee benefit trust (in shares)			0.0
Number of shares ending balance (in shares)	450.7	449.5	447.1
Ordinary Shares Held in  Employee Benefit Trust
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Number of shares beginning balance (in shares)	0.0	0.0	0.1
Stock awards (in shares)	0.0	0.0	0.0
Treasury stock purchases (in shares)			0.0
Treasury stock cancellation (in shares)			0.0
Net stock purchased for employee benefit trust (in shares)			(0.1)
Number of shares ending balance (in shares)	0.0	0.0	0.0
Treasury Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Number of shares beginning balance (in shares)	0.0	0.0	0.0
Stock awards (in shares)	0.0	0.0	0.0
Treasury stock purchases (in shares)			4.0
Treasury stock cancellation (in shares)			(4.0)
Net stock purchased for employee benefit trust (in shares)			0.0
Number of shares ending balance (in shares)	0.0	0.0	0.0

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STOCKHOLDERS’ EQUITY - Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	$ 4,214.3	$ 7,688.1	$ 10,388.9
Reclassification adjustment for net (gains) losses included in net income, net of tax	0.0	0.0	(12.0)
Other comprehensive income (loss), net of tax	84.8	(214.4)	(48.5)
Spin-off of Technip Energies	(897.2)
Ending balance	3,418.4	4,214.3	7,688.1
Foreign Currency Translation
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(1,401.2)	(1,230.1)
Other comprehensive income (loss) before reclassifications, net of tax	29.2	(171.1)
Reclassification adjustment for net (gains) losses included in net income, net of tax		0.0
Other comprehensive income (loss), net of tax	29.2	(171.1)
Spin-off of Technip Energies	213.6
Ending balance	(1,158.4)	(1,401.2)	(1,230.1)
Hedging
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	34.0	(5.8)
Other comprehensive income (loss) before reclassifications, net of tax	(19.8)	26.8
Reclassification adjustment for net (gains) losses included in net income, net of tax	(11.8)	13.0
Other comprehensive income (loss), net of tax	(31.6)	39.8
Spin-off of Technip Energies	(19.7)
Ending balance	(17.3)	34.0	(5.8)
Defined Pension  and Other Post-Retirement Benefits
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(255.3)	(171.6)
Other comprehensive income (loss) before reclassifications, net of tax	70.8	(92.9)
Reclassification adjustment for net (gains) losses included in net income, net of tax	18.0	9.2
Other comprehensive income (loss), net of tax	88.8	(83.7)
Spin-off of Technip Energies	37.2
Ending balance	(129.3)	(255.3)	(171.6)
Accumulated Other Comprehensive  Loss Attributable to TechnipFMC plc
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(1,622.5)	(1,407.5)
Other comprehensive income (loss) before reclassifications, net of tax	80.2	(237.2)
Reclassification adjustment for net (gains) losses included in net income, net of tax	6.2	22.2
Other comprehensive income (loss), net of tax	86.4	(215.0)
Spin-off of Technip Energies	231.1
Ending balance	(1,305.0)	(1,622.5)	(1,407.5)
Accumulated Other Comprehensive  Loss Attributable to Non-Controlling Interest
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(4.1)	(4.7)
Other comprehensive income (loss) before reclassifications, net of tax	(1.6)	0.6
Reclassification adjustment for net (gains) losses included in net income, net of tax	0.0	0.0
Other comprehensive income (loss), net of tax	(1.6)	0.6
Spin-off of Technip Energies	0.0
Ending balance	$ (5.7)	$ (4.1)	$ (4.7)

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STOCKHOLDERS’ EQUITY - Reclassification Out of Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	$ 46.6	$ 25.1	$ (181.6)
Revenue	6,403.5	6,530.6	6,950.2
Selling, general and administrative expense	(644.9)	(724.1)	(795.7)
Income (loss) before income taxes	198.1	(3,498.7)	(2,571.1)
Provision (benefit) for income taxes	111.1	19.4	79.0
Net income (loss)	14.4	(3,237.9)	(2,412.1)
Accumulated foreign currency adjustment attributable to parent | Amount Reclassified out of Accumulated Other Comprehensive Loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	0.0	0.0	12.0
Defined pension and other post-retirement benefits | Amount Reclassified out of Accumulated Other Comprehensive Loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Settlements and curtailments	(3.3)	(2.2)	(0.3)
Amortization of actuarial gain (loss)	(18.2)	(9.0)	(2.5)
Amortization of prior service credit (cost)	(0.5)	(1.2)	(1.0)
Income (loss) before income taxes	(22.0)	(12.4)	(3.8)
Provision (benefit) for income taxes	(4.0)	(3.2)	(0.8)
Net income (loss)	(18.0)	(9.2)	(3.0)
Foreign exchange contracts | Hedging | Amount Reclassified out of Accumulated Other Comprehensive Loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income (loss)	11.8	(13.0)	(18.2)
Cash flow hedging | Foreign exchange contracts | Hedging | Amount Reclassified out of Accumulated Other Comprehensive Loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	32.9	(4.4)	(9.1)
Revenue	(29.7)	(83.7)	(26.6)
Costs of sales	10.7	68.5	12.0
Selling, general and administrative expense	0.2	(0.4)	0.0
Income (loss) before income taxes	14.1	(20.0)	(23.7)
Provision (benefit) for income taxes	$ 2.3	$ (7.0)	$ (5.5)

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SHARE-BASED COMPENSATION - Narrative (Details) - USD ($)		12 Months Ended
	Jan. 11, 2017	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Feb. 17, 2021	Feb. 16, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized (in shares)					15,200,000
Shares available for grant (shares)		7,800,000				11,900,000
Share-based compensation expense		$ 26,800,000	$ 38,300,000	$ 44,400,000
Share-based Compensation Arrangement by Restricted Stock Units, Vested in Period, Fair Value		25,100,000	51,800,000	10,200,000
Share-based Compensation Arrangement by Performance Share Units, Vested in Period, Fair Value		3,400,000	43,200,000	13,300,000
Stock options outstanding, intrinsic value		0
Stock options exercisable, intrinsic value		0
Proceeds from stock options exercised		0	0	0
Stock option exercised during period, intrinsic value		$ 0	$ 0	$ 0
TechnipFMC plc Incentive Award Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized (in shares)	24,100,000
Vesting period	3 years
Number of stock units outstanding to active and nonemployee directors (in units)		184,600
Nonemployee Director | TechnipFMC plc Incentive Award Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	1 year
Nonemployee Director | Minimum | TechnipFMC plc Incentive Award Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Eligible grant period		1 year
Nonemployee Director | Maximum | TechnipFMC plc Incentive Award Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Eligible grant period		10 years
Restricted share units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense		$ 5,200,000
Share option awards | TechnipFMC plc Incentive Award Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	3 years

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SHARE-BASED COMPENSATION - Compensation Expenses Under Stock Based Compensation Plan (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 26.8	$ 38.3	$ 44.4
Income tax benefits related to share-based compensation expense	7.2	$ 10.3	$ 12.0
Restricted share units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 5.2

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SHARE-BASED COMPENSATION - Unrecognized Compensation Cost, Nonvested Awards (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Share-based Payment Arrangement [Abstract]
Stock-based compensation expense not yet recognized (in millions)	$ 51.6
Weighted-average recognition period (in years)	1 year 4 months 24 days

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SHARE-BASED COMPENSATION - Summary Of Changes In Nonvested Stock Units (Details)	12 Months Ended
	Dec. 31, 2021 $ / shares shares
Shares
Adjustment due to the Spin-off | shares	(2,490,300)
Weighted-Average  Grant Date  Fair Value
Adjustment due to the Spin-off (in dollar per share) | $ / shares	$ 0
Restricted share units
Shares
Nonvested at beginning of period (in shares) | shares	6,121,900
Granted (in shares) | shares	2,893,000
Vested (in shares) | shares	(667,100)
Cancelled/forfeited (in shares) | shares	(882,600)
Adjustment due to the Spin-off | shares	(2,124,300)
Nonvested at period end (in shares) | shares	9,589,500
Weighted-Average  Grant Date  Fair Value
Granted, weighted-average grant date fair value, beginning of period (in dollars per share) | $ / shares	$ 18.43
Granted, weighted-average grant date fair value (in dollars per share) | $ / shares	7.97
Vested, weighted average grant date fair value (in dollars per share) | $ / shares	37.57
Cancelled/forfeited, weighted-average grant date fair value (in dollars per share) | $ / shares	13.75
Adjustment due to the Spin-off (in dollar per share) | $ / shares	12.37
Granted, weighted-average grant date fair value, period end ( in dollars per share) | $ / shares	$ 11.35
Performance Share Units
Shares
Nonvested at beginning of period (in shares) | shares	4,840,700
Granted (in shares) | shares	2,426,200
Vested (in shares) | shares	(111,300)
Cancelled/forfeited (in shares) | shares	(1,723,200)
Adjustment due to the Spin-off | shares	(3,122,800)
Nonvested at period end (in shares) | shares	2,309,600
Weighted-Average  Grant Date  Fair Value
Granted, weighted-average grant date fair value, beginning of period (in dollars per share) | $ / shares	$ 17.55
Granted, weighted-average grant date fair value (in dollars per share) | $ / shares	11.50
Vested, weighted average grant date fair value (in dollars per share) | $ / shares	30.42
Cancelled/forfeited, weighted-average grant date fair value (in dollars per share) | $ / shares	16.03
Adjustment due to the Spin-off (in dollar per share) | $ / shares	12.37
Granted, weighted-average grant date fair value, period end ( in dollars per share) | $ / shares	$ 13.26

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SHARE-BASED COMPENSATION - Weighted Average Assumptions (Details) - $ / shares shares in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Feb. 17, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average fair value	$ 11.50	$ 10.02	$ 29.04
Expected volatility	62.70%	38.30%	34.00%
Risk-free interest rate	0.35%	0.40%	2.42%
Expected term in years	2 years 10 months 24 days	3 years	3 years
Common stock shares authorized for awards (in shares)				15.2
Share option awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average fair value			$ 5.64
Expected volatility			32.50%
Risk-free interest rate			2.50%
Expected dividend yield			2.60%
Expected term in years			6 years 6 months

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Share-Based Compensation Share-Based Compensation - Performance Share Assumptions (Details) - $ / shares shares in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Feb. 17, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average fair value	$ 11.50	$ 10.02	$ 29.04
Expected volatility	62.70%	38.30%	34.00%
Risk-free interest rate	0.35%	0.40%	2.42%
Expected term in years	2 years 10 months 24 days	3 years	3 years
Common stock shares authorized for awards (in shares)				15.2
Share option awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average fair value			$ 5.64
Expected volatility			32.50%
Risk-free interest rate			2.50%
Expected dividend yield			2.60%
Expected term in years			6 years 6 months

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SHARE-BASED COMPENSATION - Summary of Option Transactions (Details) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Stock Option Activity
Number of options outstanding, beginning balance	4,598,400
Number of options granted	0	0
Number of options exercised	0
Number of options cancelled	(532,000.0)
Adjustment due to the Spin-off	(2,490,300)
Number of options outstanding, ending balance	1,576,100	4,598,400
Stock Option Weighted Average Exercise Price
Options outstanding, weighted average exercise price per share, beginning balance (in dollars per share)	$ 29.77
Options granted, weighted average exercise price per share (in dollars per share)	0
Options exercised, weighted average exercise price per share (in dollars per share)	0
Options cancelled, weighted average exercise price per share (in dollars per share)	24.10
Options adjustment due spin-off, weighted average exercise price per share (in dollars per share)	0
Options outstanding, weighted average exercise price per share, ending balance (in dollars per share)	$ 20.17	$ 29.77
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Options outstanding, Weighted average remaining contractual term (in years)	6 years 3 months 18 days	4 years 2 months 12 days
Options exercisable, number of options (in shares)	939,300
Options exercisable, weighted average exercise price per share (in dollars per share)	$ 22.99
Options exercisable, Weighted average remaining contractual term (in years)	5 years 7 months 6 days

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SHARE-BASED COMPENSATION - Outstanding and Exercisable Options (Details)	12 Months Ended
	Dec. 31, 2021 $ / shares shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, number of options (in options) | shares	1,576,100
Options outstanding, weighted average remaining (in years)	6 years 3 months 18 days
Options outstanding, weighted average exercise price (in dollars per option)	$ 20.17
Options exercisable, number of options (in options) | shares	939,300
Options exercisable, weighted average exercise price (in dollars per option)	$ 22.99
$16.00-$19.00
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, number of options (in options) | shares	636,700
Options outstanding, weighted average remaining (in years)	7 years 2 months 12 days
Options outstanding, weighted average exercise price (in dollars per option)	$ 16.46
$16.00-$19.00 | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, exercise price range, lower range limit	16.00
$16.00-$19.00 | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, exercise price range, lower range limit	$ 19.00
$20.00-$24.00
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, number of options (in options) | shares	721,200
Options outstanding, weighted average remaining (in years)	5 years 7 months 6 days
Options outstanding, weighted average exercise price (in dollars per option)	$ 22.28
Options exercisable, number of options (in options) | shares	721,200
Options exercisable, weighted average exercise price (in dollars per option)	$ 22.28
$20.00-$24.00 | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, exercise price range, lower range limit	20.00
$20.00-$24.00 | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, exercise price range, lower range limit	$ 24.00
$25.00-$26.00
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, number of options (in options) | shares	218,200
Options outstanding, weighted average remaining (in years)	5 years 7 months 6 days
Options outstanding, weighted average exercise price (in dollars per option)	$ 25.32
Options exercisable, number of options (in options) | shares	218,100
Options exercisable, weighted average exercise price (in dollars per option)	$ 25.32
$25.00-$26.00 | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, exercise price range, lower range limit	25.00
$25.00-$26.00 | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding, exercise price range, lower range limit	$ 26.00

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IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES - Restructuring, Settlement and Impairment Provisions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Restructuring and Impairment [Line Items]
Total impairment, restructuring and other expenses	$ 66.7	$ 3,402.0	$ 2,456.7
Subsea
Restructuring and Impairment [Line Items]
Total impairment, restructuring and other expenses	53.5	2,957.5	1,748.4
Surface Technologies
Restructuring and Impairment [Line Items]
Total impairment, restructuring and other expenses	7.6	440.2	704.2
Corporate and other
Restructuring and Impairment [Line Items]
Total impairment, restructuring and other expenses	$ 5.6	$ 4.3	$ 4.1

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IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES - Goodwill and Long-Lived Assets Impairments Goodwill and Long-Lived Assets Impairments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Restructuring and Impairment [Line Items]
Impairments	$ 49.1	$ 3,273.8	$ 2,480.3
Subsea
Restructuring and Impairment [Line Items]
Impairments	44.2	2,854.5	1,794.8
Surface Technologies
Restructuring and Impairment [Line Items]
Impairments	1.9	419.3	685.5
Corporate and other
Restructuring and Impairment [Line Items]
Impairments	$ 3.0	$ 0.0	$ 0.0

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IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Restructuring and Impairment [Line Items]
Impairment of property, plant and equipment		$ 24.9	$ 190.4	$ 491.6
Goodwill, impairment charges			3,083.4	1,988.7
Operating lease right-of-use assets		$ 24.2	20.0
Subsea
Restructuring and Impairment [Line Items]
Impairment of property, plant and equipment			88.4	153.8
Goodwill, impairment charges	$ 2,747.5		2,747.5
Surface Technologies
Restructuring and Impairment [Line Items]
Impairment of property, plant and equipment			82.0	$ 168.9
Goodwill, impairment charges	$ 335.9		$ 335.9

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IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES - Restructuring and Other Expenses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Restructuring and Impairment [Line Items]
Restructuring and other charges	$ 17.6	$ 70.4	$ (23.6)
COVID-19 expenses		57.8
Subsea
Restructuring and Impairment [Line Items]
Restructuring and other charges	9.3	52.9	(46.4)
COVID-19 expenses		50.1
Surface Technologies
Restructuring and Impairment [Line Items]
Restructuring and other charges	5.7	13.2	18.7
COVID-19 expenses		7.7
Corporate and other
Restructuring and Impairment [Line Items]
Restructuring and other charges	$ 2.6	4.3	$ 4.1
COVID-19 expenses		$ 0.0

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COMMITMENTS AND CONTINGENT LIABILITIES - Narrative (Details) $ in Millions		1 Months Ended	12 Months Ended
	Jun. 25, 2019 USD ($) count	Sep. 30, 2019 USD ($)	Dec. 31, 2021 USD ($)
Guarantor Obligations [Line Items]
Litigation settlement, amount awarded to other party	$ 301.3
Deferred Prosecution Agreement period	3 years
Litigation settlement, expense		$ 5.1
Estimated litigation liability			$ 70.0
Technip USA, Inc.
Guarantor Obligations [Line Items]
Number of guilty counts | count	1
Brazilian authorities
Guarantor Obligations [Line Items]
Report submission period	2 years
U.S. Authorities
Guarantor Obligations [Line Items]
Report submission period	3 years
Indirect guarantee of indebtedness
Guarantor Obligations [Line Items]
Guarantor obligations, term			5 years

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COMMITMENTS AND CONTINGENT LIABILITIES - Guarantees (Details) $ in Millions	Dec. 31, 2021 USD ($)
Guarantor Obligations [Line Items]
Maximum potential undiscounted payments	$ 1,246.4
Financial guarantees
Guarantor Obligations [Line Items]
Maximum potential undiscounted payments	177.4
Performance guarantees
Guarantor Obligations [Line Items]
Maximum potential undiscounted payments	$ 1,069.0

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INCOME TAXES - Domestic And Foreign Components Of Income Before Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
United States	$ (288.2)	$ (2,169.3)	$ (2,376.4)
Outside United States	486.3	(1,329.4)	(194.7)
Income (loss) from continuing operations before income taxes	$ 198.1	$ (3,498.7)	$ (2,571.1)

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INCOME TAXES - Provision For Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current
United States	$ 0.2	$ (18.3)	$ 39.1
Outside United States	206.0	69.5	12.0
Total current income taxes	206.2	51.2	51.1
Deferred
United States	0.0	(2.8)	3.8
Outside United States	(95.1)	(29.0)	24.1
Total deferred income taxes	(95.1)	(31.8)	27.9
Provision for income taxes	$ 111.1	$ 19.4	$ 79.0

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INCOME TAXES - Deferred Tax Assets And Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Deferred tax assets attributable to
Accrued expenses	$ 173.0	$ 133.0
Capital loss	21.1	21.1
Non-deductible interest	95.4	77.0
Foreign tax credit carryforwards	136.5	134.4
Other tax credits	146.0	163.8
Net operating loss carryforwards	455.5	383.5
Inventories	1.2	16.6
Research and development credit	3.8	2.9
Foreign exchange	17.2	0.0
Provisions for pensions and other long-term employee benefits	31.9	66.1
Contingencies	38.3	2.9
Margin recognition on construction contracts	18.0	20.6
Leases	183.4	170.4
Other	5.4	0.6
Deferred tax assets	1,326.7	1,192.9
Valuation allowance	(935.5)	(815.1)
Deferred tax assets, net of valuation allowance	391.2	377.8
Deferred tax liabilities attributable to
Revenue in excess of billings on contracts accounted for under the percentage of completion method	32.2	33.6
U.S. tax on foreign subsidiaries’ undistributed earnings not indefinitely reinvested	0.0	4.2
Property, plant and equipment, intangibles and other assets	162.8	180.1
Foreign exchange	0.0	43.9
Leases	169.4	161.1
Deferred tax liabilities	364.4	422.9
Net deferred tax assets/(liabilities)	$ 26.8
Net deferred tax assets/(liabilities)		$ (45.1)

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INCOME TAXES - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax [Line Items]
Foreign tax credit carryforwards	$ 136.5	$ 134.4
Foreign earnings taxable as dividend	19.5		$ 21.4
Net operating loss	455.5
Operating loss estimated to be utilized against unrecognized tax benefits	23.5
Unrecognized tax benefits	32.5
Decrease in unrecognized tax benefits is reasonably possible	$ 14.3
Statutory income tax rate	19.00%	19.00%	19.00%
Related Party Transaction, Purchases from Related Party		$ 0.1
Accrued Interest and Penalties
Income Tax [Line Items]
Unrecognized tax benefits	$ 0.2	$ 0.6	$ 0.0

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INCOME TAXES - Schedule of net operating losses (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Income Tax Contingency [Line Items]
Non-Expiring	$ 288.0
Net Operating Loss	455.5	$ 383.5
2022 – 2026
Income Tax Contingency [Line Items]
Operating loss expiration	55.4
2027 – 2031
Income Tax Contingency [Line Items]
Operating loss expiration	42.0
2032 – 2042
Income Tax Contingency [Line Items]
Operating loss expiration	$ 70.1

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INCOME TAXES - Unrecognized Tax Benefits And Associated Interest And Penalties (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Unrecognized Tax Benefits [Roll Forward]
Unrecognized tax benefits, ending balance	$ 32.5
Federal, State and Foreign Tax
Unrecognized Tax Benefits [Roll Forward]
Unrecognized tax benefits, beginning balance	46.2	$ 57.6
Reductions for tax positions related to prior years	(15.2)	(7.9)
Reductions for tax positions related to current year		(2.9)
Reductions for tax positions related to current year	39.9
Reductions for tax positions due to settlements	(2.1)	(0.6)
Unrecognized tax benefits, ending balance	$ 68.8	$ 46.2

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INCOME TAXES - Reconciliation Of Effective Tax Rate (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Abstract]
Statutory income tax rate	19.00%	19.00%	19.00%
Foreign earnings subject to different tax rates	24.40%	1.30%	3.40%
Adjustments to prior year taxes	(52.40%)	(1.20%)	0.80%
Net change in unrecognized tax benefits	12.30%	0.00%	0.00%
Changes in valuation allowance	65.40%	(0.90%)	(7.20%)
Deferred tax asset/liability revaluation for tax rate change	(12.20%)	0.30%	(0.40%)
Impairments	0.00%	(19.50%)	(19.70%)
Non-deductible legal provision	0.00%	0.30%	1.10%
Other	(0.40%)	0.10%	(0.10%)
Effective income tax rate	56.10%	(0.60%)	(3.10%)

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Changes in Projected Benefit Obligations, Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Amounts recognized in balance sheet
Accrued pension and other post-retirement benefits, net of current portion	$ (113.4)	$ (268.4)
Other Post-retirement Benefits
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Projected benefit obligation, beginning balance	9.4	10.2
Service cost	0.0	0.0	$ 0.0
Interest cost	0.3	0.4	0.5
Actuarial (gain) loss	(0.7)	(0.2)
Settlements	0.0	0.0
Foreign currency exchange rate changes	(0.2)	(0.6)
Plan participants’ contributions	0.0	0.0
Benefits paid	(0.4)	(0.4)
Other	0.0	0.0
Projected benefit obligation, ending balance	8.4	9.4	10.2
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets, beginning balance	0.0	0.0
Actual return on plan assets	0.0	0.0
Company contributions	0.0	0.0
Foreign currency exchange rate changes	0.0	0.0
Settlements	0.0	0.0
Plan participants’ contributions	0.0	0.0
Benefits paid	0.0	0.0
Other	0.0	0.0
Fair value of plan assets, ending balance	0.0	0.0	0.0
Funded status of the plans (liability) as of December 31	(8.4)	(9.4)
Amounts recognized in balance sheet
Current portion of accrued pension and other post-retirement benefits	(0.6)	(0.7)
Accrued pension and other post-retirement benefits, net of current portion	(7.8)	(8.7)
Funded status as of December 31	(8.4)	(9.4)
Pre-tax amounts recognized in accumulated other comprehensive (income) loss
Unrecognized actuarial loss	0.4	1.3
Unrecognized prior service cost	0.0	0.0
Accumulated other comprehensive (income) loss as of December 31	0.4	1.3
Plans with underfunded or non-funded projected benefit obligation
Aggregate projected benefit obligation	8.4	9.4
Aggregate fair value of plan assets	0.0	0.0
Aggregate accumulated benefit obligation	0.0	0.0
Aggregate fair value of plan assets	0.0	0.0
U.S. | Pensions
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Accumulated benefit obligation	653.6
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Projected benefit obligation, beginning balance	684.7
Service cost	0.0	0.0	0.0
Interest cost	18.0	22.2	25.6
Actuarial (gain) loss	7.1
Settlements	(22.6)
Foreign currency exchange rate changes	0.0
Plan participants’ contributions	0.0
Benefits paid	(33.6)
Other	0.0
Projected benefit obligation, ending balance	653.6	684.7
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets, beginning balance	483.7
Actual return on plan assets	61.1
Company contributions	28.9
Foreign currency exchange rate changes	0.0
Settlements	(22.6)
Plan participants’ contributions	0.0
Benefits paid	(33.6)
Other	0.0
Fair value of plan assets, ending balance	517.5	483.7
Funded status of the plans (liability) as of December 31	(136.1)
Amounts recognized in balance sheet
Current portion of accrued pension and other post-retirement benefits	(2.9)	(4.6)
Accrued pension and other post-retirement benefits, net of current portion	(133.2)	(196.4)
Funded status as of December 31	(136.1)	(201.0)
Pre-tax amounts recognized in accumulated other comprehensive (income) loss
Unrecognized actuarial loss	156.6	198.4
Unrecognized prior service cost	0.0	0.0
Accumulated other comprehensive (income) loss as of December 31	156.6	198.4
International | Pensions
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Accumulated benefit obligation	589.1	598.1
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Projected benefit obligation, beginning balance	656.4	585.1
Service cost	10.0	10.4	7.0
Interest cost	9.8	11.3	13.7
Actuarial (gain) loss	(32.5)	30.4
Settlements	0.0	(2.6)
Foreign currency exchange rate changes	(11.9)	23.6
Plan participants’ contributions	0.9	1.1
Benefits paid	(22.0)	(17.8)
Other	(9.1)	14.9
Projected benefit obligation, ending balance	601.6	656.4	585.1
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets, beginning balance	591.5	521.2
Actual return on plan assets	46.4	40.1
Company contributions	19.6	27.1
Foreign currency exchange rate changes	(8.9)	20.4
Settlements	0.0	(1.9)
Plan participants’ contributions	0.9	1.1
Benefits paid	(22.0)	(15.8)
Other	0.0	(0.7)
Fair value of plan assets, ending balance	627.5	591.5	521.2
Funded status of the plans (liability) as of December 31	25.9	(64.9)
Amounts recognized in balance sheet
Current portion of accrued pension and other post-retirement benefits	(1.7)	(1.6)
Accrued pension and other post-retirement benefits, net of current portion	27.6	(63.3)
Funded status as of December 31	25.9	(64.9)
Pre-tax amounts recognized in accumulated other comprehensive (income) loss
Unrecognized actuarial loss	15.9	79.1
Unrecognized prior service cost	3.4	3.9
Accumulated other comprehensive (income) loss as of December 31	19.3	83.0
Plans with underfunded or non-funded projected benefit obligation
Aggregate projected benefit obligation	57.9	513.1
Aggregate fair value of plan assets	0.0	442.7
Aggregate accumulated benefit obligation	46.7	50.8
Aggregate fair value of plan assets	0.0	0.0
United States Pension Plan | Pensions
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Accumulated benefit obligation		684.7
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Projected benefit obligation, beginning balance	684.7	669.7
Service cost		0.0
Interest cost		22.2
Actuarial (gain) loss		53.9
Settlements		(25.6)
Foreign currency exchange rate changes		0.0
Plan participants’ contributions		0.0
Benefits paid		(35.5)
Other		0.0
Projected benefit obligation, ending balance		684.7	669.7
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets, beginning balance	483.7	520.0
Actual return on plan assets		14.3
Company contributions		0.0
Foreign currency exchange rate changes		0.0
Settlements		(19.6)
Plan participants’ contributions		0.0
Benefits paid		(31.0)
Other		0.0
Fair value of plan assets, ending balance		483.7	$ 520.0
Funded status of the plans (liability) as of December 31		(201.0)
Plans with underfunded or non-funded projected benefit obligation
Aggregate projected benefit obligation	652.2	684.7
Aggregate fair value of plan assets	516.0	483.7
Aggregate accumulated benefit obligation	652.2	684.7
Aggregate fair value of plan assets	$ 516.0	$ 483.7

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Components Of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pensions | U.S.
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Service cost	$ 0.0	$ 0.0	$ 0.0
Interest cost	18.0	22.2	25.6
Expected return on plan assets	(31.9)	(45.4)	(41.6)
Settlement cost	2.8	1.4	0.0
Curtailment benefit	0.0	0.0	0.0
Amortization of net actuarial loss (gain)	16.8	6.9	1.8
Amortization of prior service cost (credit)	0.0	0.0	0.0
Net periodic benefit cost (income)	5.7	(14.9)	(14.2)
Net actuarial gain (loss) arising during period	(22.1)	(85.1)	(50.2)
Prior service (cost) credit arising during period	0.0	0.0	0.0
Settlements and curtailments	(2.8)	1.4	0.0
Amortization of actuarial gain (loss)	(16.8)	6.9	1.8
Amortization of prior service cost (credit)	0.0	0.0	0.0
Other	0.0	0.0	0.0
Total recognized in other comprehensive income (loss)	(41.7)	(76.8)	(48.4)
Pensions | International
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Service cost	10.0	10.4	7.0
Interest cost	9.8	11.3	13.7
Expected return on plan assets	(25.0)	(36.5)	(31.3)
Settlement cost	0.0	0.5	0.0
Curtailment benefit	0.4	0.0	0.0
Amortization of net actuarial loss (gain)	1.4	0.6	0.3
Amortization of prior service cost (credit)	0.5	0.6	0.4
Net periodic benefit cost (income)	(2.9)	(13.1)	(9.9)
Net actuarial gain (loss) arising during period	(58.4)	(26.8)	(37.5)
Prior service (cost) credit arising during period	0.6	0.0	(0.9)
Settlements and curtailments	(0.4)	0.4	0.0
Amortization of actuarial gain (loss)	(1.4)	0.6	0.3
Amortization of prior service cost (credit)	(0.5)	0.6	0.4
Other	0.0	(7.5)	(1.5)
Total recognized in other comprehensive income (loss)	(60.1)	(32.7)	(39.2)
Other Post-retirement Benefits
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Service cost	0.0	0.0	0.0
Interest cost	0.3	0.4	0.5
Expected return on plan assets	0.0	0.0	0.0
Settlement cost	0.0	0.0	0.0
Curtailment benefit	0.0	0.0	0.0
Amortization of net actuarial loss (gain)	0.1	0.1	0.0
Amortization of prior service cost (credit)	0.0	0.0	0.0
Net periodic benefit cost (income)	0.4	0.5	0.5
Net actuarial gain (loss) arising during period	0.0	0.0	0.0
Prior service (cost) credit arising during period	0.0	0.0	0.0
Settlements and curtailments	0.0	0.0	0.0
Amortization of actuarial gain (loss)	0.0	(0.1)	0.0
Amortization of prior service cost (credit)	0.0	0.0	0.0
Other	(0.9)	(0.6)	1.5
Total recognized in other comprehensive income (loss)	$ (0.9)	$ (0.7)	$ 1.5

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Accumulated Other Comprehensive Income As A Component Of Net Period Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pensions | U.S.
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Amortization of net actuarial loss (gain)		$ 16.8	$ (6.9)	$ (1.8)
Amortization of prior service cost (credit)		0.0	0.0	0.0
Pensions | U.S. | Next fiscal year
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Amortization of net actuarial loss (gain)	$ (12.0)
Amortization of prior service cost (credit)	0.0
Pensions | International
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Amortization of net actuarial loss (gain)		1.4	(0.6)	(0.3)
Amortization of prior service cost (credit)		(0.5)	0.6	0.4
Pensions | International | Next fiscal year
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Amortization of net actuarial loss (gain)	0.0
Amortization of prior service cost (credit)	0.4
Other Post-retirement Benefits
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Amortization of net actuarial loss (gain)		0.0	0.1	0.0
Amortization of prior service cost (credit)		$ 0.0	$ 0.0	$ 0.0
Other Post-retirement Benefits | Next fiscal year
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Amortization of net actuarial loss (gain)	0.0
Amortization of prior service cost (credit)	$ 0.0

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Weighted-Average Assumptions Used Benefit Obligations (Details)	Dec. 31, 2021	Dec. 31, 2020
Pensions | U.S.
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Discount rate	2.90%	2.70%
Pensions | International
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Discount rate	1.99%	1.48%
Rate of compensation increase	3.15%	2.93%
Other Post-retirement Benefits
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Discount rate	5.26%	3.63%
Rate of compensation increase	4.00%	4.00%

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Weighted-Average Assumptions Used Net Periodic Benefit Cost (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other Post-retirement Benefits
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Discount rate	4.46%	4.48%	5.32%
Rate of compensation increase	4.00%	4.00%	4.00%
U.S. | Pensions
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Discount rate	2.70%	3.40%	4.40%
Expected rate of return on plan assets	6.75%	7.75%	8.65%
International | Pensions
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Discount rate	3.09%	2.01%	2.89%
Rate of compensation increase	3.15%	3.84%	3.80%
Expected rate of return on plan assets	2.22%	7.27%	7.15%

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PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Pension Plan Assets Measured At Fair Value (Details) - Pensions - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total pension plan assets, percent	98.80%
U.S.
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	$ 517.5	$ 483.7
U.S. | Fair value, measurements, recurring
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	517.4	483.7
U.S. | Fair value, measurements, recurring | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	43.4	38.1
U.S. | Fair value, measurements, recurring | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	102.1	83.3
U.S. | Fair value, measurements, recurring | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	2.1	1.1
U.S. | Fair value, measurements, recurring | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	37.9	38.4
U.S. | Fair value, measurements, recurring | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	138.8	160.9
U.S. | Fair value, measurements, recurring | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	192.5	160.9
U.S. | Fair value, measurements, recurring | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.6	1.0
U.S. | Fair value, measurements, recurring | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
U.S. | Fair value, measurements, recurring | Level 1
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	148.2	123.5
U.S. | Fair value, measurements, recurring | Level 1 | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	43.4	38.1
U.S. | Fair value, measurements, recurring | Level 1 | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	102.1	83.3
U.S. | Fair value, measurements, recurring | Level 1 | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	2.1	1.1
U.S. | Fair value, measurements, recurring | Level 1 | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 1 | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 1 | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 1 | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.6	1.0
U.S. | Fair value, measurements, recurring | Level 1 | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
U.S. | Fair value, measurements, recurring | Level 2
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 2 | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
U.S. | Fair value, measurements, recurring | Level 3
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Level 3 | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
U.S. | Fair value, measurements, recurring | Net Asset Value
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	369.2	360.2
U.S. | Fair value, measurements, recurring | Net Asset Value | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Net Asset Value | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Net Asset Value | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Net Asset Value | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	37.9	38.4
U.S. | Fair value, measurements, recurring | Net Asset Value | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	138.8	160.9
U.S. | Fair value, measurements, recurring | Net Asset Value | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	192.5	160.9
U.S. | Fair value, measurements, recurring | Net Asset Value | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
U.S. | Fair value, measurements, recurring | Net Asset Value | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
International
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	627.5	591.5	$ 521.2
International | Fair value, measurements, recurring
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	629.7	591.5
International | Fair value, measurements, recurring | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	40.5	66.3
International | Fair value, measurements, recurring | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	45.5	96.3
International | Fair value, measurements, recurring | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	143.4	208.4
International | Fair value, measurements, recurring | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	36.0	68.2
International | Fair value, measurements, recurring | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	291.0	98.3
International | Fair value, measurements, recurring | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	3.6	14.5
International | Fair value, measurements, recurring | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	69.7	39.5
International | Fair value, measurements, recurring | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
International | Fair value, measurements, recurring | Level 1
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	299.1	410.5
International | Fair value, measurements, recurring | Level 1 | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	40.5	66.3
International | Fair value, measurements, recurring | Level 1 | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	45.5	96.3
International | Fair value, measurements, recurring | Level 1 | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	143.4	208.4
International | Fair value, measurements, recurring | Level 1 | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 1 | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 1 | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 1 | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	69.7	39.5
International | Fair value, measurements, recurring | Level 1 | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
International | Fair value, measurements, recurring | Level 2
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 2 | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
International | Fair value, measurements, recurring | Level 3
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Level 3 | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0
International | Fair value, measurements, recurring | Net Asset Value
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	330.6	181.0
International | Fair value, measurements, recurring | Net Asset Value | Cash and cash equivalents
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Net Asset Value | U.S. companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Net Asset Value | International companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	0.0
International | Fair value, measurements, recurring | Net Asset Value | Registered investment companies
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	36.0	68.2
International | Fair value, measurements, recurring | Net Asset Value | Hedge funds
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	291.0	98.3
International | Fair value, measurements, recurring | Net Asset Value | Limited partnerships
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	3.6	14.5
International | Fair value, measurements, recurring | Net Asset Value | Real estate and other investments
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	0.0	$ 0.0
International | Fair value, measurements, recurring | Net Asset Value | Insurance contracts
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
Total plan assets	$ 0.0

XML

PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Contributions (Details) - Pensions - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employer contributions	$ 34.3	$ 27.1
International
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected employer contributions	$ 12.3

XML

PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Expected Benefit Payments (Details) $ in Millions	Dec. 31, 2021 USD ($)
Other Post-retirement Benefits
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
2022	$ 0.6
2023	0.6
2024	0.6
2025	0.5
2026	0.5
2027-2031	2.3
U.S. | Pensions
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
2022	33.3
2023	31.4
2024	31.7
2025	32.3
2026	32.7
2027-2031	165.9
International | Pensions
Pension and Other Postretirement Benefit Plans Disclosure [Line Items]
2022	22.0
2023	22.4
2024	23.8
2025	24.4
2026	25.6
2027-2031	$ 149.9

XML

PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS - Savings Plans (Details) - Non-Qualified Plan - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred compensation, non-current	$ 24.1	$ 22.8
Deferred compensation plan assets	24.1	22.8
Employer matching contributions	21.5	21.3
Employer contributions	$ 9.0	$ 8.3

XML

DERIVATIVE FINANCIAL INSTRUMENTS - Schedule Of Notional Amounts Of Outstanding Derivative Positions (Details) - Dec. 31, 2021 ₽ in Millions, € in Millions, ₨ in Millions, د.ك in Millions, £ in Millions, kr in Millions, Rp in Millions, RM in Millions, R$ in Millions, $ in Millions, $ in Millions, $ in Millions, $ in Millions, $ in Millions	EUR (€)	USD ($)	GBP (£)	MYR (RM)	NOK (kr)	BRL (R$)	SGD ($)	MXN ($)	AUD ($)	INR (₨)	KWD (د.ك)	RUB (₽)	CAD ($)	IDR (Rp)
Foreign exchange forward | Euro | Notional amount bought
Derivative [Line Items]
Derivative, notional amount	€ 775.4	$ 878.2
Foreign exchange forward | British pound | Short
Derivative [Line Items]
Derivative, notional amount		265.9	£ 197.2
Foreign exchange forward | Malaysian ringgit | Short
Derivative [Line Items]
Derivative, notional amount		150.5		RM 627.4
Foreign exchange forward | Norwegian krone | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		109.8			kr 967.9
Foreign exchange forward | Brazilian real | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		232.9				R$ 1,299.8
Foreign exchange forward | Singapore dollar | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		92.9					$ 125.4
Foreign exchange forward | Mexican peso | Short
Derivative [Line Items]
Derivative, notional amount		5.7						$ 116.7
Foreign exchange forward | Australian dollar | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		132.2							$ 182.4
Foreign exchange forward | Indian rupee | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		11.8								₨ 881.4
Foreign exchange forward | Kuwaiti Dinar | Short
Derivative [Line Items]
Derivative, notional amount		10.9									د.ك 3.3
Foreign exchange forward | Russian Ruble | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		12.5										₽ 925.0
Foreign exchange forward | Canadian dollar | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		15.1											$ 19.2
Foreign exchange forward | Indonesian rupiah | Short
Derivative [Line Items]
Derivative, notional amount		3.2												Rp 45,656.9
Foreign exchange forward | U.S. dollar | Short
Derivative [Line Items]
Derivative, notional amount		1,119.9
Embedded derivative financial instruments | Euro | Short
Derivative [Line Items]
Derivative, notional amount	€ 7.3	8.3
Embedded derivative financial instruments | Norwegian krone | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		0.7			6.1
Embedded derivative financial instruments | Brazilian real | Notional amount bought
Derivative [Line Items]
Derivative, notional amount		9.4				R$ 52.5
Embedded derivative financial instruments | U.S. dollar | Short
Derivative [Line Items]
Derivative, notional amount		$ 1.2			kr 1.2

XML

DERIVATIVE FINANCIAL INSTRUMENTS - Fair Value Of Derivative Instruments In Statement Of Financial Position (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Derivative assets	$ 120.8	$ 297.9
Derivative liabilities	176.5	176.3
Derivatives designated as hedging instruments | Foreign exchange contracts
Derivatives, Fair Value [Line Items]
Derivative assets	116.9	218.4
Derivative liabilities	155.0	160.7
Derivatives designated as hedging instruments | Foreign exchange contracts | Current - Derivative financial instruments
Derivatives, Fair Value [Line Items]
Derivative assets	106.4	189.5
Derivative liabilities	139.5	141.9
Derivatives designated as hedging instruments | Foreign exchange contracts | Long-term - Derivative financial instruments
Derivatives, Fair Value [Line Items]
Derivative assets	10.5	28.9
Derivative liabilities	15.5	18.8
Derivatives not designated as hedging instruments | Foreign exchange contracts
Derivatives, Fair Value [Line Items]
Derivative assets	3.9	79.5
Derivative liabilities	21.5	15.6
Derivatives not designated as hedging instruments | Foreign exchange contracts | Current - Derivative financial instruments
Derivatives, Fair Value [Line Items]
Derivative assets	3.9	79.2
Derivative liabilities	21.5	15.6
Derivatives not designated as hedging instruments | Foreign exchange contracts | Long-term - Derivative financial instruments
Derivatives, Fair Value [Line Items]
Derivative assets	0.0	0.3
Derivative liabilities	0.0
Cash flow hedging | Foreign exchange contracts
Derivatives, Fair Value [Line Items]
Foreign exchange contracts	$ (26.3)	$ 3.8	$ 12.2

XML

DERIVATIVE FINANCIAL INSTRUMENTS - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Derivative [Line Items]
Gain (loss) recognized in accumulated other comprehensive income	$ 3,402.7	$ 4,154.2
Cash flow hedge gain (loss) expected to be reclassified within 12 months	$ 3.4
Hedges maturity year	2024
Hedge
Derivative [Line Items]
Gain (loss) recognized in accumulated other comprehensive income	$ (18.7)	$ 12.9

XML

DERIVATIVE FINANCIAL INSTRUMENTS - Location of gain (loss) recognized in income related to hedges and derivatives (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Total revenue	$ 6,403.5	$ 6,530.6	$ 6,950.2
Selling, general and administrative expense	644.9	724.1	795.7
Other income (expense), net	46.6	25.1	(181.6)
Foreign exchange contracts | Revenue
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Gain (loss) recognized in income on derivatives not designated as hedging instruments	1.3	(0.8)	(1.6)
Total	(30.2)	(76.8)	(27.6)
Foreign exchange contracts | Cost of sales
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Gain (loss) recognized in income on derivatives not designated as hedging instruments	0.3	3.4	0.2
Total	7.7	62.1	4.6
Foreign exchange contracts | Selling, general and administrative expense
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Gain (loss) recognized in income on derivatives not designated as hedging instruments	0.0	0.0
Total	0.2	(0.6)
Foreign exchange contracts | Other income (expense), net
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Gain (loss) recognized in income on derivatives not designated as hedging instruments	(13.3)	35.9	(21.4)
Total	23.4	36.0	(29.9)
Foreign exchange contracts | Cash flow hedging | Revenue
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Amounts excluded from effectiveness testing	(1.8)	7.7	0.6
Total cash flow hedge gain (loss) recognized in income	(31.5)	(76.0)	(26.0)
Foreign exchange contracts | Cash flow hedging | Cost of sales
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Amounts excluded from effectiveness testing	(3.3)	(9.8)	(7.6)
Total cash flow hedge gain (loss) recognized in income	7.4	58.7	4.4
Foreign exchange contracts | Cash flow hedging | Selling, general and administrative expense
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Amounts excluded from effectiveness testing		(0.2)
Total cash flow hedge gain (loss) recognized in income	0.2	(0.6)
Foreign exchange contracts | Cash flow hedging | Other income (expense), net
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Amounts excluded from effectiveness testing	3.8	0.3	(7.2)
Total cash flow hedge gain (loss) recognized in income	36.7	0.1	(8.5)
Foreign exchange contracts | Cash flow hedging | Reclassification out of Accumulated Other Comprehensive Income | Hedging
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Total revenue	(29.7)	(83.7)	(26.6)
Costs of sales	10.7	68.5	12.0
Selling, general and administrative expense	(0.2)	0.4	0.0
Other income (expense), net	32.9	(4.4)	(9.1)
Foreign exchange contracts | Cash flow hedging | Reclassification out of Accumulated Other Comprehensive Income | Hedging | Revenue
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Total revenue	(29.7)	(83.7)	(26.6)
Foreign exchange contracts | Cash flow hedging | Reclassification out of Accumulated Other Comprehensive Income | Hedging | Cost of sales
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Costs of sales	10.7	68.5	12.0
Foreign exchange contracts | Cash flow hedging | Reclassification out of Accumulated Other Comprehensive Income | Hedging | Selling, general and administrative expense
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Selling, general and administrative expense	(0.2)	0.4
Foreign exchange contracts | Cash flow hedging | Reclassification out of Accumulated Other Comprehensive Income | Hedging | Other income (expense), net
Location of gain (loss) recognized in income related to hedges and derivatives [Line Items]
Other income (expense), net	$ 32.9	$ (0.2)	$ (1.3)

XML

DERIVATIVE FINANCIAL INSTRUMENTS - Offsetting Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivative assets
Gross Amount Recognized	$ 120.8	$ 297.9
Gross Amounts Not Offset Permitted Under Master Netting Agreements	(78.6)	(128.7)
Net Amount	42.2	169.2
Derivative liabilities
Gross Amount Recognized	176.5	176.3
Gross Amounts Not Offset Permitted Under Master Netting Agreements	(78.6)	(128.7)
Net Amount	$ 97.9	$ 47.6

XML

FAIR VALUE MEASUREMENTS - Assets And Liabilities Measured On A Recurring Basis (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets
Investment in Technip Energies	$ 292.4	$ 305.5
Equity securities	317.3	0.0
Foreign exchange contracts	42.2	169.2
Liabilities
Derivative financial instruments	97.9	47.6
Fair value, measurements, recurring
Assets
Investment in Technip Energies	317.3	0.0
Equity securities	25.0	23.4
Held-to-maturity debt securities	24.0	24.2
Assets held for sale	5.0	47.3
Total assets	494.8	395.4
Liabilities
Total liabilities	176.5	176.3
Fair value, measurements, recurring | Level 1
Assets
Investment in Technip Energies	317.3	0.0
Equity securities	25.0	23.4
Held-to-maturity debt securities	0.0	0.0
Assets held for sale	0.0	0.0
Total assets	342.3	23.4
Liabilities
Total liabilities	0.0	0.0
Fair value, measurements, recurring | Level 2
Assets
Investment in Technip Energies	0.0	0.0
Equity securities	0.0	0.0
Held-to-maturity debt securities	24.0	24.2
Assets held for sale	0.0	0.0
Total assets	147.2	323.8
Liabilities
Total liabilities	176.5	176.3
Fair value, measurements, recurring | Level 3
Assets
Investment in Technip Energies	0.0	0.0
Equity securities	0.0	0.0
Held-to-maturity debt securities	0.0	0.0
Assets held for sale	5.0	47.3
Total assets	5.0	47.3
Liabilities
Total liabilities	0.0	0.0
Foreign exchange contracts | Fair value, measurements, recurring
Assets
Foreign exchange contracts	120.8	297.9
Liabilities
Derivative financial instruments	176.5	176.3
Foreign exchange contracts | Fair value, measurements, recurring | Level 1
Assets
Foreign exchange contracts	0.0	0.0
Liabilities
Derivative financial instruments	0.0	0.0
Foreign exchange contracts | Fair value, measurements, recurring | Level 2
Assets
Foreign exchange contracts	120.8	297.9
Liabilities
Derivative financial instruments	176.5	176.3
Foreign exchange contracts | Fair value, measurements, recurring | Level 3
Assets
Foreign exchange contracts	0.0	0.0
Liabilities
Derivative financial instruments	0.0	0.0
Nonqualified Plan | Fair value, measurements, recurring
Assets
Money market fund	2.4	1.7
Stable value fund	0.3	0.9
Nonqualified Plan | Fair value, measurements, recurring | Level 1
Assets
Money market fund	0.0	0.0
Stable value fund	0.0	0.0
Nonqualified Plan | Fair value, measurements, recurring | Level 2
Assets
Money market fund	2.4	1.7
Stable value fund	0.0	0.0
Nonqualified Plan | Fair value, measurements, recurring | Level 3
Assets
Money market fund	0.0	0.0
Stable value fund	$ 0.0	$ 0.0

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FAIR VALUE MEASUREMENTS - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2021	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020	Mar. 12, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash proceeds		$ 48.0
Redeemable non-controlling interest			$ 0.0	$ 43.7
Estimate of Fair Value Measurement
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of debt			$ 1,706.1	2,199.2
Island Offshore Management AS
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Acquisition of non-controlling interest	$ 48.6
Redeemable non-controlling interest				$ 43.7
Island Offshore Management AS | TIOS AS
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners				51.00%
Island Offshore Management AS | TIOS AS | Share Purchase Agreement
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Purchased shares (percentage)					51.00%
Remaining interest (percentage)	49.00%

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FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets impairment	$ 49.1	$ 3,273.8	$ 2,480.3
Plant, property and equipment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets impairment		190.4
Plant, property and equipment | Fair Value, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, fair value	$ 25.5	$ 452.5

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SUBSEQUENT EVENTS (Details) € / shares in Units, $ in Millions											12 Months Ended
	Jan. 14, 2022 USD ($) shares	Jan. 14, 2022 EUR (€) shares	Jan. 10, 2022 USD ($) shares	Jan. 10, 2022 EUR (€) € / shares shares	Sep. 02, 2021 USD ($) shares	Sep. 02, 2021 EUR (€) € / shares shares	Jul. 29, 2021 USD ($) shares	Jul. 29, 2021 EUR (€) € / shares shares	Apr. 27, 2021 USD ($) shares	Apr. 27, 2021 EUR (€) € / shares shares	Dec. 31, 2021 USD ($) shares	Feb. 25, 2022 USD ($)	Feb. 16, 2021	Dec. 31, 2020 USD ($)
Subsequent Event [Line Items]
Investment in Technip Energies | $											$ 292.4			$ 305.5
Technip Energies
Subsequent Event [Line Items]
Equity securities, number of shares sold (in shares)											21,900,000
Percentage of share capital											12.20%
Ownership percentage													49.90%
Private Placement
Subsequent Event [Line Items]
Sale, price per share (in Euro per share) | € / shares						€ 11.15		€ 11.20		€ 11.10
Private Placement | Subsequent Event
Subsequent Event [Line Items]
Sale, price per share (in Euro per share) | € / shares				€ 13.15
Private Placement | Technip Energies
Subsequent Event [Line Items]
Equity securities, number of shares sold (in shares)					17,600,000	17,600,000	16,000,000	16,000,000	25,000,000	25,000,000
Proceeds from sale					$ 231.5	€ 196,200,000	$ 213.1	€ 179,200,000	$ 335.2	€ 277,500,000
Private Placement | Technip Energies | Subsequent Event
Subsequent Event [Line Items]
Proceeds from sale | $			$ 135.1
Technip Energies N.V. | Subsequent Event
Subsequent Event [Line Items]
Investment in Technip Energies | $												$ 155.3
Technip Energies N.V. | Private Placement | Technip Energies
Subsequent Event [Line Items]
Percentage of share capital						10.00%		9.00%		14.00%
Technip Energies | Subsequent Event
Subsequent Event [Line Items]
Equity securities, number of shares sold (in shares)			12.9	12.9
Ownership percentage				7.10%
Technip Energies | Private Placement | Subsequent Event
Subsequent Event [Line Items]
Equity securities, number of shares sold (in shares)			9,000,000	9,000,000
Proceeds from sale | €				€ 118,400,000
Technip Energies | Technip Energies N.V. | Private Placement | Subsequent Event
Subsequent Event [Line Items]
Percentage of share capital				5.00%
Orbital Marine Power | Subsequent Event
Subsequent Event [Line Items]
Ownership percentage	10.20%	10.20%
Payments to acquire equity method investments	$ 8.3	€ 6,000,000
Ordinary shares paid (in shares)	750,000	750,000

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Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019		Jan. 01, 2020
Accounting Standards Update 2016-13 | Trade receivables
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Accounts Receivable, after Allowance for Credit Loss, Current								$ 2.0
Trade receivables allowance for doubtful accounts
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of  Period		$ 40.2	[1]	$ 57.4		$ 58.7
Additions, Charged to Costs and Expenses		17.0	[1]	38.0		27.7
Additions, Charged to Other Accounts		(10.8)	[1],[2]	1.3		3.5	[2]
Deductions and Adjustments		(8.3)	[1],[3]	(56.5)		(32.5)	[3]
Balance at End of Period		38.1	[1]	40.2	[1]	57.4
Valuation allowance for deferred tax assets
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of  Period		815.1		729.1		496.6
Additions, Charged to Costs and Expenses		129.7		104.4		184.9
Additions, Charged to Other Accounts	[2]	(12.0)		(11.3)		0.0
Deductions and Adjustments	[3]	2.7		(7.1)		47.6
Balance at End of Period		$ 935.5		$ 815.1		$ 729.1

[1] On January 1, 2020, we adopted ASU 2016-13, resulting in a $2.0 million increase to our trade receivables allowance for credit losses.

[2] Additions charged to other accounts” includes translation adjustments.

[3] “Deductions and adjustments” includes write-offs, net of recoveries, increases in allowances offset by increases to deferred tax assets, and reductions in the allowances credited to expense.(c)On January 1, 2020, we adopted ASU 2016-13, resulting in a $2.0 million increase to our trade receivables allowance for credit losses.