Edgar Filing: FMC TECHNOLOGIES INC

10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

(Mark One)



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

For the fiscal year ended December 31, 2015



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

For the transition period from to

Commission file number 001-16489

FMC TECHNOLOGIES, INC.

(Exact name of registrant as specified in its charter)



Delaware	36-4412642
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

5875 N. Sam Houston Parkway W., Houston, Texas	77086
(Address of principal executive offices)	(Zip Code)

Registrant’s telephone number, including area code: 281/591-4000

Securities registered pursuant to Section 12(b) of the Act:



Title of each class	Name of each exchange on which registered
Common Stock, $0.01 par value	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act: None

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

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

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). YES ý NO ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§232.405 of this chapter) is not contained herein, and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ¨

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

Large accelerated filer ý Accelerated filer ¨ Non-accelerated filer ¨ Smaller reporting company ¨

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

The aggregate market value of the registrant’s common stock held by non-affiliates of the registrant, determined by multiplying the outstanding shares on June 30, 2015, by the closing price on such day of $41.49 as reported on the New York Stock Exchange, was $5,416,567,545.*

The number of shares of the registrant’s common stock, $0.01 par value, outstanding as of February 22, 2016 was 226,906,343.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Registrant’s definitive proxy statement relating to its 2016 annual meeting of stockholder are incorporated by reference into Part III of this Annual Report of Form 10-K where indicated. The 2016 Proxy Statement will be filed with the U.S. Securities and Exchange Commission within 120 days after the end of the fiscal year to which this report relates.



*	Excludes 99,371,968 shares of the registrant’s Common Stock held by directors, officers and holders of more than 5% of the registrant’s Common Stock as of June 30, 2015. Exclusion of shares held by any person should not be construed to indicate that such person or entity possesses the power, direct or indirect, to direct or cause the direction of the management or policies of the registrant, or that such person or entity is controlled by or under common control with the registrant.

TABLE OF CONTENTS



	Page
PART I

Item 1. Business	4
Executive Officers of the Registrant	13
Item 1A. Risk Factors	14
Item 1B. Unresolved Staff Comments	19
Item 2. Properties	20
Item 3. Legal Proceedings	20
Item 4. Mine Safety Disclosures	20

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	21
Item 6. Selected Financial Data	23
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations	24
Item 7A. Quantitative and Qualitative Disclosures About Market Risk	44
Item 8. Financial Statements and Supplementary Data	46
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	94
Item 9A. Controls and Procedures	94
Item 9B. Other Information	94

PART III

Item 10. Directors, Executive Officers and Corporate Governance	95
Item 11. Executive Compensation	95
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	95
Item 13. Certain Relationships and Related Transactions, and Director Independence	96
Item 14. Principal Accounting Fees and Services	96

PART IV

Item 15. Exhibits, Financial Statement Schedules	97
Signatures	99

Cautionary Note Regarding Forward-Looking Statements

This Annual Report on Form 10-K contains “forward-looking statements” intended to qualify for the safe harbors from liability established by the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact contained in this report are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Forward-looking statements usually relate to future events and anticipated revenues, earnings, cash flows or other aspects of our operations or operating results. Forward-looking statements are often identified by the words “believe,” “expect,” “anticipate,” “plan,” “intend,” “foresee,” “should,” “would,” “could,” “may,” “estimate,” “outlook” and similar expressions, including the negative thereof. The absence of these words, however, does not mean that the statements are not forward-looking. These forward-looking statements are based on our current expectations, beliefs and assumptions concerning future developments and business conditions and their potential effect on us. While management believes that these forward-looking statements are reasonable as and when made, there can be no assurance that future developments affecting us will be those that we anticipate.

All of our forward-looking statements involve risks and uncertainties (some of which are significant or beyond our control) and assumptions that could cause actual results to differ materially from our historical experience and our present expectations or projections. Known material factors that could cause our actual results to differ from those in the forward-looking statements are those described in Part I, Item 1A “Risk Factors” of this Annual Report on Form 10-K. We wish to caution you not to place undue reliance on any forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any of our forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise, except to the extent required by law.

PART I

ITEM 1. BUSINESS

OVERVIEW

FMC Technologies, Inc. is a global provider of technology solutions for the energy industry. FMC Technologies, Inc. was incorporated in November 2000 under Delaware law and was a wholly-owned subsidiary of FMC Corporation until our initial public offering in June 2001. Our principal executive offices are located at 5875 North Sam Houston Parkway West, Houston, Texas 77086. As used in this report, except where otherwise stated or indicated by the context, all references to the “Company,” “FMC Technologies,” “we,” “us,” and “our” are to FMC Technologies, Inc. and its consolidated subsidiaries.

We design, manufacture and service technologically sophisticated systems and products, including subsea production and processing systems, surface wellhead production systems, high pressure fluid control equipment, measurement solutions and marine loading systems for the energy industry. We report our results of operations in the following reporting segments: Subsea Technologies, Surface Technologies and Energy Infrastructure. Financial information about our business segments is incorporated herein by reference from Note 20 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

During 2012, we acquired the remaining 55% of Schilling Robotics, LLC (“Schilling Robotics”), 100% of Pure Energy Services Ltd. (“Pure Energy”) and 100% of Control Systems International, Inc. (“CSI”). Schilling Robotics is a supplier of advanced robotic intervention products, including a line of remotely operating vehicle systems (“ROV”), manipulator systems and subsea control systems and is included in our Subsea Technologies segment. Prior to 2012 we owned 45% of Schilling Robotics. The acquisition of the remaining 55% has enabled us to grow in the subsea market environment, where demand for ROVs and the need for maintenance activities of subsea equipment exists. Additionally, we acquired Pure Energy, a provider of flowback services and wireline services. The acquisition of Pure Energy complements the existing products and services of our Surface Technologies segment and creates client value by providing an integrated well site solution. Finally, we acquired CSI, a provider of automation, control and information technology to the oil and gas industry. Included in our Energy Infrastructure segment, CSI enhances our automation and controls technologies and benefits technologies to support our long-term strategy to expand our subsea production and processing systems.

Also in 2012, we formed FMC Technologies Offshore, LLC (“FTO Services”), a 50/50 joint venture with Edison Chouest Offshore LLC. Utilizing the subsea technologies, tooling and expertise of FMC Technologies, and the vessel, port logistics and ROV operations of Edison Chouest Offshore, the joint venture was formed to provide integrated vessel-based subsea services for offshore oil and gas fields around the world. The objective of the joint venture is to provide cost-effective solutions to enhance our customers’ ability to initiate, maintain and increase production from subsea field developments. Additional information regarding this joint venture is incorporated herein by reference from Note 7 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

During 2014, we completed the sale of our equity interests and assets primarily representing a product line of our material handling business to Syntron Material Handling, LLC, an affiliate of Levine Leichtman Capital Partners Private Capital Solutions II, L.P. Additional financial information is incorporated herein by reference from Note 5 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

During 2015, we signed an agreement with Technip S.A. (“Technip”) to form Forsys Subsea Limited (“Forsys Subsea”), a 50/50 joint venture. Forsys Subsea brings the proprietary technologies of FMC Technologies and Technip together to offer front-end engineering and design services aimed to identify opportunities through new technologies, services, and standardization of equipment to significantly reduce the cost of subsea field development and provide the technology to maximize well performance over the life of the field. In conjunction with the formation of Forsys Subsea, the agreement also formed an alliance with Technip that enables us to create the framework to deliver and install seabed and/or topside subsea infrastructure resulting from designs produced by Forsys Subsea. Additional financial information is incorporated herein by reference from Note 7 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

Also in 2015, we largely completed integration efforts in our Surface Technologies segment. These integration efforts, primarily in North America, bring together the services acquired from Pure Energy and our surface wellhead business to create an integrated shale offering. The integration efforts have the strategic aim (i) to improve our customers’ returns by offering integrated solutions involving multiple surface products and services, (ii) to enable execution excellence through specialization and focus, (iii) to improve scalability and (iv) to increase market share in the North American shale market. Our integration efforts of our Surface Technologies products and services resulted in Surface Technologies now being organized and operated under the three businesses of surface integrated services, surface wellhead international, and fluid control.

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, are available free of charge through our website at www.fmctechnologies.com, under “Investors—Financial Information—SEC Filings” as soon as reasonably practicable after such material is electronically filed with, or furnished to, the 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.

BUSINESS SEGMENTS

Subsea Technologies

Subsea Technologies designs and manufactures products and systems and provides services used by oil and gas companies involved in deepwater exploration and production of crude oil and natural gas. The core competencies of this segment are our

technology and engineering expertise. Our systems control the flow of crude oil and natural gas from producing wells. We specialize in offshore production systems and have manufacturing facilities near the world’s principal offshore oil and gas producing basins. We primarily market our products through our own technical sales organization.

Principal Products and Services

Subsea 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.

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 that deepwater environments present, as well as internal pressures of up to 15,000 pounds per square inch (“psi”) and temperatures in excess of 350º F. The development of our integrated subsea production systems includes initial engineering design studies and field development planning to consider all relevant aspects and project requirements including optimization of drilling programs and subsea architecture. Our subsea production systems and products include drilling systems, subsea trees, chokes and flow modules, manifold pipeline systems, control and data management systems, well access systems and other technologies. Additionally, as part of our technologies to enhance field economics by maximizing recovery, our subsea processing systems can enable cost-effective, platform-less solutions where the field is tied directly back to an existing offshore facility or directly to shore. Subsea processing system solutions include subsea boosting, subsea gas compression and subsea separation which are designed to accelerate production, increase recovery or extend field life. In order to provide these products, systems and services, we utilize engineering, project management, procurement, manufacturing, assembly and testing capabilities.

We also provide an array of subsea services aimed to improve uptime, lower lifecycle costs and increase recovery over the life of the field. These services include (i) installation services to plan and direct the technical onshore and offshore activities, resources and operations required in an installation, (ii) asset management services such as tool management, equipment refurbishment, condition and performance monitoring, processing equipment-related maintenance and rental tools, (iii) product optimization using a suite of services including flow assurance services, real-time surveillance, predictive analytics and flow modeling software, (iv) inspection, maintenance and repair of control and instrumentation modules, chokes, flow modules, and processing equipment, and (v) well access and intervention services including exploration wellheads, production and completion related services, rig-based intervention, riserless light well intervention through our FTO Services joint venture, tree commissioning, through tubing rotary drilling and plug and abandonment. Additionally, Forsys Subsea, our joint venture with Technip, offers front-end engineering and design to identify opportunities through new technologies, services, and standardization of equipment to significantly reduce the cost of subsea field development and provide the technology to maximize well performance over the life of the field.

Subsea systems represented approximately 69%, 63% and 63% of our consolidated revenue in 2015, 2014 and 2013, respectively.

Schilling Robotics. We design and manufacture ROVs and manipulator arms and provide support services for subsea control systems for subsea exploration and production. Our product offering includes electric and hydraulic work-class ROVs, tether-management systems, launch and recovery systems, remote manipulator arms and modular control systems for wide-ranging subsea applications. We also provide support and services such as product training, pilot simulator training, spare parts, and technical assistance.

Multi Phase Meters. We design and manufacture multiphase and wetgas meters to measure production rates of oil, water and gas for both topside and subsea applications. These meters have diverse applications that include production testing of well fluid rates, reservoir monitoring, measurement of fluid rates for production and revenue sharing between partners, and artificial lift optimization. The Multi Phase Meters product line augments our portfolio of technologies for increasing oil and gas recovery, early water detection, accurate fiscal allocation and reservoir optimization.

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 prior to installation. We often receive advance payments and progress billings from our customers in order to fund initial development and our working capital requirements. However, our working capital balances can vary significantly depending on the payment terms and execution timing on key contracts.

Dependence on Key Customers

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

We actively pursue alliances with oil and gas companies that are engaged in the subsea development of crude oil and natural gas to promote our integrated systems for subsea production. Development of subsea fields, particularly in deepwater environments, involves substantial capital investments by our customers. Our customers have 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 our 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. Examples of customers we have entered alliances with include Statoil, Shell, BP and Anadarko.

Petrobras is a key customer for the Subsea Technologies segment. Given the current recessionary economy in Brazil and the low crude oil price environment, our operational performance may be negatively affected by any significant changes in Petrobras’ operations, such as further decreases in their capital spending plans. As part of enhancing our customer relationship, we are working with Petrobras to delay certain deliveries of product which may affect the timing of our results of operations or cash flows.

The loss of one or more of our significant customers could have a material adverse effect on our Subsea Technologies segment. No single Subsea Technologies customer accounted for 10% or more of our 2015 consolidated revenue.

Competition

Subsea Technologies competes with companies that supply subsea systems and with other smaller companies that are focused on a specific application, technology or geographical niche in which we operate. Companies including OneSubsea (a Cameron and Schlumberger company), GE Oil & Gas (a division of General Electric Company), Aker Solutions ASA and Dril-Quip, Inc. compete with us in the marketplace across our various Subsea Technologies product and services.

Competitive factors in our industry include price, the quality of both product technology and service, and on-time delivery. Our competitive strengths include our intellectual capital, the reliability of our products, the breadth of technologies embedded in our products and services that enable us to design unique solutions for our customers’ project requirements while incorporating standardized components to contain costs and our worldwide presence and reputation in each of the major producing basins around the world. Our strong customer relationships, experience and technology help us maintain a leadership position in the subsea systems market.

Seasonality

In the North Sea, winter weather generally subdues drilling activity and demand for subsea services as certain activities cannot be performed. As a result, the level of offshore activity in our subsea services is negatively influenced and tends to decrease in the first quarter of each year.

Surface Technologies

Surface Technologies designs and manufactures products and systems and provides services used by oil and gas companies involved in land and offshore exploration and production of crude oil and natural gas. We design, manufacture and supply technologically advanced wellhead systems and high pressure valves and pumps used in stimulation activities for oilfield service companies and provide flowback and wireline services for exploration and production companies in the oil and gas industry.

Principal Products and Services

Surface Integrated Services and Surface Wellhead International. We provide a full range of drilling, completion and production wellhead systems for both standard and custom-engineered applications. Surface wellhead production systems, or trees, are used to control and regulate the flow of crude oil and natural gas from the well. Our surface wellhead products and systems are used worldwide on both onshore and offshore applications and can be used in difficult climates, including arctic cold or desert high temperatures. Our product technologies include conventional wellheads, unihead drill-thru wellheads designed for faster surface installations, drilling time optimization (“DTO”) timesaving conventional wellheads designed to reduce overall rig time and other technologies including sealing technology, thermal equipment, and valves and actuators. We support our customers through comprehensive surface wellhead system service packages that provide strategic solutions to ensure optimal equipment performance and reliability and include all phases of the asset’s life cycle, from the early planning stages through testing and installation, commissioning and operations, replacement and upgrades, interventions, decommissioning/abandonment, and maintenance, storage and preservations.

As part of our surface integrated services business, we provide an integrated shale offering which includes manifolds and trees and flowback equipment for timely and cost-effective well completion. Acquired in October 2012 and formerly known as Pure Energy Services Ltd., we also provide flowback services for the recovery of solids, fluids, and hydrocarbons from oil and natural gas wells after the stimulation of the well, cased hole electric wireline and slickline services, specialty logging services, and well optimization services for exploration companies in the oil and gas industry.

Fluid Control. 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, such as Schlumberger Limited, Baker Hughes Incorporated, Halliburton Company and Weatherford International plc. Our flowline products are used in equipment that pumps fluid into a well during the well construction and stimulation processes. Our well service pump product line includes Triplex and Quintuplex pumps utilized in a variety of applications including fracturing, acidizing and matrix stimulation and are capable of delivering flow rates up to 35 barrels per minute at pressures up to 20,000 psi. The performance of this business typically rises and falls with variations in the active rig count throughout the world and pressure pumping activity in the Americas.

Capital Intensity

Surface Technologies manufactures most of its products, resulting in a reliance on manufacturing locations throughout the world. We also maintain a large amount of rental equipment related to pressure pumping operations.

Dependence on Key Customers

No single Surface Technologies customer accounted for 10% or more of our 2015 consolidated revenue.

Competition

Surface Technologies is a market leader for its primary products and services. Some of the competitive factors include technological innovation, reliability and product quality. Surface Technologies competes with other companies that supply surface production equipment and pressure pumping products. Some of our major competitors include Cameron International Corporation, Weir Oil & Gas (a division of The Weir Group PLC), GE Oil & Gas (a division of General Electric Company) and Gardner Denver, Inc.

Seasonality

In western Canada, the level of activity in the oilfield services industry is influenced by seasonal weather patterns. During the spring months, wet weather and the spring thaw make the ground unstable and less capable of supporting heavy equipment and machinery. As a result, municipalities and provincial transportation departments enforce road bans that restrict the movement of heavy equipment during the spring months, which reduces activity levels. There is greater demand for oilfield services, specifically completion services, provided by our Canadian surface integrated services business in the winter season when freezing permits the movement and operation of heavy equipment. Activities tend to increase in the fall and peak in the winter months of November through March.

Energy Infrastructure

Principal Products and Services

Measurement Solutions. We design, manufacture and service measurement products for the worldwide 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 floating production, storage and off-loading metering systems provide the precision and reliability required for measuring large flow rates characteristic of marine loading operations. Our gas and liquid measurement systems provide many solutions in energy-related applications such as 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 to ensure processes operate efficiently while reducing operating costs and minimizing the risk associated with custody transfer. As part of our liquid measurement system offering, we also provide design, engineering, project management, training, commissioning and aftermarket services in connection with the applications of blending and transfer technology solutions and process automation systems for manufacturers in the lubricant, petroleum, fuel blending, and additive and chemical industries.

We also provide automation and control technology for the oil and gas, chemical and other industries. Acquired in April 2012 and formerly known as Control Systems International, Inc., our automation and control technology supplies innovative control and automation system solutions. One of the primary products, UCOS^®, is a comprehensive software solution that combines distributed control system and supervisory control and data acquisition system retrofits using software solutions and compression control algorithms which allows customers to control and manage the engineering, design and monitoring of their systems of operations.

Loading Systems. We provide land- and marine-based loading and transfer systems to the oil and gas, petrochemical and chemical industries. Our systems provide transfer loading solutions using Chiksan^® loading arms and Chiksan^® swivel joint technologies capable of diverse applications. While our marine systems are typically constructed on a fixed jetty platform, we have developed advanced loading systems that can be mounted on a vessel or structure to facilitate ship-to-ship and tandem loading and offloading operations in open seas or exposed locations. Both our land- and marine-based loading and transfer systems are capable of handling a wide range of products including petroleum products, liquefied natural gas (“LNG”) and chemical products.

Separation Systems. We design and manufacture systems that separate production flows from wells into oil, gas, sand and water. Our separation technology can be applied to both greenfield development as well as retrofit solutions for fields currently in production. Also, these systems provide solutions for both subsea and topside applications. For subsea applications, these systems can be designed with primary separation at the seabed which enables more effective production, increased field recovery and the reduced need for topside processing capacity for our customers.

Dependence on Key Customers

No single Energy Infrastructure customer accounted for 10% or more of our 2015 consolidated revenue.

OTHER BUSINESS INFORMATION RELEVANT TO OUR BUSINESS SEGMENTS

Product Development

We invest in product development to advance technologies necessary to support the current and future technical challenges of our customers. We seek to develop products and services aimed to assist our customers to lower capital and operating expenditures, increase oil recovery and deliver improved performance of their assets. We also strive to increase standardization within our product lines in order to reduce delivery times, improve product integrity and control costs. To satisfy all these aims, our investments in product development are focused on (i) progressing capabilities to bring products to market faster and more efficiently, (ii) developing the next generation of cost-effective production and processing equipment, (iii) advancing core enabling technologies and materials and (iv) expanding product families to address broader market applications.

To accelerate the commercialization of technologies in all of our businesses, we made several investments to enhance our research and development capabilities. First, we expanded our network of rapid prototyping centers, increasing the resources available for our engineers to design and build new products. Second, we upgraded and expanded our capabilities to conduct qualification testing. These investments included the addition of test cells, flow loops, bending fixtures and test pits along with advanced instrumentation to better facilitate monitoring of test programs. Our investments added capacity and provided new functionality to accommodate a broader range of test parameters including high pressure, high temperature (“HPHT”) conditions.

Subsea Technologies. We continue to expand our subsea technologies portfolio of solutions in order to deliver a complete production system for HPHT applications. In 2014, we entered into a joint development agreement with several major operators to develop common standards for subsea production equipment capable of operating at pressures as high as 20,000 psi and temperatures up to 350º F. In 2015, we added another major operator to this joint agreement. We believe standardization of our products is an important element in improving execution, optimizing resources, lowering lifecycle costs and providing superior long-term value. This joint development agreement is expected to result in standardized design, materials, processes and interfaces to deliver improved reliability and operability over the life of the field. During 2015, we completed major qualification testing meeting the latest industry guidelines.

The downturn in the energy market has shifted the needs of our customers. As a result, we have also invested in subsea product development focused on developing lower cost solutions. Technology development progressed on the next generation of subsea equipment utilizing designs that will be significantly smaller and lighter than current designs. In addition to the investments to develop lower cost production solutions, we continued efforts on our portfolio of product technology and services aimed to help operators maximize recovery from existing subsea fields. Along with our development partner Sulzer Pumps Ltd., we expanded the product family of pumps and motors to include more sizes and pressure ratings. Additionally, development of our well access management system was completed in 2015, and the system was successfully employed in the North Sea. This combined subsea product and service solution provided real-time data to the operator to enable the assessment of actual loading on a subsea completion riser during operations, leading to reduced operational and maintenance costs and increased oil recovery.

Surface Technologies. Development work focused on enhancing several core enabling technologies including seals, valves and instrumentation. During 2015, we completed development on a steam valve for high temperature service. The valve was successfully qualified and installed on an onshore field in North America. Additionally, we completed development on the next generation of sealing technology featuring a dual metal packoff. Developed in collaboration with one of our key customers, the new design of the sealing technology eliminates elastomers and improves seal performance. Other investments in our surface technologies portfolio included the development and testing of sensing and instrumentation technologies and of technologies for the treatment of well fluids.

Energy Infrastructure. Our measurement solutions business completed development of AccuLoad IV, the newest generation electronic preset system. This new generation includes important upgrades and enhancements such as improved diagnostics that will ensure AccuLoad^® remains a widely used preset in oil custody transfer. Our loading systems business completed extended fatigue and operating simulation testing on ATOL, our tandem offshore loading solution.

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.

Sources and Availability of Raw Materials

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

Research and Development

We are engaged in research and development (“R&D”) activities directed toward the improvement of existing products and services, the design of specialized products to meet customer needs and the development of new products, processes and services. A large part of our product development spending has focused on the improved design and standardization of our Subsea Technologies products to meet our customer needs. Financial information about R&D activities is incorporated herein by reference from Note 20 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

Patents, Trademarks and Other Intellectual Property

We own a number of U.S. and foreign patents, trademarks and licenses that are cumulatively important to our businesses. As part of our ongoing research and development, we seek patents when appropriate for new products and product improvements. We have approximately 1,530 issued patents and pending patent applications worldwide. Further, we license intellectual property rights to or from third parties. We also own numerous U.S. and foreign trademarks and trade names and have approximately 155 registrations and pending applications in the United States and abroad.

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.

Employees

As of December 31, 2015, we had approximately 17,400 full-time employees, consisting of approximately 5,700 in the United States and 11,700 in non-U.S. locations. Less than 2% of our U.S. employees are represented by labor unions.

The Iran Threat Reduction and Syria Human Rights Act of 2012

The Iran Threat Reduction and Syria Human Rights Act of 2012 amended Section 13 of the Exchange Act and requires disclosure when a company knowingly engages in specified prohibited activities involving Iran. We had no such activities to report during the year ended December 31, 2015.

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 segments’ revenue is dependent upon worldwide oil and gas exploration and production activity. Financial information about our segments and geographic areas is incorporated herein by reference from Note 20 to our consolidated financial statements in Part II, Item 8 of this Annual Report on Form 10-K.

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.

As of February 24, 2016, the executive officers of FMC Technologies, together with the offices held by them, their business experience and their ages, are as follows:



Name	Age	Current Position and Business Experience
John T. Gremp	64	Chairman and Chief Executive Officer (2015) Chairman, President and Chief Executive Officer (2013) Chairman and Chief Executive Officer (2012) Chairman, President and Chief Executive Officer (2011)
Maryann T. Mannen	53	Executive Vice President and Chief Financial Officer (2014) Senior Vice President and Chief Financial Officer (2011)
Richard G. Alabaster	55	Vice President—Surface Technologies (2015) General Manager—Surface Integrated Services (2013) General Manager—Fluid Control (2010)
Bradley D. Beitler	62	Vice President—Technology (2009)
Sanjay Bhatia	46	Vice President—Corporate Development (2012) Director of Business Development (2007)
Barry Glickman	47	Vice President—Subsea Services (2015) General Manager—Subsea Systems Western Region (2012) Vice President—Energy Infrastructure (2011) Integration Leader for GE Oil & Gas/Wood Group (2011)
Tore Halvorsen	61	Senior Vice President—Subsea Technologies (2011)
Jay A. Nutt	52	Vice President—Controller and Treasurer (2015) Vice President and Controller (2009)
Douglas J. Pferdehirt	52	President and Chief Operating Officer (2015) Executive Vice President and Chief Operating Officer (2012) Executive Vice President—Corporate Development & Communication for Schlumberger Limited (2011)
Dianne B. Ralston	49	Senior Vice President, General Counsel, and Secretary (2015) Executive Vice President, General Counsel, and Secretary for Weatherford International plc (2014) Deputy General Counsel—Corporate for Schlumberger Limited (2012) Deputy General Counsel— Government Affairs, Litigation, and IP Enforcement for Schlumberger Limited (2010)
Mark J. Scott	62	Vice President—Administration (2010)

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 ten 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 elected by the Board of Directors to hold office until their successors are elected and qualified.

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.

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 the level of exploration, development and production activity of, and the corresponding capital spending by, oil and natural gas companies. 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 exploitation of existing wells, which could adversely affect demand for our products and services and, in certain instances, result in the cancellation, modification or rescheduling 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.

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;


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


•	political and economic uncertainty and sociopolitical unrest;


•	available excess production capacity within the Organization of Petroleum Exporting Countries (“OPEC”) and the level of oil production by non-OPEC countries;


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


•	technological advances affecting energy consumption;


•	potential acceleration of the development of alternative fuels;


•	access to capital and credit markets, which may affect our customers’ activity levels and spending for our products and services; 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 current downturn in the oil and gas industry has resulted in a reduction in demand for oilfield services and could further adversely affect our financial condition, results of operations or cash flows.

The industries in which we operate or have operated expose us to potential liabilities arising out of the installation or use of our products that could adversely affect our financial condition.

We are subject to potential liabilities arising from equipment malfunctions and failures, particularly due to high temperature and pressure environments, equipment misuse and natural disasters, the occurrence of which may result in uncontrollable flows of gas or well fluids, fires and explosions. Although we have obtained insurance against many of these risks, our insurance 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 are 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 U.S. and international regulations, violations of which could have a material adverse effect on our financial condition, results of operations or cash flows.

We are exposed to a variety of federal, state, local and international laws and regulations relating to matters such as environmental, health and safety, labor and employment, import/export control, 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 operations outside of the United States require us to comply with numerous anti-bribery and anti-corruption regulations under the laws of the United States and various other countries. The U.S. Foreign Corrupt Practices Act (“FCPA”), the United Kingdom (“U.K.”) Bribery Act and the Brazilian Anti-Bribery Act (also known as the Brazilian Clean Company Act), among others, apply to us and our operations. We have internal control policies and procedures and have implemented training and compliance programs for our employees and agents with respect to these regulations. However, our policies, procedures and programs may not always protect us from reckless or criminal acts committed by our employees or agents, and severe criminal or civil sanctions may be imposed as a result of violations of these laws. We are also subject to the risks that our employees, joint venture partners and agents outside of the United States may fail to comply with applicable laws.

Moreover, we import raw materials, semi-finished goods, as well as finished products into many countries for use in such countries or for manufacturing and/or finishing for re-export and import into another country for use or further integration into equipment or systems. Most movement of raw materials, semi-finished or finished products involves imports and exports. As a result, compliance with multiple trade sanctions, embargoes and import/export laws and regulations, as well as the recently enacted conflict minerals reporting requirements, pose a constant challenge and risk to us since our business is conducted on a worldwide basis through various subsidiaries. Our failure to comply with these laws and regulations could materially affect our reputation, financial condition and results of operations.

Compliance with environmental laws and regulations may adversely affect our business and results of operations.

Environmental laws and regulations in the United States and foreign countries affect the equipment, systems and services we design, market and sell, as well as the facilities where we manufacture our equipment and systems. 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, or the issuance of orders enjoining operations. These laws and regulations, as well as the adoption of new legal requirements or other laws and regulations affecting exploration and development of drilling for crude oil and natural gas, could adversely affect our business and operating results by increasing our costs, limiting the demand for our products and services or restricting our operations.

International, national and state governments and agencies are currently evaluating and/or promulgating legislation and regulations that are focused on restricting emissions commonly referred to as greenhouse gas (“GHG”) emissions. For instance, under the U.S. Clean Air Act, the U.S. Environmental Protection Agency (“EPA”) has made findings that GHG emissions endanger public health and the environment, resulting in the EPA’s adoption of regulations requiring construction and operating permit reviews of certain stationary sources with major emissions of GHGs, which reviews require the installation of new GHG emission control technologies. The EPA has also promulgated rules requiring the monitoring and annual reporting of GHG emissions from certain sources, including onshore and offshore oil and natural gas production facilities and onshore oil and natural gas processing, transmission, storage and distribution facilities. In addition, in August 2015, the EPA announced proposed rules that would establish new air emission controls for methane emissions from certain new, modified or reconstructed equipment and processes in the oil and natural gas source category, including production, processing, transmission and storage activities, as part of an overall effort to reduce methane emissions by up to 45 percent by 2025. To the extent our customers are subject to these or other similar proposed or newly enacted laws and regulations, the additional costs incurred by our customers to comply with such laws and regulations could impact their ability or desire to continue to operate at current or anticipated levels, which would negatively impact their demand for our products and services. In addition, any new laws or regulations establishing cap-and-trade or that favor the increased use of non-fossil fuels may dampen demand for oil and gas production and lead to lower spending by our customers for our products and services. Similarly, to the extent we are or become subject to any of these or other similar proposed or newly enacted laws and regulations, we expect that our efforts to monitor, report and comply with such laws and regulations, and any related taxes imposed on companies by such programs, will increase our cost of doing business and may have a material adverse effect on our financial condition and results of operation.

Moreover, environmental concerns have been raised regarding the potential impact of hydraulic fracturing on underground water supplies. Although we do not perform hydraulic fracturing, we do provide equipment and services to companies employing this enhanced recovery technique. There have been several regulatory and governmental initiatives in the United States to restrict the hydraulic fracturing process, which could have an adverse impact on our customers’ completion or production activities. For example, the EPA has issued final regulations under the U.S. Clean Air Act governing performance standards, including standards for the capture of air emissions released during hydraulic fracturing and proposed in April 2015 the prohibition of the discharge of wastewater from hydraulic fracturing operations to publicly owned wastewater treatment plants. Also, the U.S. Bureau of Land Management finalized rules in March 2015 that impose new or more stringent standards for performing hydraulic fracturing on federal and American Indian lands. The U.S. District Court of Wyoming has temporarily stayed implementation of this rule, and a final decision has not yet been issued. These and other similar state and foreign regulatory initiatives, if adopted, would establish additional levels of regulation for our customers that could make it more difficult for our customers to complete natural gas and oil wells and could adversely affect the demand for our equipment and services, which, in turn, could adversely affect 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 manufacturing facilities in the United States and 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 such as North Africa, West Africa, the Middle East and the Commonwealth of Independent States, could have an adverse effect on the demand for our products and services, 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, terrorist attacks, cyber-terrorism, military activity and wars;


•	supply disruptions in key oil producing countries;


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


•	trade restrictions, trade protection measures or price controls;


•	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;


•	changes in, and the administration of, laws and regulations;


•	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.

Because a significant portion of our revenue is denominated in foreign currencies, 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 located outside of the United States and the amount of our stockholders’ equity. Although it is our policy to seek to minimize our currency exposure by engaging in hedging transactions where appropriate, our efforts may not be successful. Moreover, certain currencies, specifically currencies in countries such as Angola and Nigeria where we have sizable operations, do not actively trade in the global foreign exchange markets and may subject us to increased foreign currency exposures. Refer to “Quantitative and Qualitative Disclosures about Market Risk” in Part II, Item 7A of this Annual Report on Form 10-K for additional discussion of foreign currency rate risk. To the extent we sell our products and services in foreign markets, currency fluctuations may result in our products and services becoming too expensive for foreign customers. As a result, fluctuations in foreign currency exchange rates may affect our financial position or results of operations.

We may lose money on fixed-price contracts.

As customary for the types of businesses in which we operate, we often agree to provide products and services under fixed-price contracts. Under these contracts, we are typically responsible for cost overruns. Our actual costs and any gross profit realized on these fixed-price contracts may vary from the estimated amounts on which these contracts were originally based. There is inherent risk in the estimation process, including significant unforeseen technical and logistical challenges or longer than expected lead times. A fixed-price contract may prohibit our ability to mitigate the impact of unanticipated increases in raw material prices through increased pricing. Depending on the size of a project, variations from estimated contract performance could have a significant impact on our financial condition, results of operations or cash flows.

Disruptions in the timely delivery of our backlog could affect our future sales, profitability, and our 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 on 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, particularly in light of the current industry environment where customers may seek to improve their returns or cash flows.

Due to the types of contracts we enter into, the cumulative loss of several major contracts 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. If we were to lose several key alliances or agreements over a relatively short period of time we could experience a significant adverse impact on our financial condition, results of operations or cash flows.

Increased costs of raw materials and other components may result in increased operating expenses and adversely affect our results of operations or cash flows.

Our results of operations may be adversely affected by our inability to manage the rising costs and availability of raw materials and components used in our wide variety of products and systems. Unexpected changes in the size and timing of regional and/or product markets, particularly for short lead-time products, could affect our results of operations or cash flows.

In accordance with Section 1502 of the Dodd-Frank Wall Street Reform and Consumer Protection Act, the SEC’s rules regarding mandatory disclosure and reporting requirements by public companies of their use of “conflict minerals” (tantalum, tin, tungsten and gold) originating in the Democratic Republic of Congo and adjoining countries became effective in 2014. While the conflict minerals rule continues in effect as adopted, there remains uncertainty regarding how the conflict minerals rule, and our compliance obligations, will be affected in the future. Additional requirements under the rule could affect sourcing at competitive prices and availability in sufficient quantities of certain of the conflict minerals used in the manufacture of our products or in the provision of our services, which could have a material adverse effect on our ability to purchase these products in the future. The costs of compliance, including those related to supply chain research, the limited number of suppliers and possible changes in the sourcing of these minerals, could have a material adverse effect on our results of operations or cash flows.

A failure of our information technology infrastructure could adversely impact our business and results of operations.

The efficient operation of our business is dependent on our information technology (“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 our changing needs. Despite our implementation of security measures, our systems are vulnerable to damages from computer viruses, natural disasters, incursions by intruders or hackers, failures in hardware or software, power fluctuations, cyber terrorists and other similar disruptions. Additionally, we rely on third parties to support the operation of our IT hardware and software infrastructure, and in certain instances, utilize web-based applications. Although no such material incidents have occurred to date, 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, reputational harm, 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 damage caused by these disruptions or security breaches in the future.

Our success depends on our ability to implement new technologies and services.

Our success depends on the ongoing development and implementation of new product designs and improvements and on our ability to protect and maintain critical intellectual property assets related to these developments. If we are not able to obtain patent or other protection of our technology, we may not be able to continue to develop systems, services and technologies to meet evolving industry requirements, and if so, at prices acceptable to our customers.

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, to the extent deemed prudent by our management and to the extent insurance is available. However, no assurance can be given that the nature and amount of that insurance will be sufficient to fully indemnify us against liabilities arising out of pending and future claims and litigation. 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. Royalty payments under licenses from third parties, if available, would increase our costs. If a license were not available, 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. Additionally, developing non-infringing technologies would increase our costs.

A deterioration in future expected profitability or cash flows could result in an impairment of our recorded goodwill.

Goodwill is tested for impairment on an annual basis, or more frequently when impairment indicators arise. 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 changes in customer demand, cost increases, regulatory or political environment changes, and other changes in market conditions, such as decreased prices in similar market-based transactions, which could impact future earnings of the reporting unit.

At December 31, 2015, recorded goodwill of $63.7 million was associated with our U.S. surface integrated services reporting unit. The decline in crude oil prices that began in 2014 and continued throughout 2015 has introduced uncertainty associated with certain key assumptions used in estimating fair value of the reporting unit. Depressed crude oil and natural gas prices for a prolonged period of time may adversely affect the economics of our customers’ projects, particularly shale-related projects in North America, which may lead to the reduction in demand for our products and services, negatively impacting the financial results of the reporting unit. Our estimate of fair value for the U.S. surface integrated services reporting unit relies on third party forecasts of the number of hydraulic fracturing stages expected to be completed as well as the expected recovery of the overall North American oil and gas market. Management is monitoring the overall market, specifically crude oil and natural gas prices, and its effect on the estimates and assumptions used in our goodwill impairment test for U.S. surface integrated services, which may require re-evaluation and could result in an impairment of goodwill for this reporting unit.

At December 31, 2015, recorded goodwill of $54.7 million was associated with our separation systems reporting unit. The decline in crude oil prices and its related effect on customer capital spending has led to negative margins for separation systems in 2015. Our estimate of fair value for the separation systems reporting unit relies on assumptions of lower oil and gas activity over the next few years with expected market recovery in 2019 for this business. To mitigate the impact of lower commodity prices, management is expanding the reporting unit’s existing product offering in both greenfield and brownfield applications by introducing differentiating technology and expanding the system and solutions business as a growth platform. Management is monitoring the overall market, specifically crude oil prices and changes in customer capital spending, and its effect on the estimates and assumptions used in our goodwill impairment test for separation systems, which may require re-evaluation and could result in an impairment of goodwill for this reporting unit.

Refer to “Critical Accounting Estimates” in Part II, Item 7 of this Annual Report on Form 10-K for additional discussion regarding estimates and assumptions surrounding goodwill.

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

The terms of our financing are, in part, dependent on the credit ratings assigned to our debt by independent credit rating agencies. We cannot provide assurance that any of our current credit ratings will remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a rating agency. Factors that may impact our credit ratings include debt levels, capital structure, planned asset purchases or sales, near- and long-term production growth opportunities, market position, liquidity, asset quality, cost structure, product mix, customer and geographic diversification and commodity price levels. A downgrade in our credit ratings, particularly to non-investment grade levels, could limit our ability to access the debt capital markets, refinance our existing debt or cause us to refinance or issue debt with less favorable terms and conditions. Moreover, our revolving credit agreement includes an increase in interest rates if the ratings for our debt are downgraded, which could have an adverse effect on our results of operations. An increase in the level of our indebtedness and related interest costs may increase our vulnerability to adverse general economic and industry conditions and may affect our ability to obtain additional financing.

Our industry is undergoing consolidation that may impact our results of operations.

Our industry, including our customers and competitors, is undergoing consolidation which may affect demand for our products and services as a result of price concessions or decreased customer capital spending. This consolidation activity could have a significant negative impact on our results of operations, financial condition or cash flows. We are unable to predict what effect consolidations 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.

Our businesses are dependent on the continuing services of certain 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 an inability 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.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES

We lease our corporate headquarters in Houston, Texas, and own or lease numerous properties throughout the world. We operate 29 major production facilities and service bases in 18 countries.

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

The following table shows our principal properties by reporting segment at December 31, 2015:



Subsea Technologies	Surface Technologies	Energy Infrastructure
United States:
Davis, California	Brighton, Colorado	Corpus Christi, Texas
* Houston, Texas	Oklahoma City, Oklahoma	Erie, Pennsylvania
	San Antonio, Texas
	Stephenville, Texas

International:
Bergen, Norway	Abu Dhabi, U.A.E.	Arnhem, The Netherlands
* Dunfermline, Scotland	Collecchio, Italy
Kongsberg, Norway	Dammam, Saudi Arabia
Labuan, Malaysia	Edmonton, Canada
Luanda, Angola	Jakarta, Indonesia
Macaé, Brazil	Neuquén, Argentina
* Nusajaya, Malaysia	+ Sens, France
Perth, Australia
Port Harcourt, Nigeria
* Rio de Janeiro, Brazil
* Singapore
* Stavanger, Norway
Takoradi, Ghana

*These facilities are principal properties in Subsea Technologies and Surface Technologies.

+This facility is a principal property in Surface Technologies and Energy Infrastructure.

ITEM 3. LEGAL PROCEEDINGS

We are involved in various pending or potential legal actions in the ordinary course of our business. Management is unable to predict the ultimate outcome of these actions because of the inherent uncertainty of litigation. However, management believes that the most probable, ultimate resolution of these matters will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

PART II

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

Our common stock is listed on the New York Stock Exchange (“NYSE”) under the “FTI” symbol.



	2015								2014
	4th Qtr.		3rd Qtr.		2nd Qtr.		1st Qtr.		4th Qtr.		3rd Qtr.		2nd Qtr.		1st Qtr.
Common stock closing price:
High	$	35.48	$	39.79	$	44.10	$	46.52	$	57.00	$	63.52	$	61.89	$	53.27
Low	$	28.35	$	28.73	$	36.96	$	36.14	$	42.75	$	54.21	$	52.16	$	48.37



Closing stock price at December 31, 2015	$	29.01
Closing stock price at February 22, 2016	$	25.32
Number of common stockholders of record at February 22, 2016	2,876

We have not declared or paid cash dividends in 2015 or 2014, and we do not currently have a plan to pay cash dividends in the future.

As of December 31, 2015, our securities authorized for issuance under equity compensation plans were as follows:



	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	—	$	—	23,042,721	(1)
Equity compensation plans not approved by security holders	—	—		—
Total	—	$	—	23,042,721	(1)

______________________________


⁽¹⁾	The table includes shares of our common stock available for future issuance under the Amended and Restated FMC Technologies, Inc. Incentive Compensation and Stock Plan. This number includes 4,068,156 shares available for issuance for nonvested stock awards that vest after December 31, 2015.

We had no unregistered sales of equity securities during the year ended December 31, 2015.

The following table summarizes repurchases of our common stock during the three months ended December 31, 2015.

Issuer Purchases of Equity Securities



Period	Total Number of Shares Purchased (a)	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 (b)
October 1, 2015 – October 31, 2015	286,710	$	33.15	286,000	18,812,222
November 1, 2015 – November 30, 2015	260,470	$	33.97	260,000	18,552,222
December 1, 2015 – December 31, 2015	773,874	$	29.60	772,444	17,779,778
Total	1,321,054			1,318,444	17,779,778

______________________________

^(a)

Represents 1,318,444 shares of common stock repurchased and held in treasury and 2,610 shares of common stock purchased and held in an employee benefit trust established for the FMC Technologies, Inc. Non-Qualified Savings and Investment Plan. In addition to these shares purchased on the open market, we sold 2,300 shares of registered common stock held in this trust, as directed by the beneficiaries, during the three months ended December 31, 2015.

^(b)

In 2005, we announced a repurchase plan approved by our Board of Directors authorizing the repurchase of up to two million shares of our issued and outstanding common stock through open market purchases. The Board of Directors authorized extensions of this program, adding five million shares in February 2006 and eight million shares in February 2007 for a total of 15 million shares of common stock authorized for repurchase. As a result of the two-for-one stock splits (i) on August 31, 2007, the authorization was increased to 30 million shares; and (ii) on March 31, 2011, the authorization was increased to 60 million shares. The Board of Directors authorized additional extensions of this program, adding 15 million shares in both December 2011 and February 2015 for a total of 90 million shares of common stock authorized for repurchase.

ITEM 6. SELECTED FINANCIAL DATA

The following tables set forth selected financial data of the Company for each of the five years in the period ended December 31, 2015. 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.



(In millions, except per share data) Years Ended December 31	2015		2014		2013		2012		2011
Statement of income data:
Total revenue	$	6,362.7	$	7,942.6	$	7,126.2	$	6,151.4	$	5,099.0
Total costs and expenses	$	5,770.6	$	6,874.1	$	6,378.6	$	5,546.6	$	4,536.6
Net income	$	394.8	$	705.3	$	506.6	$	434.8	$	403.5
Net income attributable to FMC Technologies, Inc.	$	393.1	$	699.9	$	501.4	$	430.0	$	399.8

Earnings per share from continuing operations attributable to FMC Technologies, Inc.: ⁽¹⁾
Basic earnings per share	$	1.70	$	2.96	$	2.10	$	1.79	$	1.66
Diluted earnings per share	$	1.70	$	2.95	$	2.10	$	1.78	$	1.64

Cash dividends declared	$	—	$	—	$	—	$	—	$	—



(In millions) As of December 31	2015			2014			2013			2012			2011
Balance sheet data:
Total assets	$	6,437.9		$	7,172.1		$	6,605.6		$	5,902.9		$	4,271.0
Net (debt) cash ⁽²⁾	$	(239.8	)	$	(666.6	)	$	(973.2	)	$	(1,298.7	)	$	(279.6	)
Long-term debt, less current portion	$	1,134.1		$	1,293.7		$	1,329.8		$	1,580.4		$	36.0
Total FMC Technologies, Inc. stockholders’ equity	$	2,511.8		$	2,456.3		$	2,317.2		$	1,836.9		$	1,424.6



(In millions) Years Ended December 31	2015		2014		2013		2012		2011
Other financial information:
Capital expenditures	$	250.8	$	404.4	$	314.1	$	405.6	$	274.0
Cash flows provided by operating activities	$	932.4	$	892.5	$	795.4	$	138.4	$	164.8
Segment operating capital employed ⁽³⁾	$	3,219.1	$	3,672.7	$	3,610.8	$	3,572.6	$	2,204.2
Order backlog ⁽⁴⁾	$	4,355.6	$	6,619.4	$	6,998.2	$	5,377.8	$	4,876.4

______________________________


⁽¹⁾	On February 25, 2011, our Board of Directors approved a two-for-one stock split of our outstanding shares of common stock. The stock split was completed in the form of a stock dividend that was issued on March 31, 2011. All per share information presented has been adjusted to reflect the stock split.


⁽²⁾	Net (debt) cash consists of cash and cash equivalents less short-term debt, long-term debt and the current portion of long-term debt. Net (debt) 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 of net (debt) cash.

⁽³⁾

We view segment operating capital employed, which consists of assets, net of liabilities, as the primary measure of segment capital. Segment operating capital employed excludes corporate debt facilities and certain investments, pension liabilities, deferred and currently payable income taxes and last-in, first-out (“LIFO”) inventory adjustments. See additional financial information about segment operating capital employed in Note 20 to our consolidated financial statements in Part II, Item 8 of this Annual Report on Form 10-K.


⁽⁴⁾	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 design, manufacture and service technologically sophisticated systems and products for customers in the energy industry. We have manufacturing operations worldwide, strategically located to facilitate delivery of our products, systems and services to our customers. We report our results of operations in the following segments: Subsea Technologies, Surface Technologies and Energy Infrastructure. Management’s determination of the Company’s reporting segments was made on the basis of our strategic priorities and corresponds to the manner in which our chief operating decision maker reviews and evaluates operating performance to make decisions about resources 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 20 to our consolidated financial statements in Part II, Item 8 of this Annual Report on Form 10-K. A discussion and analysis of our consolidated results of operations and the results of operations of each of our segments for the years ended December 31, 2015, 2014 and 2013 follows.

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 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 Technologies segment is primarily affected by trends in deepwater oil and natural gas production. Our Surface Technologies segment is primarily affected by trends in land-based and shallow water oil and natural gas production, including trends in shale production. We have developed close working relationships with our customers. Our Subsea Technologies segment results reflect our ability to build long-term alliances with oil and natural gas companies that are actively engaged in offshore deepwater development 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. Our share of subsea tree awards during the year is one way we evaluate our market position.

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

In each of our segments, we serve customers from around the world. During 2015, approximately 73% 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. We have targeted opportunities in West Africa, Brazil, the North Sea and the Asia-Pacific region because of the expected offshore drilling potential in those regions.

Business Outlook

Overall Outlook—Along with volatility in global equity prices and exchange rates, crude oil price volatility which began in late 2014 continued throughout 2015, and as such, uncertainty regarding the short-term market fundamentals remains. This uncertainty is driven by multiple factors, including continued strength in U.S. oil production and international crude oil supply, especially from OPEC’s and other major non-OPEC countries’ decisions to maintain oil production levels to retain or increase their market share. The increases in global crude oil inventories in 2015 marked the second consecutive year of inventory builds and have put significant downward pressure on commodity prices. As a result of the weak crude oil price environment, many crude oil development prospects have been deferred and near-term capital spending plans of our customers have been reduced, leading to a downturn in demand for our products and services and an overall weaker demand for oilfield services. The timing of any recovery of crude oil prices is dependent on many variables, including the expected impact on supply of the relief of international sanctions on Iran’s oil sector. The market corrections necessary to address the oversupply of crude oil are expected to occur over the next couple of years. Although oil companies have reduced their near-term capital investments, most of their capital spending reductions have been in capital exploration budgets that largely affect production levels beyond 2018. However, we believe as long-term demand rises and production naturally declines, commodity prices will recover and our customers will begin to increase their investments in new sources of oil production.

Subsea Technologies—In reaction to the decline in crude oil prices, many of our customers reduced their capital spending plans in 2015 or deferred new deepwater projects. These actions had an adverse effect on our 2015 subsea inbound orders when compared to the prior year. During 2015, we reduced our workforce to maintain operating margin improvements and to align our operations with anticipated decreases in future year activity due to delayed subsea project inbound.

Given the lower industry expectations for 2016, we have strategically aligned our focus on certain objectives to ensure our continued success during these difficult times in our industry. These objectives include (i) the continuing improvement of our execution, (ii) the strengthening of our relationships with our customers, (iii) the timely identification of further restructuring efforts to effectively reduce costs, (iv) the employment of critical supply chain management to reduce product costs, (v) the capitalization of our subsea service offerings as a continued growth platform, and (vi) the integration of our overall product and service offerings to increase the value stream to our customers. We remain focused on ways to reduce customer costs by offering cost-effective approaches to our customers’ project developments, including customer acceptance of new technologies and alternative business models to help achieve their cost-reduction goals and accelerate achievement of first oil. Many customers, including our alliance customers, are actively exploring ways to utilize our standardized subsea production equipment as operators understand the cost and scheduling benefits that standardization brings to their projects.

Additionally, Forsys Subsea, our joint venture with Technip, was designed to bring the proprietary technologies of FMC Technologies and Technip together to offer front-end engineering and design services aimed to identify opportunities through new technologies, services, and standardization of equipment to significantly reduce the cost of subsea field development. Forsys Subsea received two integrated FEED studies during 2015, and we expect expanded interest and market acceptance in 2016.

In the long-term, we continue to believe deepwater development will remain a significant part of our customers’ portfolio. A critical part of our long-term strategy to maintain our subsea market leadership is to continue to invest in the technologies required to develop our customers’ fields and further expand our capabilities focused on increasing reservoir production over the life of the field. We believe the long-term commitment to deepwater was further exemplified during 2015 with Chevron joining our high-pressure, high-temperature joint industry program which is aimed to solve the technical and economic deepwater challenges operators currently face.

Surface Technologies—With the decline in crude oil prices, we expected a decline in rig counts and decreased North American land activity in 2015 to negatively affect all of our Surface Technologies businesses in North America. However, customer spending reductions, coupled with increased pricing pressure, had a greater impact in our Surface Technologies businesses than in past downturns. This market environment led us to take significant actions to reduce headcount in our North American businesses in 2015. During 2015, we largely completed the reorganization within our Surface Technologies segment. This reorganization was directly aligned with our integration efforts over the last year to bring our North American surface wellhead and completion services businesses together to create our surface integrated services businesses to strengthen our market presence and bring increased value to our customers by providing an integrated offering. Although we do not expect the North American market to recover in 2016, we expect our actions to improve our position in the North American market and reduce costs in 2016. Our international surface wellhead business delivered solid operational results in 2015 due to its strong backlog, however, pricing pressure also extended to the international markets in the latter half of 2015. This pricing pressure had a slight negative effect on our 2015 international surface wellhead inbound; however we believe international activity levels to remain resilient in 2016. Given the uncertainties regarding crude oil prices and its effect on customer spending, we believe the need for further business restructuring is likely in 2016.

CONSOLIDATED RESULTS OF OPERATIONS

YEARS ENDED DECEMBER 31, 2015, 2014 AND 2013



	Year Ended December 31,									Change
(In millions, except percentages)	2015			2014			2013			2015 vs. 2014				2014 vs. 2013
Revenue	$	6,362.7		$	7,942.6		$	7,126.2		$	(1,579.9	)	(20)%	$	816.4		11%
Costs and expenses:
Cost of sales	4,894.8			5,994.9			5,571.4			(1,100.1		)	(18)	423.5			8
Selling, general and administrative expense	628.3			750.6			694.8			(122.3		)	(16)	55.8			8
Research and development expense	135.3			123.7			112.4			11.6			9	11.3			10
Restructuring and impairment expense	112.2			4.9			—			107.3			2,190	4.9			*
Total costs and expenses	5,770.6			6,874.1			6,378.6			(1,103.5		)	(16)	495.5			8
Gain on sale of Material Handling Products	—			84.3			—			(84.3		)	*	84.3			*
Other income (expense), net	(57.2		)	(54.0		)	5.3			(3.2		)	*	(59.3		)	*
Net interest expense	(32.3		)	(32.5		)	(33.7		)	0.2			1	1.2			4
Income before income taxes	502.6			1,066.3			719.2			(563.7		)	(53)	347.1			48
Provision for income taxes	107.8			361.0			212.6			(253.2		)	(70)	148.4			70
Net income	394.8			705.3			506.6			(310.5		)	(44)	198.7			39
Less: net income attributable to noncontrolling interests	(1.7		)	(5.4		)	(5.2		)	3.7			69	(0.2		)	(4)
Net income attributable to FMC Technologies, Inc.	$	393.1		$	699.9		$	501.4		$	(306.8	)	(44)%	$	198.5		40%

_______________________

*Not meaningful

2015 Compared With 2014

Revenue decreased by $1,579.9 million in 2015 compared to the prior year. Revenue in 2015 included a $652.5 million unfavorable impact of foreign currency translation. Excluding the impact of foreign currency translation, total revenue decreased by $927.4 million year-over-year. In Subsea Technologies, we entered 2015 with a strong backlog; however, during the latter part of 2014 and throughout 2015, crude oil prices experienced a precipitous decline. The decline in crude oil prices had an unfavorable effect on the subsea market which led to decreased order activity for subsea systems and services. Additionally, the decrease in revenue was attributable to lower sales volumes in our Schilling Robotics and Multi Phase Meters businesses as a result of lower market activity. Surface Technologies posted lower revenue in 2015 driven by lower market activity in North America which decreased demand for our well service pumps and flowline products in our fluid control business and conventional wellheads and frac-tree rental, flowback and wireline services in our surface integrated services business.

Gross profit (revenue less cost of sales) decreased as a percentage of sales to 23.1% in 2015 from 24.5% in the prior year. The decrease in gross profit as a percentage of sales was primarily due to lower market activity in North America which decreased sales volumes in our surface integrated service business and decreased sales volumes for our well service pumps and flowline products in our fluid control business. Additionally, the market downturn in North America led us to take excess and obsolescence inventory charges in our surface integrated services, fluid control and measurement solutions businesses in 2015. The decrease in gross profit as a percentage of sales was partially offset by higher margin project backlog conversion in our Western Region and Asia Pacific subsea business.

Selling, general and administrative (“SG&A”) expense decreased by $122.3 million year-over-year, driven by foreign currency translation, decreased sales commissions, and costs associated with terminating a representative agreement in our international surface wellhead business in the prior year.

Information regarding impairment and restructuring expenses recognized during 2015 is incorporated herein by reference from Note 4 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

During 2014 we recognized a net $84.3 million gain on the sale of our Material Handling Products business. Further information of the sale is incorporated herein by reference from Note 5 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

Other income (expense), net, reflected foreign currency losses in 2015 primarily related to the devaluation of the Angolan kwanza. In 2014, other income (expense), net reflected foreign currency losses primarily related to a $33.4 million loss related to the remeasurement of an intercompany foreign currency transaction and other foreign currency losses primarily due to the strengthening of the U.S. dollar. Further discussion of our derivative instruments is incorporated herein by reference from Note 17 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

Our provision for income taxes reflected an effective tax rate of 21.5% and 34.0% in 2015 and 2014, respectively. The decrease in our effective tax rate in 2015 from 2014 was primarily due to a favorable change in mix of earnings, partially offset by an increase in the valuation allowance for certain intercompany interest costs and a settlement of an IRS audit. Our effective tax rate can fluctuate depending on our country mix of earnings, since our foreign earnings are generally subject to lower tax rates than in the United States. In certain jurisdictions, primarily Singapore and Malaysia, our tax rate is significantly less than the relevant statutory rate due to tax holidays which are set to expire after 2018 in Singapore and 2017 and 2020 in Malaysia. The difference between the effective tax rate and the statutory U.S. federal income tax rate primarily related to differing foreign and state tax rates.

2014 Compared With 2013

Revenue increased by $816.4 million in 2014 compared to the prior year. Revenue in 2014 included a $218.4 million unfavorable impact of foreign currency translation. Excluding the impact of foreign currency translation, total revenue increased by $1,034.8 million year-over-year. Subsea systems and services had another solid year of order activity in 2014. The impact of higher backlog coming into 2014, combined with strong market activity, led to increased Subsea Technologies sales year-over-year. Surface Technologies posted higher revenue in 2014 due to conventional wellhead system sales in our surface integrated services and international surface wellhead businesses and due to increased sales in our fluid control business as demand for our well service pumps and flowline products recovered from the slowdown of the North American shale markets experienced in the prior year.

Gross profit (revenue less cost of sales) increased as a percentage of sales to 24.5% in 2014 from 21.8% in the prior year. The increase in gross profit as a percentage of sales was primarily due to higher margin backlog conversion in our Western Region subsea business, higher volumes in subsea services across all regions and the remeasurement of the Multi Phase Meters earn-out consideration in 2013, partially offset by additional contract value in 2013 related to an Angolan withholding tax adjustment. Additionally, gross profit as a percentage of revenue increased as a result of higher volumes and higher margin projects in our international surface wellhead business, primarily in the Middle East and Europe, and due to increased demand for our well service pumps and flowline products in our fluid control business.

SG&A expense increased by $55.8 million year-over-year, driven by higher project tendering costs and reorganization expenses in our subsea business, increased sales commissions, costs associated with terminating a representative agreement in our surface wellhead business and bonus accruals.

Other income (expense), net, reflected a $33.4 million loss related to the remeasurement of an intercompany foreign currency transaction and other foreign currency losses primarily due to the strengthening of the U.S. dollar in 2014. Further discussion of our derivative instruments is incorporated herein by reference from Note 17 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

Our provision for income taxes reflected an effective tax rate of 34.0% and 29.8% in 2014 and 2013, respectively. Excluding a retroactive benefit related to the American Taxpayer Relief Act of 2012 recorded in the first quarter of 2013, our effective tax rate was 30.7% in 2013. The increase in our effective tax rate in 2014 from the adjusted rate in 2013 was primarily due to changes in Norwegian tax law effective from 2014 and an unfavorable change in mix of earnings. Our effective tax rate can fluctuate depending on our country mix of earnings, since our foreign earnings are generally subject to lower tax rates than in the United States. In certain jurisdictions, primarily Singapore and Malaysia, our tax rate is significantly less than the relevant statutory rate due to tax holidays which are set to expire after 2018 and 2015, respectively. The difference between the effective tax rate and the statutory U.S. federal income tax rate primarily related to differing foreign and state tax rates.

OPERATING RESULTS OF BUSINESS SEGMENTS

YEARS ENDED DECEMBER 31, 2015, 2014, AND 2013

Segment operating profit is defined as total segment revenue less segment operating expenses. The following items have been excluded in computing segment operating profit: corporate staff expense, net interest income (expense) associated with corporate debt facilities, income taxes, and other revenue and other expense, net. Information about amounts included in corporate items and a reconciliation of segment operating results to consolidated income before income taxes, is incorporated herein by reference from Note 20 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

We report our results of operations in U.S. dollars; however, our earnings are generated in various currencies worldwide. For example, we generate a significant amount of revenue, and incur a significant amount of costs, in Norwegian krone, Brazilian real, Singapore dollar, Malaysian ringgit, British pound, Angolan new kwanza and the euro. 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 Technologies



	Year Ended December 31,									Favorable/(Unfavorable)
(In millions, except %)	2015			2014			2013			2015 vs. 2014				2014 vs. 2013
Revenue	$	4,509.0		$	5,266.4		$	4,726.9		$	(757.4	)	(14)%	$	539.5	11%
Operating profit	$	630.2		$	748.2		$	548.2		$	(118.0	)	(16)%	$	200.0	36%

Operating profit as a percent of revenue	14.0		%	14.2		%	11.6		%				(0.2) pts.			2.6 pts.

2015 Compared With 2014

Subsea Technologies’ revenue decreased $757.4 million in 2015 compared to the prior year. Revenue for 2015 included a $540.6 million unfavorable impact of foreign currency translation, primarily as a result of the Brazilian real and Norwegian krone. Excluding the impact of foreign currency translation, Subsea Technologies’ revenue decreased by $216.8 million during 2015 compared to the prior year. We entered 2015 with a strong backlog; however, during the latter part of 2014 and throughout 2015, crude oil prices experienced a precipitous decline. The decline in crude oil price had an unfavorable effect on the subsea market which led to decreased order activity for subsea systems and services. Additionally, the decrease in revenue was attributable to lower sales volumes in our Schilling Robotics and Multi Phase Meters businesses as a result of lower market activity.

Subsea Technologies’ operating profit totaled $630.2 million, or 14.0% of revenue, in 2015, compared to the prior-year’s operating profit as a percentage of revenue of 14.2%. The margin decline was primarily driven by the following:


•	Subsea Systems - 0.5 percentage point increase due to higher margin project backlog conversion in our Western Region and Asia Pacific subsea business, partially offset by restructuring and severance charges in 2015; and


•	Schilling Robotics and Multi Phase Meters - 0.8 percentage point decrease due to the decline in crude oil price and its related effect on market activity in 2015.

Subsea Technologies’ operating profit in 2015 included a $77.5 million unfavorable impact of foreign currency translation and $49.7 million in impairment, restructuring and other severance charges.

2014 Compared With 2013

Subsea Technologies’ revenue increased $539.5 million in 2014 compared to the prior year. Revenue for 2014 included a $178.5 million unfavorable impact of foreign currency translation. Excluding the impact of foreign currency translation, Subsea Technologies’ revenue increased by $718.0 million during 2014 compared to the prior year. We entered 2014 with a strong backlog. During the first half of 2014, high crude oil prices led to solid oil and gas exploration and production activity when compared to the prior year; however, a decline in oil prices that began in mid-2014 and which significantly further declined in the fourth quarter of 2014 unfavorably affected the subsea market. Despite the late 2014 decline in crude oil prices, we had solid order activity during 2014 from high demand for subsea systems and services. The year-over-year increase in revenue was attributable to the conversion of backlog and solid order activity in 2014.

Subsea Technologies’ operating profit totaled $748.2 million, or 14.2% of revenue, in 2014, compared to the prior-year’s operating profit as a percentage of revenue of 11.6%. The margin improvement was primarily driven by our Western Region subsea business from higher margin project backlog conversion and higher volumes in subsea services, particularly in the Gulf of Mexico, partially offset by additional contract value in 2013 related to an Angolan withholding tax adjustment.

Subsea Technologies’ operating profit in 2014 included a $24.9 million unfavorable impact of foreign currency translation.

Surface Technologies



	Year Ended December 31,									Favorable/(Unfavorable)
(In millions, except %)	2015			2014			2013			2015 vs. 2014				2014 vs. 2013
Revenue	$	1,487.6		$	2,130.7		$	1,806.8		$	(643.1	)	(30)%	$	323.9	18%
Operating profit	$	60.6		$	393.0		$	257.2		$	(332.4	)	(85)%	$	135.8	53%

Operating profit as a percent of revenue	4.1		%	18.4		%	14.2		%				(14.3) pts.			4.2 pts.

2015 Compared With 2014

Surface Technologies’ revenue decreased $643.1 million in 2015 compared to the prior year. The decrease in revenue was primarily driven by lower market activity in North America which decreased demand for our well service pumps and flowline products in our fluid control business and conventional wellheads in our surface integrated services business. Foreign currency translation unfavorably impacted revenue by $74.3 million in 2015.

Surface Technologies’ operating profit totaled $60.6 million, or 4.1% of revenue, in 2015, compared to the prior-year’s operating profit as a percentage of revenue of 18.4%. The margin decline was primarily driven by the following:


•	Surface Integrated Services - 10.2 percentage point decrease due to $59.0 million in asset impairment charges primarily in Canada, excess and obsolescence inventory charges, and lower market activity in North America; and


•	Fluid Control - 5.6 percentage point decrease due to decreased sales volumes for our well service pumps and flowline products resulting from lower activity in the North American shale markets and related excess and obsolescence inventory charges and restructuring expense.

Surface Technologies’ operating profit in 2015 included a $7.6 million favorable impact of foreign currency translation, $73.7 million in impairment, restructuring and other severance charges, and $41.1 million in excess and obsolescence inventory charges.

2014 Compared With 2013

Surface Technologies’ revenue increased $323.9 million in 2014 compared to the prior year. The revenue increase was driven by growth in our international surface wellhead business, primarily in the Middle East and Europe regions, and higher activity in the North American shale markets which drove additional demand for our well service pumps and flowline products in our fluid control business. Foreign currency translation unfavorably impacted revenue by $35.9 million in 2014.

Surface Technologies’ operating profit totaled $393.0 million, or 18.4% of revenue, in 2014, compared to the prior-year’s operating profit as a percentage of revenue of 14.2%. The margin improvement was primarily driven by the following:


•	Surface Wellhead International - 1.9 percentage point increase due to higher volumes and higher margin projects in the Middle East and Europe regions; and


•	Fluid Control - 1.8 percentage point increase due to increased demand for our well service pumps and flowline products resulting from the improved North American shale markets in 2014.

Energy Infrastructure



	Year Ended December 31,									Favorable/(Unfavorable)
(In millions, except %)	2015			2014			2013			2015 vs. 2014				2014 vs. 2013
Revenue	$	395.4		$	557.4		$	617.2		$	(162.0	)	(29)%	$	(59.8	)	(10)%
Operating profit	$	3.2		$	52.5		$	74.3		$	(49.3	)	(94)%	$	(21.8	)	(29)%

Operating profit as a percent of revenue	0.8		%	9.4		%	12.0		%				(8.6) pts.				(2.6) pts.

2015 Compared With 2014

Energy Infrastructure’s revenue decreased $162.0 million in 2015 compared to the prior year. The decrease in revenue was due to lower sales volumes primarily in our measurement solutions business driven by the market downturn in 2015. Foreign currency translation unfavorably impacted revenue by $38.7 million in 2015.

Energy Infrastructure’s operating profit totaled $3.2 million, or 0.8% of revenue, in 2015, compared to the prior-year’s operating profit as a percentage of revenue of 9.4%. The margin decline was primarily driven by a 6.5 percentage point decrease in our measurement solutions business as a result of lower sales volumes due to the market downturn in 2015 and restructuring expense, severance charges and excess and obsolescence inventory charges recorded in 2015. Energy Infrastructure’s operating profit in 2015 included $8.5 million in restructuring and other severance charges and $7.4 million in excess and obsolescence inventory charges.

2014 Compared With 2013

Energy Infrastructure’s revenue decreased $59.8 million in 2014 compared to the prior year. The decrease in revenue was due to the sale of our Material Handling Products business in the second quarter of 2014. Foreign currency translation unfavorably impacted revenue by $4.1 million in 2014.

Energy Infrastructure’s operating profit totaled $52.5 million, or 9.4% of revenue, in 2014, compared to the prior-year’s operating profit as a percentage of revenue of 12.0%. The margin decline was primarily driven by the following:


•	Measurement Solutions - 1.5 percentage point decrease due to lower sales volumes and the execution of lower margin projects; and


•	Material Handling - 1.1 percentage point decrease due to the sale of our Material Handling Products business in the second quarter of 2014.

Corporate Items



	Year Ended December 31,									Favorable/(Unfavorable)
(In millions, except %)	2015			2014			2013			2015 vs. 2014				2014 vs. 2013
Corporate expense	$	(60.2	)	$	(66.3	)	$	(46.3	)	$	6.1		9%	$	(20.0	)	(43)%
Other revenue and other (expense), net	(100.8		)	(33.7		)	(85.6		)	(67.1		)	(199)%	51.9			61%
Net interest expense	(32.3		)	(32.5		)	(33.7		)	0.2			1%	1.2			4%
Total corporate items	$	(193.3	)	$	(132.5	)	$	(165.6	)	$	(60.8	)	(46)%	$	33.1		20%

2015 Compared With 2014

Our corporate items reduced earnings by $193.3 million in 2015, compared to $132.5 million in 2014. The year-over-year increase primarily reflected the following:


•	unfavorable variance of $84.3 million related to the gain on sale of our Material Handling Products business in 2014;


•	favorable variance of $8.0 million related to inventory LIFO and valuation adjustments; and a


•	favorable variance of $13.9 million associated with lower pension expense, primarily related to settlement charges in our U.S. defined benefit plan in 2014.

2014 Compared With 2013

Our corporate items reduced earnings by $132.5 million in 2014, compared to $165.6 million in 2013. The year-over-year decrease primarily reflected the following:


•	favorable variance of $84.3 million related to the gain on sale of our Material Handling Products business in 2014;


•	favorable variance of $25.1 million related to the remeasurement of the Multi Phase Meters earn-out consideration in 2013;


•	unfavorable variance of $59.9 million in foreign currency, primarily related to an intercompany foreign currency loss; and an


•	unfavorable variance of $20.0 million related to higher corporate staff expenses, primarily from increased bonus accruals.

Inbound Orders and Order Backlog

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



	Inbound Orders Year Ended December 31,
(In millions)	2015			2014
Subsea Technologies	$	3,102.7		$	5,547.1
Surface Technologies	1,289.8			2,070.4
Energy Infrastructure	379.3			473.3
Intercompany eliminations and other	(17.3		)	(6.2		)
Total inbound orders	$	4,754.5		$	8,084.6

Order backlog—Order backlog is calculated as the estimated sales value of unfilled, confirmed customer orders at the reporting date. Translation negatively affected backlog by $655.6 million and $520.8 million for the years ended December 31, 2015 and 2014, respectively.



	Order Backlog December 31,
(In millions)	2015			2014
Subsea Technologies	$	3,761.8		$	5,793.1
Surface Technologies	432.8			654.2
Energy Infrastructure	163.9			187.0
Intercompany eliminations	(2.9		)	(14.9		)
Total order backlog	$	4,355.6		$	6,619.4

Subsea Technologies. Order backlog at December 31, 2015, decreased by $2.0 billion compared to December 31, 2014, primarily due to lower inbound orders during 2015 and the negative impact of foreign currency translation. Subsea Technologies backlog of $3.8 billion at December 31, 2015, was composed of various subsea projects, including BP’s Mad Dog Phase 2 and Shah Deniz Stage 2; Chevron’s Agbami; Eni’s Block 15/06 East Hub and Jangkrik; Petrobras’ pre-salt tree and manifold award; Shell's Appomattox; Statoil’s Johan Sverdrup Phase 1; Total’s Egina; Tullow Ghana’s TEN; Wintershall’s Maria; and Woodside's Greater Western Flank Phase 2. The above listed projects represented 73% of our Subsea Technologies backlog as of December 31, 2015. We expect to convert approximately 55% to 60% of December 31, 2015 backlog into revenue during 2016.

Surface Technologies. Order backlog at December 31, 2015 decreased by $221.4 million compared to December 31, 2014. The decrease in backlog was due to lower inbound orders primarily in our fluid control and surface integrated services businesses during 2015. We expect to convert substantially all December 31, 2015 backlog into revenue into 2016.

Liquidity and Capital Resources

Substantially all of our cash balances are held outside the United States and are generally used to meet the liquidity needs of our non-U.S. operations. Most of our cash held outside the United States could be repatriated to the United States, but under current law, any such repatriation would be subject to U.S. federal income tax, as adjusted for applicable foreign tax credits. We have provided for U.S. federal income taxes on undistributed foreign earnings where we have determined that such earnings are not indefinitely reinvested.

We expect to meet the continuing funding requirements of our U.S. operations with cash generated by such U.S. operations, cash from earnings generated by non-U.S. operations that are not indefinitely reinvested and our existing revolving credit facility. If cash held by non-U.S. operations is required for funding operations in the United States, and if U.S. tax has not previously been provided on the earnings of such operations, we would make a provision for additional U.S. tax in connection with repatriating this cash, which may be material to our cash flows and results of operations.

Net debt, or 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 debt, or 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 (debt) cash should not be considered as 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 is a reconciliation of our cash and cash equivalents to net (debt) cash for the periods presented.



(In millions)	December 31, 2015			December 31, 2014
Cash and cash equivalents	$	916.2		$	638.8
Short-term debt and current portion of long-term debt	(21.9		)	(11.7		)
Long-term debt, less current portion	(1,134.1		)	(1,293.7		)
Net debt	$	(239.8	)	$	(666.6	)

The change in our net debt position was primarily due to lower capital expenditures, positive changes in our working capital position, and decreased treasury stock repurchases, partially offset by lower cash generated from operating activities from lower income from operations and cash requirements to fund our joint ventures.

Cash Flows

Cash flows for each of the years in the three-year period ended December 31, 2015, were as follows:



	Year Ended December 31,
(In millions)	2015			2014			2013
Cash provided by operating activities	$	932.4		$	892.5		$	795.4
Cash required by investing activities	(275.2		)	(285.1		)	(311.6		)
Cash required by financing activities	(345.6		)	(355.4		)	(422.3		)
Effect of exchange rate changes on cash and cash equivalents	(34.2		)	(12.3		)	(4.5		)
Increase in cash and cash equivalents	$	277.4		$	239.7		$	57.0

Operating cash flows—During 2015, we generated $932.4 million in cash flows from operating activities, which represented a $39.9 million increase compared to the prior year. Our cash flows from operating activities in 2014 were $97.1 million higher than 2013. The year-over-year increase in 2015 was due to a positive change in our working capital position driven by our portfolio of projects resulting from collections of receivables, partially offset by lower income during the year. The year-over-year increase in 2014 was due to higher income during the year, partially offset by a negative change in our working capital position driven by our portfolio of projects resulting from significant advance payments received in 2013. Our working capital balances can vary significantly depending on the payment terms and timing on key contracts.

Investing cash flows—Our cash requirements for investing activities in 2015 were $275.2 million, primarily reflecting cash required by our capital expenditure program of $250.8 million during 2015 related to continued investments in service asset primarily in our Subsea Technologies segment and $34.5 million in investments in our Forsys Subsea and FTO Services joint ventures.

Our cash requirements for investing activities in 2014 were $285.1 million, primarily reflecting cash required by our capital expenditure program of $404.4 million related to continued investments in capacity expansion and service asset investments primarily in our Subsea Technologies segment, partially offset by $105.6 million of proceeds related to the sale of our Material Handling Products business in the second quarter of 2014.

Our cash requirements for investing activities in 2013 were $311.6 million, primarily reflecting cash required by our capital expenditure program of $314.1 million related to continued investments in capacity expansion and service asset investments primarily in our Subsea Technologies segment.

Financing cash flows—Cash required by financing activities was $345.6 million in 2015. The decrease in cash required from financing activities from the prior year was driven by decreased purchases of treasury stock in 2015 and the payment of the Multi Phase Meters earn-out obligation in 2014, partially offset by higher payments to reduce our commercial paper position in 2015.

Cash required by financing activities was $355.4 million in 2014. The decrease in cash required from financing activities from the prior year was driven by higher payments to reduce our commercial paper position in 2013, payment of our outstanding balance under our revolving credit facility in 2013, partially offset by increased purchases of treasury stock during 2014.

Debt and Liquidity

Total borrowings at December 31, 2015 and 2014, comprised the following:



	December 31,
(In millions)	2015		2014
Revolving credit facility	$	—	$	—
Commercial paper	337.2		469.1
2.00% Notes due 2017	299.1		298.6
3.45% Notes due 2022	497.5		497.2
Term loan	15.6		22.9
Foreign uncommitted credit facilities	5.9		7.9
Property financing	0.7		9.7
Total borrowings	$	1,156.0	$	1,305.4

Credit Facility—On September 24, 2015, we entered into a new $2.0 billion revolving credit agreement (“credit agreement”) with Wells Fargo Bank, National Association, as Administrative Agent. The credit agreement is a five-year, revolving credit facility expiring in September 2020. Subject to certain conditions, at our request the aggregate commitments under the credit agreement may be increased by an additional $500 million.

Borrowings under the credit agreement bear interest at the highest of three base rates or the London interbank offered rate (“LIBOR”), at our option, plus an applicable margin. Depending on our senior unsecured credit rating, the applicable margin for revolving loans varies (i) in the case of LIBOR loans, from 1.00% to 1.75% and (ii) in the case of base rate loans, from 0.00% to 0.75%.

In connection with the new credit agreement, we terminated our previously existing $1.5 billion five-year, revolving credit agreement.

The following is a summary of our revolving credit facility at December 31, 2015:



(In millions) Description	Amount		Debt Outstanding		Commercial Paper Outstanding (a)		Letters of Credit		Unused Capacity		Maturity
Five-year revolving credit facility	$	2,000.0	$	—	$	337.2	$	—	$	1,662.8	September 2020

______________________________


^(a)	Under our commercial paper program, we have the ability to access up to $1.5 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 facility provides the ability to issue our commercial paper obligations on a long-term basis. We had $337.2 million of commercial paper issued under our facility at December 31, 2015. As we had both the ability and intent to refinance these obligations on a long-term basis, our commercial paper borrowings were classified as long-term in the accompanying consolidated balance sheet at December 31, 2015.

Among other restrictions, the terms of the credit agreement include negative covenants related to liens and our total capitalization ratio. As of December 31, 2015, we were in compliance with all restrictive covenants under our revolving credit facility.

Senior Notes—On September 21, 2012, we completed the public offering of $300.0 million aggregate principal amount of 2.00% senior notes due October 2017 and $500.0 million aggregate principal amount of 3.45% senior notes due October 2022 (collectively, the “Senior Notes”). Interest on the Senior Notes is payable semi-annually in arrears on April 1 and October 1 of each year, beginning April 1, 2013. Net proceeds from the offering of $793.8 million were used for the repayment of outstanding commercial paper and indebtedness under our revolving credit facility. Additional information about the Senior Notes is incorporated herein by reference from Note 10 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

Outlook for 2016

Liquidity and Capital Resources—Historically, we have generated our liquidity and capital resources primarily through operations and, when needed, through our credit facility. We have $1,662.8 million in capacity available under our revolving credit facility that we expect to utilize if working capital needs temporarily increase in response to changes in market demand. The volatility in credit, equity and commodity markets creates some uncertainty for our businesses. Although we will continue to reach payment milestones on many of our projects, we expect our consolidated operating cash flow position in 2016 to decrease as a result of the negative impact the decline in commodity prices will have on our overall business. The downturn in the oilfield services industry as a result of the decrease in commodity prices has led some of our customers to request price concessions or delays in backlog delivery. Consequently, any discounts or material product delivery delays that may ultimately be mutually agreed with our customers may adversely affect our results of operations and cash flows. However, management believes, based on our current financial condition, existing backlog levels and current expectations for future market conditions, that we will continue to meet our short- and long-term liquidity needs with a combination of cash on hand, cash generated from operations and access to capital markets.

The term loan supporting our Brazilian operations matures in 2016; however, we expect to re-finance this obligation during 2016.

We expect to make contributions of approximately $12.7 million to our international pension plans during 2016. Actual contribution amounts are dependent upon plan investment returns, changes in pension obligations, regulatory environments and other economic factors. We update our pension estimates annually or more frequently upon the occurrence of significant events. Additionally, we expect to make contributions of approximately $3.7 million to our U.S. Non-Qualified Defined Benefit Pension Plan during 2016.

We project spending approximately $180 million in 2016 for capital expenditures, largely towards maintenance expenditures in our subsea service business. Further, we expect to continue our stock repurchases authorized by our Board of Directors, with the timing and amounts of these repurchases dependent upon market conditions and liquidity.

We continue to evaluate acquisitions, divestitures and joint ventures that meet our strategic priorities. Our intent is to maintain a level of financing sufficient to meet these objectives.

Credit rating—Due to the deterioration in crude oil prices, Moody’s has placed many U.S. exploration and production and oilfield service companies, including FMC Technologies, on review for downgrade. Should a downgrade occur, we believe it is reasonably likely to affect our borrowing costs related to our commercial paper program; however, we are currently unable to estimate the incremental borrowing costs under our commercial paper program during 2016.

Contractual Obligations

The following is a summary of our contractual obligations at December 31, 2015:



	Payments Due by Period
(In millions) Contractual obligations	Total payments		Less than 1 year		1-3 years		3 -5 years		After 5 years
Long-term debt ^(a)	$	1,150.1	$	16.0	$	636.6	$	—	$	497.5
Short-term debt	5.9		5.9		—		—		—
Interest on long-term debt ^(a)	132.8		23.3		40.5		34.5		34.5
Operating leases ^(b)	421.0		85.9		128.1		78.4		128.6
Purchase obligations ^(c)	602.6		506.5		94.9		1.2		—
Pension and other post-retirement benefits ^(d)	12.7		12.7		—		—		—
Unrecognized tax benefits ^(e)	9.7		9.7		—		—		—
Total contractual obligations	$	2,334.8	$	660.0	$	900.1	$	114.1	$	660.6

______________________________


^(a)	Our available long-term 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 2015, we paid $31.0 million for interest charges, net of interest capitalized.

^(b)

In 2014 we entered into construction and operating lease agreements to finance the construction of manufacturing and office facilities located in Houston, TX. In January 2016, construction of the facilities was completed and the operating lease commenced. Upon expiration of the lease term in September 2021, we have the option to renew the lease, purchase the facilities or re-market the facilities on behalf of the lessor, including certain guarantees of residual value under the re-marketing option.

^(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 on our consolidated statements of income.


^(d)	We expect to contribute approximately $12.7 million to our international pension plans, representing primarily the U.K. and Norway qualified pension plans, in 2016. Required contributions for future years depend on factors that cannot be determined at this time. Additionally, we expect to contribute $3.7 million to our U.S. Non-Qualified Defined Benefit Pension Plan in 2016.


^(e)	It is reasonably possible that $9.7 million of liabilities for unrecognized tax benefits will be settled during 2016, and this amount is reflected in income taxes payable in our consolidated balance sheet as of December 31, 2015. Although unrecognized tax benefits are not contractual obligations, they are presented in this table because they represent demands on our liquidity.

Other Off-Balance Sheet Arrangements

The following is a summary of other off-balance sheet arrangements at December 31, 2015:



	Amount of Commitment Expiration per Period
(In millions) Other off-balance sheet arrangements	Total amount		Less than 1 year		1-3 years		3-5 years		After 5 years
Letters of credit and bank guarantees ^(a)	$	677.8	$	266.5	$	188.0	$	115.4	$	107.9
Surety bonds ^(a)	5.7		1.1		4.0		—		0.6
Third party guarantees ^(b)	20.0		20.0		—		—		—
Total other off-balance sheet arrangements	$	703.5	$	287.6	$	192.0	$	115.4	$	108.5

______________________________

^(a)

As collateral for our performance on certain sales contracts or as part of our agreements with insurance companies, we are liable under letters of credit, surety bonds and other bank guarantees. Our ability to generate revenue from certain contracts is dependent upon our ability to obtain these off-balance sheet financial instruments. These off-balance sheet financial instruments may be renewed, revised or released based on changes in the underlying commitment. Historically, our commercial commitments have not been drawn upon to a material extent; consequently, management believes it is not reasonably likely there will be material claims against these commitments. However, should these financial instruments become unavailable to us, our operations and liquidity could be negatively impacted.


^(b)	In August 2014 FMC Technologies entered into an arrangement to jointly guarantee the debt obligations under a revolving credit facility of FTO Services, our joint venture with Edison Chouest Offshore LLC. Information regarding our guarantee is incorporated herein by reference from Note 12 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

Critical Accounting Estimates

The preparation of financial statements in conformity with U.S. generally accepted accounting principles 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 included in Part II, Item 8 of this Annual Report on Form 10-K for a description of our significant accounting policies.

Percentage of Completion Method of Accounting

We recognize revenue on construction-type manufacturing projects using the percentage of completion method of accounting whereby revenue is recognized as work progresses on each contract. There are several acceptable methods under U.S. generally accepted accounting principles of measuring progress toward completion. Most frequently, we use the ratio of costs incurred to date to total estimated contract costs at completion to measure progress toward completion.

We execute contracts with our customers that clearly describe the equipment, systems and/or services that we will provide and the amount of consideration we will receive. 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.

Revenue recognized using the percentage of completion method of accounting was approximately 60%, 52% and 55% of total revenue recognized for the years ended December 31, 2015, 2014 and 2013, respectively. A significant portion of our total revenue recognized under the percentage of completion method of accounting relates to our Subsea Technologies segment, primarily for subsea exploration and production equipment projects that involve the design, engineering, manufacturing and assembly of complex, customer-specific systems. The systems are not entirely built from standard bills of material and typically require extended periods of time to design and construct.

Total estimated contract cost affects both the revenue recognized in a period as well as the reported profit or loss on a project. The determination of profit or loss on a contract requires consideration of contract revenue, change orders and claims, less costs incurred to date and estimated costs to complete. Profits are recognized based on the estimated project profit multiplied by the percentage complete. 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 contracts under the percentage of completion method of accounting 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 using the percentage of completion method of accounting is sensitive to changes in our estimates of total contract costs. For each contract in progress at December 31, 2015, a 1% increase or decrease in the estimated margin earned on each contract would have increased or decreased total revenue and pre-tax income by $30.1 million for the year ended December 31, 2015.

The total estimated contract cost in the percentage of completion method of accounting is a critical accounting estimate because it can materially affect revenue and profit and requires us to make judgments about matters that are uncertain. There are many factors, including, but not limited to, the ability to properly execute the engineering and designing phases consistent with our customers’ expectations, the availability and costs of labor and material resources, productivity and weather, that can affect the accuracy of our cost estimates, and ultimately, our future profitability. In the past, we have realized both lower and higher than expected margins and have incurred losses as a result of unforeseen changes in our project costs; however, historically, our estimates have been reasonably dependable regarding the recognition of revenue and profit on contracts using the percentage of completion method of accounting.

Inventory Valuation

Inventory is recorded at the lower of cost or market. We evaluate the components of inventory on a regular basis for excess and obsolescence. We record the decline in the carrying value of estimated excess or obsolete inventory as a reduction of inventory and as an expense included in cost of sales in the period in which it is identified. Our estimate of excess and obsolete inventory is a critical accounting estimate because it is highly susceptible to change from period to period. In addition, the estimate requires management to make judgments about the future demand for inventory.

In order to quantify excess or obsolete inventory, we begin by preparing a candidate listing of the components of inventory that have a quantity on hand in excess of usage within the most recent two-year period. The list is reviewed with sales, engineering, production and materials management personnel to determine whether the list of potential excess or obsolete inventory items is accurate. As part of this evaluation, management considers whether there has been a change in the market for finished goods, whether there will be future demand for on-hand inventory items and whether there are components of inventory that incorporate obsolete technology. Finally, an assessment is made of our historical usage of inventory previously written off as excess or obsolete, and a further adjustment to the estimate is made based on this historical experience. As a result, our estimate of excess or obsolete inventory is sensitive to changes in assumptions about future usage of inventory. Factors that could materially impact our estimate include changes in crude oil prices and its effect on the longevity of the current industry downturn, which would impact the demand for our products and services, as well as changes in the pattern of demand for the products that we offer. We believe our inventory valuation reserve is adequate to properly value potential excess and obsolete inventory as of December 31, 2015, however, any significant changes to the factors mentioned above could lead our estimate to change. Refer to Note 6 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K for additional information related to inventory valuation adjustments recorded during 2015.

Impairment of Long-Lived and Intangible Assets

Long-lived assets, including 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 flow 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 future productivity of the asset, operating costs and capital decisions and all available information at the date of review. During 2015, we identified various assets whose carrying values were impaired due to the downturn in the oilfield services industry, driven by the decline in crude oil prices. Refer to Note 4 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K for additional information related to asset impairment charges recorded during 2015. If future market conditions deteriorate beyond our current expectations and assumptions, additional impairments of long-lived assets may be identified if we conclude that the carrying amounts are no longer recoverable.

Impairment of Goodwill

Goodwill is not subject to amortization but is tested for impairment 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. Reporting units with goodwill are tested for impairment by first assessing qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of the reporting unit is less than its carrying amount. If after assessing the totality of events or circumstances, or based on management’s judgment, we determine it is more likely than not that the fair value of a reporting unit is less than its carrying amount, a two-step quantitative impairment test is performed.

When using the two-step 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.

At December 31, 2014, we determined the fair values of our heritage completion services and automation and control reporting units did not substantially exceed their carrying values. As a result, we conducted interim goodwill impairments tests for both these reporting units during the first and second quarter in 2015. As part of management’s strategy to integrate our products and services in our Surface Technologies segment, the services of our completion services reporting unit became part of our U.S. and Canadian surface integrated services reporting units during the third quarter of 2015. Refer to Part I, Item 1 “Business” for further information regarding these integration efforts. A goodwill impairment charge of $8.4 million related to our Canadian surface integrated services reporting unit was recorded in our Surface Technologies segment during the third quarter of 2015 as a result of the continued deterioration in crude oil prices and its related effect on demand for services of the reporting unit. Refer to Note 4 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K for additional information related to asset impairment charges recorded in 2015. We did not recognize any goodwill impairment during 2014, as the fair values of our reporting units with goodwill balances exceeded their carrying amounts. In addition, there were no negative conditions, or triggering events, that occurred in 2014 requiring us to perform additional impairment reviews.

A lower fair value estimate in the future for any of our reporting units, specifically our U.S. surface integrated services and separation systems 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.

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 States 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 an allowance reducing 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 the expected realizability of a deferred tax asset would require that we adjust the valuation allowance applied against the gross value of our total deferred tax assets, resulting in a change to net income.

As of December 31, 2015, we believe that it is not more likely than not that we will generate future taxable income in certain foreign jurisdictions in which we have cumulative net operating losses and, therefore, we have provided a valuation allowance against the related deferred tax assets. As of December 31, 2015, we believe that it is more likely than not that we will have future taxable income in the United States to utilize our domestic deferred tax assets. Therefore, we have not provided a valuation allowance against any domestic deferred tax assets.

The need for a valuation allowance is sensitive to changes in our estimate of future taxable income. If our estimate of future taxable income was 25% lower than the estimate used, we would still generate sufficient taxable income to utilize such domestic deferred tax 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

Our pension and other post-retirement (health care and life insurance) obligations are described in Note 15 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.

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 on our consolidated balance sheet 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. These measures are critical accounting estimates because they are subject to management’s judgment and can materially affect net income.

The discount rate affects the interest cost component of net periodic pension cost and the calculation of the projected benefit obligation. The discount rate is based on rates at which the pension benefit obligation could be effectively settled on a present value basis. Discount rates are derived by identifying a theoretical settlement portfolio of long-term, high quality (“AA” rated) corporate bonds at our determination date that is sufficient to provide for the projected pension benefit payments. A single discount rate is determined that results in a discounted value of the pension benefit payments that equate to the market value of the selected bonds. The resulting discount rate is reflective of both the current interest rate environment and the pension’s distinct liability characteristics. Significant changes in the discount rate, such as those caused by changes in the yield curve, the mix of bonds available in the market, the duration of selected bonds and the timing of expected benefit payments, may result in volatility in our pension expense and pension liabilities.

The expected long-term rate of return on plan assets is a component of net periodic pension cost. Our estimate of the expected long-term 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. The difference between the expected return and the actual return on plan assets is amortized over the expected remaining service life of employees, resulting in a lag time between the market’s performance and its impact on plan results.

Holding other assumptions constant, 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 2015 Pension Expense Before Income Taxes			Increase (Decrease) in Projected Benefit Obligation at December 31, 2015
50 basis point decrease in discount rate	$	9.9		$	88.7
50 basis point increase in discount rate	$	(9.2	)	$	(79.8	)
50 basis point decrease in expected long-term rate of return on plan assets	$	4.3
50 basis point increase in expected long-term rate of return on plan assets	$	(4.3	)

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.

Other Matters

As previously disclosed, during the second quarter of 2014, we received an inquiry and a subpoena from the SEC seeking information about paid-time-off accruals within the automation and control business unit. The inquiry continued into the second half of 2014 and covered revenue and expenses in certain business units. Pursuant to additional subpoenas received in 2015, we provided information regarding our tax department and our previously disclosed accounting treatment for uncertain foreign tax positions.

We have fully responded to all of the SEC’s requests for information and have cooperated and engaged in discussions with the SEC. On January 19, 2016, we received a notice indicating that the SEC had made a preliminary determination to recommend that the SEC Division of Enforcement file a civil enforcement action against the Company for alleged violations of the reporting, books-and-records and internal control provisions of U.S. securities laws. We believe that no enforcement action is warranted against us, and we intend to vigorously defend any claims that may be brought. We have discussed these matters with our independent registered public accounting firm and our Audit Committee.

Recently Issued Accounting Standards

Refer to Note 2 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. At December 31, 2015 and 2014, 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 at December 31, 2015, would have changed our revenue and income before income taxes attributable to FMC Technologies, Inc. by approximately 4% and 2%, 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 derivatives 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 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.

We have prepared a sensitivity analysis of our foreign currency forward contracts hedging anticipated transactions that are accounted for as cash flow hedges. This analysis assumes that each foreign currency rate would change 10% against a stronger and then weaker U.S. dollar. A 10% increase in the value of the U.S. dollar would result in an additional loss of $68.0 million in the net fair value of cash flow hedges reflected in our consolidated balance sheet at December 31, 2015.

Interest Rate Risk

At December 31, 2015, we had unhedged variable rate debt of $337.2 million with a weighted average interest rate of 0.89%. Using sensitivity analysis to measure the impact of a 10% adverse movement in the interest rate, or nine basis points, would result in an increase to interest expense of $0.3 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 have 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 $0.4 million in unrealized earnings in the period of change. Based on our portfolio as of December 31, 2015, we have material positions with exposure to the 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

MANAGEMENT’S 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) of the Securities Exchange Act of 1934, as amended. Our internal control over financial reporting is a process designed under the supervision of the Chief Executive Officer and Chief Financial Officer to provide reasonable assurance regarding the reliability of financial reporting and the preparation of our consolidated financial statements in accordance with U.S. generally accepted accounting principles. All internal control systems, no matter how well designed and operated, have inherent limitations. Therefore, even internal control systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and reporting.

Under the supervision and with the participation of management, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation, we concluded that our internal control over financial reporting was effective in providing this reasonable assurance as of December 31, 2015.

KPMG LLP, an independent registered public accounting firm, has audited the Company’s consolidated financial statements as of and for the three-year period ended December 31, 2015, and has issued an attestation report on the Company’s internal control over financial reporting as of December 31, 2015, which is included herein.



/s/ JOHN T. GREMP		/s/ MARYANN T. MANNEN
John T. Gremp		Maryann T. Mannen
Chairman and Chief Executive Officer		Executive Vice President and Chief Financial Officer

February 24, 2016

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

FMC Technologies, Inc.:

We have audited FMC Technologies, Inc.’s internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). FMC Technologies, Inc.’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on FMC Technologies, Inc.’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

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

In our opinion, FMC Technologies, Inc. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of FMC Technologies, Inc. and subsidiaries as of December 31, 2015 and 2014, and the related consolidated statements of income, comprehensive income, cash flows, and changes in stockholders’ equity for each of the years in the three-year period ended December 31, 2015, and our report dated February 24, 2016 expressed an unqualified opinion on those consolidated financial statements.

/s/ KPMG LLP

Houston, Texas

February 24, 2016

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

FMC Technologies, Inc.:

We have audited the accompanying consolidated balance sheets of FMC Technologies, Inc. and subsidiaries as of December 31, 2015 and 2014, and the related consolidated statements of income, comprehensive income, cash flows, and changes in stockholders’ equity for each of the years in the three-year period ended December 31, 2015. In connection with our audits of the consolidated financial statements, we also have audited financial statement schedule II. These consolidated financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements and financial statement schedule based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of FMC Technologies, Inc. and subsidiaries as of December 31, 2015 and 2014, and the results of their operations and their cash flows for each of the years in the three-year period ended December 31, 2015, in conformity with U.S. generally accepted accounting principles. Also in our opinion, the related financial statement schedule II, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), FMC Technologies, Inc.’s internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 24, 2016 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

/s/ KPMG LLP

Houston, Texas

February 24, 2016

FMC TECHNOLOGIES, INC. AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME



	Year Ended December 31,
(In millions, except per share data)	2015			2014			2013
Revenue:
Product revenue	$	5,084.5		$	6,335.7		$	5,724.7
Service revenue	1,024.8			1,276.5			1,066.0
Lease and other income	253.4			330.4			335.5
Total revenue	6,362.7			7,942.6			7,126.2
Costs and expenses:
Cost of product revenue	3,915.9			4,855.1			4,562.4
Cost of service revenue	772.1			925.0			792.7
Cost of lease and other revenue	206.8			214.8			216.3
Selling, general and administrative expense	628.3			750.6			694.8
Research and development expense	135.3			123.7			112.4
Restructuring and impairment expense (Note 4)	112.2			4.9			—
Total costs and expenses	5,770.6			6,874.1			6,378.6
Gain on sale of Material Handling Products (Note 5)	—			84.3			—
Other income (expense), net	(57.2		)	(54.0		)	5.3
Income before interest income, interest expense and income taxes	534.9			1,098.8			752.9
Interest income	0.8			1.1			0.7
Interest expense	(33.1		)	(33.6		)	(34.4		)
Income before income taxes	502.6			1,066.3			719.2
Provision for income taxes (Note 14)	107.8			361.0			212.6
Net income	394.8			705.3			506.6
Net income attributable to noncontrolling interests	(1.7		)	(5.4		)	(5.2		)
Net income attributable to FMC Technologies, Inc.	$	393.1		$	699.9		$	501.4
Earnings per share attributable to FMC Technologies, Inc. (Note 3):
Basic	$	1.70		$	2.96		$	2.10
Diluted	$	1.70		$	2.95		$	2.10
Weighted average shares outstanding (Note 3):
Basic	230.9			236.3			238.3
Diluted	231.7			236.9			239.1

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

FMC TECHNOLOGIES, INC. AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME



	Year Ended December 31,
(In millions)	2015			2014			2013
Net income	$	394.8		$	705.3		$	506.6
Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments ⁽¹⁾	(182.3		)	(107.6		)	(99.7		)
Net gains (losses) on hedging instruments:
Net gains (losses) arising during the period	(64.9		)	(108.4		)	27.1
Reclassification adjustment for net losses (gains) included in net income	55.1			(0.8		)	(5.2		)
Net gains (losses) on hedging instruments ⁽²⁾	(9.8		)	(109.2		)	21.9
Pension and other post-retirement benefits:
Net actuarial gain (loss) arising during the period	(21.0		)	(152.7		)	112.5
Prior service cost arising during the period	—			(1.7		)	(0.4		)
Reclassification adjustment for settlement losses included in net income	1.2			15.7			3.2
Reclassification adjustment for amortization of prior service cost (credit) included in net income	0.1			0.3			(0.3		)
Reclassification adjustment for amortization of net actuarial loss included in net income	22.9			12.3			18.2
Reclassification adjustment for amortization of transition asset included in net income	(0.1		)	(0.1		)	(0.1		)
Net pension and other post-retirement benefits ⁽³⁾	3.1			(126.2		)	133.1
Other comprehensive income (loss), net of tax	(189.0		)	(343.0		)	55.3
Comprehensive income	205.8			362.3			561.9
Comprehensive income attributable to noncontrolling interest	(1.7		)	(5.4		)	(5.2		)
Comprehensive income attributable to FMC Technologies, Inc.	$	204.1		$	356.9		$	556.7

______________________


⁽¹⁾	Net of income tax (expense) benefit of $7.9, $7.2 and $(1.6) for the years ended December 31, 2015, 2014 and 2013, respectively.


⁽²⁾	Net of income tax benefit of $3.3, $25.7 and $1.0 for the years ended December 31, 2015, 2014 and 2013, respectively.


⁽³⁾	Net of income tax (expense) benefit of $(4.1), $56.9 and $(81.8) for the years ended December 31, 2015, 2014 and 2013, respectively.

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

FMC TECHNOLOGIES, INC. AND CONSOLIDATED SUBSIDIARIES CONSOLIDATED BALANCE SHEETS

	December 31,
(In millions, except par value data)	2015			2014
Assets
Cash and cash equivalents	$	916.2		$	638.8
Receivables, net of allowances of $19.2 in 2015 and $9.4 in 2014 (Note 22)	1,522.4			2,127.0
Inventories, net (Note 6)	744.6			1,021.2
Derivative financial instruments (Note 17)	371.9			197.6
Prepaid expenses	48.9			48.5
Income taxes receivable	68.7			23.4
Other current assets	276.0			379.9
Total current assets	3,948.7			4,436.4
Investments	29.6			35.9
Property, plant and equipment, net (Note 8)	1,371.5			1,458.4
Goodwill (Note 9)	514.7			552.1
Intangible assets, net (Note 9)	246.3			314.5
Deferred income taxes (Note 14)	183.3			106.5
Derivative financial instruments (Note 17)	0.1			134.9
Other assets	143.7			133.4
Total assets	$	6,437.9		$	7,172.1
Liabilities and equity
Short-term debt and current portion of long-term debt (Note 10)	$	21.9		$	11.7
Accounts payable, trade	519.3			723.5
Advance payments and progress billings	664.6			965.2
Accrued payroll	185.8			256.8
Derivative financial instruments (Note 17)	554.9			230.2
Income taxes payable	57.2			152.9
Other current liabilities	339.6			443.3
Total current liabilities	2,343.3			2,783.6
Long-term debt, less current portion (Note 10)	1,134.1			1,293.7
Accrued pension and other post-retirement benefits, less current portion (Note 15)	230.4			236.7
Derivative financial instruments (Note 17)	0.5			220.2
Deferred income taxes (Note 14)	98.2			54.3
Other liabilities	100.5			105.9
Commitments and contingent liabilities (Note 12)
Stockholders’ equity (Note 13):
Preferred stock, $0.01 par value, 12.0 shares authorized; no shares issued in 2015 or 2014	—			—
Common stock, $0.01 par value, 600.0 shares authorized in 2015 and 2014; 286.3 shares issued in 2015 and 2014; and 226.8 and 231.5 shares outstanding in 2015 and 2014, respectively	2.9			2.9
Common stock held in employee benefit trust, at cost; 0.2 shares in 2015 and 2014	(7.0		)	(8.0		)
Treasury stock, at cost, 59.4 and 54.6 shares in 2015 and 2014, respectively	(1,607.8		)	(1,431.1		)
Capital in excess of par value of common stock	759.0			731.9
Retained earnings	4,237.4			3,844.3
Accumulated other comprehensive loss	(872.7		)	(683.7		)
Total FMC Technologies, Inc. stockholders’ equity	2,511.8			2,456.3
Noncontrolling interests	19.1			21.4
Total equity	2,530.9			2,477.7
Total liabilities and equity	$	6,437.9		$	7,172.1

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

FMC TECHNOLOGIES, INC. AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS



	Year Ended December 31,
(In millions)	2015			2014			2013
Cash provided (required) by operating activities:
Net income	$	394.8		$	705.3		$	506.6
Adjustments to reconcile net income to cash provided (required) by operating activities:
Depreciation	179.5			170.8			156.0
Amortization	72.1			61.7			53.8
Employee benefit plan and stock-based compensation costs	81.8			89.3			93.5
Deferred income tax provision (benefit), net	12.1			(18.1		)	(20.4		)
Unrealized loss (gain) on derivative instruments	59.5			54.4			(5.7		)
Impairments	66.5			—			—
Gain on sale of Material Handling Products	—			(84.3		)	—
Other	44.9			10.8			30.4
Changes in operating assets and liabilities, net of effects of acquisitions:
Receivables, net	395.0			(243.0		)	(391.0		)
Inventories, net	238.0			(99.4		)	(28.9		)
Accounts payable, trade	(154.5		)	33.8			103.8
Advance payments and progress billings	(234.7		)	225.0			329.0
Income taxes payable, net	(129.7		)	16.2			77.3
Payment of Multi Phase Meters earn-out consideration	—			(43.6		)	(32.2		)
Accrued pension and other post-retirement benefits, net	(24.8		)	(32.0		)	(60.1		)
Other assets and liabilities, net	(68.1		)	45.6			(16.7		)
Cash provided by operating activities	932.4			892.5			795.4
Cash provided (required) by investing activities:
Capital expenditures	(250.8		)	(404.4		)	(314.1		)
Investments in joint ventures	(34.5		)	(3.0		)	(2.0		)
Proceeds from sale of Material Handling Products, net of cash divested	—			105.6			—
Other	10.1			16.7			4.5
Cash required by investing activities	(275.2		)	(285.1		)	(311.6		)
Cash provided (required) by financing activities:
Net increase (decrease) in short-term debt	(0.7		)	(25.8		)	8.5
Net decrease in commercial paper	(131.9		)	(32.3		)	(168.4		)
Proceeds from issuance of long-term debt	—			—			26.2
Repayments of long-term debt	(1.2		)	(1.6		)	(136.0		)
Purchase of treasury stock	(186.2		)	(247.6		)	(116.3		)
Payment of Multi Phase Meters earn-out consideration	—			(31.0		)	(25.1		)
Acquisitions, payment of withheld purchase price	(9.6		)	—			—
Payments related to taxes withheld on stock-based compensation	(8.8		)	(13.0		)	(17.5		)
Other	(7.2		)	(4.1		)	6.3