EDGAR 10-K Filing

Company CIK: 1681459
Filing Year: 2021
Filename: 1681459_10-K_2021_0001681459-21-000043.json

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ITEM 1. BUSINESS
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 its registered office at One St. Paul’s Churchyard, London EC4M 8AP, 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 Paris, France, and Houston, Texas, United States, and operate across three business segments: Subsea, Technip Energies, 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. On February 16, 2021, the Company completed the Spin-off. Subsequent to the Spin-off, the Company will operate under two reporting segments: Subsea and Surface Technologies, for further details see section “The Spin-off” below.
Enhancing our performance and competitiveness is a key component of this 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 segments we serve.
Each of our more than 35,000 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, Technip and FMC Technologies announced in May 2016 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 complimentary 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 where 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.
TechnipFMC’s expertise does not end with the production of hydrocarbons. Because of its best-in-class Engineering and Construction (“E&C”) project design and execution capabilities, enabled by a portfolio of proprietary technologies, TechnipFMC continues to secure and deliver projects that further enable our clients to monetize resources - from liquefaction of gas, both onshore and on floating vessels, through refining and product facilities and with green chemistry and renewables.
The Spin-off
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 (”EPC”) project execution. Due to the COVID-19 pandemic, a significant decline in commodity prices, and the heightened volatility in global equity markets, on March 15, 2020, we announced the postponement of the completion of the transaction until the markets sufficiently recover. On January 7, 2021, we announced the resumption of activity toward completion of the transaction based on increased clarity in the market outlook and our demonstrated ability to successfully execute projects.
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. 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, on January 7, 2021, BPI, which has been one of our substantial shareholders since 2009, entered into a Share Purchase Agreement 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”). On February 25, 2021, BPI paid $200.0 million in connection with the Share Purchase Agreement. The Purchase Price is subject to adjustments, and BPI’s ownership stake will be determined based upon a thirty day volume-weighted average price of Technip Energies N.V.’ s shares (with BPI’s ownership collared between an 11.82 percentage floor and a 17.25 percentage cap), less a six percent discount. The BPI Investment is subject to customary conditions and regulatory approval. We intend to significantly reduce our shareholding in Technip Energies N.V. over the 18 months following the Spin-off, including in connection with the sale of shares to BPI pursuant to the BPI Investment.
Beginning in the first quarter of 2021, Technip Energies’ historical financial results for periods prior to the Distribution will be reflected in our consolidated financial statements as discontinued operations.
The Spin-off enables both companies to benefit from distinct and compelling market opportunities across the energy value chain; dedicated focus of management, resources, and capital; and unique value propositions with differentiated investment appeal.
•TechnipFMC is a fully-integrated technology and services provider, driving energy development across deepwater, conventional, and unconventional resources. TechnipFMC continues to successfully demonstrate leadership in integrated subsea project delivery and is focused on replicating this success through the development of integrated production models for the surface market. TechnipFMC is also poised to benefit from service opportunities resulting from the world’s largest installed base of subsea production equipment, umbilicals, risers, and flowlines, and in the supply of surface integrated systems in the drilling, frac, production and measurement markets.
•Technip Energies is a leading engineering and construction player, with a robust project delivery model, strong technical capabilities, and proven track record as demonstrated by the successful execution of some of the world’s most iconic EPC projects. Technip Energies will continue to leverage its industry-leading process technology portfolio, particularly in the areas of ethylene and hydrogen, while pursuing further opportunities to enhance and differentiate this portfolio, and to accelerate the journey to a low-carbon future.
BUSINESS SEGMENTS
On February 16, 2021, we completed the Spin-off. Subsequent to the Spin-off, we will operate under two reporting segments: Subsea and Surface Technologies.
Subsea
We are focused on transforming subsea by safely delivering 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, and subsea umbilicals, risers, and flowlines (“SURF”) and subsea robotics. We also have the capability to install these products and related subsea infrastructure with 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 the life of field.
Our integrated business model is unlocking incremental opportunities and materially expanding the deepwater opportunity set. Since the first iEPCI project was awarded in 2016, market adoption of the business model has accelerated each year.
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 equipment, new technologies, and simplified installation, we can significantly reduce subsea development costs and accelerate time to first production.
Our first-mover advantage and ability to convert iFEED studies into iEPCI contracts, often as a direct award, 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 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 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 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, 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.
Rigid Pipe. We design and fabricate rigid pipes for production and service applications at our spoolbases. Rigid pipes are installed from our fleet of differentiated rigid pipelay vessels. Our pipelines optimize flow assurance through innovative insulation coatings, electric trace heating, plastic liners, and pipe-in-pipe systems.
Flexible Pipe and Umbilicals. We design and manufacture flexible pipes as well as steel tube, thermoplastic hose, power, communication, and hybrid (a combination of steel tube, thermoplastic hose, and electrical cables) umbilicals. TechnipFMC vessels will typically perform the installation of the flexible pipes and umbilicals, but we also sell these products directly to oil companies or to other vessel operators.
Vessels. We have a fleet of 18 vessels that are used for the installation and servicing of our products. We have sole ownership of ten vessels, ownership of six vessels as part of joint ventures, and two vessels operated under long-term charters.
Subsea Services. We provide a portfolio of well and asset services that improve economics and enhance performance over the life of our clients' subsea development cycle. Well services include all service offerings: (i) provision of exploration and production wellhead systems and services; (ii) remotely operated vehicle (“ROV”) drill support services; (iii) well completion installation services; (iv) well access and intervention services, both rig-based and vessel-based (riserless light well intervention or “RLWI”); and (v) well plug and abandonment. Asset Services include all service offerings, such as (i) maintenance services for test, modification, refurbishment, and upgrade of subsea equipment and tooling; (ii) integrity services based on product and field data to optimize the performance of the subsea asset, including proactive inspection, maintenance, and repair (“IMR”) of subsea infrastructure; and (iii) production metering services to enhance well and field production, including real time virtual metering services and flow assurance services.
Key drivers of subsea services market activity are the services linked to subsea wells in greenfield development and brownfield subsea tiebacks, or infill developments.
Additionally, with our extensive experience in subsea equipment, our leading installed base of subsea production equipment, our broad range of services, and our historical technical design and manufacturing leadership, we are in a unique position to offer integrated solutions across the “life of field” (“LOF”) services. These combine asset light solutions (e.g. RLWI), digital services (e.g. data driven monitoring, surveillance, and production management suite of applications), and leading edge automated and robotic systems (e.g. Schilling ROVs) to enhance the economics of producing fields through maximization of asset uptime, higher production volumes, and lower operating expense.
Robotics, Controls and Automation. We design and manufacture ROVs and manipulator arms that are used in subsea drilling, construction, IMR, and life of field services. Our product offering includes hydraulic work-class ROVs, tether-management systems, launch and recovery systems, remote manipulator arms, and modular control systems. We also provide support and services such as product training, pilot simulator training, spare parts, and technical assistance.
We also provide electro-hydraulic and electric production and intervention control systems, allowing accurate control and monitoring of subsea installations to ensure the highest production availability that can ensure safe and environmentally friendly field operations. These include the sensors, multiphase flow meters, digital infrastructure, integrity monitoring, control functionality, and automation features needed for subsea systems. Robotics capabilities are now being used in the control of manifold valves during production, which demonstrates a convergence of our technologies in order to provide better systems for our customers.
Subsea Studio™ Digital Platform. Subsea Studio™ is our portfolio of digital solutions to increase performance, transform experience, and enable innovation. Subsea Studio™ FD is our front-end field development tool,
transforming conventional concept, FEED and tender phases into ultra-fast digital field development. Subsea Studio™ Ex is our project execution digital application that increases the efficiency and speed of project execution with a data-centric approach. Subsea Studio™ LOF uses our digitally enabled operations and advanced data driven services to enhance performance and production targets.
Research, Engineering, Manufacturing and Supply Chain (“REMS”). REMS is an organization formed in September of 2019 to support accelerated technology innovation, and product delivery improvements. 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 how we manage workflow. 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 primarily supports our Subsea segment but is also integrated across our Surface Technologies segment.
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 function enables REMS, and the Subsea and Surface Technologies businesses to drive the understanding of customer requirements, competitive landscape, and investment prioritization.
Capital Intensity
Many of the systems and products we supply for subsea applications are highly engineered to meet the unique demands of our customers’ field properties and are typically ordered one to two years before installation. We often receive advance payments and progress billings from our customers to fund initial development and working capital requirements.
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 alliances 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 2020 consolidated revenue.
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., Saipem S.p.A. (“Saipem”), 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
The volatile, and generally low, crude oil price environment of the last several years led many of our customers to reduce their capital spending plans and defer new deepwater projects. Order activity in 2020 was particularly impacted by the sharp decline in commodity prices in April, driven in part by the reduced economic activity, and the general uncertainty related to the COVID-19 pandemic. The reduction and deferral of new projects resulted in delayed subsea projects inbound for the industry.
While economic activity continues to be impacted by the pandemic, the short-term outlook for crude oil has improved as the OPEC+ countries better manage the oversupplied market. Long-term demand for energy is still forecast to rise, and we believe this outlook will ultimately provide our customers with the confidence to increase investments in new sources of oil and natural gas production.
The trajectory and pace of further recovery and expansion in the subsea market is subject to the capital our clients dedicate to developing offshore oil and gas fields amongst their entire portfolio of projects and drivers of capital expansion or discipline. The risk of project sanctioning delays is still present in the current environment; however, innovative approaches to subsea projects, like our iEPCI solution, have improved project economics, and many offshore discoveries can be developed economically at today’s crude oil prices. In the long-term, deepwater development is expected 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 future order activity.
Strategy
With our proprietary technologies and production systems, and integration expertise, we are transforming subsea by safely delivering innovative solutions that improve economics, enhance performance, and reduce emissions. We have used these capabilities to develop a new subsea commercial model that is transforming the way we interact with our customers and create value with them.
Our strategy includes the following priorities:
•Engagement in the conceptual design and integrated front-end engineering of subsea development projects to create value through technology and integration of scopes by simplifying field architecture and accelerating both delivery schedules and time to first production.
•Innovative research and development (“R&D”), often in collaboration with clients and partners, to develop leading products and technologies that deliver greater efficiency to the client, lower development costs, unlock stranded and/or marginal fields, and enable frontier developments.
•Focus on selecting the right projects to ensure a strong and healthy backlog.
•Superior project execution capabilities allowing us to mobilize the right teams, assets, and facilities to capture and profitably execute complex subsea projects and services.
•Capitalize on combined competencies coming from alliances and partnerships with both clients and suppliers.
•Leverage supplier relationships to optimize supply chain market dynamics and implement greater simplification and standardization in products and processes.
TechnipFMC is a clear leader in the subsea industry. Our success has been built on our technological strength, innovation, focus on digitalization, and strong partnerships with major oil companies to expand market opportunities.
Recent and Future Developments
We continue to focus on performance improvement and optimization strategies that will improve our profitability. Our investments decisions fully support our business with technologies that will differentiate our portfolio.
Subsea StudioTM is transforming the conventional concept, FEED and tendering phases of subsea projects. Working with our clients, we are now able to develop ultra-fast, digital field architectures that bring together decades of engineering knowledge with artificial intelligence and machine learning to optimize product configurations, accelerate execution, and maximize value.
Subsea StudioTM has an open architecture that allows integration with other engineering and manufacturing systems, eliminating the need for multiple hand-offs, and resulting in as much as a 50% reduction in the time required for front-end engineering. We are extending the platform beyond subsea system design to incorporate the execution and field management phases of a project. Once fully implemented, we will have a complete digital thread from concept design, all the way through to the life of the field.
To further our commitment to meaningfully contribute to the energy transition, we formed New Energy Ventures to define a detailed business plan and identify and develop business opportunities and investment cases. We seek to make energy more sustainable through electrification of offshore fields through renewable sources. Offshore floating wind, wave energy, and green hydrogen will be main contributors to our subsea energy transition vision. Our core competencies in systems engineering, safety control and systems, high pressure gas pipelines and risers, connection systems, and subsea tank systems are easily transferable from oil and gas to alternative energy solutions.
We have set a target to reduce up to 50 percent of CO2 emissions from offshore upstream life of field. Subsea is a field development solution that is uniquely positioned to minimize carbon footprint and drive simplification in field design, product design and offshore operations to enable a platform-less future.
Subsea all-electric field developments enable longer step-out and tiebacks as well as unmanned platforms and operations. Subsea processing and power solutions move technology from topside to seabed. Automation and robotics such as the Gemini ROV represent a step change towards autonomous operations.
Our subsea products and infrastructure help our clients' businesses be less carbon intensive across activities by reducing CO2 emissions.
We expect our iEPCI capabilities to provide a competitive advantage as we deliver comprehensive and differentiated solutions. In addition, we anticipate the following longer-term trends in the subsea market:
•Increased market adoption of integrated subsea projects, leading to further penetration of our integrated business model and higher levels of iEPCI order activity for our Company.
•Growing service opportunities, driven by (i) higher levels of project activity, (ii) increased asset integrity and production management activities focused on improving uptime and production volume and lowering emissions, and (iii) increased maintenance and intervention activity resulting from an expanding and aging installed equipment base.
•Smaller projects (less than $75 million) and direct awards will continue to contribute meaningfully to our order mix. In 2020, these awards collectively represented more than half of our total subsea inbound orders, with the remainder being publicly announced projects and subsea service activities. Subsea tiebacks are often part of this mix, and these shorter cycle brownfield expansions provide operators with faster paybacks and higher returns.
•There is a growing trend towards independent operators and new entrants undertaking subsea developments; we are a natural partner for this customer group because of our ability to offer fully integrated solutions.
•Natural gas developments are growing in prominence. We believe that more than 20 percent of offshore capital expenditures could be directed at natural gas developments by early next decade. We also anticipate that 45 percent of gas production will come from offshore, with significant growth in the Middle East (shallow water) followed by Australia (deep water) in the next five years.
We continue to work closely with our customers and believe that, in the context of lower oil prices, with our unique business model we can further reduce their project break-even levels by offering cost-effective approaches to their project developments and accelerating time to first oil and gas.
Product Development
Technology development progressed on our Subsea 2.0™ (“Subsea 2.0”) product platform, the next generation of subsea equipment, using designs that are significantly simpler, leaner, and smarter than current designs. These products incorporate a modular product architecture and component level standardization to enable a flexible configure-to-order approach, reducing hardware delivery time for clients. The products are expected to deliver breakthroughs in the way subsea products are manufactured, assembled, installed, and maintained over the life of the field. Incorporating our Subsea 2.0 platform can greatly simplify the subsea infrastructure, while reducing greenhouse gas emissions. When combined with iEPCI, it also simplifies vessel installation campaigns by providing an even greater environmental and economic benefit and unlocks first oil and gas faster. In 2020, we installed Subsea 2.0 trees on two projects, with production under way offshore in Brazil. Additionally, we were awarded our latest iEPCI project with Shell in Malaysia. It incorporates our Subsea 2.0 technology as well as a diverse set of other projects in some of the most active basins in the world.
Our Joint Industry Program for electrification of the field progressed well this year. This system solution will drive reduced emissions, enable more digitally enabled intelligent field operations, improve economics for long step-out and subsea tie-back to short field developments, and contribute to a more sustainable way to develop oil and gas resources.
In a partnership with Halliburton, we introduced Odassea™, the first distributed acoustic sensing solution for subsea wells. This technology platform enables operators to execute intervention-less seismic imaging and reservoir diagnostics to reduce total cost of ownership while improving reservoir knowledge. This project expands our unique integrated subsea solution and leverages the competencies and know-how to drive a higher level of sustainability. In the field, we are delivering solutions with the technology to multiple subsea projects at all stages from conceptual design to execution and installation.
This year, we have also advanced on our journey towards more autonomous operations with the launch of the Gemini™® (“Gemini”) ROV system, featuring advanced automation and precision robotics to increase offshore productivity. Gemini is the next generation of advanced 250 horse power work class ROV system providing unprecedented subsea productivity. The integration of ROV, manipulators and tooling enables a transition to highly automated subsea robotics, which reduces task time from hours to minutes, ensuring predictable results every time. Featuring a significant advancement in manipulator design, the Gemini manipulators provide integrated hydraulics, electric power, communications, and force compliance. Additionally, the ROV has access to more than 30 subsea exchangeable tools and a comprehensive fluid intervention system to support the most demanding deepwater drilling and completion operations. With a depth rating of up to 4,000 meters, Gemini can remain subsea for one month, enabling 24/7 operations without recovery for tooling reconfiguration. Its combination of system availability, capability and productivity reduces operational costs and delivers unequaled performance.
In addition to investments to develop lower-cost production solutions, we also invest in the development of technology to expand our service portfolio. As an example, we have simultaneously launched a suite of new ROV services for drill rigs alongside Gemini to drive even greater efficiency.
Acquisitions and Investments
We did not make any material acquisitions or corporate investments in 2020. We have focused on business transformation to mitigate the adverse effects of the rapidly changing market environment and to ensure the long-term viability of our subsea business.
Going forward, we will need fewer assets to deliver more comprehensive solutions:
•We are optimizing our operations across geographies, and if economic returns don’t make sense, we will look to exit.
•We continue to right-size our assets to better align with and leverage the benefits of our differentiated offering and the advantages of new technologies - such as Subsea 2.0 - and integrated project delivery.
•We continue to partner with others, providing us access to unique assets in a more capital efficient manner.
As the subsea industry continues to evolve, we are accelerating actions to further streamline our organization, achieve standardization, and reduce cycle times. We aim to continuously align our operations with activity levels, while preserving our core capacity in order to deliver current projects in backlog and future order activity.
Technip Energies
Technip Energies offers a full range of design, project management, and construction services to our customers spanning the entire downstream value chain, including technical consulting, concept selection, and final acceptance test. With the drive of the energy transition, we are increasingly deploying low-carbon solutions. We have been successful in meeting our clients’ needs given our proven skills in managing large engineering, procurement, and construction projects.
Technip Energies’ onshore business combines the study, engineering, procurement, construction, and project management of the entire range of facilities related to the production, treatment, and transportation of gas, oil and renewables, the transformation of petrochemicals such as ethylene, polymers, and fertilizers, as well as other major activities including refining and hydrogen.
Technip Energies conducts large-scale, complex, and challenging projects that involve extreme climatic conditions and non-conventional resources and are subject to increasing environmental and regulatory performance standards. Technip Energies relies on technological know-how for process design and engineering, either through the integration of technologies from leading alliance partners or through its own technologies. Technip Energies seeks to integrate and develop advanced technologies and reinforce its strong project execution capabilities in each of its onshore activities.
Technip Energies’ offshore business combines the study, engineering, procurement, construction, and project management within the entire range of fixed and floating offshore facilities, many of which were the first of their kind, including the development of floating liquefied natural gas (“FLNG”) facilities.
Principal Products and Services
Onshore Engineering & Construction. Technip Energies designs and builds different types of facilities for the development of onshore gas, oil, and renewables, processing facilities, and product export systems. In addition, Technip Energies renovates existing facilities by modernizing production equipment and control systems, in accordance with applicable environmental standards.
Natural Gas Treatment and Liquefaction. Technip Energies offers a complete range of services across the gas value chain to support its clients’ capital projects from concept to delivery. Technip Energies’ capabilities include the design and construction of facilities for liquefied natural gas (“LNG”), gas-to-liquids (“GTL”), natural gas liquids (“NGL”) recovery, and gas treatment.
In the field of LNG, Technip Energies pioneered base-load LNG plant construction through the first-ever facility in Arzew, Algeria. Working with its partners, Technip Energies has constructed facilities that can deliver more than 105 million metric tonnes per annum (“Mtpa”), which is a significant portion of the global liquefaction capacity in operation today. Technip Energies brings knowledge and conceptual design capabilities that are unique among engineering and construction companies involved in LNG. Technip Energies has engineered and delivered a broad range of LNG plants, including mid-scale and very large-scale plants, both onshore and offshore, and plants in remote locations. Technip Energies has experience in the complete range of services for LNG, receiving terminals from conceptual design studies to EPC. Reference projects include LNG trains in Qatar (the sixth largest ever constructed), Yemen, and a series of mid-scale LNG plants in China. Together with its joint venture partners,
Technip Energies delivered the first phase of the Yamal LNG plant (“Yamal”) in the Russian Arctic with all three trains put in production before the end of 2018. During 2019, the Arctic LNG 2 project for Novatek was sanctioned following award of the EPC contract to Technip Energies, together with its joint venture partners. Technip Energies combines its capabilities with its technology and know-how to develop new solutions that supports the energy transition in reducing LNG plant emissions and improving their energy efficiency.
Technip Energies is also well-positioned in the GTL market and are one of the few contractors with experience in large GTL facilities. Technip Energies has unique experience in delivering plants using Sasol’s “Slurry Phase Distillate” technology, and it has provided front-end engineering design for the Fischer-Tropsch section of more than 60 percent of commercial liquids conversion capacity worldwide. Technip Energies’ clients also benefit from its development of environmental protection measures, including low nitrogen oxide and sulfur oxide emissions, waste-water treatment, and waste management.
Technip Energies specializes in the design and construction of large-scale gas treatment complexes as well as existing facility upgrades. Gas treatment includes the removal of carbon dioxide and sulfur components from natural gas using chemical or physical solvents, sulfur recovery, and gas sweetening processes based on the use of an amine solvent. Technip Energies ranks among the top contractors in the field in relation to sulfur recovery units installed in refineries or natural gas processing plants. Given its long-term experience in the field of sour gas processing, Technip Energies can provide support to clients for the overall evaluation of the gas sweetening/sulfur recovery chain and the selection of optimum technologies.
Refining. Technip Energies is a leader in the design and construction of refineries. Technip Energies manages many aspects of these projects, including the preparation of concept and feasibility studies, and the design, construction, and start-up of complex refineries or single refinery units. Technip Energies has been involved in the design and construction of more than 30 new refineries or major refinery expansions and are one of the few contractors in the world to have built seven new refineries since 2000. Technip Energies has extensive experience with technologies related to refining and have completed more than 840 individual process units within major expansion or refurbishment projects, implemented in more than 75 countries. As a result of its cooperation with the most highly renowned technology licensors and catalyst suppliers, and its strong technological expertise and refinery consulting services, Technip Energies is able to provide an independent selection of appropriate technologies to meet specific project and client targets. These technologies result in direct benefits to the client, such as energy efficiency, emission control and environmental protection, including hydrogen and carbon dioxide management, sulfur recovery units, water treatment, and zero flaring. With a strong record of accomplishment in refinery optimization and performance improvement projects, Technip Energies has experience and competence in relevant technological fields in the refining sector. Transition to a low-carbon economy is a strategic trend driving the refining industry today for which Technip Energies offers significant experience, technological skills, solid project development, and delivery references.
Biofuels. Biofuels are a renewable alternative to fossil fuels and an advanced solution to meet stringent, medium-term climate targets. In this domain, Technip Energies is one of the global leaders and delivers a wide range of biofuel plants utilizing various technologies. Technip Energies has end-to-end project management expertise, delivering projects from feasibility studies to full EPC project execution. Opportunities lie in expansions or revamps of existing refineries, as well as stand-alone projects. As an example, Technip Energies is a partner of choice for Neste’s NEXBTL projects, being involved in its facilities in Singapore and Rotterdam.
Hydrogen. Hydrogen is widely used in the production of cleaner transport fuels and is also the most widely used industrial gas in the refining, chemical, and petrochemical industries. With more than 55 years' experience and expertise in the production of hydrogen, Technip Energies offers a single point of responsibility for the design and construction of hydrogen and synthesis gas production units, with tailored solutions ranging from Process Design Packages to full lump-sum turnkey projects. Technip Energies also offers services for maintenance and performance optimization of running units as well as a wide choice of proprietary technologies, including steam reforming technology used worldwide. Technip Energies has solutions in place for carbon capture readiness in future hydrogen plants, targeting more than a two-thirds' reduction in carbon dioxide release from hydrogen plants. Driven by its track record in grey and blue hydrogen projects, Technip Energies is also focused on positioning carbon-free, green, hydrogen in the current and future energy landscape, on the basis of its extensive expertise in hydrogen technology. In October 2020, Technip Energies entered into a strategic alliance with McPhy, a leading manufacturer and supplier of carbon-free hydrogen production and distribution equipment, to develop large-scale and competitive carbon-free hydrogen solutions from production to liquefaction, storage, and distribution.
Ethylene. Technip Energies holds proprietary technologies and is a leader in the design, construction, and commissioning of ethylene production plants. Technip Energies designs steam crackers, from concept stage through construction and commissioning, for both new plants (including mega-crackers) and plant expansions. Technip Energies has a portfolio of the latest generation of commercially proven technologies and is uniquely positioned to be both a licensor and an EPC contractor. Technip Energies’ technological developments have improved the energy efficiency in ethylene plants by improving thermal efficiency of the furnaces and reducing the compression power required per ton, thereby reducing carbon dioxide emissions per ton of ethylene by 30 percent over the last 20 years.
Petrochemicals. Technip Energies is one of the world leaders in the process design, licensing, and realization of petrochemical units, including basic chemicals, intermediate, and derivative plants. Technip Energies provides a range of services that includes process technology licensing and development and full EPC complexes. Technip Energies is accelerating the energy transition by improving monomer and energy efficiencies of its plants and by integrating feedstock shifts to improve production costs and carbon footprints. Technip Energies licenses a portfolio of chemical technologies through long-standing alliances and relationships with leading manufacturing companies and technology providers. Technip Energies has research centers to develop and test technologies for polymer and petrochemical applications, where fully automated pilot plants gather design data to scale-up processes for commercialization.
Fertilizers. Technip Energies’ expertise covers the entire value chain from mining and beneficiation to fertilizers, including ammonia, urea, and phosphoric acid plants. Working in more than 40 countries, Technip Energies has engineered and delivered more than 350 large fertilizer complexes and integrated units. Technip Energies services offerings range from global strategic planning, technical consulting, and feasibility studies to complete turnkey facilities and further assistance to production and de-bottlenecking. Through its commitment to continuous end-to-end innovation for higher performance and efficiencies, Technip Energies helps its clients develop optimized and sustainable process schemes for their projects and meet the highest environmental standards.
Sustainable Chemistry. Technip Energies is a key player in sustainable chemistry and offers a variety of technologies, processes and services in the areas of biofuels, biochemicals, and circular economy applications. With leading engineering and project management capabilities originating from expertise in chemicals, petrochemicals, refining, and fermentation, it provides high value for clients - from process development in the very early stage of the project, to the implementation of large and complex sustainable chemicals plants.
Decarbonization. Technip Energies provides solutions that span from energy efficiency to full carbon removal, adapting to a variety of client challenges and requirements. Technip Energies makes clients’ businesses less carbon intensive across activities, decarbonizes fossil-based energies and manages the resulting CO2 in a sustainable manner. Technip Energies current portfolio of sustainable technologies includes process designs that improve energy efficiency and reduce emissions and provides answers today for its customers.
Carbon-free energy solutions. To offer carbon-free solutions requires overcoming many technical and commercial challenges, as well as integrating multiple technologies for the management of electrical power from wind or solar intermittency. In this field, Technip Energies is expanding its portfolio of technologies and processes to carbon-free energy chains such as green hydrogen produced from renewable energy.
Fixed Platforms. Technip Energies offers a broad range of fixed platform solutions in shallow water, including: (i) large conventional platforms with pile steel jackets whose topsides are installed offshore either by heavy lift vessel or floatover; (ii) small, conventional platforms installed by small crane vessel; (iii) steel gravity-based structure platforms, generally with floatover topsides; and (iv) small to large self-installing platforms. Technip Energies offers a range of design, construction, and industrial applications that are key to the global transition to a less carbon intensive economy.
Floating Production Units. Technip Energies offers a broad range of floating platform solutions for moderate to ultra-deepwater applications, including:
•Spar Platforms: Capable of operating in a wide range of water depths, the Spar is a low motion floater that can support full drilling with dry trees or with tender assist and flexible or steel catenary risers. The Spar topside is installed offshore either by heavy lift vessel or floatover. Technip Energies has constructed 17 Spar facilities which are currently operating in the world.
•Semi-Submersible Platforms: These platforms are well-suited for oil field developments where subsea wells drilled by a mobile offshore drilling unit are appropriate. Semi-Submersibles can operate in a wide range of water depths and may have full drilling and large topside capabilities. Technip Energies has its own unique design of low-motion Semi-Submersible platforms that can accommodate dry trees.
•Tension-Leg Platforms (“TLP”): An appropriate platform for deepwater drilling and production in water depths up to approximately 1,500 meters, the TLP can be configured with full drilling or with tender assist and is generally a dry tree unit. The TLP and our topside can be integrated on to the substructure in a cost-effective manner at quayside.
Floating Production, Storage and Offloading (“FPSO”). Working with its construction partners, Technip Energies has delivered some of the largest FPSOs in the world. FPSOs enable offshore production and storage of oil which is then transported by a tanker where pipeline export is uneconomic or technically challenged (e.g., ultra-deepwater). FPSOs utilize onshore processes adapted to a floating marine environment. They can support large topsides and hence large production capacities. Leveraging its industry-leading capabilities in gas monetization, particularly FLNG, Technip Energies is currently well-positioned to leverage the global offshore gas cycle with gas FPSOs.
Floating Liquefied Natural Gas. FLNG is an innovative alternative to traditional onshore LNG plants and is suitable for remote and stranded gas fields that were previously deemed uneconomical. FLNG is a commercially attractive and carbon conscious approach to the monetization of offshore stranded gas fields or associated gas from oil production. It avoids the cost of building and operating long-distance pipelines and extensive onshore infrastructure. Technip Energies pioneered the FLNG industry and is the contractor best able to integrate all of the core activities required to deliver an FLNG project: LNG process, offshore facilities, loading systems, and subsea infrastructure. Technip Energies delivered the industry’s first and largest FLNG facilities and is currently executing ENI’s Coral South FLNG, which will be installed offshore Mozambique in East Africa.
Mining and Metals. Technip Energies offers its clients an integrated approach and expertise across the mineral value chain from mining to processing. The Sintoukola potash project in the Congo is a prime example of this integrated approach. Technip Energies covers the entire project lifecycle, from conceptual studies to engineering, procurement, construction, and project management services or EPC Lump-Sum Turn-Key services with references including successful completed projects and ongoing projects dedicated to the treatment of nickel, uranium, phosphate, potash, alumina, and iron ore. Technip Energies brings together the know-how and determination to transform its clients’ project economics.
Life Sciences. Technip Energies is a leading provider in the design and construction of pharmaceuticals and bio-technologies facilities, bringing together know-how, process engineering expertise, construction management, commissioning, and qualification. Technip Energies offers fully integrated technical and regulatory solutions from design to validation. Technip Energies provides its clients a robust experience with more than 350 pharmaceuticals and bio-technologies facilities delivered in the past 25 years.
Nuclear. Technip Energies has recognized expertise and dedicated capabilities at several stages of the nuclear industry chain, from mining to chemistry, underground waste storage and reprocessing. Technip Energies provides engineering services from basic to detailed design, project management, control assistance, and construction services for the nuclear market.
Loading Systems. Technip Energies is globally recognized for setting technical and performance standards in fluid transfer, delivering liquid and gas loading systems to the most challenging applications, both onshore and offshore. Technip Energies leads the market with 10,000 loading arms supplied, including more than 500 arms for LNG. Technip Energies has developed unique offshore LNG transfer systems for all FLNG facilities operating to-date. Technip Energies offers equipment design and fabrication projects, as well as services over the life of its systems.
Cybernetix robotics and surveillance. Technip Energies offers innovative robotics and surveillance systems for harsh environments and operational constraints. Technip Energies works with an array of clients in the energy industry. This includes nuclear, where Technip Energies involvement dates back more than 20 years. Technip Energies’ solutions help energy clients increase uptime, reduce costs, and improve safety and speed of decision-making through augmented monitoring and advanced robotics solutions for inspection and dexterous interventions.
Capital Intensity
Technip Energies executes turnkey contracts on a lump-sum or reimbursable basis through engineering, procurement, construction, and project management services on both brownfield and greenfield developments and projects. Technip Energies can execute EPC contracts through sole responsibility, joint ventures, or consortiums with other companies. Technip Energies often receives advance payments and progress billings from its customers to fund initial development and working capital requirements. However, its working capital balances can vary significantly through the project lifecycle depending on the payment terms and timing on contracts.
Dependence on Key Customers
Generally, Technip Energies' customers are major integrated oil companies or national oil companies. Technip Energies has developed long-term relationships with its main clients around its portfolio of technologies, expertise in project management, and strong execution, while addressing national content development requirements. Technip Energies’ customers have sought the security of partnerships with Technip Energies to ensure timely and cost-effective delivery of their projects. One customer, Arctic LNG, represented more than 10 percent of our 2020 consolidated revenue.
Competition
In the onshore market, Technip Energies faces a large number of competitors, including U.S. companies (Bechtel Corporation, Fluor Corporation, KBR, Inc. (“KBR”), and McDermott), Asian and Australian companies (Chiyoda Corporation, JGC Corporation, Hyundai Engineering & Construction Co., Ltd., Samsung Engineering Co., Ltd, SK Engineering & Construction Co., Ltd, and Worley Limited), European companies (Wood Group plc, Maire Tecnimont Group, Petrofac, Ltd., Saipem, and Tecnicas Reunidas, S.A.). In addition, Technip Energies competes against smaller, specialized, and locally based engineering and construction companies in certain countries or for specific units such as petrochemicals.
Competition in the offshore market is relatively fragmented and includes various players with different core capabilities, including offshore construction contractors, shipyards, leasing contractors, and local yards in Asia Pacific, the Middle East, and Africa. Competitors include China Offshore Oil Engineering Co., Ltd., Daewoo Shipbuilding & Marine Engineering Co., Ltd., Hyundai Heavy Industries Co., Ltd., JGC Corporation, KBR, McDermott, MODEC Inc., Saipem, and Samsung Heavy Industries Co., Ltd.
Seasonality
Technip Energies’ onshore business is generally not impacted by seasonality. Technip Energies’ offshore business could be impacted by seasonality in the North Sea and other harsh environment regions during the offshore installation campaign at the end of a project.
Market Environment
In the first quarter of 2020, the COVID-19 pandemic provoked an unprecedented drop in demand for oil and gas, while supply was maintained at a high level for some time by some large oil and gas producing countries, resulting in sharp price reductions. Technip Energies’ clients reacted rapidly, cutting their investments and delaying project sanctions.
Given the long cycle nature of Technip Energies business and the resilience and maturity of the projects in backlog, Technip Energies has been able to mitigate a significant portion of COVID-19 operational impacts. For its large capital projects, deferrals of new projects were recorded while on-going projects were maintained. With the introduction of its energy transition framework, Technip Energies is well positioned to accompany clients in their shift towards low-carbon societies and pursue commercial opportunities, including in digitalization.
The onshore market activity continues to provide a tangible set of opportunities in LNG due to the critical role that natural gas plays as a transition fuel. By focusing on selectivity, cost competitiveness and an agility to capture new opportunities, Technip Energies continues to pursue refining, petrochemical, fertilizer, and renewables project opportunities. Based on a solid track-record, technologies and its energy transition framework, Technip Energies is well positioned for growth in sustainable chemistry and other low-carbon or carbon-free energy solutions.
Offshore market activity is expected to benefit in the near-term as macro conditions continue to support the international growth cycle, resulting in increased activity in offshore and deepwater exploration and development. In the long term, new upstream investment will also be required as gas becomes a bigger portion of the global energy mix. Technip Energies is well positioned to capture these opportunities due to its offering in all offshore markets and leadership position in FLNG or gas FPSO.
Strategy
Technip Energies strategy is based on the following:
•Selectivity of clients, projects, and geographies, which serves to maintain early engagement, leading to influence over technological choices, design considerations, and project specifications that make projects economically viable.
•Technology-driven differentiation with strong project management, which eliminates or significantly reduces technical and project risks, leading to both schedule and cost certainty without compromising safety.
•Excellence in project execution, because of our global, multi-center project delivery model complemented by deep partnerships and alliances to ensure the best possible execution for complex projects.
Technip Energies continues to invest in innovation and technology. Technip Energies is at the forefront of digital solutions due in part to its investment in three dimensional models, often referred to as digital twin, and interfaces.
Technip Energies continues to serve its clients in traditional markets, developing more energy-efficient solutions while making their facilities less-carbon intensive. Technip Energies’ framework about Energy Transition is organized around four pillars, and will help us accelerate the journey to a low-carbon society:
•LNG - to deliver the necessary infrastructure as a global leader as we transition to a low-carbon society.
•Sustainable Chemistry - to design and implement processes for products from renewable sources and to provide circular solutions for the generation of safe and sustainable substances that are in demand by industry and society.
•Decarbonization - to make Technip Energies’ clients’ businesses less carbon intensive across our activities, decarbonize fossil-based energies and manage the resulting CO2 in a sustainable manner.
•Carbon-Free Solutions - to expand Technip Energies’ portfolio of technologies and processes that provide non-carbon-based energy alternatives.
Recent and Future Developments
Technip Energies’ active early engagement with its clients through front-end engineering studies serves to optimize project economics while also significantly mitigating risks during project execution. Technip Energies direct engagement led to the signing of a major EPC contract in July for the construction of a new hydrocracking complex for the Assiut refinery in Egypt. Technip Energies continues to selectively track refining, petrochemical, fertilizer, and sustainable chemistry project opportunities - notably in the Middle East, Africa, Asia and North America - as these sectors typically prove to be more resilient through a downturn.
In response to an increase in demand for gas, new offshore investment will be required in the long term. Recent discoveries of offshore fields with reserves in regions such as Australia and East Africa are expected to benefit future activity; however, the timing of increased investment in these regions could be deferred. Offshore continued as a leader in gas projects with the ongoing Karish FPSO project for Energean, Tortue FPSO project for BP, and Coral FLNG project for Eni.
Product Development
Technip Energies is positioned as a premier provider of project execution and technology solutions, which enables its customers to unlock resources at advantaged capital and operating economics. Technip Energies invests in these main onshore R&D areas: (i) the development of process technology and equipment for economy of scale; (ii) continuous improvement of its proprietary process technologies and other solutions to reduce operating and investment cost; and (iii) diversification of its proprietary technology offering, especially in the energy transition domain.
Technip Energies’ offshore R&D efforts are focused on improving the economics of its clients’ diverse fixed and floating platform projects. Additionally, to further reduce operating and investment costs, Technip Energies continues to progress the development of robotic solutions for offshore platforms and work towards a standard and adaptable design for Normally Unmanned Installations. Technip Energies is also evaluating the various opportunities that will emerge as the industry and societal demands shift as part of the energy transition. Technip Energies continues to assess and implement the best digital technologies to support the business.
Acquisitions and Investments
Technip Energies has made an investment in McPhy, a leading manufacturer and supplier of carbon-free hydrogen production and distribution equipment. Technip Energies also signed a memorandum of understanding with McPhy, pursuant to which the two companies will jointly work on technology development and project implementation. In addition to its leadership position in hydrogen, this collaboration will help Technip Energies develop large-scale and competitive Green hydrogen solutions.
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 (i) drilling, (ii) stimulation, (iii) production, (iv) measurement, and (v) 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 in both vertical and horizontal 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 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 (i) conventional wellheads, (ii) Unihead® drill-thru wellheads designed for faster installation and drill-time optimization, and (iii) high-pressure, high-temperature (“HPHT”) systems for extreme production applications.
We also provide services associated to 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
Completion and stimulation. Our 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 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. These products are typically supplied to exploration and production operators who 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 and 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 a portfolio of flexible solutions for the onshore stimulation 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 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: (i) heavy-duty power ends, paired with main journal roller bearings and heavy-duty rod journal bearings, (ii) heavy-duty crankshafts, (iii) fluid cylinders, with accessible packing and valves, and (iv) 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 fully optimized and environmentally conscious, compact systems.
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, de-sanders, 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 deliquidisers, 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. We provide hardware and software solutions to 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.
Measurement. We design, manufacture, and service measurement products for the oil and gas industry. Our flow computers and control systems manage and monitor liquid and gas measurement for applications such as custody transfer, fiscal measurement, and batch loading and deliveries. Our FPSO metering systems provide the precision and reliability required for measuring large flow rates of marine loading operations. Our gas and liquid measurement systems are utilized in multiple energy-related applications, including crude oil and natural gas production and transportation, refined product transportation, petroleum refining, and petroleum marketing and distribution. We combine advanced measurement technology with state-of-the-art electronics and supervisory control systems to provide the measurement of both liquids and gases. This ensures processes operate efficiently while reducing operating costs and minimizing the risks associated with custody transfer.
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.
Capital Intensity
Surface Technologies manufactures most of its products, resulting in a reliance on manufacturing locations throughout the world, including fully owned manufacturing hubs in Stephenville, Texas, U.S., and Singapore, and a wide global network of third-party suppliers. We also maintain a large quantity of rental equipment related to our drilling and completion and pressure control offerings.
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% or more of our 2020 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 The Weir Group plc.
Market Environment
It has been a challenging year for the surface market, driven in part by the COVID-19 pandemic and the decline in hydrocarbon demand. Drilling and completion activity during 2020 decreased by approximately 40 percent compared to 2019 levels.
North American activity remained lower during the year, however, the number of U.S. fracturing crews has started to recover from the trough reached in May, and the weekly U.S. rig count has stabilized. Activity outside of North America remains resilient. We also continue to benefit from our exposure to the Middle East and Asia Pacific, both of which are being supported by strength in gas-related activity. The business mix outside of North America is expected to account for as much as 65% of total segment revenue in 2021.
Strategy
We exist to transform the surface market in order to provide customers with breakthrough reductions in cost and carbon intensity in the drilling, completion, upstream production, and midstream and downstream transportation sectors. We distinguish our offering by three key strengths: technology, integration, and automation.
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.
Automation: Intelligent products that are remotely managed using actionable data, reducing manpower in the field, maximizing uptime, and enabling enhanced production.
Product Development
In 2020, we capitalized on the launch of our revolutionary integrated ecosystems, iProduction™ and iComplete™, with the successful installation of our first iProduction™ system with Shell in their Permian basin iShale™
production site, and the implementation of our iComplete™ integrated system in the U.S. utilizing our digital interface technology, CyberFrac™.
iProduction™ is a modern production approach that includes well pad processing, gathering lines, and central processing facilities under a single digital interface. iProduction™ uses proprietary process technology, allowing customers to eliminate tanks, decrease GHG emissions and reduce footprint while maintaining reliability. By integrating and modularizing pre-engineered standard products, we reduced our clients’ costs by up to 33 percent, reduce time to first oil by up to 30 percent and, using our digital twin technology, each site is monitored and controlled remotely - delivering new levels of insightful data to ensure uptime.
iComplete™ uses standardized equipment that can be set up for any unconventional well in the world. The integrated system removes 80 percent of connections and reduces the need for manual intervention during operations thanks to our CyberFrac™ digital interface, which provides actionable data remotely. Our customers get to oil faster and reduce operating costs by 30 percent. This revolutionary approach is making our customers' frac pads faster, safer, and smarter.
Acquisitions and Investments
In June 2018, we broke ground on a new 52,000 square meter facility in Dhahran, Saudi Arabia, with work continuing throughout 2019. Despite the COVID-19 pandemic, work has progressed through 2020 and we are on track to open the facility by mid-2021. The facility, which will be comprised of 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 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.
Capitalizing on Energy Transition
TechnipFMC continues to innovate and introduce new technologies across our portfolio of products and services. Leveraging our vast experience and competencies from decades of working in the transformation of the energy sector, we enable our clients to achieve their energy transition targets.
In Subsea, we fundamentally changed the way we design, manage, and execute projects, starting with digital tools such as our Subsea Studio™. Our Subsea 2.0™ platform can greatly simplify subsea infrastructure, while reducing greenhouse gas emissions by nearly 50%. Combined with iEPCI™, our unique integrated model, it simplifies vessel installation campaigns, providing an even greater environmental and economic benefit. Our vision includes an “all-electric” system powered by renewable energy, with the potential to eliminate emissions.
Technip Energies continues to break boundaries and accelerate the journey to a low-carbon society. With decades of experience in the energy industry, Technip Energies is using its engineering, process and technology competencies as well as R&D facilities to find decarbonized solutions for a better environment. Technip Energies has structured its energy transition framework around four pillars: LNG, sustainable chemistry, decarbonization and carbon-free energy solutions. Technip Energies is a leader in gas treatment and liquefaction and has significant expertise and prospects in sustainable chemistry, such as its partnership with Neste’s for renewable diesel projects. It has expanded its footprint in the circular economy, including collaboration with Carbios to demonstrate its recycling technology. Technip Energies’ Genesis advisory services have a particular focus on energy transition. Technip Energies is a leader in hydrogen, with proven technology to deliver blue hydrogen and, through its investment in McPhy, it is well positioned for the emerging Green hydrogen market.
Surface Technologies’ high-efficiency solutions enable our clients to reach hydrocarbons faster with fully optimized and environmentally compact systems. Our integrated service lines, such as iProduction™ and iComplete™, provide additional opportunities and benefits to our customers. For instance, a project utilizing our iProduction™ integrated production system allows the client to capture more than 50 percent of the greenhouse gases that are typically released into the atmosphere during the production phase of an unconventional development.
OTHER BUSINESS INFORMATION RELEVANT TO OUR BUSINESS SEGMENTS
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 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 and Technip Energies 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 7,300 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 660 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 are 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.
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
Diversity
In the first quarter of 2018, we developed a global framework and key performance indicators for 2018 and beyond to promote and accelerate the development of women in all functions of our global organization.
Our Advancing Gender Diversity objectives include the following:
•Ensure gender pay equality everywhere we operate and review all jobs to ensure gender pay equality and monitor them through a full review every three years.
•Improve gender balance in the organization, across all functions and levels.
•Promote women fairly and equally through the career development process.
In 2018, we reviewed 100 percent of job functions to ensure pay equity. We identified areas for improvement and completed all necessary salary adjustments in 2019 to ensure fair compensation for all of our employees. Continuous monitoring to ensure pay equity was a focus for 2020. Additionally, in 2020, we announced a global parental leave policy for 2021 implementation.
In 2019, to foster a diverse and inclusive culture, we launched its “Diversity & Inclusion - It Matters!” e-learning module with an aim to raise awareness of our differences and help our employees improve as people and professionals. This e-learning module was added to new hire orientation in 2020 to promote our commitment to advancing gender diversity and an inclusive culture where all employees can reach their full potential. We also continued to improve gender balance in 2020 with a focus on increasing the representation of women hired as new graduates. 40 percent of all graduates hired globally in 2020 were women, surpassing our goal of 30 percent.
We continued to foster Employee Resource Groups (“ERGs”) and encourage participation throughout the whole Company. Our CEO made the pledge to CEO Action for Diversity and Inclusion, committing to create a trusting environment where all ideas are welcomed and employees feel comfortable and empowered to draw on their unique experiences and backgrounds. Our seven ERGs continue to be instrumental in engaging employees and creating a platform to have complex, and sometimes difficult conversations about diversity and inclusion.
Continuous discussions around improving representation of women in the organization helps us promote women fairly and equally throughout their career development process within our Company. In 2020, our People and Culture team reviewed all senior management succession plans to ensure that female candidates were considered and included.
As a result, 76 percent of our senior management succession plans in 2020 include at least one woman versus 70 percent in 2019, which exceeded our 2020 goal to increase representation of women in succession plans by five percent.
As of December 31, 2020, TechnipFMC had the following number of employees:
Male Employees Female Employees Total % of Female Employees
2019 2020 2019 2020 2019 2020 2019 2020
Executive officers 7 5 4 3 11 8 36 % 38 %
Senior managers 84 92 24 19 108 111 22 % 19 %
Employees on payroll (overall) 28,760 26,948 8,407 8,135 37,167 35,086 23 % 23 %
We are committed to improving this dimension and took necessary steps in strengthening our succession plans and graduate intake in 2020. We have also developed an inclusive leadership curriculum, which, along with executive leadership team commitment and systemic changes to policy and talent standards, will help improve women representation in senior manager roles in the medium to long term.
In June 2020, we decided to broaden our inclusion focus by reflecting not only gender but also race, ethnicity, religion, sexual orientation and disability. This committee is renamed to “Inclusion and Diversity” empowering our people to be the difference through inclusion and exercising the value of diversity. This will be accomplished through our people, culture and internal and external partnerships.
Promoting Cultural and Ethnic Diversity
We focus on our broad cultural and ethnic diversity, which we constantly promote and develop throughout the Company and our subsidiaries, through the internationalization of our teams, multicultural programs, and international mobility.
Providing Employment to People with Disabilities
Three of our Foundational Beliefs - integrity, respect, and sustainability - are tangibly embedded in fair employment practices and equal opportunity. Our 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 our policy wherever practicable to provide continuing employment under our usual terms and conditions, and to provide training, career development, and promotion opportunities to the disabled employee to the fullest extent possible.
Employee and Social Matters
People and culture are at the heart of our development strategy. People are our wealth and strength. We are committed to our employees, our employee guidelines are specified in our Code of Business Conduct, which applies to all employees, regardless of their roles and where they work.
We believe that all of 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:
December 31
2018 2019 2020
Permanent employees 33,528 34,454 31,395
Temporary employees (fixed-term) 3,616 2,713 3,691
Employees on payroll 37,144 37,167 35,086
Contracted workforce 3,458 5,310 2,880
Total workforce 40,602 42,477 37,966
Developing and Keeping Talent
We simplified the process of identifying key talents in the organization in 2020 and the new process helped us achieve significant and quality progress in a remote working environment. We also strengthened the depth of our succession planning for leadership roles in the organization.
Following the 2019 enhancement of our processes and practices, in 2020 we continued our journey of offering best-in-class development opportunities to our people:
•We introduced a new process called 'Talking Talents' in 2020 to identify and flag talents to develop in the key areas of Leadership, Technology and Project Management. This population represented 6 percent of our global population and will be the primary focus for development initiatives.
•Our new and improved performance appraisal process kicked off for all TechnipFMC employees in October 2020 and we concluded with 98 percent completion. A stronger focus was put on employees’ behaviors, as part of our core values framework, and a simplified workflow for employees and managers for an efficient performance appraisal process.
•We continued to support our talent acquisition efforts by reinforcing the TechnipFMC employer brand in 2020, reflecting what our people say about TechnipFMC: we work on breakthrough projects, in a global playground and, as a result, our people live inspiring experiences. This is the key message we want potential future employees to associate with TechnipFMC. Initiatives, such as #technipfmcproud, launched in 2020 comprised of a series of webinars, inviting employees to share their own inspiring TechnipFMC experiences. This, along with other initiatives and onboarding of brand ambassadors, helped us put our employer brand into operation in 2020.
Enabling our people to grow and develop is a significant priority and during 2020 we launched and improved upon a number of learning and knowledge management initiatives to enhance the capabilities of our employees. While our ambition is to create a learning environment and tools and resources for everyone to succeed - some of our content is indeed focused on the following development pathways of Leadership, Technology and Project Management mentioned earlier.
•In October 2020, we launched the global technical expertise program, onboarding more than 650 technical experts and laying the foundation for identifying and nurturing more technical experts who help us in creating differentiated technologies.
•Engagement in the iLearn learning platform gained significant traction in 2020 as we embraced a digital transformation of learning. This hub is a learning experience platform with a modern and easy-to-use interface. In 2020, there were more than 6,860 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 job. 50 percent of our training hours and 95 percent of our course completions were done in a digital or virtual environment, which resulted in 5.85 training hours per employee. The top five areas of learning in 2020 were Health, Safety, Environment and Security, Engineering, Manufacturing, Quality and Surface.
•2020 also saw significant progress in the knowledge management space with our knowledge repository “The Well” having over 646,000 visits with 16,674 employees having utilized it. Our second knowledge-sharing platform, The Bridge, which aligns with The Well, enables chartered global knowledge-sharing networks. It had a soft launch in May 2020, and now has 17 enterprise-wide business and technical communities with the expectation that there will be more than 50 by the end of 2021.
Employee attrition in 2020 was 2.5 percent compared to 6.2 percent in 2019 attributable to a major extent to our continued focus on learning and talent development.
Strengthening Social Dialogue
TechnipFMC 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 European Works Council (“EWC”) meets at least twice a year and all of our European entities had joined the EWC by the end of 2019 with the EWC agreement signed by participants' representatives by the end of 2019. In the first quarter of 2020, the EWC elected its new member and held two meetings in 2020, first in May and the second in December.
We also foster ERGs, which are voluntary, employee-led focus groups dedicated to a diverse and inclusive work environment. We currently have seven active ERGs with approximately 1,800 members in the United States, the United Kingdom, and Brazil, covering Diversity in Science, Technology, Engineering and Mathematics, Mothers Network, Black Organization for Leadership & Development, Young Professionals Group, Military Veterans & Friends Network, and Handicap Inclusion. ERGs discuss and promote topics related to diversity and inclusion, develop and organize workshops internally and externally, support local initiatives, and propose actions to improve accessibility and inclusivity for all at the workplace. TechnipFMC provides executive support to our ERGs to help maintain cordial employee relations and improve the wellbeing of our people.
Employee Wellbeing
In light of the global challenges faced in 2020 due to COVID-19 pandemic, we ran a global employee wellbeing survey in May to understand how our employees were coping with social distancing and other related domestic challenges during the pandemic. We received a strong response, with 19,954 (55 percent) employees responding globally which helped us develop policies to assist in the challenges our people are facing in these unprecedented times. 74 percent of responding employees answered favorably to the question on their overall wellbeing. The survey also gave us insights on other topics that helped in improving overall communication and employee engagement.
Internal Communication
We have a robust internal communications strategy and support communication channels that ensure that all employees are communicated to within a timely and relevant way. The effectiveness of internal communication is continually monitored and adjusted based on a focus group feedback program that reaches multiple levels across the organization. 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 our intranet site. These consultations and meetings ensure that employees are kept informed of the financial and economic factors affecting our performance and matters of concern to them as employees.
Labor Relations and Collective Agreements
We seek to maintain constructive relationships with works councils and trade unions, and to comply with relevant local laws and collective agreements in relation to collective or individual labor relations. We also operate through local subsidiaries in many countries, a number of which, including France, Germany, Norway, and Italy, 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 company. The same approach of sharing information and maintaining a regular dialogue with employees exists at a local level through the action of the local
communications teams and the managers. In countries where staff representatives or works councils are in place, we seek to maintain an effective and regular dialogue. To get the direct feedback of employees, employees surveys are performed in some countries or business, such as Norway, Americas, and the Asia Pacific region. Every quarter, all employees receive a direct communication from the Chairman and CEO about our financial results and main business information. While travelling to a company center, the executive leadership team members take this as an opportunity to engage with employees, either through town halls or informal meetings.
EXECUTIVE OFFICERS OF THE REGISTRANT
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 March 5, 2021, 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)
57 Executive Chairman and Chief Executive Officer (2019)
Chief Executive Officer (2017)
President and Chief Executive Officer of FMC Technologies (2016)
Alf Melin (a)
51 Executive Vice President and Chief Financial Officer (2021)
Senior Vice President, Finance Operations (2017)
Senior Vice President, Surface Americas (2017)
General Manager, Fluid Control (2015)
Victoria Lazar (a)
55 Executive Vice President, General Counsel and Secretary (2020)
Senior Vice President, General Counsel and Corporate Secretary for Bristow Group (2020)
Executive Counsel, M&A, General Electric (2019)
Associate General Counsel, Baker Hughes, a GE Company (2018)
Associate General Counsel, GE Oil & Gas (2017)
Justin Rounce (a)
54 Executive Vice President and Chief Technology Officer (2018)
President, Valves & Measurement for Schlumberger Limited (2018)
Senior Vice President, Marketing & Technology for Schlumberger Limited (2016)
Agnieszka Kmieciak (a)
47 Executive Vice President, People and Culture (2018)
HR Director, Production Group for Schlumberger Limited (2017)
Talent Manager and Workforce Planning Manager for Schlumberger Limited (2015)
Barry Glickman (a)
52 President, Surface Technologies (2019)
President, Engineering, Manufacturing and Supply Chain (2017)
Vice President, Subsea Services of FMC Technologies (2015)
Jonathan Landes (a)
48 President, Subsea (2020)
Senior Vice President, Subsea Commercial (2017)
President, Subsea Projects North America (2017)
General Manager, Western Region Subsea (2015)
Krisztina Doroghazi (b)
49 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.

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ITEM 1A. RISK FACTORS
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.
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 highly 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.
•The COVID-19 pandemic, the United Kingdom’s withdrawal from the European Union, 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 and Euroclear may cease to act as depository and clearing agencies 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.
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 of our IT infrastructure, 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.
•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; 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 French or 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.
Risks Related to the Spin-off and the Related Transactions
•The Spin-off may subject us to future liabilities and may not achieve some or all of the anticipated benefits.
•We are a significant shareholder of Technip Energies and the value of our investment in Technip Energies may fluctuate substantially and may result in a significant impact to our results of operations.
•We may be required to refund the Purchase Price under the Share Purchase Agreement to BPI in the event that certain conditions thereunder are not met.
General Risk Factors
•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.
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;
•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 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 control the value chain, which may affect demand for our products and services because of price concessions for 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 prices, 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.
The COVID-19 pandemic has significantly 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 significant 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.
Significant 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. Beginning in the first quarter of 2020, we have experienced operational impacts including supply chain disruptions, productivity declines and logistics constraints. We have also experienced incremental, direct costs as a result of COVID-19.
COVID-19, and the volatile 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 success of actions taken by governments and health organizations to combat the disease and treat its effects, including vaccine acceptance, distribution and effectiveness; 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, and 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.
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 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.
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 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;
•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.
DTC and Euroclear may cease to act as depository and clearing agencies for our shares.
Our shares were issued into the facilities of The Depository Trust Company (“DTC”) with respect to shares listed on the NYSE and Euroclear with respect to shares listed on Euronext Paris (DTC and Euroclear being referred to as the “Clearance Services”). The Clearance Services are widely used mechanisms that allow for rapid electronic transfers of securities between the participants in their respective systems, which include many large banks and brokerage firms. The Clearance Services have general discretion to cease to act as a depository and clearing agencies for our shares. If either of the Clearance Services determine 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 or Euronext Paris, as applicable, 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 based in the United Kingdom and have operational headquarters in Paris, France; Houston, Texas, United States; and in London, United Kingdom, 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. For example, any divergence in the United Kingdom from European Union law could eliminate the benefit of certain tax-related European Union directives currently applicable to United Kingdom companies such as us, including the Parent-Subsidiary Directive and the Interest and Royalties Directive, which could, subject to any relief under an available tax treaty, raise our tax cost.
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, 2020, our total debt was $4.0 billion. In addition, in connection with Spin-off, we obtained commitments from a syndicate of financial institutions for a senior secured revolving credit facility of up to $1.0 billion. We will 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:
•make it more difficult for us to make payments on our debt;
•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 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 or our other debt.
The London Interbank Offered Rate (“LIBOR”), the Euro Interbank Offered Rate 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, which regulates LIBOR, has announced that the continuation of LIBOR on the current basis cannot and will not be guaranteed after 2021 and it is unclear if LIBOR will cease to exist or if new methods of calculating LIBOR will evolve. If LIBOR ceases to exist or if the methods of calculating LIBOR change from their current form, interest rates on our current or future 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 multicurrency 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 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.
Risks Related to Our Operations
We may lose money on fixed-price contracts.
As 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 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.
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.
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 the 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.
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 of our IT infrastructure, 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 our IT systems. 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. We have been subject to cyber-attacks in the past, including phishing, malware, and ransomware. No such attack has had a material adverse effect on our business, however this may not be the case with future attacks. Our systems 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, loss or destruction of data (including confidential customer 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. The security and privacy measures implemented by such third parties, as well as the measures implemented by any 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 IT vendor agreements 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 arise from numerous sources, not all of which are within our 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, or terrorist acts. The failure
of our IT systems or those of our vendors to perform as anticipated for any reason or any significant breach of security 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, regulatory action and fines included for a breach of data protection laws, reputational harm, regulatory fines or investigations, increased overhead costs, 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 disruptions or security breaches in the future. Our insurance coverage may not cover all of the costs and liabilities we incur as the result of any disruptions or security breaches, 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.
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 uncontrollable flows of gas or well fluids, 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, in the future, operate, 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 increases 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 internal controls 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 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 Environmental, Social and Governance (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, 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.
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 shares of 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 and 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 the 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 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 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, or GDPR, in the European Economic Area, or EEA, and the United Kingdom (“UK”) GDPR and Data Protection Act 2018 in the UK. The 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’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. In addition, the UK’s withdrawal from the European Union may mean that in future we are required to find alternative solutions for the compliant transfer of personal data into the UK.
Failure to comply with the requirements of GDPR and the local laws implementing or supplementing the GDPR could result in fines of up to €20,000,000 or up to 4% of the total worldwide annual turnover of the preceding financial year, whichever is higher, as well as other administrative penalties. The UK GDPR mirrors the fines under the GDPR. In addition, a breach of the GDPR or UK GDPR could result in regulatory investigations and enforcement action, reputational damage, and civil claims including representative actions and other class action type litigation.
We are likely to be required to expend significant capital and other resources to ensure ongoing compliance with the GDPR and 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 recent guidance from the U.S. Treasury 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.
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 had an extended focus on issues related to the taxation of multinational corporations. 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. 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 also 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.
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.
Risks Related to the Spin-off and the Other Transactions
The Spin-off may subject us to future liabilities.
On February 16, 2021, we completed the Spin-off, resulting in Technip Energies, which holds our former Technip Energies business segment, becoming a stand-alone publicly traded corporation. Pursuant to agreements we entered into with Technip Energies in connection with the Spin-off, we and Technip Energies are each generally responsible for the obligations and liabilities related to our respective businesses. Pursuant to those agreements, we and Technip Energies each agreed to cross-indemnities principally designed to allocate financial responsibility for the obligations and liabilities of our business to us and those of Technip Energies’ business to it. However, third parties, including governmental agencies, could seek to hold us responsible for obligations and liabilities that Technip Energies agreed to retain or assume, and there can be no assurance that the indemnification from Technip Energies will be sufficient to protect us against the full amount of such obligations and liabilities, or that Technip Energies will be able to fully satisfy its indemnification obligations. Additionally, if a court were to determine that the Spin-off or related transactions were consummated with the actual intent to hinder, delay or defraud current or future creditors or resulted in Technip Energies receiving less than reasonably equivalent value when it was insolvent, or that it was rendered insolvent, inadequately capitalized or unable to pay its debts as they become due, then it is possible that the court could disregard the allocation of obligations and liabilities agreed to between us and Technip Energies, impose substantial obligations and liabilities on us and void some or all of the transactions related to the Spin-off. Any of the foregoing could adversely affect our results of operations and financial position.
The Spin-off may not achieve some or all of the anticipated benefits.
We may not realize some or all of the anticipated strategic, financial, operational or other benefits from the Spin-off. As independent publicly-traded companies, we and Technip Energies are smaller, less diversified companies with a narrower business focus, and may be more vulnerable to changing market conditions, which could materially adversely affect our and its results of operations, cash flows and financial position.
In addition, other events outside of our control, including, but not limited to, political climate, the severity and duration of the pandemic, and regulatory or legislative changes, could also adversely affect our ability to realize the anticipated benefits from the Spin-off. Any such difficulties could have an adverse effect on our business, financial condition, or results of operations, and cause the combined market value of us and Technip Energies after the Spin-off to fall short of the market value of our shares prior to the Spin-off.
We are a significant shareholder of Technip Energies and the value of our investment in Technip Energies may fluctuate substantially.
Following completion of the Spin-off, we own approximately 49.9% of the outstanding shares of common stock of Technip Energies. The value of our investment in Technip Energies may be adversely affected by negative changes in its results of operations, cash flows and financial position, which may occur as a result of the many risks attendant with operating in the onshore/offshore industry, including the effect of laws and regulations on the operation of Technip Energies’ business and the development of its assets, increased competition, loss of contract commitments, delays in the timing of or the failure to complete projects, lack of access to capital and operating risks and hazards. The value of our investment in Technip Energies may fluctuate substantially and may result in a significant impact to our results of operations.
We intend to significantly reduce our shareholding in Technip Energies over the 18 months following the Spin-off, including in connection with the sale of Technip Energies shares to BPI (as defined herein) pursuant to the Investment (as defined herein). However, we can offer no guarantee that we will be able to complete such disposition or, if completed, the extent to which we will reduce our shareholding or the value that we will realize in connection with such disposition. The occurrence of any of these and other risks faced by Technip Energies could adversely affect the value of our investment in Technip Energies.
We may be required to refund the Purchase Price under the Share Purchase Agreement to BPI in the event that certain conditions thereunder are not met.
In connection with the Spin-off, we entered into the Share Purchase Agreement with BPI, pursuant to which BPI agreed to purchase from us for $200.0 million, subject to a purchase price adjustment as described below (the “Purchase Price”), a number of Technip Energies shares (the “Purchased Shares”) determined based upon a thirty day volume-weighted average price of Technip Energies’ shares, less a six percent discount (the “Investment”). Pursuant to the Share Purchase Agreement, BPI paid us the Purchase Price on February 25, 2021, however (i) if the number of Purchased Shares due from us to BPI is less than 11.82% of the number of Technip Energies shares outstanding immediately following completion of the Spin-off, then BPI may, upon written notice to us, terminate the Share Purchase Agreement and we will be required to refund the Purchase Price to BPI or (ii) if the number of Purchased Shares due from us to BPI exceeds 17.25% of the number of Technip Energies shares outstanding immediately following completion of the Spin-off (the “Cap”), then we will transfer to BPI an aggregate number of Technip Energies shares equal to the Cap and will pay to BPI, as a reduction of the Purchase Price, an amount equal to (x) the difference between the number of Technip Energies shares that we would have delivered to BPI but for the Cap and the number of Technip Energies shares that we actually delivered to BPI, multiplied by (y) the applicable price per Technip Energy share. Any such refund or reduction of the Purchase Price could have a material adverse effect on our financial condition or cash flows.
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 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, Russia, 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. 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 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.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.

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ITEM 2. PROPERTIES
ITEM 2. PROPERTIES
Our corporate headquarters is in London, England. We also maintain corporate offices in Houston, Texas and Paris, France, 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 as of December 31, 2020:
Location
Segment
Africa
Dande, Angola
Subsea
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
Technip Energies
Dahej, India
Technip Energies
Hyderabad, India
Surface
Jakarta, Indonesia
Surface
Johor, Malaysia
Subsea
Kuala Lumpur, Malaysia
Subsea, Surface, Technip Energies
Mumbai, India
Technip Energies
New Delhi, India
Technip Energies
Noida, India
Subsea, Surface, Technip Energies
Nusajaya, Malaysia
Subsea, Surface
Singapore
Subsea, Surface
Australia
Henderson, Australia
Subsea
Perth, Australia
Subsea, Technip Energies
Europe
Aberdeen, United Kingdom
Subsea, Surface
Aktau, Kazakhstan
Surface
Arnhem, The Netherlands
Surface
Atyrau, Kazakhstan
Surface
Barcelona, Spain
Technip Energies
Bergen, Norway
Subsea
Compiegne, France
Technip Energies
Courbevoie (Paris - La Défense), France
Subsea, Technip Energies
Dunfermline, United Kingdom
Subsea, Surface
Ellerbek, Germany
Surface
Evanton, United Kingdom
Subsea
Horten, Norway
Subsea
Kongsberg, Norway
Subsea, Surface
Krakow, Poland
Subsea
La Garenne-Colombes, France
Technip Energies
Le Trait, France
Subsea, Surface
Lisbon, Portugal
Subsea
London, United Kingdom
Subsea, Technip Energies
Lyon, France
Technip Energies
Lysaker, Norway
Subsea, Technip Energies
Moscow, Russia
Subsea, Surface, Technip Energies
Newcastle, United Kingdom
Subsea
Orkanger, Norway
Subsea
Rome, Italy
Technip Energies
Sens, France
Surface, Technip Energies
St. Petersburg, Russia
Technip Energies
Stavanger, Norway
Subsea, Surface
Veenord, Netherlands
Surface
Zoetermeer, Netherlands
Technip Energies
Middle East
Abu Dhabi, United Arab Emirates
Surface, Technip Energies
Al-Khobar, Saudi Arabia
Technip Energies
Dammam, Saudi Arabia
Surface
Doha, Qatar
Technip Energies
North America
Brighton (Colorado), United States
Surface
Calgary (Alberta), Canada
Surface
Davis (California), United States
Subsea
Erie (Pennsylvania), United States
Surface
Houston (Texas), United States
Subsea, Surface, Technip Energies
Odessa (Texas), United States
Surface
Oklahoma City (Oklahoma), United States
Surface
San Antonio (Texas), United States
Surface
Speers (Pennsylvania), United States
Surface
St. John’s (Newfoundland), Canada
Subsea
Stephenville (Texas), United States
Surface
Theodore (Alabama), United States
Subsea
South America
Bogota, Colombia
Technip Energies
Macaé, Brazil
Subsea
Neuquén, Argentina
Surface
Rio de Janeiro, Brazil
Subsea, Surface
São João da Barra, Brazil
Subsea
Veracruz, Mexico
Surface
Yopal, Colombia
Surface
The following table shows marine vessels in which we held an interest or operated as of December 31, 2020:
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
Global 1200 (a)
PLSV/HCV Conventional pipelay/Heavy handling operations
Deep Orient HCV Construction/installation systems
North Sea Atlantic (b)
HCV Construction/installation systems
Skandi Africa (b)
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
(a) At December 31, 2020, this vessel is held for sale.
(b) Vessels under long term charter.
PLSV: Pipelay Support Vessel
HCV: Heavy Duty Construction Vessel
DSV: Diving Support Vessel
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 the regulated market of Euronext Paris, in each case trading under the “FTI” symbol.
For information about dividends, see Note 17 “Stockholders’ Equity” to the Consolidated Financial Statements in Item 8.
As of February 25, 2021, according to data provided by our transfer agent, there were 101 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 20,500 shareholders whose shares were held in “street name” by banks, brokers, or other financial institutions at February 25, 2021.
We had no unregistered sales of equity securities during the year ended December 31, 2020.
Issuer Purchases of Equity Securities
Period
Total Number
of Shares
Purchased Average Price
Paid per Share Total Number of
Shares Purchased
as Part of Publicly
Announced Plans
or Programs Maximum
Number of Shares
That May Yet
Be Purchased
Under the Plans
or Programs (a)
October 1, 2020 - October 31, 2020 - $ - - 14,286,427
November 1, 2020 - November 30, 2020 - $ - - 14,286,427
December 1, 2020 - December 31, 2020 - $ - - 14,286,427
Total - - 14,286,427
(a)In December 2018, our Board of Directors authorized an extension of our share repurchase program for $300 million for the purchase of ordinary shares. As of December 31, 2020, $207.8 million remained authorized under the share repurchase program.
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, 2020 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.
December 31
2017 2018 2019 2020
TechnipFMC plc $ 87.76 $ 55.89 $ 62.63 $ 28.03
S&P 500 Index 119.82 114.56 150.62 178.32
PHLX Oil Services Index 82.00 44.93 44.68 25.88
ITEM 6. SELECTED FINANCIAL DATA
The following tables set forth selected financial data for each of the five years in the period ended December 31, 2020. This information should be read in conjunction with Part I, Item 1 “Business,” Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the audited consolidated financial statements and notes thereto included in Part II, Item 8 of this Annual Report on Form 10-K.
Year Ended December 31,
(In millions, except per share data) 2020 2019 2018 2017 2016
Statement of income data
Total revenue $ 13,050.6 $ 13,409.1 $ 12,552.9 $ 15,056.9 $ 9,199.6
Total costs and expenses $ 15,936.2 $ 14,935.8 $ 13,470.5 $ 14,091.7 $ 8,743.6
Net income (loss) $ (3,237.9) $ (2,412.1) $ (1,910.8) $ 134.2 $ 371.1
Net income (loss) attributable to TechnipFMC plc $ (3,287.6) $ (2,415.2) $ (1,921.6) $ 113.3 $ 393.3
Earnings (loss) per share from continuing operations attributable to TechnipFMC plc
Basic earnings (loss) per share $ (7.33) $ (5.39) $ (4.20) $ 0.24 $ 3.29
Diluted earnings (loss) per share $ (7.33) $ (5.39) $ (4.20) $ 0.24 $ 3.16
As of December 31,
(In millions) 2020 2019 2018 2017 2016
Balance sheet data
Total assets $ 19,692.6 $ 23,518.8 $ 24,784.5 $ 28,263.7 $ 18,679.3
Long-term debt, less current portion $ 3,317.7 $ 3,980.0 $ 4,124.3 $ 3,777.9 $ 1,869.3
Total TechnipFMC plc stockholders’ equity $ 4,154.2 $ 7,659.3 $ 10,357.6 $ 13,345.9 $ 5,013.8
Year Ended December 31,
(In millions) 2020 2019 2018 2017 2016
Other financial information
Capital expenditures $ 291.8 $ 454.4 $ 368.1 $ 255.7 $ 312.9
Cash flows provided (required) by operating activities $ 656.9 $ 848.5 $ (185.4) $ 210.7 $ 493.8
Net cash $ 853.9 $ 714.8 $ 1,348.3 $ 2,882.4 $ 3,716.4
Order backlog $ 21,388.2 $ 24,251.1 $ 14,560.0 $ 12,982.8 $ 15,002.0
The results of our operations for the year ended December 31, 2020 include goodwill and long-lived asset impairment charges of $3,083.4 million and $204.0 million, respectively. The results of our operations for the year ended December 31, 2019 include goodwill and long-lived asset impairment charges of $1,988.7 million and $495.4 million, respectively. The results of our operations for the year ended December 31, 2018 include goodwill and vessels impairment charges of $1,383.0 million and $372.9 million, respectively, and a legal provision of $280.0 million. See Notes 19 and 20 to our consolidated financial statements for further details.
The results of our operations for the year ended December 31, 2017 consist of the combined results of operations of Technip and FMC Technologies. Due to the Merger, FMC Technologies’ results of operations have been included in our financial statements for periods subsequent to the consummation of the Merger on January 16, 2017 and as a result, data presented for the year December 31, 2017 is not comparable to actual results presented in prior periods. Technip was the accounting acquirer, therefore results for the years ended December 31, 2016 represent Technip only.
Net cash consists of cash and cash equivalents less short-term debt, long-term debt and the current portion of long-term debt. Net cash is a non-GAAP measure that management uses to evaluate our capital structure and financial leverage. See “Liquidity and Capital Resources” in Part II, Item 7 of this Annual Report on Form 10-K for additional discussion and reconciliations of net cash.
Order backlog is calculated as the estimated sales value of unfilled, confirmed customer orders at the reporting date.
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 the following segments: Subsea, Technip Energies 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 description of our products and services and annual financial data for each segment can be found in Part I, Item 1, “Business” and 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. Our Technip Energies segment is impacted by change in commodity prices, population growth and demand for natural gas, although the onshore market is typically more resilient to these changes impacting the segment. Our Subsea and Technip Energies segments both benefit from the current market fundamentals supporting the demand for new liquefied natural gas facilities. Technip Energies also benefits from the construction of petrochemical and fertilizer plants.
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 cash are therefore key performance indicators of cash flows.
In each of our segments, we serve customers from around the world. During 2020, approximately 84 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.
In connection with the Spin-off, on January 7, 2021, BPI, which has been one of our substantial shareholders since 2009, entered into a Share Purchase Agreement with us pursuant to which BPI agreed to purchase a portion of our retained stake in Technip Energies N.V. for $200.0 million. On February 25, 2021, BPI paid $200.0 million in connection with the Share Purchase Agreement. The Purchase Price is subject to adjustment, and BPI’s ownership stake will be determined based upon a thirty day volume-weighted average price of Technip Energies N.V.’ shares (with BPI’s ownership collared between an 11.82 percentage floor and a 17.25 percentage cap), less a six percent discount. The BPI Investment is subject to customary conditions and regulatory approval. We intend to significantly reduce our shareholding in Technip Energies N.V. over the 18 months following the Spin-off, including in connection with the sale of shares to BPI pursuant to the BPI Investment.
Beginning in the first quarter of 2021, Technip Energies’ historical financial results for periods prior to the Distribution will be reflected in our consolidated financial statements as discontinued operations.
BUSINESS OUTLOOK
Overall outlook - While economic activity continues to be impacted by the COVID-19 pandemic, the short-term outlook for crude oil has improved as the OPEC+ countries better manage the oversupplied market. Long-term demand for energy is still forecast to rise, and we believe this outlook will ultimately provide our customers with the confidence to increase investments in new sources of oil and natural gas production.
Subsequent to the Spin-off, we will operate under two reporting segments: Subsea and Surface Technologies, therefore the discussion below relates to these two reporting segments only.
Subsea - The volatile, and generally low crude oil price environment of the last several years led many of our customers to reduce their capital spending plans and defer new deepwater projects. Order activity in 2020 was particularly impacted by the sharp decline in commodity prices, driven in part by the reduced economic activity, and the general uncertainty related to the pandemic. The reduction and deferral of new projects resulted in delayed subsea project inbound for the industry.
The trajectory and pace of further recovery and expansion in the subsea market is subject to more stringent capital discipline and the allocation of capital our clients dedicate to developing offshore oil and gas fields amongst their entire portfolio of projects. The risk of project sanctioning delays still exists in the current environment; however, innovative approaches to subsea projects, like our iEPCI solution, have improved project economics, and many offshore discoveries can be developed economically at today’s crude oil prices. In the long-term, deepwater development is expected 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 future order activity.
We have experienced renewed operator confidence in advancing subsea activity as a result of the improved economic outlook, lower market volatility and higher oil price. With crude now trending back above $50 per barrel, the opportunity set of large subsea projects to be sanctioned over the next 24 months has expanded.
FEED activity is also improving, with solid momentum experienced in the second half of 2020. FEED activity in the current year is expected to return to the more robust levels seen in 2019, which further supports our view of a sustainable recovery for deepwater. We expect at least 60% of the projects undergoing studies in 2021 to include an iEPCI solution, many of which could be directly awarded to our Company upon reaching final investment decision.
TechnipFMC is increasingly less dependent on larger, publicly tendered projects.
•We anticipate that an increasing share of our inbound orders will result from projects that will be direct awarded to our Company, many of which come from our alliance partners;
•We anticipate higher activity in subsea services, with the industry’s largest installed base; and
•We expect a higher mix of iEPCI project awards, demonstrating strong geographic diversity and new adopters of our unique, integrated approach to subsea development.
For 2021, we believe that Subsea inbound orders will meet or exceed the $4 billion achieved in 2020. We expect Brazil to be the most active region of the world for new project orders, driven by continued investment in the pre-salt field discoveries. We see additional market growth potential coming from the North Sea, Asia Pacific and Africa. The strong front end activity we are experiencing today should further support project award momentum into 2022.
Surface Technologies - Surface Technologies’ 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 the Americas.
The North America shale market is sensitive to oil price fluctuations. The average rig count declined by just over 50 percent in 2020, with drilling and completion spending estimated to have declined by a similar amount. North America activity improved over the second half of the year as the rig count increased following the rising oil price. The rig count exited 2020 below prior year-end levels but has experienced further improvement in the current year.
In 2021, we expect our completions-related revenue to outperform the overall market, driven by increased market adoption of iComplete - our fully integrated, digitally-enabled pressure control system. iComplete has already achieved significant market penetration since its introduction in the third quarter of 2020, with 10 customers utilizing the new integrated system.
Despite the sequential improvement in market activity, full year revenue for North America is expected to be flat to down modestly versus 2020.
Drilling activity in international markets is less cyclical than North America as most activity is 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 Middle East and Asia Pacific, both of which are being supported by strength in gas-related activity. The average rig count in these two regions declined by a more modest 17 percent in 2020 versus the prior year.
International revenue has been gaining significance in our total segment revenue, representing over 60 percent in 2020. We expect a gradual and steady recovery in well count in 2021 to drive modest international market growth, with spending increases led by national oil companies, particularly in the Middle East.
Our unique capabilities in the international markets, which demand higher specification equipment, global services and local content, provide a platform for us to extend our leadership positions. We remain levered to these more resilient markets where we expect to source approximately 65% of our full year revenue in 2021.
CONSOLIDATED RESULTS OF OPERATIONS
This section of this Form 10-K generally discusses 2020 and 2019 items and year-to-year comparisons between 2020 and 2019. Discussions of 2018 items and year-to-year comparisons between 2019 and 2018 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, 2019.
Year Ended December 31, Change
(In millions, except percentages) 2020 2019 2018 2020 vs. 2019 2019 vs. 2018
Revenue $ 13,050.6 $ 13,409.1 $ 12,552.9 $ (358.5) (2.7) % $ 856.2 6.8 %
Costs and expenses
Cost of sales 11,209.4 10,950.7 10,273.0 258.7 2.4 % 677.7 6.6 %
Selling, general and administrative expense 1,066.2 1,228.1 1,140.6 (161.9) (13.2) % 87.5 7.7 %
Research and development expense 119.8 162.9 189.2 (43.1) (26.5) % (26.3) (13.9) %
Impairment, restructuring and other expense 3,501.3 2,490.8 1,831.2 1,010.5 40.6 % 659.6 36.0 %
Separation costs 39.5 72.1 - (32.6) (45.2) % 72.1 n/a
Merger transaction and integration costs - 31.2 36.5 (31.2) (100.0) % (5.3) (14.5) %
Total costs and expenses 15,936.2 14,935.8 13,470.5 1,000.4 6.7 % 1,465.3 10.9 %
Other income (expense), net 31.1 (220.7) (323.9) 251.8 114.1 % 103.2 31.9 %
Income from equity affiliates 63.0 62.9 114.3 0.1 0.2 % (51.4) (45.0) %
Net interest expense (293.0) (451.3) (360.9) 158.3 35.1 % (90.4) (25.0) %
Loss before income taxes (3,084.5) (2,135.8) (1,488.1) (948.7) (44.4) % (647.7) (43.5) %
Provision for income taxes 153.4 276.3 422.7 (122.9) (44.5) % (146.4) (34.6) %
Net loss (3,237.9) (2,412.1) (1,910.8) (825.8) (34.2) % (501.3) (26.2) %
Net profit attributable to non-controlling interests (49.7) (3.1) (10.8) (46.6) (1,503.2) % 7.7 71.3 %
Net loss attributable to TechnipFMC plc $ (3,287.6) $ (2,415.2) $ (1,921.6) $ (872.4) (36.1) % $ (493.6) (25.7) %
Results of Operations in 2020 Compared to 2019
Revenue
Revenue decreased by $358.5 million in 2020 compared to 2019. Subsea revenue decreased year-over-year primarily due to decreased project activity in the Gulf of Mexico and the North Sea. Increased revenue in Technip Energies was primarily driven by the continued ramp-up of Arctic LNG 2, increased activity on downstream projects and in the Process Technology business, which more than offset the decline in revenue from Yamal LNG. Technip Energies revenue was also favorably impacted by the result of a litigation settlement. Surface Technologies revenue decreased, primarily as a result of the significant decline in operator activity in North America, with partial positive impact from order intake timing in international markets. In addition, our consolidated revenues were negatively impacted by operational challenges associated with the COVID-19 related disruptions.
Gross Profit
Gross profit (revenue less cost of sales) as a percentage of sales decreased to 14.1% in 2020 compared to 18.3% in 2019. Subsea gross profit decreased due to a more competitively priced backlog and the negative operational impacts related to COVID-19. Gross profit declined in Technip Energies due in large part to a reduced contribution from Yamal LNG as the project reached physical completion last year and is progressing through the warranty phase. Surface Technologies gross profit was negatively impacted by the year-over-year decline in North American drilling and completions activity, which was partially offset by the lower costs from our accelerated cost reduction initiative implemented during 2020.
Selling, General and Administrative Expense
Selling, general and administrative expense decreased by $161.9 million year-over-year, primarily as a result of decreased corporate expenses. During the beginning of 2020, in response to the deteriorated market environment, driven in part by the COVID-19 pandemic, we implemented a series of cost reduction initiatives that resulted in significant savings and extended to all business segments and support functions.
Impairment, Restructuring and Other Expenses
We incurred $3,501.3 million of restructuring, impairment and other expenses in 2020. These charges primarily included $3,083.4 million of goodwill impairment, $204.0 million of long-lived assets impairment, $101.8 million of COVID-19 related expenses, and $112.1 million for restructuring and severance expenses. 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. COVID-19 related expenses exclude costs associated with project and/or operational inefficiencies, time delays in performance delivery, indirect costs increases and potentially reimbursable or recoverable expenses. During 2019, we incurred $2,490.8 million of restructuring, impairment and other expenses, which included $1,988.7 million and $495.4 million of goodwill and long-lived assets impairments, respectively. See Note 19 to our consolidated financial statements for further details.
Separation costs
During the year ended December 31, 2020, we incurred $39.5 million of separation costs associated with the preparation of the separation transaction. During the first quarter of 2020, we incurred $27.1 million of separation costs associated with the separation transaction, which was postponed due to the COVID-19 pandemic, the significant decline in commodity prices, and the heightened volatility in global equity markets. During the fourth quarter of 2020, we incurred $12.4 million of separation costs associated with the January 2021 announcement of the resumption of activities toward the separation of Technip Energies. During the year ended December 31, 2019, we incurred $72.1 million of separation costs associated with the separation transaction. See Note 3 to our consolidated financial statements for further details.
Merger Transaction and Integration Costs
Prior to the initial announcement of the planned separation transaction in August 2019, we incurred merger transaction and integration costs of $31.2 million during the first half of 2019 relating to the continuation of the integration activities following the Merger. No such costs were incurred subsequently in 2019 or in 2020.
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. During 2020, we recognized $31.1 million of other income, which primarily included $23.1 million of gains on sales of property, plant and equipment and other assets. During 2019, we recognized $220.7 million of other expenses, which primarily included $146.9 million of net foreign exchange losses and $54.6 million of legal provision, net of settlements. The change in foreign exchange losses is primarily due to a reduction in foreign exchange losses from unhedged currencies, more favorable hedging costs, and the effects of a weakened U.S. dollar on naturally hedged projects.
Net Interest Expense
Net interest expense decreased $158.3 million in 2020 compared to 2019, primarily due to the change in the fair value of the redeemable financial liability. We revalued the mandatorily redeemable financial liability to reflect current expectations about the obligation and recognized a charge of $202.0 million, as compared to $423.1 million recognized in 2019. See Note 24 to our consolidated financial statements for further details. Net interest expense, excluding the fair value measurement of the mandatorily redeemable financial liability and including interest income decreased by $62.8 million during 2020.
Provision for Income Taxes
Our provision for income taxes for 2020 and 2019 reflected effective tax rates of (5.0)% and (12.9)%, respectively. The year-over-year change in the effective tax rate was primarily due to the impact of nondeductible goodwill impairments, increase in adjustment on prior year taxes, offset in part by the amount of tax expense associated with movements in valuation allowances.
Our effective tax rate can fluctuate depending on our country mix of earnings, which may change based on changes in the jurisdictions in which we operate.
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 %) 2020 2019 2018 2020 vs. 2019 2019 vs. 2018
Revenue $ 5,471.4 $ 5,523.0 $ 4,840.0 $ (51.6) (0.9) % $ 683.0 14.1 %
Operating loss $ (2,815.5) $ (1,447.7) $ (1,529.5) $ (1,367.8) (94.5) % $ 81.8 5.3 %
Operating loss as a percentage of revenue (51.5) % (26.2) % (31.6) % (25.3) pts. 5.4 pts.
Subsea revenue decreased $51.6 million, or (0.9)% year-over-year, primarily due to operational challenges driven by the COVID-19 pandemic. However, despite these challenges and related disruptions, we continued to demonstrate strong execution of our backlog.
Subsea operating loss is primarily due to significant impairment and other non-recurring charges. The operating loss included $2,957.5 million of goodwill and long-lived assets impairments, restructuring and other charges and COVID-19 related expenses compared to $1,752.2 million in 2019. Non-recurring charges incurred related to COVID-19 disruptions during 2020 were $50.1 million. See Note 19 to our consolidated financial statements for further details.
Refer to ‘Non-GAAP Measures’ for more information regarding our segment operating results.
Technip Energies
Year Ended December 31, Favorable/(Unfavorable)
(In millions, except %) 2020 2019 2018 2020 vs. 2019 2019 vs. 2018
Revenue $ 6,520.0 $ 6,268.8 $ 6,120.7 $ 251.2 4.0 % $ 148.1 2.4 %
Operating profit $ 683.6 $ 959.6 $ 824.0 $ (276.0) (28.8) % $ 135.6 16.5 %
Operating profit as a percentage of revenue 10.5 % 15.3 % 13.5 % (4.8) pts. 1.8 pts.
Technip Energies revenue increased $251.2 million year-over-year. Revenue benefited from the continued ramp-up of Arctic LNG 2 and higher activity on downstream projects in Africa, North America and India, which more than offset the decline in revenue from Yamal LNG. COVID-19 related operational efficiencies and business disruption also impeded revenue growth during 2020. Revenue during the period benefited from a $113.2 million litigation settlement.
Operating profit decreased year-over-year, primarily due to a reduced contribution from Yamal LNG and lower margin realization on early stage projects, including Arctic LNG 2. Project execution remained strong across the portfolio. Non-recurring charges incurred related to COVID-19 disruptions during the period were $44.0 million.
Refer to ‘Non-GAAP Measures’ for more information regarding our segment operating results. Subsequent to the Spin-off, we operate under two reporting segments: Subsea and Surface Technologies, for further details see Note 3 to our consolidated financial statements.
Surface Technologies
Year Ended December 31, Favorable/(Unfavorable)
(In millions, except %) 2020 2019 2018 2020 vs. 2019 2019 vs. 2018
Revenue $ 1,059.2 $ 1,617.3 $ 1,592.2 $ (558.1) (34.5)% $ 25.1 1.6 %
Operating profit (loss) $ (429.3) $ (656.1) $ 172.8 $ 226.8 34.6% $ (828.9) (479.7) %
Operating profit (loss) as a percentage of revenue (40.5) % (40.6) % 10.9 % 0.1 pts. (51.5) pts.
Surface Technologies revenue decreased $558.1 million, or (34.5)% year-over-year, primarily driven by the significant reduction in operator activity in North America. Revenue outside of North America displayed resilience, with a more modest decline due to reduced activity levels. Nearly 64% of total segment revenue was generated outside of North America in the period.
Surface Technologies operating loss was primarily due to impairment and other non-recurring charges. The operating loss included $440.2 million of goodwill and long-lived assets impairments, restructuring and other charges and COVID-19 related expenses compared to $704.2 million incurred in 2019. Operating loss was also negatively impacted by the reduced demand in North America driven by the significant decline in rig count and completions-related activity, which was partially offset by lower costs from our accelerated cost reduction actions initiated in the first quarter of 2020. Non-recurring charges incurred related to COVID-19 disruptions during the period were $7.7 million. See Note 19 to our consolidated financial statements for further details.
Refer to ‘Non-GAAP Measures’ for more information regarding our segment operating results.
Corporate Items
Year Ended December 31, Favorable/(Unfavorable)
(In millions, except %) 2020 2019 2018 2020 vs. 2019 2019 vs. 2018
Corporate expense $ (201.5) $ (393.4) $ (478.0) $ 191.9 49% $ 84.6 18%
Corporate expenses decreased by $191.9 million during 2020. The reduction in corporate expenses is primarily due to $54.6 million decrease in legal provision, net of settlements; $38.6 million decrease due to lower activity and the impact of cost reductions implemented in 2020; $32.7 million decrease in separation costs; $31.2 million decrease in integration expenses and $16.6 million decrease in restructuring and impairment expenses.
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:
-Net income (loss), excluding charges and credits, as well as measures derived from it (excluding charges and credits;
-Income (loss) before net interest expense and income taxes, excluding charges and credits (“Adjusted Operating profit”);
-Adjusted diluted earnings per share 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”);
-Corporate expenses excluding charges and credits;
-Net cash; and
-Free cash flow.
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.
The following is a reconciliation of the most comparable financial measures under GAAP to the non-GAAP financial measures.
Year Ended
December 31, 2020
Net income (loss) attributable to TechnipFMC plc Net income (loss) attributable to non-controlling interests Provision for income taxes Net interest expense Income (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 $ (3,287.6) $ 49.7 $ 153.4 $ 293.0 $ (2,791.5) $ 447.2 $ (2,344.3)
Charges and (credits):
Impairment and other charges 3,271.0 - 16.4 - 3,287.4 - 3,287.4
Restructuring and other charges 96.1 - 16.0 - 112.1 - 112.1
Direct COVID-19 expenses 83.7 - 18.1 - 101.8 - 101.8
Litigation settlement (113.2) - - - (113.2) - (113.2)
Separation costs 36.3 - 3.2 - 39.5 - 39.5
Purchase price accounting adjustment 6.5 - 2.0 - 8.5 (8.5) -
Valuation allowance (3.5) - 3.5 - - - -
Adjusted financial measures $ 89.3 $ 49.7 $ 212.6 $ 293.0 $ 644.6 $ 438.7 $ 1,083.3
Diluted earnings (loss) per share attributable to TechnipFMC plc, as reported $ (7.33)
Adjusted diluted earnings per share attributable to TechnipFMC plc $ 0.20
Year Ended
December 31, 2019
Net income (loss) attributable to TechnipFMC plc Net income (loss) attributable to non-controlling interests Provision for income taxes Net interest expense Income (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 $ (2,415.2) $ (3.1) $ 276.3 $ (451.3) $ (1,684.5) $ 509.6 $ (1,174.9)
Charges and (credits):
Impairment and other charges 2,364.2 - 119.9 - 2,484.1 - 2,484.1
Restructuring and other charges 27.7 - 9.3 - 37.0 - 37.0
Business combination transaction and integration costs 23.1 - 8.1 - 31.2 - 31.2
Separation costs 54.2 - 17.9 - 72.1 - 72.1
Reorganization 17.2 - 8.1 - 25.3 - 25.3
Legal provision, net 46.3 - 8.3 - 54.6 - 54.6
Purchase price accounting adjustment 26.0 - 8.0 - 34.0 (34.0) -
Valuation allowance 187.0 - (187.0) - - - -
Adjusted financial measures $ 330.5 $ 3.1 $ 268.9 $ 451.3 $ 1,053.8 $ 475.6 $ 1,529.4
Diluted earnings per share attributable to TechnipFMC plc, as reported $ (5.39)
Adjusted diluted earnings per share attributable to TechnipFMC plc $ 0.74
Year Ended
December 31, 2020
Subsea Technip Energies Surface Technologies Corporate Expense Foreign Exchange, net Total
Revenue $ 5,471.4 $ 6,520.0 $ 1,059.2 $ - $ - $ 13,050.6
Operating profit (loss), as reported (pre-tax) $ (2,815.5) $ 683.6 $ (429.3) $ (201.5) $ (28.8) $ (2,791.5)
Charges and (credits):
Impairment and other charges 2,854.5 10.3 419.3 3.3 - 3,287.4
Restructuring and other charges* 52.9 39.3 13.2 6.7 - 112.1
Direct COVID-19 expenses 50.1 44.0 7.7 - - 101.8
Litigation settlement - (113.2) - - - (113.2)
Separation costs - - - 39.5 - 39.5
Purchase price accounting adjustments 8.5 - - - - 8.5
Subtotal 2,966.0 (19.6) 440.2 49.5 - 3,436.1
Adjusted Operating profit (loss) 150.5 664.0 10.9 (152.0) (28.8) 644.6
Adjusted Depreciation and amortization 316.4 34.2 70.1 18.0 - 438.7
Adjusted EBITDA $ 466.9 $ 698.2 $ 81.0 $ (134.0) $ (28.8) $ 1,083.3
Operating profit margin (51.5) % 10.5 % (40.5) % (21.4) %
Adjusted Operating profit margin 2.8 % 10.2 % 1.0 % 4.9 %
Adjusted EBITDA margin 8.5 % 10.7 % 7.6 % 8.3 %
*On December 30, 2019, we completed the acquisition of the remaining 50% of Technip Odebrecht PLSV CV. A $7.3 million gain was recorded within restructuring and other charges in the Subsea segment during 2020.
Year Ended
December 31, 2019
Subsea Technip Energies Surface Technologies Corporate Expense Foreign Exchange, net Total
Revenue $ 5,523.0 $ 6,268.8 $ 1,617.3 $ - $ - $ 13,409.1
Operating profit (loss), as reported (pre-tax) $ (1,447.7) $ 959.6 $ (656.1) $ (393.4) $ (146.9) $ (1,684.5)
Charges and (credits):
Impairment and other charges* 1,798.6 - 685.5 - - 2,484.1
Restructuring and other charges* (46.4) 17.0 39.8 26.6 - 37.0
Business combination transaction and integration costs - - - 31.2 - 31.2
Separation costs - - - 72.1 - 72.1
Reorganization - 25.3 - - - 25.3
Legal provision, net - - - 54.6 - 54.6
Purchase price accounting adjustments 34.0 - - - - 34.0
Subtotal 1,786.2 42.3 725.3 184.5 - 2,738.3
Adjusted Operating profit (loss) 338.5 1,001.9 69.2 (208.9) (146.9) 1,053.8
Adjusted Depreciation and amortization 311.6 38.7 107.9 17.4 - 475.6
Adjusted EBITDA $ 650.1 $ 1,040.6 $ 177.1 $ (191.5) $ (146.9) $ 1,529.4
Operating profit margin (26.2) % 15.3 % (40.6) % (12.6) %
Adjusted Operating profit margin 6.1 % 16.0 % 4.3 % 7.9 %
Adjusted EBITDA margin 11.8 % 16.6 % 11.0 % 11.4 %
*On December 30, 2019, we completed the acquisition of the remaining 50 percent of Technip Odebrecht PLSV CV, which resulted in a net loss of $0.9 million that was recorded in the Subsea segment. The net loss was comprised of an impairment charge of $84.2 million included within impairment and other charges and a gain on bargain purchase of $83.3 million included within restructuring and other charges.
INBOUND ORDERS AND ORDER BACKLOG
Inbound orders - Inbound orders represent the estimated sales value of confirmed customer orders received during the reporting period. The significant decline in commodity prices, due in part to the lower demand resulting from COVID-19 contributed to the decrease in the inbound orders during 2020.
Inbound Orders
Year Ended December 31,
(In millions) 2020 2019
Subsea $ 4,003.0 $ 7,992.6
Technip Energies 5,001.3 13,080.5
Surface Technologies 1,061.2 1,619.9
Total inbound orders $ 10,065.5 $ 22,693.0
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) 2020 2019
Subsea $ 6,876.0 $ 8,479.8
Technip Energies 14,098.7 15,298.1
Surface Technologies 413.5 473.2
Total order backlog $ 21,388.2 $ 24,251.1
Subsea - Order backlog for Subsea as of December 31, 2020, decreased by $1.6 billion from December 31, 2019. Subsea backlog of $6.9 billion as of December 31, 2020, was composed of various subsea projects, including Total Mozambique LNG; Eni Coral and Merakes; Petrobras Mero I and Mero II; Energean Karish; ExxonMobil Payara; Reliance MJ-1; Equinor Johan Sverdrup Phase 2; Husky West White Rose; BP Platina; Chevron Gorgon Stage 2; and Woodside Pyxis and Lambert Deep.
Technip Energies - Technip Energies order backlog as of December 31, 2020, decreased by $1.2 billion compared to December 31, 2019. Technip Energies backlog of $14.1 billion as of December 31, 2020 was composed of various projects, including Arctic LNG 2, Yamal LNG; Midor refinery expansion; BP Tortue FPSO; Long Son Petrochemicals; ExxonMobil Beaumont refinery expansion; HURL fertilizer plants; Petronas Kasawari; Energean Karish; Neste bio-diesel expansion; and Motor Oil Hellas New Naphtha Complex. Subsequent to the Spin-off, we will operate under two reporting segments: Subsea and Surface Technologies, for further details see Note 3 to our consolidated financial statements.
Surface Technologies - Order backlog for Surface Technologies as of December 31, 2020, decreased by $59.7 million compared to December 31, 2019, mainly driven by the transfer of the Loading Systems business unit from Surface Technologies to Technip Energies. 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 - Non-consolidated backlog reflects the proportional share of backlog related to joint ventures that is not consolidated due to our minority ownership position.
Non-consolidated order backlog
(In millions) December 31,
Subsea $ 640.2
Technip Energies 1,890.3
Total order backlog $ 2,530.5
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 Cash - Net cash, is a non-GAAP financial measure reflecting cash and cash equivalents, net of debt. Management uses this non-GAAP financial measure to evaluate our capital structure and financial leverage. We believe net cash is a meaningful financial measure that may assist investors in understanding our financial condition and recognizing underlying trends in our capital structure. Net cash 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 cash, utilizing details of classifications from our consolidated balance sheets.
(In millions) December 31, 2020 December 31, 2019
Cash and cash equivalents $ 4,807.8 $ 5,190.2
Short-term debt and current portion of long-term debt (636.2) (495.4)
Long-term debt, less current portion (3,317.7) (3,980.0)
Net cash $ 853.9 $ 714.8
Cash Flows
Cash flows for the years ended December 31, 2020, 2019 and 2018 were as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Cash provided (required) by operating activities $ 656.9 $ 848.5 $ (185.4)
Cash required by investing activities (180.6) (419.8) (460.2)
Cash required by financing activities (1,082.2) (784.4) (444.8)
Effect of exchange rate changes on cash and cash equivalents 223.5 5.9 (107.0)
Decrease in cash and cash equivalents $ (382.4) $ (349.8) $ (1,197.4)
Working capital $ 54.0 $ (82.2) $ (759.0)
Free cash flow $ 365.1 $ 394.1 $ (553.5)
Operating cash flows - During 2020, we generated $656.9 million in cash flows from operating activities as compared to $848.5 million generated in 2019, resulting in a $191.6 million decrease compared to 2019. The decrease in operating cash flows is primarily driven by the decrease in cash generated by our operations during the year due to the overall decline in activity.
Investing cash flows - Investing activities used $180.6 million and $419.8 million of cash in 2020 and 2019, respectively. The decrease in cash used by investing activities was due primarily to decreased capital expenditures, decreased payments to acquire debt securities and increased proceeds from sale of assets and debt securities during 2020. In 2019, we purchased a deepwater dive support vessel, Deep Discoverer for $116.8 million, that was subsequently funded through a sale-leaseback transaction.
Financing cash flows - Financing activities used $1,082.2 million and $784.4 million in 2020 and 2019, respectively. The increase of $297.8 million in cash required for financing activities was due primarily to the increased debt pay down activity during 2020 of $883.6 million, partially offset by $338.6 million reduction in settlements of mandatorily redeemable financial liability and our efforts and commitment to preserve cash, which included reduction in cash dividends of $173.6 million and reduction in share repurchases of $92.7 million .
Working capital represents total changes in operating current assets and liabilities.
Free cash flow is defined as operating cash flows less capital expenditures. The following table reconciles cash provided by operating activities, which is directly comparable financial measure determined in accordance with GAAP, to free cash flow (non-GAAP measure).
Year Ended December 31,
(In millions) 2020 2019 2018
Cash provided (required) by operating activities $ 656.9 $ 848.5 $ (185.4)
Capital expenditures (291.8) (454.4) (368.1)
Free cash flow $ 365.1 $ 394.1 $ (553.5)
Debt and Liquidity
Significant Funding and Liquidity Activities - During 2020, we completed the following transactions in order to enhance our total liquidity position:
•Repaid $233.9 million of 5.00% 2010 private placement notes;
•Repaid the remaining outstanding balance of $190.0 million of the term loan assumed in connection with the acquisition of the remaining 50% interest in TOP CV.
•Issued €200 million aggregate principal amount of 4.500% Private Placement Notes due June 30, 2025. Within three months of the effective date of the Spin-off of Technip Energies, if there is a downgrade by a nationally recognized rating agency of the corporate rating of TechnipFMC from an investment grade to a non-investment grade rating or a withdrawal of any such rating, the interest rate applicable to the Private Placement Notes will be increased to 5.75%;
•Entered into a new, six-month €500 million senior unsecured revolving credit facility agreement, which may be extended for two additional three-month periods (the “Euro Facility”); and
•Entered into the Bank of England’s COVID Corporate Financing Facility program (the “CCFF Program”), which allows us to issue up to £600 million of unsecured commercial paper notes.
Total borrowings as of December 31, 2020 and 2019 were as follows:
(In millions) December 31,
2020 2019
Commercial paper $ 1,525.9 $ 1,967.0
Synthetic bonds due 2021 551.2 492.9
3.45% Senior Notes due 2022 500.0 500.0
5.00% Notes due 2020 - 224.6
3.40% Notes due 2022 184.0 168.5
3.15% Notes due 2023 159.5 146.0
3.15% Notes due 2023 153.4 140.4
4.50% Notes due 2025 245.4 -
4.00% Notes due 2027 92.0 84.2
4.00% Notes due 2032 122.7 112.3
3.75% Notes due 2033 122.7 112.3
Bank borrowings and Other 309.9 536.3
Unamortized debt issuance costs and discounts (12.8) (9.1)
Total borrowings $ 3,953.9 $ 4,475.4
Credit Facilities - The following is a summary of our credit facilities as of December 31, 2020:
(In millions)
Description
Amount Debt
Outstanding Commercial
Paper
Outstanding
(a) Letters
of Credit Unused
Capacity Maturity
Revolving credit facility $ 2,500.0 $ - $ 708.0 $ - $ 1,792.0 January 2023
CCFF Program £ 600.0 £ - £ 600.0 £ - £ - March 2021
Euro Facility € 500.0 € - € - € - € 500.0 February 2021
Bilateral credit facility € 100.0 € - € - € - € 100.0 May 2021
(a)Under our commercial paper program, we have the ability to access up to $1.5 billion and €1.0 billion of financing through our commercial paper dealers. Our available capacity under our revolving credit facility is reduced by any outstanding commercial paper.
Committed credit available under our revolving credit facilities provides the ability to issue our commercial paper obligations on a long-term basis. We had $708.0 million of commercial paper issued under our facilities as of December 31, 2020. In addition, we had $817.9 million of Notes outstanding under the CCFF Program. When we have both the ability and intent to refinance certain obligations on a long-term basis, the obligations are classified as long-term, as such, the commercial paper borrowings were classified as long-term debt in our consolidated balance sheet as of December 31, 2020.
On June 12, 2020, we entered into Amendment No. 1 to the Facility Agreement and into an Amendment and Restatement Agreement to our Euro Facility. The amendments, which are effective through the respective expirations of the Facility Agreement and Euro Facility, permit us to include the gross book value of $3.2 billion of goodwill (fully impaired in the quarter ended March 31, 2020) in the calculation of consolidated net worth, which is used in the calculation of our quarterly compliance with the total capitalization ratio under the Facility Agreement and Euro Facility.
The amended and restated Facility Agreement and Euro Facility contain usual and customary covenants, representations and warranties, and events of default for credit facilities of this type, including financial covenants requiring that our total capitalization ratio not exceed 60% at the end of any financial quarter. The Facility Agreement and Euro Facility also contain covenants restricting our ability and our subsidiaries’ ability to incur additional liens and indebtedness, enter into asset sales, or make certain investments.
As of December 31, 2020, we were in compliance with all restrictive covenants under our credit facilities.
Refer to Note 24 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K for further information related to credit risk.
Credit Ratings - As of February 25, 2021, our credit ratings with Standard and Poor’s (S&P) are BB+ for our long-term secured debt and B for commercial paper program. Our credit ratings with Moody’s are Ba1 for our long-term secured 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.
Financial Position Outlook
Overview
We are committed to a strong balance sheet and ample liquidity that that will enable us to avoid distress in cyclical troughs and access capital markets throughout the cycle. We believe our liquidity has and continues to exceed the level required to achieve this goal.
Our objective in financing our business is to maintain sufficient liquidity, adequate financial resources and financial flexibility in order to fund the requirements of our business. 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 2021 are estimated to be approximately $250.0 million. Projected capital expenditures do not include any contingent capital that may be needed to respond to a contract award.
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 Revolving Credit Facility that provides for aggregate revolving capacity of up to $1.0 billion. Availability of borrowings under the Revolving Credit Facility is reduced by any outstanding letters of credit issued against the facility. At February 25, 2021, there were no outstanding letters of credit and availability of borrowings under the Revolving Credit Facility was $800 million.
On January 29, 2021, we issued $1.0 billion of 6.5% senior notes due 2026 (the “2021 Notes”). 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.
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 $522.8 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 and the CCFF Program we entered into on May 19, 2020. In connection with the termination of these credit facilities, we repaid most of the outstanding commercial paper borrowings, which were $1,525.9 million as of December 31, 2020.
We will continue to be strategically focused on cash and liquidity preservation. Subsequent to the completion of the Spin-off, we own 49.9% of the outstanding shares of Technip Energies. The ownership percentage will be further reduced by the sale of shares to BPI pursuant to the Share Purchase Agreement, for further details see section “The Spin-off” in “Item 1. Business.” We intend to conduct an orderly sale of our stake in Technip Energies over time and will use the proceeds from future sales to further reduce our net leverage.
CONTRACTUAL OBLIGATIONS
The following is a summary of our contractual obligations as of December 31, 2020:
Payments Due by Period
(In millions) Total
payments Less than
1 year 1-3
years 3-5
years After 5
years
Debt (a)
$ 3,953.9 $ 636.2 $ 2,589.1 $ 294.0 $ 434.6
Interest on debt (a)
242.3 58.1 69.3 42.9 72.0
Operating leases (b)
1,128.0 131.2 328.6 196.8 471.4
Purchase obligations (c)
5,709.4 4,587.5 1,008.9 112.0 1.0
Pension and other post-retirement benefits (d)
19.0 19.0 - - -
Unrecognized tax benefits (e)
56.1 4.2 4.2 47.6 0.1
Other contractual obligations (f)
246.6 141.9 104.7 - -
Total contractual obligations $ 11,355.3 $ 5,578.1 $ 4,104.8 $ 693.3 $ 979.1
(a)Our available debt is dependent upon our compliance with covenants, including negative covenants related to liens and our total capitalization ratio. Any violation of covenants or other events of default, which are not waived or cured, or changes in our credit rating could have a material impact on our ability to maintain our committed financing arrangements.
Due to our intent and ability to refinance commercial paper obligations on a long-term basis under our revolving credit facility and the variable interest rates associated with these debt instruments, only interest on our Senior Notes is included in the table. During 2020, we paid $107.0 million for interest charges, net of interest capitalized.
Subsequent to the Spin-off, we expect the total future principal payments on debt and total future interest payments to be approximately $2,376.8 million and $556.1 million, respectively.
(b)We lease office space, manufacturing facilities and various types of manufacturing and data processing equipment. Leases of real estate generally provide for payment of property taxes, insurance and repairs by us. Substantially all of our leases are classified as operating leases.
(c)In the normal course of business, we enter into agreements with our suppliers to purchase raw materials or services. These agreements include a requirement that our supplier provide products or services to our specifications and require us to make a firm purchase commitment to our supplier. As substantially all of these commitments are associated with purchases made to fulfill our customers’ orders, the costs associated with these agreements will ultimately be reflected in cost of sales in our consolidated statements of income. Subsequent to the Spin-off, we expect the total remaining future purchase obligations to be approximately $1,094.1 million.
(d)We expect to contribute approximately $20.7 million to our international pension plans during 2021. Required contributions for future years depend on factors that cannot be determined at this time. Additionally, we expect to pay directly to beneficiaries approximately $14.3 million for international unfunded pension plan and $4.7 million for U.S. Non-Qualified unfunded pension plan during 2021. Subsequent to the Spin-off, we expect to contribute approximately $18.9 million to our international pension plans during 2021.
(e)It is reasonably possible that $4.2 million of liabilities for unrecognized tax benefits will be settled during 2021, and this amount is reflected in income taxes payable in our consolidated balance sheet as of December 31, 2020. Although unrecognized tax benefits are not contractual obligations, they are presented in this table because they represent demands on our liquidity.
(f)Other contractual obligations represent our share of the mandatorily redeemable financial liability, which is recorded at its fair value. The mandatorily redeemable financial liability relates to our voting control interests in legal Technip Energies contract entities which own and account for the design, engineering and construction of the Yamal LNG plant. During the year ended December 31, 2020 we revalued the liability to reflect current expectations about the obligation. See Note 24 to our consolidated financial statements for further details.
OTHER OFF-BALANCE SHEET ARRANGEMENTS
The following is a summary of other off-balance sheet arrangements for our consolidated subsidiaries as of December 31, 2020:
Amount of Commitment Expiration per Period
(In millions) Total
amount Less than
1 year 1-3
years 3-5
years After 5
years
Financial guarantees (a)
$ 310.1 $ 204.1 $ 38.9 $ 24.7 $ 42.4
Performance guarantees (b)
4,659.6 1,968.0 2,011.4 565.7 114.5
Total other off-balance sheet arrangements $ 4,969.7 $ 2,172.1 $ 2,050.3 $ 590.4 $ 156.9
(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.
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 Technip Energies and Subsea segments, primarily for the entire range of onshore facilities, fixed and floating offshore oil and gas facilities, and subsea exploration and production equipment projects that involve the design, engineering, manufacturing, construction, and assembly of complex, customer-specific 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.
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 loss for the year ended December 31, 2020 was positively impacted by approximately $457.9 million, as a result of changes in contract estimates related to projects that were in progress as of December 31, 2019. During the year ended December 31, 2020, we recognized changes in our estimates that had an impact on our margin in the amounts of $519.5 million, $(56.5) million and $(5.1) million in our Technip Energies, Subsea and Surface Technologies segments, respectively. The changes in contract estimates are attributed to better, than expected performance throughout our execution of our projects.
Our operating loss for the year ended December 31, 2019 was positively impacted by approximately $1,114.3 million, as a result of changes in contract estimates related to projects that were in progress as of December 31, 2018. During the year ended December 31, 2019, we recognized changes in our estimates that had an impact on our margin in the amounts of $797.2 million, $324.7 million and $(7.6) million in our Technip Energies, Subsea and Surface Technologies segments, respectively. The changes in contract estimates are attributed to better, than expected performance throughout our execution of our projects.
Our operating profit for the year ended December 31, 2018 was positively impacted by approximately $553.4 million, as a result of changes in contract estimates related to projects that were in progress as of December 31, 2017. During the year ended December 31, 2018, we recognized changes in our estimates that had an impact on our margin in the amounts of $379.2 million, $169.9 million and $4.3 million in our Technip Energies, Subsea and Surface technologies segments, respectively. The changes in contract estimates are attributed to better, 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, 2020, we have provided a valuation allowance against the related deferred tax assets where we believe it is not more likely than not that we will generate future taxable income sufficient to realize such assets.
The calculation of our income tax expense involves dealing with uncertainties in the application of complex tax laws and regulations in numerous jurisdictions in which we operate. We recognize tax benefits related to uncertain tax positions when, in our judgment, it is more likely than not that such positions will be sustained on examination, including resolutions of any related appeals or litigation, based on the technical merits. We adjust our liabilities for uncertain tax positions when our judgment changes as a result of new information previously unavailable. Due to the complexity of some of these uncertainties, their ultimate resolution may result in payments that are materially different from our current estimates. Any such differences will be reflected as adjustments to income tax expense in the periods in which they are determined.
Accounting for Pension and Other Post-retirement Benefit Plans
The determination of the projected benefit obligations of our pension and other post-retirement benefit plans are important to the recorded amounts of such obligations in our consolidated balance sheets and to the amount of pension expense in our consolidated statements of income. In order to measure the obligations and expense associated with our pension benefits, management must make a variety of estimates, including discount rates used to value certain liabilities, expected return on plan assets set aside to fund these costs, rate of compensation increase, employee turnover rates, retirement rates, mortality rates and other factors. We update these estimates on an annual basis or more frequently upon the occurrence of significant events. These accounting estimates bear the risk of change due to the uncertainty and difficulty in estimating these measures. Different estimates used by management could result in our recognition of different amounts of expense over different periods of time.
Due to the specialized and statistical nature of these calculations which attempt to anticipate future events, we engage third-party specialists to assist management in evaluating our assumptions as well as appropriately measuring the costs and obligations associated with these pension benefits. The discount rate and expected long-term rate of return on plan assets are 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 it 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 2020 Pension Expense Before Income Taxes Increase (Decrease) in Projected Benefit Obligation as of December 31, 2020
25 basis point decrease in discount rate $ 3.2 $ 66.8
25 basis point increase in discount rate $ (3.2) $ (63.5)
25 basis point decrease in expected long-term rate of return on plan assets $ 3.7 N/A
25 basis point increase in expected long-term rate of return on plan assets $ (1.6) 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 2 to our consolidated financial statements for further details.
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 which 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.
During the first quarter of 2020 a severe decline in the Company’s market capitalization, significant decline in crude oil prices and the growing pandemic caused by COVID-19 triggered the need for an impairment test at March 31, 2020. We utilized a market approach to measure the fair value of our reporting units as of March 31, 2020. In measuring a fair value of the Company we used the Company’s market capitalization. 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.
During our annual impairment test the following significant estimates were used by management in determining the fair values of our reporting units in order to test the remaining goodwill at October 31:
2020 2019 2018
Year of cash flows before terminal value 4 4 5
Discount rates 0.15 12.5% to 15.0% 12.0% to 13.0%
EBITDA multiples N/A 6.0 - 8.5x 7.0 - 8.5x
During the year ended December 31, 2020, the significant estimates used by management in determining the fair value described above relate to Technip Energies reporting unit only. Based on the impairment tests performed during the year ended December 31, 2020 we recorded $2,747.5 million and $335.9 million of goodwill impairment charges recorded in our Subsea and Surface Technologies reporting units, respectively. No goodwill impairment charges were recorded in our Technip Energies reporting unit. The fair value over carrying amount for our Technip Energies segment was in excess of 300% of its carrying amount at our annual impairment test date that is October 31, 2020.
During the year ended December 31, 2019, we recorded $1,321.9 million and $666.8 million of goodwill impairment charges in our Subsea and Surface Technologies segments, respectively.
During the year ended December 31, 2018, we recorded $1,383.0 million of goodwill impairment charges in our Subsea segment.
See Notes 15 and 19 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 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. As we continue to progress our discussions with PNF towards resolution, 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, 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 included in Part II, Item 8 of this Annual Report on Form 10-K.
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 where the objective is to generate profits solely from trading activities. As of December 31, 2020 and 2019, substantially all of our derivative holdings consisted of foreign currency forward contracts and foreign currency instruments embedded in purchase and sale contracts.
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, 2020, would have changed our revenue and income before income taxes attributable to TechnipFMC by approximately $813.0 million and $38.0 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 $68.4 million in the net fair value of cash flow hedges reflected in our consolidated balance sheet as of December 31, 2020.
Interest Rate Risk
As of December 31, 2020, we had commercial paper of approximately $1.5 billion with a weighted average interest rate of 0.26%. Using sensitivity analysis to measure the impact of a 10% adverse movement in the interest rate, or three basis points, would result in an increase to interest expense of $0.5 million.
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 $1.5 million in unrealized earnings in the period of change. Based on our portfolio at December 31, 2020, we have material positions with exposure to interest rates in the United States, Canada, Australia, Brazil, the United Kingdom, Singapore, the European Community, and Norway.
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, 2020 and 2019, 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, 2020, including the related notes and schedule of valuation and qualifying accounts for each of the three years in the period ended December 31, 2020 appearing under Item 15(a)(2) (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2020, 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, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 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, 2020, 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 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 matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate 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 matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Revenue Recognition - Determination of Estimated Costs to Complete for Long-Term Contracts
As described in Note 6 to the consolidated financial statements, approximately 86% of the total revenue of $13.1 billion for the year ended December 31, 2020 is generated from long-term contracts. As disclosed by management, 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. 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 which 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 estimates of 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 estimates of 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.
Long-Lived Asset Impairments - Certain Asset Groups in the Subsea and Surface Segments
As described in Notes 1, 14, and 19 to the consolidated financial statements, the Company’s consolidated net property, plant and equipment was $2,861.8 million as of December 31, 2020. For the year ended December 31, 2020, the Company recorded impairment charges in relation to certain asset groups in the Subsea and Surface segments in the amount of $88.4 million and $82.0 million, respectively. Management conducts impairment tests on long-lived assets whenever events or changes in circumstances indicate the carrying value 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. Due to the substantial decline in global demand for oil caused by the COVID-19 pandemic, management reviewed the corresponding impact on the asset group’s service potential and determined the carrying amount of the asset groups exceeded their fair value. As disclosed by management, 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. The expected future cash flows used for impairment reviews and related fair value calculations are based on judgmental assessments of future revenue, forecasted utilization, operating costs, and capital decisions and all available information at the date of review.
The principal considerations for our determination that performing procedures relating to the long-lived asset impairments - certain asset groups in the Subsea and Surface segments is a critical audit matter are the significant judgment by management when determining the fair value estimates, 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 future revenue for certain asset groups in the Subsea segment and future revenue and operating costs for certain asset groups in the Surface segment.
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 management’s long-lived assets impairment assessments, including controls over management’s determination of the fair value of certain asset groups in the Subsea and Surface segments. These procedures also included, among others, testing management’s process for developing the fair value estimates, by (i) evaluating the appropriateness of the method used; (ii) testing the completeness and accuracy of the underlying data used in estimating the net future cash flows; and (iii) evaluating the reasonableness of significant assumptions related to future revenue for certain asset groups in the Subsea segment and future revenue and operating costs for certain asset groups in the Surface segment. Evaluating management’s significant assumptions involved evaluating whether the significant assumptions used by management were reasonable considering the current and past performance of the business in which the assets operate in and whether they were consistent with evidence obtained in other areas of the audit.
/s/ PricewaterhouseCoopers LLP
Houston, Texas
March 5, 2021
We have served as the Company’s auditor since 2017.
TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
Year Ended
(In millions, except per share data) 2020 2019 2018
Revenue
Service revenue $ 9,708.2 $ 9,789.7 $ 9,057.6
Product revenue 3,200.4 3,352.9 3,272.6
Lease revenue 142.0 266.5 222.7
Total revenue 13,050.6 13,409.1 12,552.9
Costs and expenses
Cost of service revenue 8,261.9 7,767.2 7,452.7
Cost of product revenue 2,830.8 3,015.6 2,676.9
Cost of lease revenue 116.7 167.9 143.4
Selling, general and administrative expense 1,066.2 1,228.1 1,140.6
Research and development expense 119.8 162.9 189.2
Impairment, restructuring and other expense (Note 19) 3,501.3 2,490.8 1,831.2
Separation costs (Note 3) 39.5 72.1 -
Merger transaction and integration costs - 31.2 36.5
Total costs and expenses 15,936.2 14,935.8 13,470.5
Other income (expense), net 31.1 (220.7) (323.9)
Income from equity affiliates (Note 12) 63.0 62.9 114.3
Loss before interest income, interest expense and income taxes (2,791.5) (1,684.5) (1,127.2)
Interest income 56.6 116.5 121.4
Interest expense (349.6) (567.8) (482.3)
Loss before income taxes (3,084.5) (2,135.8) (1,488.1)
Provision for income taxes (Note 21) 153.4 276.3 422.7
Net loss (3,237.9) (2,412.1) (1,910.8)
Net profit attributable to non-controlling interests (49.7) (3.1) (10.8)
Net loss attributable to TechnipFMC plc $ (3,287.6) $ (2,415.2) $ (1,921.6)
Earnings (loss) per share attributable to TechnipFMC plc (Note 8)
Basic $ (7.33) $ (5.39) $ (4.20)
Diluted $ (7.33) $ (5.39) $ (4.20)
Weighted average shares outstanding (Note 8)
Basic 448.7 448.0 458.0
Diluted 448.7 448.0 458.0
The accompanying notes are an integral part of the consolidated financial statements.
TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Year Ended
(In millions) 2020 2019 2018
Net loss $ (3,237.9) $ (2,412.1) $ (1,910.8)
Foreign currency translation adjustments
Net gain (losses) arising during the period (169.1) 15.6 (183.3)
Reclassification adjustment for net gains included in net income - (12.0) (41.1)
Foreign currency translation adjustments(a)
(169.1) 3.6 (224.4)
Net gains (losses) on hedging instruments
Net gains (losses) arising during the period 25.4 8.9 (58.7)
Reclassification adjustment for net losses (gains) included in net income 13.0 18.2 (2.0)
Net gains (losses) on hedging instruments (b)
38.4 27.1 (60.7)
Pension and other post-retirement benefits
Net losses arising during the period (88.3) (81.5) (72.4)
Prior service cost arising during the period (4.6) (0.7) (2.1)
Reclassification adjustment for settlement losses (gains) included in net income 1.4 0.2 (2.5)
Reclassification adjustment for amortization of prior service cost included in net income 0.9 2.0 1.2
Reclassification adjustment for amortization of net actuarial loss included in net income 6.9 0.8 0.3
Net pension and other post-retirement benefits (c)
(83.7) (79.2) (75.5)
Other comprehensive loss, net of tax (214.4) (48.5) (360.6)
Comprehensive loss (3,452.3) (2,460.6) (2,271.4)
Comprehensive income attributable to non-controlling interest (50.4) (2.4) (6.2)
Comprehensive loss attributable to TechnipFMC plc $ (3,502.7) $ (2,463.0) $ (2,277.6)
(a)Net of income tax (expense) benefit of nil, $7.9 and $3.6 for the years ended December 31, 2020, 2019 and 2018, respectively.
(b)Net of income tax (expense) benefit of $(9.7), $(6.9) and $16.6 for the years ended December 31, 2020, 2019 and 2018, respectively.
(c)Net of income tax (expense) benefit of $25.5, $20.3 and $15.5 for the years ended December 31, 2020, 2019 and 2018, respectively.
The accompanying notes are an integral part of the consolidated financial statements.
TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(In millions, except par value data) December 31,
Assets 2020 2019
Cash and cash equivalents $ 4,807.8 $ 5,190.2
Trade receivables, net of allowances of $108.9 in 2020 and $95.4 in 2019
2,289.8 2,287.1
Contract assets, net of allowances of $1.0 in 2020 and $2.5 in 2019
1,267.6 1,520.0
Inventories, net (Note 9) 1,268.5 1,416.0
Derivative financial instruments (Note 23) 301.4 101.9
Income taxes receivable 313.4 264.6
Advances paid to suppliers 203.6 242.9
Other current assets (Note 10) 992.6 863.7
Total current assets 11,444.7 11,886.4
Investments in equity affiliates (Note 12) 358.9 300.4
Property, plant and equipment, net (Note 14) 2,861.8 3,162.0
Operating lease right-of-use assets (Note 5) 1,016.7 892.6
Finance lease right-of-use assets (Note 5) 27.5 -
Goodwill (Note 15) 2,512.5 5,598.3
Intangible assets, net (Note 15) 981.1 1,086.6
Deferred income taxes (Note 21) 217.9 260.5
Derivative financial instruments (Note 23) 35.9 39.5
Other assets 235.6 292.5
Total assets $ 19,692.6 $ 23,518.8
Liabilities and equity
Short-term debt and current portion of long-term debt (Note 16) $ 636.2 $ 495.4
Operating lease liabilities (Note 5) 247.0 275.1
Finance lease liabilities (Note 5) 26.9 -
Accounts payable, trade 2,740.3 2,659.8
Contract liabilities 4,736.1 4,585.1
Accrued payroll 418.8 411.5
Derivative financial instruments (Note 23) 167.2 141.3
Income taxes payable 74.1 75.7
Other current liabilities (Note 10) 1,368.6 1,494.5
Total current liabilities 10,415.2 10,138.4
Long-term debt, less current portion (Note 16) 3,317.7 3,980.0
Operating lease liabilities, less current portion (Note 5) 881.0 681.7
Deferred income taxes (Note 21) 79.5 138.2
Accrued pension and other post-retirement benefits, less current portion (Note 22) 420.8 368.6
Derivative financial instruments (Note 23) 23.3 52.7
Other liabilities 297.1 430.0
Total liabilities 15,434.6 15,789.6
Commitments and contingent liabilities (Note 20)
Mezzanine equity
Redeemable non-controlling interest 43.7 41.1
Stockholders’ equity (Note 17)
Ordinary shares, $1 par value; 618.3 shares authorized in 2020 and 2019; 449.5 shares and 447.1 shares issued and outstanding in 2020 and 2019, respectively; nil and 4.0 shares canceled in 2020 and 2019, respectively
449.5 447.1
Capital in excess of par value of ordinary shares 10,242.4 10,182.8
Accumulated deficit (4,915.2) (1,563.1)
Accumulated other comprehensive loss (1,622.5) (1,407.5)
Total TechnipFMC plc stockholders’ equity 4,154.2 7,659.3
Non-controlling interests 60.1 28.8
Total equity 4,214.3 7,688.1
Total liabilities and equity $ 19,692.6 $ 23,518.8
The accompanying notes are an integral part of the consolidated financial statements.
TECHNIPFMC PLC AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
(In millions) 2020 2019 2018
Cash provided (required) by operating activities
Net loss $ (3,237.9) $ (2,412.1) $ (1,910.8)
Adjustments to reconcile net income to cash provided (required) by operating activities
Depreciation 323.5 383.5 367.8
Amortization 123.7 126.1 182.6
Impairments (Note 19) 3,287.4 2,484.1 1,792.6
Employee benefit plan and share-based compensation costs 47.5 63.3 22.4
Deferred income tax provision (benefit), net (6.7) (75.4) 48.8
Unrealized loss (gain) on derivative instruments and foreign exchange (41.2) 32.5 102.7
Income from equity affiliates, net of dividends received (58.1) (58.8) (110.7)
Other 195.5 364.4 291.8
Changes in operating assets and liabilities, net of effects of acquisitions
Trade receivables, net and contract assets 348.1 (39.7) (664.1)
Inventories, net 82.8 (169.6) (339.4)
Accounts payable, trade 18.4 26.1 (1,248.7)
Contract liabilities (75.2) 520.1 762.7
Income taxes payable (receivable), net (52.8) 12.7 (190.7)
Other current assets and liabilities, net (267.3) (431.8) 921.2
Other noncurrent assets and liabilities, net (30.8) 23.1 (213.6)
Cash provided (required) by operating activities 656.9 848.5 (185.4)
Cash required by investing activities
Capital expenditures (291.8) (454.4) (368.1)
Payment to acquire debt securities (3.9) (71.6) -
Proceeds from sale of debt securities 51.5 18.9 -
Acquisition of equity securities (17.9) - -
Acquisitions, net of cash acquired - 16.0 (104.9)
Cash received from (used by) divestitures 8.8 (2.1) (6.7)
Proceeds from sale of assets 46.0 7.8 19.5
Proceeds from repayment of advance to joint venture 26.7 62.0 -
Other - 3.6 -
Cash required by investing activities (180.6) (419.8) (460.2)
Cash required by financing activities
Net decrease in short-term debt (24.4) (49.6) (34.9)
Net increase (decrease) in commercial paper (554.5) 57.3 496.6
Proceeds from issuance of long-term debt 223.2 96.2 -
Repayments of long-term debt (423.9) - -
Purchase of ordinary shares - (92.7) (442.6)
Dividends paid (59.2) (232.8) (238.1)
Payments related to taxes withheld on share-based compensation (7.4) - -
Settlements of mandatorily redeemable financial liability (224.2) (562.8) (225.8)
Acquisition of non-controlling interest (11.8) - -
Cash required by financing activities (1,082.2) (784.4) (444.8)
Effect of changes in foreign exchange rates on cash and cash equivalents 223.5 5.9 (107.0)
Decrease in cash and cash equivalents (382.4) (349.8) (1,197.4)
Cash and cash equivalents, beginning of year 5,190.2 5,540.0 6,737.4
Cash and cash equivalents, end of year $ 4,807.8 $ 5,190.2 $ 5,540.0
Year Ended December 31,
(In millions) 2020 2019 2018
Supplemental disclosures of cash flow information
Cash paid for interest (net of interest capitalized) $ 107.0 $ 109.4 $ 99.0
Cash paid for income taxes (net of refunds received) $ 219.7 $ 374.5 $ 410.6
The accompanying notes are an integral part of the consolidated financial statements.
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, 2017 $ 465.1 $ (4.8) $ 10,483.3 $ 3,406.0 $ (1,003.7) $ 21.5 $ 13,367.4
Adoption of accounting standards (Note 6) - - - (91.5) - 0.1 (91.4)
Net income (loss) - - - (1,921.6) - 10.8 (1,910.8)
Other comprehensive loss - - - - (356.0) (4.6) (360.6)
Cancellation of treasury shares (Note 17) (14.8) - (333.5) (94.5) - - (442.8)
Issuance of ordinary shares 0.2 - - - - - 0.2
Net sales of ordinary shares for employee benefit trust - 2.4 - - - - 2.4
Cash dividends declared ($0.52 per share) (Note 17)
- - - (238.1) - - (238.1)
Share-based compensation (Note 18) - - 49.1 - - - 49.1
Other - - (1.9) 11.9 - 3.5 13.5
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 (Note 5) - - - 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 17) (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 17)
- - - (232.8) - - (232.8)
Share-based compensation (Note 18) - - 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 (Note 4) - - - (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 17)
- - - (59.2) - - (59.2)
Share-based compensation (Note 18) - - 69.0 - - - 69.0
Acquisition of 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
The accompanying notes are an integral part of the consolidated financial statements.
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, Technip Energies and Surface Technologies. We have manufacturing operations worldwide, strategically located to facilitate delivery of our products, systems and services to our customers. On February 16, 2021, we completed the separation of Technip Energies segment (the “Spin-off”). Subsequent to the Spin-off, we will operate under two reporting segments: Subsea and Surface Technologies.
In this Annual Report on Form 10-K, we are reporting the results of our operations for the year ended December 31, 2020. Beginning in the first quarter of 2021, Technip Energies’ historical financial results for periods prior to the Spin-off will be reflected in our consolidated financial statements as discontinued operations.
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, which we adopted on January 1, 2018, using the modified retrospective method. 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 noncurrent based on the timing of when we expect to recognize the expense. The current and noncurrent 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.
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 synthetic bonds, 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.
During 2018, Argentina’s three year cumulative inflation rate exceeded 100% based on published inflation data, and effective July 1, 2018, Argentina’s currency was considered highly inflationary. Our local operations in Argentina use U.S. dollars as the functional currency and both monetary and non-monetary assets and liabilities denominated in Argentina pesos were remeasured into U.S. dollars with gains and losses resulting from foreign currency transactions included in current results of operations. This event did not have a material impact on TechnipFMC’s consolidated financial statements.
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.
NOTE 2. BUSINESS COMBINATION AND OTHER TRANSACTIONS
On October 7, 2020, we signed a Memorandum of Understanding with McPhy Energy S.A. (“McPhy”), a leading manufacturer and supplier of carbon-free hydrogen production and distribution equipment, pursuant to which we will jointly work on technology development and project implementation. In October 2020, we subscribed to 638,297 shares for €15 million that represents 2.29% of McPhy’s capital. The investment was recorded at the fair value.
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 and a gain on bargain purchase of $83.3 million included within restructuring and other charges in our consolidated statement of income.
In February 2018, we signed an agreement with the Island Offshore Group to acquire a 51% stake in Island Offshore’s wholly-owned subsidiary, Island Offshore Subsea AS. Island Offshore Subsea AS provides RLWI project management and engineering services for plug and abandonment (“P&A”), riserless coiled tubing, and well completion operations. In connection with the acquisition of the controlling interest, TechnipFMC and Island Offshore entered into a strategic cooperation agreement to deliver RLWI services on a worldwide basis, which also include TechnipFMC’s RLWI capabilities. Island Offshore Subsea AS has been rebranded to TIOS AS and is now the operating unit for TechnipFMC’s RLWI activities worldwide. The acquisition was completed on April 18, 2018 for total cash consideration of $42.4 million. As a result of the acquisition, we recorded a redeemable financial liability equal to the fair value of a written put option and a goodwill of $85.0 million.
On July 18, 2018, we entered into a share sale and purchase agreement with POC Holding Oy to sell 100% of the outstanding shares of Technip Offshore Finland Oy. The total pre-tax gain recognized in 2018 was $27.8 million.
Additional acquisitions, including purchased interests in equity method investments, during 2018 totaled $62.5 million in consideration paid.
NOTE 3. SEPARATION TRANSACTION
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. Due to the COVID-19 pandemic, a significant decline in commodity prices, and the heightened volatility in global equity markets, on March 15, 2020, we announced the postponement of the completion of the transaction until the markets sufficiently recover. On January 7, 2021, we announced the resumption of activity toward completion of the transaction based on increased clarity in the market outlook and our demonstrated ability to successfully execute projects.
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. 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, on January 7, 2021, Bpifrance Participations SA (“BPI”), which has been one of our substantial shareholders since 2009, entered into a share purchase agreement with us (the “Share Purchase Agreement”) 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”). On February 25, 2021, BPI paid $200.0 million in connection with the Share Purchase Agreement. The Purchase Price is subject to adjustment, and BPI’s ownership stake will be determined based upon a thirty day volume-weighted average price of Technip Energies N.V.’s shares (with BPI’s ownership collared between an 11.82 percentage floor and a 17.25 percentage cap), less a six percent discount. The BPI Investment is subject to customary conditions and regulatory approval. We intend to significantly reduce our shareholding in Technip Energies N.V. over the 18 months following the Spin-off, including in connection with the sale of shares to BPI pursuant to the BPI Investment.
Beginning in the first quarter of 2021, Technip Energies’ historical financial results for periods prior to the Distribution will be reflected in our consolidated financial statements as discontinued operations, as the Spin-off represented a strategic shift that will have a major impact to our operations and consolidated financial statements. Following the completion of the Spin-off, we elected to apply a fair value option to account for our equity method investment in Technip Energies N.V.
During the years ended December 31, 2020 and 2019, we incurred $39.5 million and $72.1 million of separation costs associated with the Spin-off transaction, respectively.
NOTE 4. NEW ACCOUNTING STANDARDS
Recently Adopted Accounting Standards under GAAP
Effective January 1, 2020, we adopted Accounting Standards Update (“ASU”) No. 2018-13, “Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement.” This update modifies the disclosure requirement on fair value measurements in Topic 820. The amendments on changes in unrealized gains and losses, the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements, and the narrative description of measurement uncertainty should be applied prospectively. The adoption of this update concerns presentation and disclosure only as it relates to our consolidated financial statements. See Note 24 for our fair value measurements disclosure.
Effective January 1, 2020, we adopted ASU No. 2018-15, “Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract (a consensus of the FASB Emerging Issues Task Force).” This update requires that the implementation costs incurred in a cloud computing arrangement under a service contract are deferred, not capitalized. The adoption of this update did not have a material impact on our consolidated financial statements.
Effective January 1, 2020, we adopted ASU No. 2018-18, “Collaborative Arrangements (Topic 808)-Clarifying the Interaction between Topic 808 and Topic 606.” This update clarifies the interaction between the guidance for certain collaborative arrangements and the Revenue Recognition financial accounting and reporting standard. The adoption of this update concerns presentation and disclosure only with no material impact to our consolidated financial statements.
Effective January 1, 2020, we adopted ASU No. 2019-04, “Codification Improvements to
•Topic 326, Financial Instruments-Credit Losses;
•Topic 815, Derivatives and Hedging; and
• Topic 825, Financial Instruments.”
The update clarifies and improves areas of guidance related to the recently issued standards including
• ASU No. 2016-01, “Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Liabilities”;
• ASU No. 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.”; and
• ASU No. 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities.”
The adoption of this update concerns presentation and disclosure only with no material impact to our consolidated financial statements.
Adoption of ASU No. 2016-13 “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments
Effective January 1, 2020, we adopted ASU No. 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” This ASU introduces a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. The guidance applies to (1) loans, accounts receivable, trade receivables, and other financial assets measured at amortized cost, (2) loan commitments and other off-balance sheet credit exposures, (3) debt securities and other financial assets measured at fair value through other comprehensive income, and (4) beneficial interests in securitized financial assets.
In June 2016, the Financial Accounting Standards Board (“FASB”) issued an update of the ASU to provide a practical expedient for transition and targeted improvements.
We adopted Topic 326 using a modified retrospective transition method through a cumulative-effect adjustment to beginning retained earnings in the period of adoption. The effect of adopting Topic 326 was an increase in accumulated deficit of $7.8 million, which includes a $2.1 million increase in noncurrent deferred tax assets, with a corresponding decrease in trade receivables, loans, and debt notes receivable.
Financial assets at amortized cost include trade receivables, loans issued to third or related parties, and held to maturity debt securities. These financial assets were presented under other current assets or other assets, as applicable. Contract assets are subject to the credit losses standard per revenue recognition standard.
Trade receivables and contract assets constitute a homogeneous portfolio, and therefore, to measure the expected credit losses, trade receivables and contract assets have been grouped together. The contract assets relate to unbilled work in progress and have substantially the same risk characteristics as the trade receivables for the same types of contracts. We have therefore concluded that the expected loss rates for trade receivables are a reasonable approximation of the loss rates for the contract assets.
The following table summarizes the balances of financial assets and non-financial assets at amortized cost as of January 1, 2020:
(In millions) As reported as of December 31, 2019 Impact of ASC 326 Balance as of January 1, 2020
Trade receivables, net $ 2,287.1 $ (3.8) $ 2,283.3
Loans receivable, net 138.5 (1.5) 137.0
Security deposits and other, net 36.6 (1.0) 35.6
Held-to-maturity
Debt securities at amortized cost 71.9 (1.1) 70.8
Total financial assets $ 2,534.1 $ (7.4) $ 2,526.7
Non-financial assets
Contract assets, net $ 1,520.0 $ (2.5) $ 1,517.5
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, 2020.
(In millions) Year of origination Balance as of December 31, 2020
Loans receivables, security deposits and other
Moody’s rating Ba2 2019 $ 133.0
Debt securities at amortized cost
Moody’s rating B3 2019 23.7
Total financial assets $ 156.7
Credit Losses
For contract assets and trade receivables, 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 short-term notes receivable an expected credit loss is calculated assuming the maximum possible loss in the event of a default (that is, the loan is fully drawn and no amount is recovered). Management established a probability of default based on the counterparty’s credit risk as determined by external credit rating agencies and the maximum loss given default (average recovery rate of sovereign bond issuers as published by credit rating agencies). Based on these factors we determine the expected credit loss for our short-term loans receivable.
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 for the year ended December 31, 2020.
Balance as of December 31, 2020
(In millions) Trade receivables Contract assets Loans receivable Security deposit and other Held-to-maturity debt securities
Beginning balance in allowance for credit losses $99.2 $5.0 $9.5 $1.6 $1.1
Current period provision for expected credit losses 54.3 (0.2) (0.1) 0.9 (0.6)
Write-offs charged against the allowance (46.9) - - - -
Recoveries 2.3 (3.8) (0.9) (1.4) -
Ending balance in the allowance for credit losses $ 108.9 $ 1.0 $ 8.5 $ 1.1 $ 0.5
Other than certain trade receivables due in one year or less, we do not have any financial assets that are past due or are on non-accrual status.
Recently Issued 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. The amendments in this update are required to be adopted retrospectively. We adopted this amendment as of January 1, 2021. The adoption of this update 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 generally accepted accounting principles (GAAP) for which costs 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. The adoption of this update 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. The adoption of this update did not have a material impact on our consolidated financial statements.
In March 2020, the FASB issued ASU No. 2020-04, “Facilitation of the Effects of Reference Rate Reform on Financial Reporting (Topic 848),” The amendments in this update apply only to contracts, hedging relationships, and other transactions that reference 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 are effective as of March 12, 2020 through December 31, 2022. The adoption of this update is not expected to have a material impact on our consolidated 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 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, 2020 and 2019:
Year Ended December 31,
(In millions) 2020 2019
Operating lease costs including variable costs $ 312.1 $ 362.4
Short-term lease costs 13.7 20.8
Less: sublease income 7.3 8.9
Net lease cost $ 318.5 $ 374.3
Supplemental cash flow information related to leases for the years ended December 31, 2020 and 2019 is as follows:
Year Ended December 31,
(In millions) 2020 2019
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases $ 314.2 $ 384.7
Right-of-use assets obtained in exchange for lease liabilities
Operating leases $ 535.9 $ 125.4
Supplemental balance sheet information related to leases as of December 31, 2020 and 2019 is as follows:
December 31,
(In millions, except lease term and discount rate) 2020 2019
Weighted average remaining lease term
Operating leases 11.8 years 7.5 years
Finance leases 0.6 years $ -
Weighted average discount rate
Operating leases 5.1 % 4.4 %
Finance leases 2.1 % - %
Maturities of operating lease liabilities as of December 31, 2020 are as follows:
(In millions) Operating Leases
2021 $ 252.5
2022 191.5
2023 137.1
2024 117.6
2025 79.2
Thereafter 471.4
Total lease payments 1,249.3
Less: Imputed interest (a)
121.3
Total lease liabilities (b)
$ 1,128.0
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 $247.0 million for operating leases.
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 land underneath Gremp Campus which the Company owned to the New Lessor. TechnipFMC concurrently executed a new lease agreement for both 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 has 4 renewal periods of 10 years each after the expiration of initial term. At inception of the new lease agreement, TechnipFMC did not consider any renewal period as probable of being exercised.
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.
The following table is a summary of components of lease revenue for the years ended December 31, 2020 and 2019:
Year Ended December 31,
(In millions) 2020 2019
Operating lease revenue including variable revenue $ 142.0 $ 266.5
The following table is a summary of the maturity analysis of the undiscounted cash flows to be received on an annual basis for each of the first five years, and a total of the amounts for the remaining years:
(In millions) Operating Leases
2021 $ 21.4
2022 14.3
2023 1.0
2024 -
2025 -
Thereafter -
Total undiscounted cash flows $ 36.7
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. On January 1, 2018, we adopted Topic 606 of GAAP using the modified retrospective method applied to those contracts that were not completed as of January 1, 2018 resulting in a $91.5 million reduction to retained earnings.
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 86.0%, 81.7% and 82.4% of our revenue for the years ended December 31, 2020, 2019 and 2018, 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.
Technip Energies
Our Technip Energies segment designs and builds onshore facilities related to the production, treatment, transformation and transportation of hydrocarbons and renewable feedstock; and designs, manufactures and installs fixed and floating platforms for the offshore production and processing of oil and gas reserves.
Our onshore business combines the design, engineering, procurement, construction and project management of the entire range of onshore facilities. Our onshore activity covers all types of onshore facilities related to the production, treatment and transportation of oil and gas, as well as transformation with petrochemicals such as ethylene, polymers and fertilizers. Some of the onshore activities include the development of onshore fields, refining, natural gas treatment and liquefaction, and design and construction of hydrogen and synthesis gas production units.
Many of these contracts provide a combination of engineering, procurement, construction, project management and installation services, which may last several years. We have determined that contracts of this nature have generally one performance obligation. In these contracts, the final product is highly customized to the specifications of the field and the customer’s requirements. Therefore, the customer obtains control of the asset over time, and thus revenue is recognized over time.
Our offshore business combines the design, engineering, procurement, construction and project management within the entire range of fixed and floating offshore oil and gas facilities, many of which were the first of their kind, including the development of floating liquefied natural gas (“FLNG”) facilities. Similar to onshore contracts, contracts grouped under this segment provide a combination of services, which may last several years.
We have determined that contracts of this nature have one performance obligation. In these contracts, the final product is highly customized to the specifications of the field and the customer’s requirements. We have determined that the customer obtains control of the asset over time, and thus revenue is recognized over time as the customized products do not have an alternative use for us and we have an enforceable right to payment plus reasonable profit for performance completed to date. Subsequent to the Spin-off, we operate under two reporting segments: Subsea and Surface Technologies, for further details see Note 3 for further details.
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.
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 products and services revenue by geography for each reportable segment for the years ended December 31, 2020, 2019 and 2018:
Reportable Segments
Year Ended December 31,
2020 2019 2018
(In millions) Subsea Technip Energies Surface Technologies Subsea Technip Energies Surface Technologies Subsea Technip Energies Surface Technologies
Europe, Russia, Central Asia $ 1,641.9 $ 3,111.6 $ 188.2 $ 1,745.2 $ 2,813.1 $ 236.7 $ 1,528.1 $ 3,506.1 $ 227.7
Americas 1,957.7 982.6 373.1 1,770.0 766.2 732.1 1,721.5 365.1 865.5
Asia Pacific 753.2 1,094.3 123.4 659.9 1,152.5 189.3 532.9 1,236.1 123.2
Africa 893.9 884.4 45.8 824.8 526.0 61.1 758.1 252.7 57.9
Middle East 169.8 447.1 241.6 407.1 1,011.0 247.6 181.2 760.7 213.4
Total products and services revenue $ 5,416.5 $ 6,520.0 $ 972.1 $ 5,407.0 $ 6,268.8 $ 1,466.8 $ 4,721.8 $ 6,120.7 $ 1,487.7
The following table represents revenue by contract type for each reportable segment for the years ended December 31, 2020, 2019 and 2018:
Reportable Segments
Year Ended December 31,
2020 2019 2018
(In millions) Subsea Technip Energies Surface Technologies Subsea Technip Energies Surface Technologies Subsea Technip Energies Surface Technologies
Services $ 3,121.1 $ 6,436.9 $ 150.2 $ 3,244.5 $ 6,268.8 $ 276.4 $ 2,687.1 $ 6,120.7 $ 249.8
Products 2,295.4 83.1 821.9 2,162.5 - 1,190.4 2,034.7 - 1,237.9
Total products and services revenue 5,416.5 6,520.0 972.1 5,407.0 6,268.8 1,466.8 4,721.8 6,120.7 1,487.7
Lease and other(a)
54.9 - 87.1 116.0 - 150.5 118.2 - 104.5
Total revenue $ 5,471.4 $ 6,520.0 $ 1,059.2 $ 5,523.0 $ 6,268.8 $ 1,617.3 $ 4,840.0 $ 6,120.7 $ 1,592.2
(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.
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, 2020 and 2019:
December 31,
(In millions) 2020 2019 $ change % change
Contract assets $ 1,267.6 $ 1,520.0 $ (252.4) (16.6)
Contract (liabilities) (4,736.1) (4,585.1) (151.0) (3.3)
Net contract liabilities $ (3,468.5) $ (3,065.1) $ (403.4) (13.2)
The decrease in our contract assets from December 31, 2019 to December 31, 2020 was primarily due to the timing of milestones.
The increase in our contract liabilities was primarily due to additional cash received, excluding amounts recognized as revenue 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, 2020 and 2019 that were included in the contract liabilities balance as of December 31, 2019 and 2018 was $1,267.5 million and $2,414.0 million, respectively.
In addition, net revenue recognized for the years ended December 31, 2020 and 2019 from our performance obligations satisfied in previous periods had favorable impacts of $470.8 million and $1,176.5 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, 2020, the aggregate amount of the transaction price allocated to order backlog was $21,388.2 million. TechnipFMC expects to recognize revenue on approximately 51.2% of the order backlog through 2021 and 48.8% thereafter.
The following table details the order backlog for each business segment as of December 31, 2020:
(In millions) 2021 2022 Thereafter
Subsea $ 3,585.4 $ 2,217.2 $ 1,073.4
Technip Energies 7,016.2 4,081.7 3,000.8
Surface Technologies 343.6 69.4 0.5
Total remaining unsatisfied performance obligations $ 10,945.2 $ 6,368.3 $ 4,074.7
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 Chairman 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 report the results of operations in the following segments:
•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.
•Technip Energies - offers extensive experience, knowledge and unique project management capabilities in onshore and offshore hydrocarbon infrastructure businesses; it also combines its leading engineering and construction capabilities with its technological know-how, products and services to develop new solutions that will support the world’s energy transition.
•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.
Beginning in the first quarter of 2020, in anticipation of our separation transaction, we renamed our Onshore/Offshore segment to Technip Energies, which includes our Loading Systems business that was previously reported in the Surface Technologies segment and our process automation business, Cybernetix, that was previously reported in the Subsea segment. Prior year information has not been restated due to these businesses not being material. Subsequent to the Spin-off, we operate under two reporting segments: Subsea and Surface Technologies, for further details see Note 3 for further details.
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, net interest income (expense) associated with corporate debt facilities, income taxes, and other revenue and other expense, net.
Information by business segment
Segment revenue and segment operating profit (loss) were as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Segment revenue
Subsea $ 5,471.4 $ 5,523.0 $ 4,840.0
Technip Energies 6,520.0 6,268.8 6,120.7
Surface Technologies 1,059.2 1,617.3 1,592.2
Total revenue $ 13,050.6 $ 13,409.1 $ 12,552.9
Segment operating profit (loss)
Subsea $ (2,815.5) $ (1,447.7) $ (1,529.5)
Technip Energies 683.6 959.6 824.0
Surface Technologies (429.3) (656.1) 172.8
Total segment operating loss (2,561.2) (1,144.2) (532.7)
Corporate items
Impairment, restructuring and other expenses (10.0) (17.4) (18.9)
Separation costs (39.5) (72.1) -
Merger transaction and integration costs - (31.2) (36.5)
Legal expenses - (54.6) (280.0)
Other corporate expenses (a)
(152.0) (218.1) (142.6)
Corporate expense (201.5) (393.4) (478.0)
Interest income 56.6 116.5 121.4
Interest expense (349.6) (567.8) (482.3)
Foreign exchange losses (28.8) (146.9) (116.5)
Total corporate items (523.3) (991.6) (955.4)
Loss before income taxes (b)
$ (3,084.5) $ (2,135.8) $ (1,488.1)
(a)Other corporate expenses primarily include corporate staff expenses, share-based compensation expenses, and other employee benefits.
(b)Includes amounts attributable to non-controlling interests.
During the year ended December 31, 2020, revenue from Arctic LNG exceeded 10% of our consolidated revenue. During the years ended December 31, 2019 and 2018, revenue from Yamal LNG exceeded 10% of our consolidated revenue.
Segment assets were as follows:
December 31,
(In millions) 2020 2019
Segment assets
Subsea $ 6,796.6 $ 10,824.2
Technip Energies 5,058.3 4,448.8
Surface Technologies 1,758.3 2,246.4
Total segment assets 13,613.2 17,519.4
Corporate (a)
6,079.4 5,999.4
Total assets $ 19,692.6 $ 23,518.8
(a)Corporate includes cash, 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) 2020 2019 2018 2020 2019 2018 2020 2019 2018
Subsea $ 213.6 $ 287.7 $ 223.2 $ 324.9 $ 345.6 $ 440.4 $ 66.5 $ 134.4 $ 145.2
Technip Energies 13.0 22.6 7.6 34.2 38.7 38.2 44.5 13.2 29.7
Surface Technologies 38.5 96.6 111.9 70.1 107.9 66.6 8.8 15.3 14.3
Corporate 26.7 47.5 25.4 18.0 17.4 5.2 - - -
Total $ 291.8 $ 454.4 $ 368.1 $ 447.2 $ 509.6 $ 550.4 $ 119.8 $ 162.9 $ 189.2
Information by geography
Sales by geography were identified based on the country where our products and services were delivered, and are as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Revenue
Russia $ 2,451.5 $ 2,378.0 $ 2,773.3
United States 2,141.4 1,931.2 1,275.8
Norway 1,393.5 1,371.1 1,202.6
Brazil 698.8 1,099.7 1,478.7
United Kingdom 513.8 540.8 442.1
Angola 488.5 447.8 385.7
Egypt 445.9 177.6 13.2
Mozambique 391.4 166.1 116.2
India 386.4 518.0 214.0
Senegal 353.0 176.5 1.2
Vietnam 340.7 72.1 34.7
Israel 333.6 757.0 243.8
Guyana 330.1 7.2 7.6
Australia 320.8 372.8 926.6
Singapore 312.2 64.9 23.4
Indonesia 286.9 237.6 130.7
Malaysia 281.7 283.8 362.3
France 186.9 92.8 138.9
China 151.4 272.9 112.3
United Arab Emirates 147.9 327.2 460.3
All other countries 1,094.2 2,114.0 2,209.5
Total revenue $ 13,050.6 $ 13,409.1 $ 12,552.9
Long-lived assets by geography represent property, plant and equipment, net, and are as follows:
December 31,
(In millions) 2020 2019
Long-lived assets
United Kingdom $ 936.2 $ 957.1
United States 467.5 558.1
Netherlands 419.5 493.0
Norway 312.2 333.0
Brazil 260.0 313.2
All other countries 466.4 507.6
Total long-lived assets $ 2,861.8 $ 3,162.0
NOTE 8. EARNINGS (LOSS) PER SHARE
A reconciliation of the number of shares used for the basic and diluted earnings per share calculation was as follows:
Year Ended December 31,
(In millions, except per share data) 2020 2019 2018
Net loss attributable to TechnipFMC plc $ (3,287.6) $ (2,415.2) $ (1,921.6)
Weighted average number of shares outstanding 448.7 448.0 458.0
Dilutive effect of restricted stock units - - -
Dilutive effect of performance shares - - -
Total shares and dilutive securities 448.7 448.0 458.0
Basic loss per share attributable to TechnipFMC plc $ (7.33) $ (5.39) $ (4.20)
Diluted loss per share attributable to TechnipFMC plc $ (7.33) $ (5.39) $ (4.20)
For the years ended December 31, 2020, 2019 and 2018, 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, 2019 and 2018, 3.8 million shares, 4.3 million shares and 2.7 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) 2020 2019 2018
Share option awards 4.6 4.0 3.5
Restricted share units 1.8 - -
Performance shares 1.9 1.6 -
Total 8.3 5.6 3.5
NOTE 9. INVENTORIES
Inventories consisted of the following:
December 31,
(In millions) 2020 2019
Raw materials $ 272.4 $ 347.5
Work in process 245.2 290.2
Finished goods 750.9 778.3
Inventories, net $ 1,268.5 $ 1,416.0
All amounts in the table above are reported net of obsolescence reserves of $162.8 million and $135.7 million as of December 31, 2020 and 2019, respectively.
Net inventories accounted for under the LIFO method totaled $408.5 million and $386.6 million as of December 31, 2020 and 2019, respectively. The current replacement costs of LIFO inventories exceeded their recorded values by $11.6 million and $10.9 million as of December 31, 2020 and 2019, respectively. There was no reduction to the base LIFO inventory in 2020.
NOTE 10. OTHER CURRENT ASSETS & OTHER CURRENT LIABILITIES
Other current assets consisted of the following:
December 31,
(In millions) 2020 2019
Value - added tax receivables $ 450.5 $ 395.2
Sundry receivables 179.3 69.6
Prepaid expenses 111.7 66.8
Other taxes receivables 90.1 100.7
Assets held for sale 47.3 25.8
Current financial assets at amortized cost 40.6 42.0
Held-to-maturity investments 24.2 49.7
Other 48.9 113.9
Total other current assets $ 992.6 $ 863.7
Other current liabilities consisted of the following:
December 31,
(In millions) 2020 2019
Warranty accruals and project contingencies 285.9 310.1
Value - added tax and other taxes payable $ 221.3 $ 240.4
Legal provisions 188.5 183.6
Redeemable financial liability 141.9 129.1
Social security liability 108.9 116.5
Provisions 75.5 86.6
Compensation accrual 54.3 89.6
Current portion of accrued pension and other post-retirement benefits 13.9 14.9
Liabilities classified as held for sale - 9.3
Other accrued liabilities 278.4 314.4
Total other current liabilities $ 1,368.6 $ 1,494.5
NOTE 11. WARRANTY OBLIGATIONS
Warranty obligations are included within “Other current liabilities” in our consolidated balance sheets as of December 31, 2020 and 2019. A reconciliation of warranty obligations for the years ended December 31, 2020 and 2019 is as follows:
Year Ended December 31,
(In millions) 2020 2019
Balance at beginning of period $ 193.5 $ 234.4
Warranty expenses 95.6 78.8
Adjustment to existing accruals (86.2) (57.5)
Claims paid (28.1) (62.2)
Balance at end of period $ 174.8 $ 193.5
NOTE 12. 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.
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. None of our proportionate consolidation investments, individually or in the aggregate, are significant to our consolidated results for 2020, 2019, or 2018.
Our equity investments were as follows as of December 31, 2020 and 2019:
December 31
2020 2019
(In millions, except %) Percentage Owned Carrying Value
Dofcon Brasil AS 50.0 % 234.7 167.4
Magma Global Limited 25.0 % 51.4 50.2
Serimax Holdings SAS 20.0 % 18.8 21.5
Other 54.0 61.3
Investments in equity affiliates $ 358.9 $ 300.4
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”) - is an affiliated company in the form of a collaborative agreement signed in 2018 between Technip-Coflexip UK Holdings Limited and Magma Global to develop hybrid flexible pipe for use in offshore applications. As part of the collaboration, TechnipFMC holds a minority stake. We have accounted for our 25% investment using the equity method investment of accounting with results reported in our Subsea segment.
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.
Our income from equity affiliates included in each of our reporting segments was as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Subsea $ 64.6 $ 59.8 $ 80.9
Technip Energies (1.6) 3.1 33.4
Income from equity affiliates $ 63.0 $ 62.9 $ 114.3
NOTE 13. 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 receivables due from following related parties:
December 31,
(In millions) 2020 2019
TP JGC Coral France SNC $ 38.1 $ 40.1
Equinor ASA 24.1 -
TTSJV W.L.L. 14.9 22.4
Novarctic SNC 9.7 -
Dofcon Navegacao 4.2 -
Techdof Brasil AS 8.0 4.3
Storengy 6.1 3.1
Others 8.4 6.9
Total trade receivables $ 113.5 $ 76.8
TP JGC Coral France SNC, TTSJV W.L.L., Dofcon Navegacao, and Novarctic SNC are equity method affiliates. Techdof Brasil AS is a wholly owned subsidiary of Dofcon Brasil AS, our equity method affiliate. A member of our Board of Directors serves on the Board of Directors for Storengy. In October 2020, we added a new member of our Board of Directors who is an executive of Equinor ASA.
Trade payables consisted of payables due to following related parties:
December 31,
(In millions) 2020 2019
Chiyoda $ 14.2 $ 24.8
Nipigas 14.2 -
Saipem 23.7 -
JGC Corporation 1.9 15.1
IFP Energies nouvelles - 2.4
Dofcon Navegacao 1.5 2.1
Others 5.7 6.7
Total trade payables $ 61.2 $ 51.1
Chiyoda and JGC Corporation are joint venture partners on our Yamal project. Saipem and Nipigas are joint venture partners on our Arctic LNG project. A member of our Board of Directors serves as an executive officer of IFP Energies nouvelles until June 2020.
Additionally, we have note receivable balance of $40.3 million and $65.2 million as of December 31, 2020 and 2019, respectively. The note receivable balance includes $37.6 million and $62.5 million with Dofcon Brasil AS as of December 31, 2020 and 2019, respectively. Dofcon Brasil AS is a VIE and accounted for as an equity method affiliate. 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) 2020 2019 2018
TTSJV W.L.L. $ 47.2 $ 127.9 $ -
TP JGC Coral France SNC 44.2 110.4 118.2
Equinor ASA 81.1 - -
Equinor Brasil 38.5 - -
Anadarko Petroleum Company - 67.1 124.8
TOP CV - 11.9 7.2
Storengy 10.7 8.8 -
Novarctic SNC 10.7 0.4 -
Dofcon Navegacao 3.4 8.4 2.9
Techdof Brasil AS 11.2 8.3 7.0
JGC Corporation - 6.7 -
Others 27.2 29.7 33.2
Total revenue $ 274.2 $ 379.6 $ 293.3
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 2 for further details.
Equinor Brasil is a subsidiary of Equinor ASA in Brazil.
Expenses consisted of amounts to following related parties:
Year Ended December 31,
(In millions) 2020 2019 2018
Chiyoda $ 1.4 $ 25.1 $ 53.0
JGC Corporation 0.4 20.8 81.2
Arkema S.A. 5.3 18.9 2.6
Serimax Holdings SAS 0.4 17.7 0.1
Saipem 26.8 - -
Nipigas 36.8 - -
Magma Global Limited 14.0 7.3 3.0
TP JGC Coral France SNC - 5.0 -
Jumbo Shipping 16.0 4.5 -
Dofcon Navegacao 24.0 1.8 -
Others 24.6 41.3 14.8
Total expenses $ 149.7 $ 142.4 $ 154.7
Serimax Holdings SAS and Magma Global Limited are equity method affiliates. Members of our Board of Directors serve on the Board of Directors for Arkema S.A. and Jumbo Shipping.
NOTE 14. PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment consisted of the following:
December 31,
(In millions) 2020 2019
Land and land improvements $ 88.4 $ 108.4
Buildings 611.0 626.9
Vessels 1,968.1 2,091.9
Machinery and equipment 1,919.4 1,930.6
Office fixtures and furniture 292.0 285.0
Construction in process 148.1 130.9
Other 243.5 277.1
5,270.5 5,450.8
Accumulated depreciation (2,408.7) (2,288.8)
Property, plant and equipment, net $ 2,861.8 $ 3,162.0
Depreciation expense was $323.5 million, $383.5 million and $367.8 million in 2020, 2019 and 2018, respectively. The amount of interest cost capitalized was not material for the years presented.
During 2020 and 2019, we determined the carrying amount of certain of our long-lived assets exceeded their fair value and recorded an impairment. See Note 19 for further details.
In December 2020, we declared our intent to sell our G1200 vessel as part of our overall strategy to optimize the profile and size of our subsea fleet and classified it as an asset held for sale in Other Current Assets in our consolidated balance sheet. We also evaluated the vessel’s book value and recorded an impairment charge of $8.3 million within Impairment, Restructuring and Other Expenses in our consolidated statement of income for the year ended December 31, 2020.
In December 2019, we completed the sale of our G1201 vessel as part of our overall strategy to optimize the profile and size of our subsea fleet. We recorded a net loss of $7.1 million, which is included in other income (expense), net in our consolidated statements of income.
NOTE 15. 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.
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 based on internal forecasts of revenues and expenses over a specified period plus a terminal value (the income approach).
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 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.
During our annual impairment tests the following significant estimates were used by management in determining the fair values of reporting units in order to test the goodwill at October 31:
2020 2019 2018
Year of cash flows before terminal value 4 4 5
Discount rates 15.0% 12.5% to 15.0% 12.0% to 13.0%
EBITDA multiples N/A 6.0 - 8.5x 7.0 - 8.5x
During the year ended December 31, 2020, the significant estimates used by management in determining the fair value described above relate to Technip Energies reporting unit only. The fair value over carrying amount for our Technip Energies segment was in excess of 300% of its carrying amount at October 31, 2020.
Based on the impairment tests performed during the year ended December 31, 2020 we recorded $2,747.5 million and $335.9 million of goodwill impairment charges recorded in our Subsea and Surface Technologies reporting units, respectively. No goodwill impairment charges were recorded in our Technip Energies reporting unit.
During the year ended December 31, 2019, we recorded $1,321.9 million and $666.8 million of goodwill impairment charges in our Subsea and Surface Technologies reporting units, respectively. See Note 19 for further details.
The carrying amount of goodwill by reporting segment was as follows:
(In millions) Subsea Technip Energies Surface Technologies Total
December 31, 2018 4,142.4 2,447.7 1,017.5 7,607.6
Impairments (1,321.9) - (666.8) (1,988.7)
Purchase accounting adjustment - - 9.9 9.9
Other - (17.7) - (17.7)
Translation (6.4) (6.4) - (12.8)
December 31, 2019 2,814.1 2,423.6 360.6 5,598.3
Impairments (2,747.5) - (335.9) (3,083.4)
Transfers (a)
(21.2) 46.1 (24.9) -
Translation (45.4) 42.8 0.2 (2.4)
December 31, 2020 $ - $ 2,512.5 $ - $ 2,512.5
(a) Beginning in the first quarter of 2020, Technip Energies includes our Loading Systems business that was previously reported in the Surface Technologies segment and our process automation business, Cybernetix, that was previously reported in the Subsea segment. See Note 7 for further details.
As of December 31, 2020 and 2019, accumulated goodwill impairment was $6,455.1 million and $3,371.7 million, respectively.
Intangible assets - The components of intangible assets were as follows:
December 31,
2020 2019
(In millions) Gross
Carrying
Amount Accumulated
Amortization Gross
Carrying
Amount Accumulated
Amortization
Acquired technology $ 247.1 $ 98.1 $ 246.7 $ 73.6
Backlog - - 175.0 175.0
Customer relationships 285.4 114.4 285.4 85.9
Licenses, patents and trademarks 816.8 264.0 811.1 227.6
Software 232.1 178.9 215.9 151.1
Other 120.2 65.1 115.9 50.2
Total intangible assets $ 1,701.6 $ 720.5 $ 1,850.0 $ 763.4
We recorded $123.7 million, $126.1 million and $182.6 million in amortization expense related to intangible assets during the years ended December 31, 2020, 2019 and 2018, respectively. During the years 2021 through 2025, annual amortization expense is expected to be as follows: $117 million in 2021, $114 million in 2022, $110 million in 2023, $96 million in 2024, $93 million in 2025 and $451 million thereafter.
NOTE 16. DEBT
Overview
Short-term debt and current portion of long-term debt - Short-term debt and current portion of long-term debt consisted of the following:
December 31,
(In millions) 2020 2019
Bank borrowings and other $ 85.0 $ 270.8
Synthetic bonds due 2021 551.2 -
5.00% 2010 Private placement notes due 2020
- 224.6
Total short-term debt and current portion of long-term debt $ 636.2 $ 495.4
Long-term debt consisted of the following:
December 31,
(In millions) 2020 2019
Commercial paper $ 1,525.9 $ 1,967.0
Synthetic bonds due 2021 551.2 492.9
3.45% Senior Notes due 2022
500.0 500.0
5.00% 2010 Private placement notes due 2020
- 224.6
3.40% 2012 Private placement notes due 2022
184.0 168.5
3.15% 2013 Private placement notes due 2023
159.5 146.0
3.15% 2013 Private placement notes due 2023
153.4 140.4
4.50% 2020 Private placement notes due 2025
245.4 -
4.00% 2012 Private placement notes due 2027
92.0 84.2
4.00% 2012 Private placement notes due 2032
122.7 112.3
3.75% 2013 Private placement notes due 2033
122.7 112.3
Bank borrowings and other 309.9 536.3
Unamortized debt issuance costs and discounts (12.8) (9.1)
Total debt 3,953.9 4,475.4
Less: current borrowings 636.2 495.4
Long-term debt $ 3,317.7 $ 3,980.0
Debt maturities as of December 31, 2020, 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 $ 3,953.9 $ 636.2 $ 2,589.1 $ 294.0 $ 434.6
Subsequent to the Spin-off, we expect the total future principal payments on debt to be approximately $2,376.8 million. Refer to Note 26 for further details.
Significant Funding and Liquidity Activities
During 2020, we completed the following transactions in order to enhance our total liquidity position:
•Repaid $233.9 million of 5.00% 2010 private placement notes;
•Repaid the remaining outstanding balance of $190.0 million of the term loan assumed in connection with the acquisition of the remaining 50% interest in TOP CV.
•Issued €200 million aggregate principal amount of 4.500% 2020 Private Placement Notes due June 30, 2025. Within three months of the effective date of the Spin-off of Technip Energies, if there is a downgrade by a nationally recognized rating agency of the corporate rating of TechnipFMC from an investment grade to a non-investment grade rating or a withdrawal of any such rating, the interest rate applicable to the 2020 Private Placement Notes will be increased to 5.75%;
•Entered into a new, six-month €500 million senior unsecured revolving credit facility agreement, which may be extended for two additional three-month periods (the “Euro Facility”); and
•Entered into the Bank of England’s COVID Corporate Financing Facility program (the “CCFF Program”), which allows us to issue up to £600 million of unsecured commercial paper notes.
Credit Facilities and Debt
Revolving credit facility - On January 17, 2017, we acceded to a new $2.5 billion senior unsecured revolving credit facility agreement (“Facility Agreement”) between FMC Technologies, Inc., Technip Eurocash SNC (the “Borrowers”), and TechnipFMC plc (the “Additional Borrower”) with JPMorgan Chase Bank, National Association (“JPMorgan”), as agent and an arranger, SG Americas Securities LLC as an arranger, and the lenders party thereto.
The Facility Agreement provides for the establishment of a multicurrency, revolving credit facility, which includes a $1.5 billion letter of credit subfacility. Subject to certain conditions, the Borrowers may request the aggregate commitments under the facility agreement be increased by an additional $500.0 million. On November 26, 2018, we entered into an extension which extends the expiration date to January 2023.
Borrowings under the facility agreement bear interest at the following rates, plus an applicable margin, depending on currency:
•U.S. dollar-denominated loans bear interest, at the Borrowers’ option, at a base rate or an adjusted rate linked to the London interbank offered rate (“Adjusted LIBOR”);
•sterling-denominated loans bear interest at Adjusted LIBOR; and
•euro-denominated loans bear interest at the Euro interbank offered rate (“EURIBOR”).
Depending on the credit rating of TechnipFMC, the applicable margin for revolving loans varies (i) in the case of Adjusted LIBOR and EURIBOR loans, from 0.820% to 1.300% and (ii) in the case of base rate loans, from 0.000% to 0.300%. The “base rate” is the highest of (a) the prime rate announced by JPMorgan, (b) the greater of the Federal Funds Rate and the Overnight Bank Funding Rate plus 0.5% or (c) one-month Adjusted LIBOR plus 1.0%. As of December 31, 2020, there were no outstanding borrowings under our revolving credit facility.
Euro Facility - On May 19, 2020, we entered into the Euro Facility with HSBC France, as agent, and the lenders party thereto, which provides for the establishment of a six-month revolving credit facility denominated in Euros with total commitments of €500 million, which may be extended by us for two additional three-month periods. Borrowings under the Euro Facility bear interest at the Euro interbank offered rate for a period equal in length to the interest period of a given loan (which may be three or six months), plus an applicable margin. As of December 31, 2020, there were no outstanding borrowings under Euro Facility.
On June 12, 2020, we entered into Amendment No. 1 to the Facility Agreement and into an Amendment and Restatement Agreement to our Euro Facility. The amendments, which are effective through the respective expirations of the Facility Agreement and Euro Facility, permit us to include the gross book value of $3.2 billion of goodwill (fully impaired in the quarter ended March 31, 2020) in the calculation of consolidated net worth, which is used in the calculation of our quarterly compliance with the total capitalization ratio under the Facility Agreement and Euro Facility.
The Facility Agreement and Euro Facility contain usual and customary covenants, representations and warranties, and events of default for credit facilities of this type, including financial covenants requiring that our total capitalization ratio not exceed 60% at the end of any financial quarter. The Facility Agreement and Euro Facility also contain covenants restricting our ability and our subsidiaries’ ability to incur additional liens and indebtedness, enter into asset sales, or make certain investments.
As of December 31, 2020, we were in compliance with all restrictive covenants under our credit facilities.
CCFF Program - On May 19, 2020, we entered into a dealer agreement (the “Dealer Agreement”) with Bank of America Merrill Lynch International DAC (the “Dealer”) and an Issuing and Paying Agency Agreement (the “Agency Agreement”, and together with the Dealer Agreement, the “Agreements”) with Bank of America, National Association, London Branch, relating to the European commercial paper program established under the CCFF Program as a source of additional liquidity.
The Agreements provide the terms under which we may issue, and the Dealer will arrange for, the sale of short-term, unsecured commercial paper notes (the “Notes”) to reduce existing debt or decrease overall borrowing costs. The Notes contain customary representations, warranties, covenants, defaults, and indemnification provisions, and will be sold at such discounts from their face amounts as shall be agreed between us and the Dealer. The Notes will be fully payable at maturity, and the maturities of the Notes will vary but may not exceed 364 days. The principal amount of outstanding Notes may not exceed £600 million. The Agency Agreement provides for the terms of
issuance and payment of the Notes. As of December 31, 2020, our commercial paper borrowings under the CCFF Program had a weighted average interest rate of 0.43%. As of December 31, 2020, we had $817.9 million of Notes outstanding and recorded as long-term borrowings under the CCFF Program. When we have both the ability and intent to refinance certain obligations on a long-term basis, the obligations are classified as long-term, as such, the outstanding borrowings of the CCFF Program were classified as long-term debt in our consolidated balance sheet as of December 31, 2020.
Bilateral credit facility - We have access to a €100.0 million bilateral credit facility expiring in May 2021.
The bilateral credit facility contains usual and customary covenants, representations and warranties and events of default for credit facilities of this type.
As of December 31, 2020, there were no outstanding borrowings under our bilateral credit facility.
Commercial paper - Under our commercial paper program, we have the ability to access $1.5 billion and €1.0 billion of short-term financing through our commercial paper dealers, subject to the limit of unused capacity of our facility agreement. When we have both the ability and intent to refinance certain obligations on a long-term basis, the obligations are classified as long-term, as such, the commercial paper borrowings were classified as long-term debt in our consolidated balance sheets as of December 31, 2020 and 2019. Commercial paper borrowings are issued at market interest rates. 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 and (0.06)% on the Euro denominated borrowings. As of December 31, 2020, we had $708.0 million of outstanding commercial paper borrowings under this program.
Synthetic bonds - On January 25, 2016, we issued €375.0 million principal amount of 0.875% convertible bonds with a maturity date of January 25, 2021 and a redemption at par of the bonds which have not been converted. On March 3, 2016, we issued additional convertible bonds for a principal amount of €75.0 million issued on the same terms, fully fungible with and assimilated to the bonds issued on January 25, 2016. The issuance of these non-dilutive cash-settled convertible bonds (“Synthetic Bonds”), which are linked to our ordinary shares were backed simultaneously by the purchase of cash-settled equity call options in order to hedge our economic exposure to the potential exercise of the conversion rights embedded in the Synthetic Bonds. As the Synthetic Bonds could only be cash settled, they did not result in the issuance of new ordinary shares or the delivery of existing ordinary shares upon conversion. Interest on the Synthetic Bonds is 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 - We have outstanding 3.45% $500.0 million senior notes due October 1, 2022 (the “Senior Notes”). The terms of the Senior Notes are governed by the indenture, dated as of March 29, 2017 between TechnipFMC and U.S. Bank National Association, as trustee (the “Trustee”), as amended and supplemented by the First Supplemental Indenture between TechnipFMC and the Trustee (the “First Supplemental Indenture”) relating to the issuance of the 2017 Notes and the Second Supplemental Indenture between TechnipFMC and the Trustee (the “Second Supplemental Indenture”) relating to the issuance of the 2022 Notes.
At any time prior to July 1, 2022, in the case of the 2022 Notes, we may redeem some or all of the Senior Notes at the redemption prices specified in the First Supplemental Indenture and Second Supplemental Indenture, respectively. At any time on or after July 1, 2022, we may redeem the 2022 Notes at the redemption price equal to 100% of the principal amount of the 2022 Notes redeemed. The Senior Notes are our senior unsecured obligations. The Senior Notes will rank equally in right of payment with all of our existing and future unsubordinated debt, and will rank senior in right of payment to all of our future subordinated debt.
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 4.50% and are due June 2025. 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. In addition, within three months of the effective date of the Spin-off of Technip Energies, if there is a downgrade by a nationally recognized rating agency of the corporate rating of TechnipFMC from an investment grade to a non-investment grade rating or a withdrawal of any such rating, the interest rate applicable to the 2020 Private Placement Notes will be increased to 5.75%.
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 condensed 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 17. STOCKHOLDERS’ EQUITY
Cash dividends paid during the years ended December 31, 2020, 2019 and 2018 were $59.2 million, $232.8 million and $238.1 million, respectively. In April 2020, our Board of Directors announced its decision to lower the annual dividend by 75% to $0.13 per share.
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, 2020, 2019 and 2018:
(Number of shares in millions) Ordinary
Shares Issued Ordinary Shares
Held in
Employee
Benefit Trust Treasury Stock
December 31, 2017 465.1 - -
Stock awards 0.2 - -
Treasury stock purchases - - 14.8
Treasury stock cancellation (14.8) - (14.8)
Net stock purchased for employee benefit trust - 0.1 -
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 - -
In 2017, the Board of Directors authorized a share repurchase program of up to $500.0 million in ordinary shares. 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, 2020, 2019 and 2018, we repurchased $0.0 million, $92.7 million and $442.8 million of shares, respectively. As of December 31, 2020, 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, 2018 $ (1,234.4) $ (32.9) $ (92.4) $ (1,359.7) $ (4.0)
Other comprehensive income (loss) before reclassifications, net of tax 16.3 8.9 (82.2) (57.0) (0.7)
Reclassification adjustment for net (gains) losses included in net income, net of tax (12.0) 18.2 3.0 9.2 -
Other comprehensive income (loss), net of tax 4.3 27.1 (79.2) (47.8) (0.7)
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)
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) 2020 2019 2018
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 $ 41.1 Other income (expense), net
Gains (losses) on hedging instruments
Foreign exchange contracts $ (83.7) $ (26.6) $ (2.4) Revenue
68.5 12.0 3.4 Costs of sales
(0.4) - (0.1) Selling, general and administrative expense
(4.4) (9.1) 1.0 Other Income (expense), net
(20.0) (23.7) 1.9 Income (loss) before income taxes
(7.0) (5.5) (0.1) Provision (benefit) for income taxes
$ (13.0) $ (18.2) $ 2.0 Net income (loss)
Pension and other post-retirement benefits
Settlements and curtailments (2.2) (0.3) 3.0 (a)
Amortization of actuarial gain (loss) (9.0) (2.5) (0.6) (a)
Amortization of prior service credit (cost) (1.2) (1.0) (1.3) (a)
(12.4) (3.8) 1.1 Income (loss) before income taxes
(3.2) (0.8) 0.1 Provision (benefit) for income taxes
$ (9.2) $ (3.0) $ 1.0 Net income (loss)
(a) These accumulated other comprehensive income components are included in the computation of net periodic pension cost (See Note 22 for further details).
NOTE 18. 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. As of December 31, 2020, 8.5 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, 2020, outstanding awards to active and retired non-employee directors included 254.3 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 was as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Share-based compensation expense $ 69.0 $ 74.5 $ 49.1
Income tax benefits related to share-based compensation expense $ 18.6 $ 20.1 $ 13.2
As of December 31, 2020, the portion of share-based compensation expense related to outstanding awards to be recognized in future periods is as follows:
December 31, 2020
Share-based compensation expense not yet recognized (in millions) $ 68.1
Weighted-average recognition period (in years) 1.8
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, 2019 4,525.9 $ 27.44
Granted 3,836.0 $ 9.27
Vested (1,909.1) $ 27.16
Cancelled/forfeited (330.9) $ 15.71
Non-vested as of December 31, 2020 6,121.9 $ 18.43
The total grant date fair value of restricted stock share units vested during the years ended December 31, 2020 and 2019 was $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,
2020 2019 2018
Weighted-average fair value (a)
$10.02 $29.04 $41.97
Expected volatility (b)
38.30 % 34.00 % 34.00 %
Risk-free interest rate (c)
0.40 % 2.42 % 2.37 %
Expected performance period in years (d)
3.0 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 2020, 2019 and 2018.
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, 2019 3,817.7 $ 28.52
Granted 2,828.4 $ 10.02
Vested (1,364.4) $ 31.65
Cancelled/forfeited (441.0) $ 20.62
Non-vested as of December 31, 2020 4,840.7 $ 17.55
The total grant date fair value of performance share units vested during years ended December 31, 2020, 2019 and 2018 was $43.2 million, $13.3 million and $7.0 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.
The weighted-average fair value and the assumptions used to measure fair value are as follows:
Year Ended December 31,
2020 2019 2018
Weighted-average fair value (a)
$ - $ 5.64 $ 9.07
Expected volatility (b)
- % 32.5 % 32.5 %
Risk-free interest rate (c)
- % 2.5 % 2.7 %
Expected dividend yield (d)
- % 2.6 % 2.0 %
Expected term in years (e)
0 6.5 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)There were no share options awarded in 2020. Share options awarded in 2019 and 2018 were valued using an expected dividend yield of 2.6% and 2.0%, respectively.
(e)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 2020, 2019 and 2018.
The following is a summary of share option transactions during the year ended December 31, 2020:
Number of Shares Weighted average exercise price Weighted average remaining life
(in years)
Balance as of December 31, 2019 4,842.4 $ 29.68 5.3
Granted - $ -
Exercised - $ -
Cancelled (244.0) $ 28.08
Balance as of December 31, 2020 4,598.4 $ 29.77 4.2
Exercisable as of December 31, 2020 3,460.8 $ 31.47 3.0
The aggregate intrinsic value of stock options outstanding and stock options exercisable as of December 31, 2020 was nil and nil, respectively.
Cash received from the share option exercises was nil, during each of the years ended December 31, 2020, 2019 and 2018. The total intrinsic value of share options exercised during each of the years ended December 31, 2020, 2019 and 2018 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, 2020:
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
$20.00-$33.00 4,087.2 4.6 $ 26.68 2,949.5 $ 26.90
$45.00-$51.00 33.0 1.0 $ 45.49 33.0 $ 45.49
$55.00-$57.00 478.2 0.4 $ 56.93 478.3 $ 56.93
Total 4,598.4 4.2 $ 29.77 3,460.8 $ 31.47
NOTE 19. IMPAIRMENT, RESTRUCTURING AND OTHER EXPENSES
Impairment, restructuring and other expenses were as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Subsea $ 2,957.5 $ 1,752.2 $ 1,801.9
Technip Energies 93.6 17.0 (3.4)
Surface Technologies 440.2 704.2 13.8
Corporate and other 10.0 17.4 18.9
Total impairment, restructuring and other expenses $ 3,501.3 $ 2,490.8 $ 1,831.2
Goodwill and Long-Lived Assets Impairments
Goodwill and long-lived assets impairments were as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Subsea $ 2,854.5 $ 1,798.6 $ 1,784.2
Technip Energies 10.3 - -
Surface Technologies 419.3 685.5 4.5
Corporate and other 3.3 - 3.9
Total impairments $ 3,287.4 $ 2,484.1 $ 1,792.6
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 $204.0 million, respectively, related to goodwill and long-lived assets impairments. The $204.0 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 reportable segment; and $33.6 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 $495.4 million, respectively, related to goodwill and long-lived assets impairments. The $495.4 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 reportable segment due to the prolonged downturn in the energy market and its corresponding impact on our business outlook.
The prolonged downturn in the energy market and its corresponding impact on our business outlook in 2018 led us to conclude the carrying amount of certain of our assets in our Subsea operating segment exceeded their fair value as of December 31, 2018. During the year ended December 31, 2018, we recorded $1,383.0 million and $372.9 million, respectively, related to goodwill and vessel impairments in our Subsea operating segment.
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 involves significant judgement, when determining the present value of expected future cash flows. Significant judgements included expected revenue, operating costs and capital decisions that were available at the time of the assessment.
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,
2020 2019 2018
(In millions) Restructuring and other charges COVID-19 expenses Restructuring and other charges Restructuring and other charges
Subsea $ 52.9 $ 50.1 $ (46.4) $ 17.7
Technip Energies 39.3 44.0 17.0 (3.4)
Surface Technologies 13.2 7.7 18.7 9.3
Corporate and other 6.7 - 17.4 15.0
Total $ 112.1 $ 101.8 $ 6.7 $ 38.6
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 20. 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 of our consolidated subsidiaries consisted of the following:
(In millions) December 31, 2020
Financial guarantees (a)
$ 310.1
Performance guarantees (b)
4,659.6
Maximum potential undiscounted payments $ 4,969.7
(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. As we continue to progress our discussions with PNF towards resolution, 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, 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, 2020 and 2019, and that the ultimate resolution of such matters will not materially affect our consolidated financial position, results of operations, or cash flows.
NOTE 21. INCOME TAXES
Components of income (loss) before income taxes - U.S. and outside U.S. components of income (loss) before income taxes were as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
United States $ (3,073.5) $ (1,406.5) $ (197.0)
Outside United States $ (11.5) $ (729.3) $ (1,291.1)
Loss before income taxes $ (3,085.0) $ (2,135.8) $ (1,488.1)
Provision for income tax - The provision for income taxes consisted of:
Year Ended December 31,
(In millions) 2020 2019 2018
Current
United States $ (4.7) $ 34.7 $ 52.1
Outside United States 164.8 317.0 321.8
Total current income taxes 160.1 351.7 373.9
Deferred
United States (3.1) 2.6 19.5
Outside United States (3.6) (78.0) 29.3
Total deferred income taxes (6.7) (75.4) 48.8
Provision for income taxes $ 153.4 $ 276.3 $ 422.7
Deferred tax assets and liabilities - Significant components of deferred tax assets and liabilities were as follows:
December 31,
(In millions) 2020 2019
Deferred tax assets attributable to
Accrued expenses $ 147.8 $ 124.4
Capital loss 21.1 21.1
Non-deductible interest 77.0 84.7
Foreign tax credit carryforwards 145.8 135.3
Other tax credits 166.8 113.2
Net operating loss carryforwards 489.0 430.5
Inventories 16.5 6.3
Research and development credit 3.4 7.6
Foreign exchange - 20.4
Provisions for pensions and other long-term employee benefits 96.1 84.1
Contingencies 43.4 163.3
Margin recognition on construction contracts 113.9 115.9
Leases 254.9 219.8
Revenue in excess of billings on contracts accounted for under the percentage of completion method - 10.9
Other - 6.9
Deferred tax assets 1,575.7 1,544.4
Valuation allowance (935.3) (916.9)
Deferred tax assets, net of valuation allowance 640.4 627.5
Deferred tax liabilities attributable to
Revenue in excess of billings on contracts accounted for under the percentage of completion method 42.6 -
U.S. tax on foreign subsidiaries’ undistributed earnings not indefinitely reinvested 4.2 10.4
Property, plant and equipment, intangibles and other assets 185.8 279.6
Foreign exchange 27.8 -
Leases 237.0 215.2
Other 4.7 -
Deferred tax liabilities 502.1 505.2
Net deferred tax assets $ 138.3 $ 122.3
At December 31, 2020 and 2019, 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, 2020, 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 a valuation allowance against the related deferred tax assets.
Foreign tax credit carryforwards. At December 31, 2020, deferred tax assets included U.S. foreign tax credit carryforwards of $145.8 million, which, if not utilized, will begin to expire in 2024. 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 $61 thousand in 2020, $3.8 million in 2019 and $307.6 million in 2018.
Net operating loss carryforwards. As of December 31, 2020, deferred tax assets include tax benefits relating to net operating loss carryforwards. If not utilized, these net operating loss carryforward will begin to expire in 2021. Except in Norway (net operating losses of $373.7 million), management believes it is more likely than not that we will not be able to utilize these operating loss carryforwards before expiration; thus, we have established a valuation allowance against the related deferred tax assets (inclusive of NOL’s generated in United Kingdom, Saudi Arabia, Netherlands, Mexico, Brazil, Canada, United States, Luxembourg, and Germany). Except in Canada, Mexico, and Netherlands, all of these tax loss carryforwards extend indefinitely.
Certain Adjustments to Valuation Allowance. The net increase in valuation allowance from December 31, 2019 to December 31, 2020 includes certain adjustments which did not impact net tax expense. These adjustments include $62.0 million of deferred tax assets which were recorded in 2020 and are related to certain previously unrecorded tax credits in the Netherlands that are subject to a full valuation allowance. In addition, the Company wrote off $15.3 million and $11.3 million of deferred tax assets in Italy and Mexico, respectively, that had been subject to a full valuation allowance.
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, 2018 $ 91.0
Reductions for tax positions related to prior years (62.4)
Additions for tax positions related to current year 72.9
Reductions for tax positions due to settlements (20.8)
Balance at December 31, 2019 $ 80.7
Reductions for tax positions related to prior years (7.9)
Additions for tax positions related to current year 0.9
Reductions for tax positions due to settlements (2.6)
Balance at December 31, 2020 $ 71.1
The amounts reported above for uncertain tax positions excludes interest and penalties of $3.7 million, $0.1 million, and $2.8 million for the years ended December 31, 2020, 2019, and 2018, 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, $4.2 million of liabilities for unrecognized tax benefits will be settled. This amount is reflected in income taxes payable, the remaining balance of the unrecognized tax benefits is recorded in other long term liabilities.
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: 2010 for Norway, 2016 for Nigeria, 2016 for Brazil, 2017 for France, and 2016 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 2020, 2019, and 2018.
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,
2020 2019 2018
Statutory income tax rate 19.0 % 19.0 % 19.0 %
Net difference resulting from
Foreign earnings subject to different tax rates (1.5) % 0.3 % (9.7) %
Adjustments to prior year taxes (1.3) % (0.4) % (0.7) %
Changes in valuation allowance - % (8.8) % (14.4) %
Deferred tax asset/liability revaluation for tax rate change - % (0.5) % (1.7) %
Impairments (22.5) % (21.9) % (16.5) %
Non-deductible legal provision - % (0.8) % (3.8) %
Other 1.3 % 0.2 % (0.6) %
Effective income tax rate (5.0) % (12.9) % (28.4) %
Income tax holidays. We benefit from income tax holidays in Singapore and Malaysia which will expire after 2023 for Singapore and 2020 for Malaysia. For the year ended December 31, 2020, these tax holidays reduced our provision for income taxes by $5.8 million, or $0.01 per share on a diluted basis.
NOTE 22. 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.
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, 2020 and 2019, were as follows:
Pensions Other
Post-retirement
Benefits
2020 2019 2020 2019
(In millions) U.S. Int’l U.S. Int’l
Accumulated benefit obligation $ 684.7 $ 873.0 $ 669.6 $ 773.3
Projected benefit obligation at January 1 $ 669.7 $ 881.0 $ 598.1 $ 753.4 $ 10.6 $ 9.5
Service cost - 19.1 - 16.3 - -
Interest cost 22.2 14.1 25.6 18.3 0.4 0.5
Actuarial (gain) loss 53.9 35.5 80.7 102.8 (0.2) 1.4
Amendments - 0.1 - 0.9 - -
Curtailments - (0.2) - - - -
Settlements (25.6) (3.5) - (0.6) - -
Foreign currency exchange rate changes - 48.0 - 11.1 (0.5) (0.1)
Plan participants’ contributions - 1.1 - 1.1 - -
Benefits paid (35.5) (27.2) (34.7) (25.7) (0.5) (0.5)
Other - 2.1 - 3.4 - (0.2)
Projected benefit obligation as of December 31 684.7 970.1 669.7 881.0 9.8 10.6
Fair value of plan assets at January 1 520.0 657.8 477.4 570.6 - -
Actual return on plan assets 14.3 45.9 72.0 89.1 - -
Company contributions - 28.7 - 6.9 - -
Foreign currency exchange rate changes - 33.4 - 13.5 - -
Settlements (19.6) (1.9) - - - -
Plan participants’ contributions - 1.1 - 1.1 - -
Benefits paid (31.0) (20.8) (29.4) (19.6) - -
Other - 2.0 - (3.8) - -
Fair value of plan assets as of December 31 483.7 746.2 520.0 657.8 - -
Funded status of the plans (liability) as of December 31 $ (201.0) $ (223.9) $ (149.7) $ (223.2) $ (9.8) $ (10.6)
Pensions Other
Post-retirement
Benefits
2020 2019 2020 2019
(In millions) U.S. Int’l U.S. Int’l
Current portion of accrued pension and other post-retirement benefits (4.6) (8.6) (5.5) (8.8) (0.7) (0.6)
Accrued pension and other post-retirement benefits, net of current portion (196.4) (215.3) (144.2) (214.4) (9.1) (10.0)
Funded status as of December 31 $ (201.0) $ (223.9) $ (149.7) $ (223.2) $ (9.8) $ (10.6)
The following table summarizes the pre-tax amounts in accumulated other comprehensive (income) loss as of December 31, 2020 and 2019 that have not been recognized as components of net periodic benefit cost:
Pensions Other
Post-retirement
Benefits
2020 2019 2020 2019
(In millions) U.S. Int’l U.S. Int’l
Pre-tax amounts recognized in accumulated other comprehensive (income) loss
Unrecognized actuarial loss $ 198.4 $ 122.3 $ 121.6 $ 90.7 $ 1.3 $ 1.9
Unrecognized prior service cost - 6.2 - 7.0 - -
Accumulated other comprehensive (income) loss as of December 31 $ 198.4 $ 128.5 $ 121.6 $ 97.7 $ 1.3 $ 1.9
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, 2020 and 2019:
Pensions Other
Post-retirement
Benefits
2020 2019 2020 2019
(In millions) U.S. Int’l U.S. Int’l
Plans with underfunded or non-funded projected benefit obligation
Aggregate projected benefit obligation $ 684.7 $ 818.7 $ 668.4 $ 741.2 $ 9.8 $ 10.7
Aggregate fair value of plan assets $ 483.7 $ 596.7 $ 518.8 $ 522.8 $ - $ -
Pensions Other
Post-retirement
Benefits
2020 2019 2020 2019
(In millions) U.S. Int’l U.S. Int’l
Plans with underfunded or non-funded accumulated benefit obligation
Aggregate accumulated benefit obligation $ 684.7 $ 325.7 $ 668.4 $ 292.1 $ - $ -
Aggregate fair value of plan assets $ 483.7 $ 154.0 $ 518.8 $ 140.3 $ - $ -
The following table summarizes the components of net periodic benefit cost (income) for the years ended December 31, 2020, 2019 and 2018:
Pensions Other Post-retirement
Benefits
2020 2019 2018 2020 2019 2018
(In millions) U.S. Int’l U.S. Int’l U.S. Int’l
Components of net periodic benefit cost (income)
Service cost $ - $ 19.1 $ - $ 16.3 $ 0.2 $ 21.2 $ - $ - $ -
Interest cost 22.2 14.1 25.6 18.3 23.8 20.9 0.4 0.5 0.4
Expected return on plan assets (45.4) (37.9) (41.6) (33.5) (50.1) (41.2) - - -
Settlement cost 1.4 0.8 - 0.3 0.4 0.4 - - -
Curtailment benefit - - - - - (3.8) - - -
Amortization of net actuarial loss (gain) 6.9 2.1 1.8 0.7 - 0.6 0.1 - -
Amortization of prior service cost (credit) - 1.2 - 1.0 - 1.3 - - -
Net periodic benefit cost (income) $ (14.9) $ (0.6) $ (14.2) $ 3.1 $ (25.7) $ (0.6) $ 0.5 $ 0.5 $ 0.4
The following table summarizes changes in plan assets and benefit obligations recognized in other comprehensive income (loss) for the years ended December 31, 2020, 2019 and 2018:
Pensions Other Post-retirement
Benefits
2020 2019 2018 2020 2019 2018
(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 $ (85.1) $ (27.2) $ (50.2) $ (47.3) $ (73.5) $ (15.3) $ - $ - $ -
Prior service (cost) credit arising during period - (0.1) - (0.9) 0.2 (2.7) - - -
Settlements and curtailments 1.4 0.8 - 0.3 0.4 (3.4) - - -
Amortization of net actuarial loss (gain) 6.9 2.1 1.8 0.7 - 0.6 (0.1) - -
Amortization of prior service cost (credit) - 1.2 - 1.0 - 1.3 - - -
Other - (7.5) - (0.8) - 1.4 (0.6) (0.1) (0.1)
Total recognized in other comprehensive income (loss) $ (76.8) $ (30.7) $ (48.4) $ (47.0) $ (72.9) $ (18.1) $ (0.7) $ (0.1) $ (0.1)
Included in accumulated other comprehensive income (loss) as of December 31, 2020, 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 $ 16.8 $ 4.0 $ -
Prior service cost $ - $ 1.2 $ -
Key assumptions - The following weighted-average assumptions were used to determine the benefit obligations:
Pensions Other
Post-retirement
Benefits
2020 2019 2020 2019
U.S. Int’l U.S. Int’l
Discount rate 2.70 % 1.23 % 3.40 % 1.70 % 3.47 % 4.31 %
Rate of compensation increase N/A 1.92 % N/A 2.39 % 4.00 % 4.00 %
The following weighted-average assumptions were used to determine net periodic benefit cost:
Pensions Other
Post-retirement
Benefits
2020 2019 2018 2020 2019 2018
U.S. Int’l U.S. Int’l U.S. Int’l
Discount rate 3.40 % 1.65 % 4.40 % 2.56 % 3.70 % 2.39 % 4.31 % 5.04 % 4.33 %
Rate of compensation increase N/A 2.33 % N/A 2.34 % N/A 2.39 % 4.00 % 4.00 % 4.00 %
Expected rate of return on plan assets 7.75 % 4.84 % 8.65 % 5.04 % 8.57 % 4.90 % 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, 86% 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, 2020 and 2019.
•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, 2020 and 2019. 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, 2020 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 $ 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 - - - 209.1 209.1 - - -
Registered investment companies 38.4 - - - 38.4 68.2 - - - 68.2
Insurance contracts - - - - - 154.0 - 154.0 - -
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 $ 746.2 $ 411.2 $ 154.0 $ - $ 181.0
December 31, 2019
Cash and cash equivalents $ 50.5 $ 50.5 $ - $ - $ - $ 10.0 $ 10.0 $ - $ - $ -
Equity securities
U.S. companies 110.3 110.3 - - - 70.4 70.4 - - -
International companies 5.4 5.4 - - - 251.5 251.5 - - -
Registered investment companies 36.3 - - - 36.3 63.4 - - - 63.4
Common/collective trusts 12.5 - - - 12.5 - - - - -
Insurance contracts - - - - - 138.5 - 138.5 - -
Hedge funds 164.3 - - - 164.3 82.0 - - - 82.0
Limited partnerships 139.4 - - - 139.4 7.9 - - - 7.9
Real estate and other investments 1.3 1.3 - - - 36.0 36.0 - - -
Total assets $ 520.0 $ 167.5 $ - $ - $ 352.5 $ 659.7 $ 367.9 $ 138.5 $ - $ 153.3
(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 $20.7 million to our international pension plans, representing primarily the Netherlands qualified pension plans and U.K. qualified pension plans. 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 2021. All of the contributions are expected to be in the form of cash. In 2020 and 2019, we contributed $28.7 million and $6.9 million to all pension plans, respectively. Subsequent to the Spin-off, we expect to contribute approximately $18.9 million to our non-U.S. pension plans.
Estimated future benefit payments - The following table summarizes expected benefit payments from our various pension and post-retirement benefit plans through 2028. Actual benefit payments may differ from expected benefit payments.
Pensions Other
Post-retirement
Benefits
(In millions) U.S. International
2021 $ 47.6 $ 36.6 $ 0.6
2022 32.4 30.6 0.6
2023 31.0 32.8 0.6
2024 31.7 34.8 0.6
2025 31.9 34.8 0.6
2025-2029 $ 164.3 $ 198.3 $ 2.6
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, 2020 and 2019, our liability for the Non-Qualified Plan was $22.8 million and $26.3 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, 2020 and 2019, we had investments for the Non-Qualified Plan totaling $22.8 million and $26.3 million at fair market value, respectively.
During the years ended December 31, 2020, and 2019 we recognized expense of $29.9 million and $34.0 million, respectively for matching contributions to these plans in 2020 and 2019, respectively. Additionally, during the years ended December 31, 2020 and 2019, we recognized expense of $12.1 million and $13.2 million, respectively, for non-elective contributions.
NOTE 23. 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 trading purposes where the objective is solely to generate profit.
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, 2020, we held the following material net positions:
Net Notional Amount
Bought (Sold)
(In millions) USD Equivalent
Euro 1,794.5 2,201.8
British pound 771.7 1,054.3
Malaysian ringgit 891.0 221.5
Norwegian krone 1,721.6 201.7
Brazilian real 681.4 131.1
Singapore dollar 171.2 129.4
Mexican peso 1,288.0 64.7
Australian dollar 78.2 60.3
Indian rupee 3,172.0 43.4
Japanese yen 1,124.4 10.9
Columbian peso 37,142.2 10.8
Hong Kong dollar (97.6) (12.6)
Indonesian rupiah (201,679.7) (14.3)
U.S. dollar (2,922.1) (2,922.1)
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, 2020, our portfolio of these instruments included the following material net positions:
Net Notional Amount
Bought (Sold)
(In millions) USD Equivalent
Brazilian real 77.9 15.0
Hong Kong dollar 48.3 6.2
Euro (8.7) (10.7)
Norwegian krone (142.8) (16.7)
U.S. dollar 5.2 5.2
Fair value amounts for all outstanding derivative instruments have been determined using available market information and commonly accepted valuation methodologies. See Note 24 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, 2020 December 31, 2019
(In millions) Assets Liabilities Assets Liabilities
Derivatives designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments $ 215.8 $ 151.6 $ 94.3 $ 125.0
Long-term - Derivative financial instruments 35.6 23.3 34.8 48.0
Total derivatives designated as hedging instruments 251.4 174.9 129.1 173.0
Derivatives not designated as hedging instruments
Foreign exchange contracts
Current - Derivative financial instruments 85.6 15.6 7.6 16.3
Long-term - Derivative financial instruments 0.3 - 0.4 0.4
Total derivatives not designated as hedging instruments 85.9 15.6 8.0 16.7
Long-term - Derivative financial instruments - Synthetic Bonds - Call Option Premium - - 4.3 -
Long-term - Derivative financial instruments - Synthetic Bonds - Embedded Derivatives - - - 4.3
Total derivatives $ 337.3 $ 190.5 $ 141.4 $ 194.0
Cash flow hedges of forecasted transactions, net of tax, which qualify for hedge accounting, resulted in accumulated other comprehensive gains (losses) of $32.5 million and $(5.8) million as of December 31, 2020 and 2019, respectively. We expect to transfer an approximately $107.6 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 2025.
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) 2020 2019 2018
Foreign exchange contracts $ 28.0 $ 10.3 $ (75.4)
The following represents the effect of cash flow hedge accounting on the consolidated statements of income for the year ended December 31, 2020, 2019 and 2018:
Year Ended December 31,
(In millions) 2020 2019 2018
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 Selling,
general
and
administrative
expense Other income (expense), net
Cash Flow hedge gain (loss) recognized in income
Foreign Exchange Contracts
Amounts reclassified from accumulated OCI to income (loss) $ (83.7) $ 68.5 $ (0.4) $ (4.4) $ (26.6) $ 12.0 $ - $ (9.1) $ (2.4) $ 3.4 $ (0.1) $ 1.0
Amounts excluded from effectiveness testing 7.7 (9.8) (0.2) 34.2 0.6 (7.6) - (34.9) (2.2) (4.8) - (12.3)
Total cash flow hedge gain (loss) recognized in income (76.0) 58.7 (0.6) 29.8 (26.0) 4.4 - (44.0) (4.6) (1.4) (0.1) (11.3)
Gain (loss) recognized in income on derivatives not designated as hedging instruments (0.8) 3.4 - 22.7 (1.6) 0.2 - (10.2) (1.7) 0.2 - (11.4)
Total $ (76.8) $ 62.1 $ (0.6) $ 52.5 $ (27.6) $ 4.6 $ - $ (54.2) $ (6.3) $ (1.2) $ (0.1) $ (22.7)
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, 2020 and 2019, we had no collateralized derivative contracts. The following tables present both gross information and net information of recognized derivative instruments:
December 31, 2020 December 31, 2019
(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 $ 337.3 $ (134.0) $ 203.3 $ 141.4 $ (112.5) $ 28.9
Derivative liabilities $ 190.5 $ (134.0) $ 56.5 $ 194.0 $ (112.5) $ 81.5
NOTE 24. FAIR VALUE MEASUREMENTS
Recurring Fair Value Measurements
Assets and liabilities measured at fair value on a recurring basis were as follows:
December 31, 2020 December 31, 2019
(In millions) Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3
Assets
Investments
Equity securities(a)
$ 65.6 $ 65.6 $ - $ - $ 54.8 $ 54.8 $ - $ -
Money market fund 1.7 - 1.7 - 1.5 - 1.5 -
Stable value fund(b)
0.9 - - - 2.1 - - -
Held-to-maturity debt securities 24.2 - 24.2 - 71.9 - 71.9 -
Derivative financial instruments
Synthetic bonds - call option premium - - - - 4.3 - 4.3 -
Foreign exchange contracts 337.3 - 337.3 - 137.1 - 137.1 -
Assets held for sale 47.3 - - 47.3 25.8 - - 25.8
Total assets $ 477.0 $ 65.6 $ 363.2 $ 47.3 $ 297.5 $ 54.8 $ 214.8 $ 25.8
Liabilities
Redeemable financial liability $ 246.6 $ - $ - $ 246.6 $ 268.8 $ - $ - $ 268.8
Derivative financial instruments
Synthetic bonds - embedded derivatives - - - - 4.3 - 4.3 -
Foreign exchange contracts 190.5 - 190.5 - 189.7 - 189.7 -
Liabilities held for sale - - - - 9.3 - - 9.3
Total liabilities $ 437.1 $ - $ 190.5 $ 246.6 $ 472.1 $ - $ 194.0 $ 278.1
(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.
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 and liabilities held for sale - The fair value of our assets and liabilities held for sale was determined using a market approach that took into consideration the expected sales price.
Mandatorily redeemable financial liability - We have a mandatorily redeemable financial liability which is recorded at its fair value. The mandatorily redeemable financial liability relates to our voting control interests in legal Technip Energies contract entities which own and account for the design, engineering and construction of the Yamal LNG plant. The fair value is determined using a discounted cash flow model. The key assumptions used in applying the income approach are the selected discount rates and the expected dividends to be distributed in the future to the non-controlling interest holders. Expected dividends to be distributed are based on the non-controlling interests’ share of the expected profitability of the underlying contract, a 15.0% discount rate and the overall timing of completion of the project.
A mandatorily redeemable financial liability of $246.6 million, $268.8 million and $408.5 million was recognized as of December 31, 2020, 2019 and 2018, respectively, to account for the fair value of the non-controlling interests. During the years ended December 31, 2020, 2019 and 2018, we revalued the liability to reflect current expectations about the obligation, which resulted in the recognition of a loss of $202.0 million, $423.1 million and $322.3 million, respectively.
A decrease of one percentage point in the discount rate would have increased the liability by $2.0 million as of December 31, 2020. The fair value measurement is based upon significant unobservable inputs not observable in the market and is consequently classified as a Level 3 fair value measurement.
Change in the fair value of our Level 3 mandatorily redeemable financial liability is recorded as interest expense on the consolidated statements of income and was as follows:
Year Ended December 31,
(In millions) 2020 2019 2018
Balance at beginning of period $ 268.8 $ 408.5 $ 312.0
Less: Expenses recognized in net interest expense (202.0) (423.1) (322.3)
Less: Settlements 224.2 562.8 225.8
Balance at end of period $ 246.6 $ 268.8 $ 408.5
Redeemable non-controlling interest - We own a 51% share in Island Offshore Subsea AS that was subsequently renamed to TIOS AS. The non-controlling interest is recorded as mezzanine equity at fair value. The fair value measurement is based upon significant unobservable inputs not observable in the market and is consequently classified as a Level 3 fair value measurement. As of December 31, 2020 and 2019, the fair value of our redeemable non-controlling interest was $43.7 million and $41.1 million, respectively. See Note 2 for further details.
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 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 23 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, 2020 and 2019:
Year Ended December 31,
2020 2019
(In millions) Impairment Fair Value (a)
Impairment Fair Value (a)
Long-lived assets $ 204.0 $ 464.7 $ 495.4 $ 342.5 (b)
(a)Measured as of the impairment date using the income approach and a 10.8% risk-adjusted rate of interest, resulting in a Level 3 fair value measurement.
(b)Includes $104.0 million fair value of vessels determined using the transaction price of a similar vessel, resulting in a Level 2 fair value measurement.
Other fair value disclosures
Fair value of debt - The fair value of our Synthetic Bonds, Senior Notes and private placement notes are as follows:
December 31, 2020 December 31, 2019
(In millions) Carrying Amount (a)
Fair Value (b)
Carrying Amount (a)
Fair Value (b)
Synthetic bonds due 2021 $ 551.2 $ 552.0 $ 492.9 $ 513.1
3.45% Senior Notes due 2022 500.0 513.2 500.0 499.2
5.00% Notes due 2020 - - 224.6 230.0
3.40% Notes due 2022 184.0 188.8 168.5 180.6
3.15% Notes due 2023 159.5 163.7 146.0 156.8
3.15% Notes due 2023 153.4 161.8 140.4 150.5
4.50% Notes due 2025 245.4 256.8 - -
4.00% Notes due 2027 92.0 99.7 84.2 96.4
4.00% Notes due 2032 122.7 136.8 112.3 127.8
3.75% Notes due 2033 122.7 126.4 112.3 123.8
(a)Carrying amounts include unamortized debt discounts and premiums and unamortized debt issuance costs of $12.8 million and $9.1 million as of December 31, 2020, and 2019, respectively.
(b)Fair values are based on Level 2 quoted market prices.
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.
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 25. QUARTERLY INFORMATION (UNAUDITED)
2020 2019
(In millions, except per share data) 4th Qtr. 3rd Qtr. 2nd Qtr. 1st Qtr. 4th Qtr. 3rd Qtr. 2nd Qtr. 1st Qtr.
Revenue $ 3,426.1 $ 3,335.7 $ 3,158.5 $ 3,130.3 $ 3,726.8 $ 3,335.1 $ 3,434.2 $ 2,913.0
Cost of sales 2,973.8 2,882.3 2,647.0 2,706.3 3,067.2 2,726.4 2,745.2 2,411.9
Net income (loss) (13.9) 6.4 15.3 (3,245.7) (2,430.3) (115.3) 113.7 19.8
Net income (loss) attributable to TechnipFMC plc $ (39.3) $ (3.9) $ 11.7 $ (3,256.1) $ (2,414.0) $ (119.1) $ 97.0 $ 20.9
Basic earnings (loss) per share (1)
$ (0.09) $ (0.01) $ 0.03 $ (7.28) $ (5.40) $ (0.27) $ 0.22 $ 0.05
Diluted earnings (loss) per share (1)
$ (0.09) $ (0.01) $ 0.03 $ (7.28) $ (5.40) $ (0.27) $ 0.21 $ 0.05
(1) Basic and diluted earnings (loss) per share are computed independently for each of the quarters presented. Therefore, the sum of quarterly basic and diluted per share information may not equal annual basic and diluted earnings (loss) per share.
NOTE 26. SUBSEQUENT EVENT
On February 16, 2021, we completed the Spin-off, see Note 3 for further details. 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.
On February 16, 2021, we entered into a new senior secured revolving credit facility (the “Revolving Credit Facility”) that provides for aggregate revolving capacity of up to $1.0 billion. Availability of borrowings under the Revolving Credit Facility is reduced by any outstanding letters of credit issued against the facility. At February 25, 2021, there were no outstanding letters of credit and availability of borrowings under the Revolving Credit Facility was $800 million.
On January 29, 2021, we issued $1.0 billion of 6.5% senior notes due 2026 (the “2021 Notes”). 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.
The proceeds from the debt issuance described above along with the available cash on hand were used to fund the repayment of all $522.8 million of the outstanding Synthetic Convertible Bonds that matured in January 2021 and the repayment of all $500.0 million aggregate principal amount of outstanding 3.45% Senior Notes due 2022.
In addition, we terminated the $2.5 billion senior unsecured revolving credit facility we entered into on January 17, 2017 and terminated the €500.0 million Euro Facility and CCFF Program we entered into on May 19, 2020. In connection with the termination of these credit facilities, we repaid most of the outstanding commercial paper borrowings, which were $1,525.9 million as December 31, 2020.
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, 2020, 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, 2020, 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, 2020 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, 2020.
The effectiveness of our internal control over financial reporting as of December 31, 2020, 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 year ended December 31, 2020 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
ITEM 9B. OTHER INFORMATION
None.

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ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
A purported shareholder class action filed in 2017 and amended in January 2018 and captioned Prause v. TechnipFMC, et al., No. 4:17-cv-02368 (S.D. Texas) is pending in the U.S. District Court for the Southern District of Texas (“District Court”) against TechnipFMC and certain current and former officers and employees of TechnipFMC. The suit alleged violations of the federal securities laws in connection with the restatement of our first quarter 2017 financial results and a material weakness in our internal control over financial reporting announced on July 24, 2017. On January 18, 2019, the District Court dismissed claims under Section 10(b) and 20(a) of the Securities Exchange Act of 1934, as amended, and Section 15 of the Securities Act of 1933, as amended (“Securities Act”). The shareholder also asserted a claim for alleged violation of Section 11 of the Securities Act in connection with the reporting of certain financial results in our Form S-4 Registration Statement filed in 2016. On December 13, 2020, the parties filed a Stipulation and Agreement of Settlement to settle all claims asserted in the suit with prejudice. The defendants entered into the Stipulation solely to eliminate the burden, expense, uncertainty and risk of further litigation, and denied, and continue to deny, each and all of the claims and contentions alleged by the shareholder plaintiff in this action. On December 16, 2020, the District Court entered an order preliminarily approving the settlement and ordering notice to the settlement class. A settlement hearing is scheduled in the first quarter 2021.
In addition to the above-referenced matter, we are involved in various other 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.

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ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
PART III
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(n) - Election of Directors”, and if applicable, “Delinquent Section 16(a) Reports” in our 2021 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-Governance” and is available in print to shareholders without charge by submitting a request to 11740 Katy Freeway, Energy Tower 3, Houston, Texas 77079, 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 Executive Chairman 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 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 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
James M. Ringler Former non-executive Chairman of the Board of Teradata Corporation, a provider of database software, data warehousing and analytics
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
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” and “Executive Compensation Discussion and Analysis” of our Proxy Statement for the 2021 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 Our Management and Holders of More Than 5% of our Outstanding Ordinary Shares” of our Proxy Statement for the 2021 Annual General Meeting of Shareholders.
As of December 31, 2020, 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 4,598.4 $ 29.77 14,250.2
Equity compensation plans not approved by security holders - - -
Total 4,598.4 $ 29.77 14,250.2
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 2021 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 2021 Annual General Meeting of Shareholders.
PART IV
ITEM 15. EXHIBITS 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
Consolidated Statements of Income for the Years Ended December 31, 2020, 2019 and 2018
Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2020, 2019, and 2018
Consolidated Balance Sheets as of December 31, 2020 and 2019
Consolidated Statements of Cash Flows for the Years Ended December 31, 2020, 2019 and 2018
Consolidated Statements of Changes in Stockholders’ Equity for the Years Ended December 31, 2020, 2019 and 2018
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.
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, 2018
Trade receivables allowance for doubtful accounts $ 117.4 $ 54.7 $ 0.3 $ (52.8) $ 119.6
Valuation allowance for deferred tax assets $ 430.0 $ 213.8 $ (21.3) $ 60.9 $ 683.4
Year Ended December 31, 2019
Trade receivables allowance for doubtful accounts $ 119.6 $ 22.0 $ (2.9) $ (43.3) $ 95.4
Valuation allowance for deferred tax assets $ 683.4 $ 187.0 $ (2.1) $ 48.6 $ 916.9
Year Ended December 31, 2020
Trade receivables allowance for doubtful accounts (c)
$ 95.4 $ 66.8 $ 11.9 $ (65.2) $ 108.9
Valuation allowance for deferred tax assets $ 916.9 $ 94.7 $ (7.3) $ (69.0) $ 935.3
(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 $3.8 million increase to our trade receivables allowance for doubtful accounts. See Note 4 for further details.
See accompanying Report of Independent Registered Public Accounting Firm.
ITEM 16. SUMMARY
None.
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)
2.3 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)
10.1.a* 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)
10.1.b* 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)
10.7* 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)
10.8* 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)
10.9* 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)
10.10* 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)
10.11* 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)
10.12* 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)
10.13* 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)
10.14* 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)
10.15* 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)
10.16* 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)
10.17* 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)
10.18* 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)
10.19* 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)
10.20* 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)
10.21 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)
10.22 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)
10.23* 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)
10.24 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)
10.25* TechnipFMC plc Directors Deferred Compensation Plan
10.26 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)
10.27 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)
10.28 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)
10.29 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)
10.30 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)
10.31 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)
10.32 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)
10.33 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)
10.34 €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)
10.35 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)
10.36 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)
10.37 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)
10.38 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)
10.39 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)
10.40 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)
10.41 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)
10.42 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)
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.
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: March 5, 2021
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.
Date Signature
March 5, 2021 /S/ DOUGLAS J. PFERDEHIRT
Douglas J. Pferdehirt
Chairman and Chief Executive Officer
(Principal Executive Officer)
March 5, 2021 /S/ ALF MELIN
Alf Melin
Executive Vice President and Chief Financial Officer
(Principal Financial Officer)
March 5, 2021 /S/ ELEAZAR DE CARVALHO FILHO
Eleazar de Carvalho Filho,
Director
March 5, 2021 /S/ CLAIRE S. FARLEY
Claire S. Farley,
Director
March 5, 2021 /S/ PETER MELLBYE
Peter Mellbye,
Director
March 5, 2021 /S/ JOHN O’LEARY
John O’Leary,
Director
March 5, 2021 /S/ MARGARETH ØVRUM
Margareth Øvrum,
Director
March 5, 2021 /S/ KAY G. PRIESTLY
Kay G. Priestly,
Director
March 5, 2021 /S/ JAMES M. RINGLER
James M. Ringler,
Director
March 5, 2021 /S/ JOHN YEARWOOD
John Yearwood,
Director

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY

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ITEM 6. SELECTED FINANCIAL DATA

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS

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ITEM 9A. CONTROLS AND PROCEDURES

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ITEM 9B. OTHER INFORMATION

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
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(n) - Election of Directors”, and if applicable, “Delinquent Section 16(a) Reports” in our 2021 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-Governance” and is available in print to shareholders without charge by submitting a request to 11740 Katy Freeway, Energy Tower 3, Houston, Texas 77079, 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 Executive Chairman 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 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 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
James M. Ringler Former non-executive Chairman of the Board of Teradata Corporation, a provider of database software, data warehousing and analytics
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

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ITEM 11. EXECUTIVE COMPENSATION
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” and “Executive Compensation Discussion and Analysis” of our Proxy Statement for the 2021 Annual General Meeting of Shareholders.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
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 Our Management and Holders of More Than 5% of our Outstanding Ordinary Shares” of our Proxy Statement for the 2021 Annual General Meeting of Shareholders.
As of December 31, 2020, 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 4,598.4 $ 29.77 14,250.2
Equity compensation plans not approved by security holders - - -
Total 4,598.4 $ 29.77 14,250.2

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
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 2021 Annual General Meeting of Shareholders.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
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 2021 Annual General Meeting of Shareholders.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS 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
Consolidated Statements of Income for the Years Ended December 31, 2020, 2019 and 2018
Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2020, 2019, and 2018
Consolidated Balance Sheets as of December 31, 2020 and 2019
Consolidated Statements of Cash Flows for the Years Ended December 31, 2020, 2019 and 2018
Consolidated Statements of Changes in Stockholders’ Equity for the Years Ended December 31, 2020, 2019 and 2018
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.
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, 2018
Trade receivables allowance for doubtful accounts $ 117.4 $ 54.7 $ 0.3 $ (52.8) $ 119.6
Valuation allowance for deferred tax assets $ 430.0 $ 213.8 $ (21.3) $ 60.9 $ 683.4
Year Ended December 31, 2019
Trade receivables allowance for doubtful accounts $ 119.6 $ 22.0 $ (2.9) $ (43.3) $ 95.4
Valuation allowance for deferred tax assets $ 683.4 $ 187.0 $ (2.1) $ 48.6 $ 916.9
Year Ended December 31, 2020
Trade receivables allowance for doubtful accounts (c)
$ 95.4 $ 66.8 $ 11.9 $ (65.2) $ 108.9
Valuation allowance for deferred tax assets $ 916.9 $ 94.7 $ (7.3) $ (69.0) $ 935.3
(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 $3.8 million increase to our trade receivables allowance for doubtful accounts. See Note 4 for further details.
See accompanying Report of Independent Registered Public Accounting Firm.