EDGAR 10-K Filing

Company CIK: 1021860
Filing Year: 2021
Filename: 1021860_10-K_2021_0001564590-21-005708.json

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ITEM 1. BUSINESS
ITEM 1.
BUSINESS
General
NOV Inc. (“NOV” or the “Company”) is a leading independent equipment and technology provider to the global energy industry. Originally founded in 1862, NOV and its predecessor companies have spent 159 years helping transform oil and gas field development and improving its cost-effectiveness, efficiency, safety, and environmental impact. Over the past few decades, the Company has pioneered and refined key technologies to improve the economic viability of frontier resources, including unconventional and deepwater oil and gas. More recently, by applying its deep expertise and technology, the company has helped advance the transition toward sustainable energy.
NOV’s extensive proprietary technology portfolio supports the industry’s full-field drilling, completion, and production needs. With unmatched cross-segment capabilities, scope, and scale, NOV continues to develop and introduce technologies that further enhance the economics and efficiencies of energy production, with a focus on automation, predictive analytics, and condition-based maintenance.
NOV serves major-diversified, national, and independent service companies, contractors, and energy producers in 61 countries, operating under three segments: Wellbore Technologies, Completion & Production Solutions, and Rig Technologies.
Business Strategy and Competitive Strengths
NOV’s primary business objective is to generate above-average long-term capital returns and further enhance its position as a leading independent global energy technology and equipment provider by delivering technologies, equipment, and services that help lower the marginal cost and environmental footprint associated with energy development and production from oil, gas, and renewable sources. NOV is executing the following competitive strategies:
Leverage NOV’s advantages of size, scope, scale, and market position
NOV’s position as a leading independent global energy technology and equipment provider affords several competitive advantages, including:
Economies of scale in procurement and manufacturing. NOV’s global leadership and footprint, spanning almost every major petroleum market, provides the Company with economies of scale, enabling development of a unique global supply chain, which allows materials procurement from lower-cost sources. The Company’s global manufacturing footprint and diverse production flexibility also enables NOV to rapidly adapt to demand changes, efficiently leverage manufacturing capacity in high-demand areas, and manufacture goods in lower-cost jurisdictions. NOV’s geographic diversity also reduces potential revenue volatility from shifts in activity location, regional differences in energy prices, and adverse weather events.
Scope and scale for distribution and marketing. With operations in 61 countries, NOV has developed an efficient worldwide distribution network and relationships with virtually every petroleum producer, service company, and contractor. NOV uses its customer relationships and distribution capabilities to accelerate the commercialization of new products and technologies. NOV also routinely develops technologies for the global marketplace where the Company’s infrastructure allows for quick market penetration and creation of a first-mover advantage with standardized operations around certain products.
Reputation, experience, and benefits of fleet standardization. NOV’s reputation and experience make its products a lower-risk purchase for customers. The Company benefits from customer efforts to standardize training, maintenance, and spare parts, resulting in reduced downtime and inventory-stocking requirements, lower training costs, and better safety. Customers may prefer standardized equipment from NOV, a well-capitalized market leader with which they can enter into long-term service agreements that offer big-data analytics and condition monitoring to maximize uptime and reduce the total cost of equipment ownership.
Large installed base of equipment. As a leading original equipment manufacturer (“OEM”) for oil and gas operations, NOV is well positioned to provide aftermarket support for its large base of installed equipment. Most service companies prefer, and many of their customers demand, OEM aftermarket support. Customers frequently encounter higher risk and cost when they purchase and use potentially incompatible products from different vendors, particularly where products must interact through complex interfaces, which are common sources of failures and unplanned costs. Additionally, certain past events have increased the industry’s risk profile with government regulatory bodies, which have shown a strong preference for OEM service contractor critical equipment maintenance.
Digital products and technologies. NOV’s size, scale, and breadth of knowledge provide inherent competitive advantages in technology relative to smaller, less-diversified organizations. NOV’s proficiencies in building capital equipment, control systems, sensors, field instrumentation, and data acquisition systems provide for unique comprehensive digital energy solutions development. Additionally, NOV’s well-established, global field-service infrastructure affords the Company a distinct capability and advantage in the commercialization and support required to deploy digital solutions that must collect, aggregate, and transmit field-level data from complex machinery and equipment in harsh environments. NOV is investing considerable time and resources to develop its MaxTM platform and MaxTM edge devices, which enable large-scale collection, aggregation, and big-data analytics of real-time equipment and process data, both at the edge and in the cloud. While this platform’s initial application was a predictive analytics and condition-based equipment-monitoring solution, it is also the edge-focused backbone of the Company’s data services and software solutions and is used for monitoring, analyzing, and optimizing many of the Company’s manufacturing operations.
Develop proprietary technologies and solutions that assist oil and gas operators in reducing their marginal cost of supply
NOV strives to further develop its substantial technology portfolio and is known for developing innovative customer productivity solutions. The Company is well positioned to introduce breakthrough technologies that enhance efficiencies and address industry needs, to generate strong returns. The Company’s cross-business-unit expertise uniquely positions NOV to pioneer proprietary technologies across its business lines. For example, NOV’s Wellbore Technologies and Rig Technologies segments jointly introduced closed-loop drilling technologies, which link real-time data from the well bottom to drilling rig controls and use machine learning to drive greater efficiency. NOV works closely with customers to identify needs, and its technical experts use internal capabilities to develop value-added technologies.
Capitalize on and drive end-market fragmentation
Technology and product availability to all industry participants is a key tenet of NOV’s business model. To the extent NOV can provide equipment and technology products that are equal to or better than those developed by service providers, it will prevent any one organization from having a proprietary advantage and therefore drive fragmentation. This fragmentation expands NOV’s customer base and avoids customer concentration in most of its businesses. NOV has resisted the recent trend toward vertical integration, leaving the Company in an attractive and unique position as the largest global independent technology and equipment provider to the oilfield service sector. Governments in certain international markets are pursuing initiatives that drive local content and greater local employment. These actions will likely prompt more local startup enterprises, further expanding demand for NOV’s equipment.
Leverage core capabilities and competencies to assist customers in efforts to reduce environmental footprint and advance energy transition initiatives
NOV’s engineering expertise, complex global supply chain management, low-cost manufacturing, and large-scale energy infrastructure development support provide unique capabilities to assist customers with energy transition advancement. The Company has pioneered numerous innovations that help reduce emissions, including its recently-introduced Ideal eFrac™ equipment, which significantly reduces emissions and lowers costs associated with hydraulic stimulation, and its PowerBlade™ Kinetic Energy Recovery System, which recaptures energy from cranes, winches, and draw-works. NOV is also a leading geothermal equipment and technology provider, offering a broad array of tools and equipment specifically designed for the ultra-harsh conditions associated with geothermal development. Additionally, with expertise in offshore heavy-lift equipment and naval architectural design, the Company is the leading equipment and technology provider for purpose-built vessels used to build, install, and maintain offshore wind towers and turbines. While NOV’s research and development includes efforts in land and offshore-based wind, solar power, hydrogen energy, geothermal power, and carbon capture and sequestration, the Company sees the most promise in development and commercialization of novel products and technologies to improve the efficiencies and economics of land and offshore-based wind, geothermal power generation, and carbon capture and sequestration (See “Energy Transition” below).
Employ a capital-light business model with the ability to quickly scale operations
NOV’s manufacturing facilities require relatively low investment and maintenance expenses versus the sales they enable. NOV manufactures a diverse line of products and improves efficiency by shifting production runs to high-demand or lowest-cost facilities. The Company also benefits from a customer base requiring technically complex equipment for use in extreme environments. Using sophisticated tools to precisely place a wellbore several miles into the earth, and then physically cracking open reservoir rock using large volumes of highly abrasive fluids pumped at extremely high pressures, is incredibly rough on equipment, creating recurring sales opportunities for equipment replacement and aftermarket sales and service.
NOV’s infrastructure leverages the energy industry’s cyclicality. As commodity prices rise, the industry typically enters an expansionary phase, and equipment orders increase. NOV is able to ramp up manufacturing capacity quickly to capture the up-cycle value while meeting customer demand. During down-cycles, the Company’s focus is internal efficiency and technological advancement. NOV’s continuous pursuit of cyclical technological initiatives enhances its ability to drive long-term customer and shareholder value. The Company also outsources non-critical
machining operations with lower tolerance requirements during increased activity and brings the machining operations back into Company-owned facilities during down-cycles for lower cost and effective utilization.
Employ a conservative capital structure with ample liquidity to capitalize on volatility associated with the oil and gas industry
NOV maintains a conservative capital structure with an investment-grade credit rating and ample liquidity. The Company carefully manages its capital structure by continuously monitoring cash flow, capital spending, and debt capacity. Maintaining financial strength inspires confidence from customers who make large purchase commitments delivered over multi-year timeframes and who expect NOV to support their equipment with OEM aftermarket parts and services for decades to come. NOV’s strong balance sheet provides flexibility to execute its strategy, including advancing technological offerings, through industry volatility and commodity price cycles. The Company intends to maintain a conservative approach to balance sheet management to preserve operational and strategic flexibility.
Energy Transition
As a leading independent global energy technology and equipment provider, NOV can be a key participant in the world’s transition to a low-carbon future. While oil and gas will remain critical to many parts of the global economy, the transition to clean, carbon-neutral energy sources represents an enormous economic opportunity for organizations that can improve the economic competitiveness of renewable energy. The International Energy Agency estimates that approximately $71 trillion, or $3.4 trillion per year, must be spent by 2040 in order for global CO2 emissions to decline 50 percent as outlined in the Paris Agreement. NOV is working to develop proprietary solutions to improve project execution, drive higher capital returns, and lower levelized costs of energy (“LCOE,” which is a measure of the average net present cost of electricity generation over a source’s lifetime) associated with renewable energy.
Fixed Offshore Wind
NOV has drawn on its expertise in oil and gas jack-up vessel design, robust aftermarket network, and strong reputation in marine equipment design to become the leading global equipment and design provider for offshore wind turbine installation vessels. NOV’s comprehensive offerings include designing and manufacturing critical jacking systems, cranes, and mooring equipment; developing and licensing vessel designs; working closely with shipyards to install and commission equipment on wind installation vessels; and aftermarket parts, service, and repair. The Company expects an upcoming growth period in the global offshore wind installation vessel market, driven primarily by the need for larger vessels required to support the installation of wind turbines with increasingly large rotor diameters, nacelle weights, and hub heights. The vessels required to install modern, heavier nacelles at higher hub heights are similar to those previously designed by NOV and are relatively consistent across global geographies. Additionally, as U.S. fixed offshore wind projects approach final permitting approval, the need for Jones Act-compliant wind installation vessels will become more urgent. As a result, the Company is well-positioned to capture additional orders associated with future newbuild wind installation vessels.
Floating Offshore Wind
The nascent floating offshore wind market presents one of the great renewable resource opportunities of the next decade. NOV is actively developing new products and technologies to support this industry alongside its legacy portfolio, which includes cranes, winches, mooring systems, cable-lay systems, ballasting systems, and chain connectors and tensioners. NOV has developed a patent-pending Tri-Floater semi-submersible floating foundation that requires less steel than competing offerings. NOV is also designing several proprietary lifting and handling tools for streamlined turbine component installation. Today, the floating offshore wind market sits in the pre-commercial development phase, with industry players focused on proofs of concept and mitigating execution risk. NOV is working to become a value-added partner capable of meaningfully reducing project execution risk by leveraging the Company’s broad and growing portfolio of relevant technology, extensive track record of successfully managing complex marine projects, relationships with global shipyards, and robust global supply chain accustomed to stringent quality and traceability.
Onshore Wind
NOV is developing technology to lower onshore wind’s LCOE by economically constructing increasingly tall wind towers. Higher hub heights allow turbines to reach stronger winds, significantly increasing energy capture, lowering energy cost, and expanding the regions where wind projects can be profitably developed. Higher hub heights are also required for larger, more efficient turbines. The combination of larger turbines and steadier, higher winds improves wind farm economics. Consequently, wind turbine size and tower height have been increasing steadily for several years. NOV’s core design and manufacturing competencies for large, industrial capital equipment, including cranes, lifting tools, and rotating machinery, uniquely position NOV to develop fit-for-purpose wind components and installation equipment to facilitate building onshore wind turbines at higher hub heights.
In 2019, NOV acquired a minority interest in Keystone Tower Systems (“KTS”), which has developed a patented tapered spiral-welding process that enables automated wind tower section production. The proprietary process significantly decreases tower section production times and reduces costs. Additionally, the process enables in-field manufacturing operations, which can reduce costs and eliminate many logistical limitations of transporting the
larger-diameter sections necessary for tall tower developments. KTS’s first commercial line is currently under construction within NOV’s facility in Pampa, TX.
NOV is developing a fit-for-purpose onshore wind tower erection system. Constructing onshore wind towers currently requires large crawler cranes, which provide advantaged mobility at low and moderate hub heights but are significantly less efficient at high hub heights. NOV’s technology, built upon the intellectual property, control systems, and experience developed through mobile desert and arctic drilling rig design, uses a tower crane in conjunction with a unique mobility system. This patent-pending combination creates a structurally-sound, mobile tower crane that is expected to significantly improve the safety, reliability, and efficiency of tall wind tower installation processes.
Geothermal
Today, many of NOV’s oil and gas products are used for drilling geothermal wells which produce steam that turns surface-mounted turbines to generate electricity. NOV’s top drives, blowout preventers, drill pipe, drill pipe inspection and coating, liner hangers, completion tools, drill bits, and full land rig packages have been a critical part of global geothermal development. Further, with geothermal power generation’s recently renewed traction, NOV has developed new proprietary products that address many unique geothermal production challenges and is investigating certain novel geothermal energy forms that could expand the worldwide geothermal power generation market.
Carbon Capture and Sequestration
NOV is positioned to play a vital role in the growing carbon capture and sequestration industry. Technology from NOV’s Wellstream Processing business enables CO2-from-hydrocarbon separation, dehydration, and liquification, all vital parts of the carbon capture chain. In addition, the APL business’s turret and mooring systems facilitate the development of offshore carbon re-injection sites.
Lowering the Carbon and Environmental Footprint of the Oil & Gas Industry
NOV is committed to providing products and services that economically reduce carbon intensity and deliver superior performance. The Company has pioneered numerous solutions for improving the industry’s safety and environmental footprint, including NOV’s closed-loop solids control and thermal desorption systems, dual-containment flowline technologies, solar pumping systems, and hydrocarbon leak detection systems, among others. NOV remains committed to reducing emissions and improving industry sustainability.
NOV’s recently-introduced PowerBlade™ Kinetic Energy Recovery System is a regenerative braking technology that utilizes both flywheel energy and lithium-ion battery energy storage to significantly reduce fuel consumption and emissions associated with drilling and hoisting. The PowerBlade™ system captures and regenerates electrical energy that would have previously dissipated as heat when a drawworks, crane, or winch slows and stops. The PowerBladeTM system then returns this energy when needed.
NOV also recently introduced its Ideal eFrac™ fleet, delivering advanced well stimulation technology to dramatically reduce emissions and decrease ownership cost. The patent-pending Ideal eFrac™ system enhances wellsite safety by reducing complexity and removing personnel from hazardous environments. In addition to lower operating emissions and greater power density, the Ideal eFrac™ system is less disruptive to neighboring communities due to its reduced noise and smaller footprint, requiring 40 percent fewer truckloads for delivery.
Business Segment Overview
Wellbore Technologies provides the critical technologies, equipment, and services required to maximize customer oil and gas drilling efficiencies and economics. The segment contains the following business units:
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Downhole is a leading independent drilling and intervention equipment supplier with engineering teams, manufacturing facilities, supply hubs, and service centers situated in oil and gas activity regions with a constantly-evolving product portfolio that includes downhole drilling motors, SelectShiftTM motors,
agitator systems, and fishing and thru-tubing tools. Downhole’s offerings enable significant efficiency increases in drilling, workover, and intervention.
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Tuboscope is a tubular coating and inspection leader, servicing drill-pipe and other oil country tubular goods (“OCTG”) such as casing, production tubing, and line pipe. With an 80-year track record, Tuboscope offers a fully integrated inspection, coating, and repair process that enables critical OCTG customer confidence. In addition, Tuboscope offers artificial lift rod solutions, line-pipe connection systems, pipe thread protection systems, and RFID technology for complete drill-pipe lifecycle management.
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Grant Prideco is a leading premium drill-stem tubular manufacturer. With an integrated supply chain and an array of premium drill-pipe connections, Grant Prideco offers one-stop shopping. Grant Prideco leverages its expertise in metallurgy and connection technologies to offer an innovative product portfolio ranging from the simplest vertical land well to deepwater, extended-reach, high-pressure/high-temperature, and factory-drilling applications.
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IntelliServ is the only commercial telemetry network enabling real-time broadband data transmission for instantaneous two-way communication between the bottomhole assembly and surface control system utilizing wired drill-pipe. IntelliServTM telemetry enables real-time information, real-time bottom-hole pressure monitoring, and significant rig-time savings as surveys, downlinks, slide orientations, and other data-driven activities are performed in seconds.
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Directional Drilling Technologies is a designer and manufacturer of downhole tools and technologies for directional drilling operations. Directional Drilling Technologies’ measurement-while-drilling tools enable real-time wellbore location monitoring, and its logging-while-drilling tools provide real-time critical formation data. Its rotary-steerable-systems, including tools with closed-loop directional control, enable directional well trajectory drilling at high rates of penetration with limited surface interaction. As an independent supplier, Directional Drilling Technologies provides critical technologies required for efficient directional well drilling and enables service companies, drilling contractors, and E&P operators worldwide to deliver productive wells cost-effectively and reliably.
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WellSite Services is a leading provider of solids control and waste management equipment and services, advanced wellhead cellar systems, managed-pressure-drilling systems, and wellsite logistics solutions. WellSite Services manufactures, sells, and rents highly-engineered solids control equipment and provides field services that improve customers’ bottom line by efficiently separating solids and reclaiming drilling fluids for reuse. After separating drill cuttings, WellSite Services provides waste management (both onsite and at centralized locations), including transport and storage. Additionally, Wellsite Services provides water management solutions, and managed pressure drilling services, combined with a network of wellsite experts who support operators in bringing their wells in on-time and on-budget. WellSite Services offers diversified resources to help manage the full wellsite lifecycle from initial preparation and cellar installation to worksite abandonment and remediation, including generators, temperature-control equipment, and other wellsite accessories.
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ReedHycalog is a premier technical provider of performance-engineered drill bits and borehole enlargement products to help operators improve well construction efficiency and economics. The specialized product base centers on directly breaking the rock during rotary drilling operations, primarily through design, manufacturing, sales and rentals of high-quality, customized fixed cutter drill bits and the use of industry-leading cutter technology. The portfolio also includes roller cone drill bits, borehole enlargement tools that excel in the most demanding applications, and geographically focused coring tools and services.
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M/D Totco is a leading independent oilfield digital solutions provider offering the full spectrum of sensors (both surface and downhole), data acquisition units, data aggregation, remote transmission, and analytics. Supported by a global field service infrastructure, M/D Totco’s ability to deliver real-time data, edge analytics, and digital solutions around critical parameters improves customer wellsite safety and operational efficiency. Using IntelliServ high-speed wired drill-pipe telemetry services, M/D Totco harnesses NOV’s unique ability to connect downhole tools with surface equipment to enable the world’s first closed-loop drilling automation and optimization solutions, using heuristic functions and machine-learning capabilities to transform drilling performance.
Completion & Production Solutions provides critical technologies to optimize the well completion process and production phase of a well’s lifecycle. Completion & Production Solutions business units include:
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Intervention and Stimulation Equipment (“ISE”) designs and manufactures capital equipment and related consumables for oilfield pressure pumpers and coiled tubing, wireline, and well testing/flowback service companies. For hydraulic stimulation jobs, ISE’s manufacturing and assembly includes value-add technologies and complex process equipment, such as hydration units, chemical additive systems, blenders, and control systems. In addition, the business unit produces essential consumables to support pressure pumping spreads, including centrifugal pumps, valves, seats, and flowline equipment. Along with providing surface well-testing and flowback equipment for ultimate production assurance, the unit designs and manufactures cement pumping, mixing, transport, and storage equipment for well construction. ISE is also a leading provider of coiled tubing units and strings, pressure control and nitrogen support equipment, injector heads, and snubbing units. The business unit designs and manufactures wireline products for electric and slickline applications, including critical pressure control equipment like wireline lubricators. With integrated control systems, including condition-based maintenance solutions in engineered equipment and other digital offerings, ISE extends equipment life through real-time analytics, prevents non-productive time, and provides remote operations monitoring. ISE supports all its equipment with comprehensive repair, recertification, and other services through an unmatched global aftermarket facilities network.
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Fiber Glass Systems (“FGS”) leads the market in the design, manufacture, and delivery of high-end composite piping systems, pressure vessels, tanks, and structures engineered to solve both corrosion and weight challenges. With manufacturing facilities spanning five continents and a sales and distribution network covering 40 countries, FGS serves a wide array of applications. In addition to oil and gas products, including composite downhole tubing and casing, high-pressure line pipe, spoolable pipe, and tanks, FGS supplies the marine and offshore industry with piping systems, scrubbers, and structural components such as handrails and grating. FGS also supplies packaged, UL-certified fiberglass pipe and tank solutions to the fuel handling market, as well as supporting chemical, industrial, and mining applications with corrosion and abrasion-resistant piping systems, tanks, and structural components.
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Process and Flow Technologies (“PFT”) provides integrated processing, production, and pumping equipment to energy producers. For the production space, PFT manufactures reciprocating, multistage, and progressive cavity pumps, as well as artificial lift support systems. For the midstream space, PFT manufactures closures and transfer pumps. For fluid processing, PFT designs and manufactures integrated systems that provide water treatment, separation, sand management, hydrate inhibition, and gas processing for use both on and offshore. Building on its processing equipment portfolio, PFT offers comprehensive floating production systems, including turret mooring and topside process modules that minimize execution risk and maximize operability and crew safety. PFT can partner with operators from concept to deployment or operate as the equipment provider to both end customers and engineering, procurement, and construction (“EPC”) firms. PFT, along with alliance partners, offers complete technology, engineering, and project management to supply comprehensive topside solutions for floating production, storage, and offloading (“FPSO”) vessel projects.
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Subsea Production Systems (“SPS”) provides technical innovation to reduce cost and improve subsea infrastructure and customer productivity. The business unit manufactures flexible subsea pipe systems designed to operate worldwide in demanding offshore conditions. Flexible pipes are highly engineered, complex, helically wound structures composed of multiple unbonded steel and composite layers, allowing them to withstand the demanding pressures and tensile loads of deepwater production while remaining resistant to wave- and tidal-induced fatigue. SPS also provides an assortment of critical subsea production equipment, such as water injection and tie-in connector systems, subsea storage units, and other related products.
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XL Systems (“XLS”) provides integral and weld-on connectors for oil and gas applications, including conductor strings, surface casing, and liners, with diameters ranging from 16 to 72 inches. XLS is the sole provider of a proprietary line of wedge thread connections on large-bore pipe. In addition, XLS supplies connector products with threads machined on high-strength forging material and then welded to the pipe.
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Completion Tools solves the most pressing needs of the global completions marketplace, including lowering well cost through operational efficiency maximization, significant water consumption reduction, and increased production and ultimate recovery. Completion Tools’ technologies include multistage frac products, such as its proprietary BPSTM (Burst Port System), VapRTM dissolvable frac plug, i-Frac CEMTM multistage frac sleeve, VoyagerTM Open Hole frac sleeve, and BullmastiffTM frac system, which incorporates sand-control capabilities. The breadth of these offerings provides customers with optimal solutions for their application. Completion Tools also provides well construction technologies, including liner hangers and real-time optimization solutions such as iConTM RT.
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Industrial Pumps and Mixers is a leading provider of specialized, technology-driven progressive cavity pumps and mixers for moving high-viscosity liquids for a variety of attractive end markets with high failure cost. Products include progressive cavity pumps for sludge movement, fluid metering, and sanitation sold under the Moyno and Mono brands; and industrial and static mixers, homogenizers, mixing systems, impellers, and agitators sold under the Chemineer, Kenics, Greerco, and Prochem brands. Marketed under globally recognized brands known for quality and reliability and backed by more than 75 years of advanced fluid-handling experience, Industrial Pumps and Mixers serves a wide breadth of end markets, including food and beverage, water/wastewater, chemical, mineral processing, pulp & paper, pharmaceutical, and general industrial processes.
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Pole Products provides premium products to support connectivity, lighting, and power for municipal and residential applications, including 5G, smart-city infrastructure, roads and highways, and energy-grid modernization. The business unit is a national leading manufacturer of premium spun-cast concrete, tapered steel, and innovative fiberglass poles for diverse applications. Known for durability, aesthetic design, superior lead times, and differentiated field services, Pole Products provides bundled installed products to the telecom, utility, and transportation infrastructure markets.
Rig Technologies is the global leader in the engineering, manufacturing, and support of advanced drilling equipment packages and related capital equipment for oil and gas wells. The segment also designs, builds, installs, and supports renewable energy equipment and technology, with a focus on wind and solar. Rig Technologies operates two business units:
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Rig Equipment designs, manufactures, and sells land rigs, complete offshore drilling packages, and rig components designed to mechanize and automate complex drilling rig processes, including the NOVOSTM automation control system and ATOMTM RTX Robotics solutions. Rig Equipment’s portfolio includes designs that changed the way rigs are operated, such as the TDS top drive drilling system and automated roughneck. The product portfolio has evolved with market needs and includes solutions to reduce energy consumption and enable energy regeneration, resulting in reduced drilling environmental impact. The business unit also provides comprehensive aftermarket products and services to maximize rig fleet drilling uptime and reduce total cost of ownership through big-data analytics, condition monitoring, and digital solutions like TrackerVisionTM and eHawkTM that enable efficient remote support. Aftermarket offerings include upgrades of existing equipment and systems, spare parts, repair, and rentals, as well as comprehensive remote equipment monitoring, technical support, field service, and customer training through an extensive aftermarket facilities network strategically located in major drilling areas around the world.
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Marine Construction designs, engineers, and manufactures heavy-lift cranes; a large range of knuckle-boom and lattice-boom cranes, including active heave options; mooring, anchor, and deck-handling machinery; a full range of jacking systems both for drilling rigs and wind turbine installation jack-ups; and solutions for installing offshore wind towers and turbines, pipelay, and construction vessel systems. Within Marine Construction, GustoMSC provides design solutions for drilling jack-ups and floaters, wind turbine installation jack-ups, and floating offshore wind solutions like the TriFloater. Marine Construction serves the oil and gas industry as well as wind energy and other marine-based end markets. This business unit also provides aftermarket support, including upgrades of existing equipment, spare parts, repair and field services.
See Note 16 to the Consolidated Financial Statements for financial information by segment and a geographical revenue and long-lived asset breakout. We have also included a glossary of oilfield terms at the end of Item 1. “Business” of this Annual Report.
Overview of Oil and Gas Well-Construction Processes
The well-construction process starts with an oil and gas operator and its contractors designating a suitable drilling site and placing a drilling rig at the location. The rig’s crew assembles the drill stem, which consists of drillpipe joints, specialized drilling components known as downhole tools, and a drill bit at the end. Modern rigs typically power the drill bit through a drilling motor, which is attached to the bottom of the drill stem and provides rotational force directly to the bit, or a top drive, a device suspended from the derrick that turns the entire drill stem. The evolution of drilling motors and top drives has facilitated operators’ abilities to drill directionally and horizontally as opposed to being limited to the traditional vertical trajectory. The Company sells and rents drilling motors, agitators, drill bits, downhole tools and drill pipe through Wellbore Technologies, and sells top drives through Rig Technologies.
Heavy drilling fluids, or “drilling muds,” are pumped down the drill stem and forced out through jets in the bit. The drilling mud returns to the surface through the space between the borehole wall and the drill stem, carrying with it the rock cuttings drilled out by the bit. The cuttings are removed from the mud by a solids control system (which can include shakers, centrifuges, and other specialized equipment) and disposed of in an environmentally sound manner. The solids control system permits the mud, which is often comprised of expensive compounds, to be continuously reused and re-circulated back into the hole. Rig Technologies sells the large “mud pumps” that are used to pump drilling mud through the drill stem, down, and back up the hole. Wellbore Technologies sells and rents solids control equipment and provides solids control, waste management and drilling fluids services.
Many operators internally coat the drill stem to improve its hydraulic efficiency and protect it from the corrosive fluids sometimes encountered during drilling; have hard-facing alloys applied to drillpipe joints, collars, and other components to protect tool joints and casing against wear; and inspect and assess the integrity of the drillpipe from time to time. Wellbore Technologies manufactures and sells drillpipe and provides coating, “hardfacing,” and drillpipe inspection and repair. As hole depth increases, additional joints of drillpipe are continuously added to the drill stem. When the bit becomes dull or the equipment at the bottom of the drill stem - including the drilling motors - otherwise requires servicing, the entire drill stem is pulled out of the hole and disassembled by disconnecting the joints of drillpipe. These are set aside or “racked,” the old bit is replaced or service is performed, and the drill stem is reassembled and lowered back into the hole (a process called “tripping”). During drilling and tripping operations, joints of drillpipe must be screwed together and tightened (“made up”), and loosened and unscrewed (“spun out”), a process that can create a considerable amount of stress on the pipe connections while also being quite time consuming. Rig Technologies provides drilling equipment to manipulate and maneuver the drillpipe in an efficient and safe manner, and Wellbore Technologies manufactures premium connections that are designed to reduce failure downhole and improve the rate of connection on the rig floor. When the hole has reached a specified depth, all the drillpipe is pulled out of the hole, and larger-diameter pipe known as casing is lowered into the hole and permanently cemented in place in order to protect against collapse and contamination of the hole. The casing is typically inspected before it is lowered into the hole, another service provided by Wellbore Technologies. Hole openers from Wellbore Technologies, which mount above the drill bits in the drill stem, open the tolerance of the hole to allow for easier and faster casing installation. Completion & Production Solutions manufactures cement mixing and pumping equipment that is used to cement the casing in place. The rig’s hoisting system raises and lowers the drill stem while drilling or tripping, and lowers casing into the wellbore. A conventional hoisting system is a block-and-tackle mechanism that works within the drilling rig’s derrick. The mechanism is lifted by a series of pulleys that are attached to the drawworks at the base of the derrick. Rig Technologies sells and installs drawworks and pipe hoisting-systems.
During the course of normal drilling operations, the drill stem passes through different geological formations that exhibit varying pressure characteristics. If this pressure is not contained, oil, gas, and/or water would flow out of these formations to the surface. Containing reservoir pressures is accomplished primarily by the circulation of heavy drilling muds and secondarily by blowout preventers (“BOPs”), should the mud prove inadequate. Drilling muds are carefully designed to exhibit certain qualities that optimize the drilling process. In addition to containing formation pressure, they must provide power to the drilling motor; carry drilled solids to the surface; protect the drilled formations from being damaged; and cool the drill bit. Achieving these objectives often requires a formulation specific to a given well, requires a high level of cleanliness for better bottomhole assembly, and can involve the use of expensive chemicals as well as natural materials, such as certain types of clay. The fluid itself is often oil or more expensive synthetic mud. Given the cost, it is highly desirable to reuse as much of the drilling mud as possible. Solids control equipment such as shale shakers, centrifuges, cuttings dryers, and mud cleaners help accomplish this objective. Wellbore Technologies provides drilling fluids and rents, sells, operates, and services
solids control equipment. Rig Technologies manufactures pumps that power the flow of the mud and fluid downhole and back to the surface. Drilling muds are formulated based on expected drilling conditions. However, as the hole is drilled, the drill stem may encounter a high-pressure zone where the mud density is inadequate to maintain sufficient pressure. Should efforts to “weight up” the mud to contain such a pressure kick fail, a blowout could result, whereby reservoir fluids would flow uncontrolled into the well. A series of BOPs are positioned at the top of the well and, when activated, form tight seals that prevent the escape of fluids to the surface. Conventional BOPs prevent normal rig operations when closed so the BOPs are activated only if drilling mud and normal well control procedures cannot safely contain the pressure. Rig Technologies engineers and manufactures BOPs.
The operations of the rig and the condition of the drilling mud are closely monitored by various sensors, which measure operating parameters such as the weight on the rig’s hook, the incidence of pressure kicks, the operation of the drilling mud pumps, weight on bit, etc. Wellbore Technologies sells and rents drilling rig instrumentation packages that perform these monitoring functions as well as additional sensors that continuously collect downhole data that can be transmitted back to the surface via wired drill pipe. Wellbore Technologies’ also offers drilling optimization and automation software and services that utilize this downhole data to maximize drilling performance by mitigating vibrations, dynamic and impact loading, and stick-slip, which ensures longer bit runs, and reduces the number of necessary trips.
During drilling operations, the drilling rig and related equipment and tools are subject to severe stresses, pressures, and temperatures, as well as a corrosive environment, and require regular repair and maintenance. Rig Technologies supplies spare parts and can dispatch field service engineers with the expertise to quickly repair and maintain equipment, minimizing down time.
Once a well has been drilled, cased, and cemented, and the operator determines hydrocarbons are present in commercial quantities, the well is then completed, and sometimes stimulated. After the casing is cemented in place, the well undergoes one of several completion processes to open the bottom of the wellbore and allow hydrocarbons to flow from the reservoir and up the well to the surface. The most commonly used technique is known as perforation. The perforating process entails lowering a string of shaped charges to the desired depth in the well using an electric wireline unit and firing the charges to perforate the casing or liner. Wireline units are also used to perform logging operations and other intervention services. At this point, the operator may decide, based on well design and flow rate, to further enhance production by stimulating the well. Unconventional wells almost always require stimulation through multi-stage hydraulic fracturing, a process by which a fluid or slurry is pumped down the well by large pumping units. This causes the underground formation to crack or fracture, opening up space for hydrocarbons to flow more freely out of tight rock formations. A proppant is suspended in the fluid and lodges in the cracks, propping them open and allowing hydrocarbons to flow after the fluid is gone. A coiled tubing unit is often used to drill out bridge plugs that isolate the many stages needed to stimulate a horizontal well. A coiled tubing unit utilizes a large continuous length of steel tubing to enter and traverse long laterals and perform completion and well remediation operations. As drilling laterals have lengthened in recent years, many operators are electing to use larger high-specification well service rigs to assist in several phases of the completion phase by conveying tools downhole and drilling out completion plugs. Workover rigs are similar to drilling rigs in their capabilities to handle tubing but are usually smaller and somewhat less sophisticated. Completion & Production Solutions provides the essential equipment necessary for the entirety of the completion and stimulation process, designing and manufacturing coiled tubing units, wireline units, pressure pumping equipment, completion tools, snubbing units, nitrogen units, and treating iron. In addition, the well completion process creates a large amount of wear and tear on the equipment used, which creates healthy demand for Completion & Production Solutions’ aftermarket services. The use of coiled tubing and wireline equipment typically requires the use of a BOP to ensure safety during operations. Completion & Production Solutions manufactures this well control equipment. Due to the corrosive nature of many produced fluids, production tubing is often inspected and coated, services offered by Wellbore Technologies. Increasingly, operators choose to use corrosion-resistant composite materials or alloys in the process, which are also sold by Completion & Production Solutions.
Once the well has been stimulated, it is usually ready to be capped with a production wellhead and linked up to a gathering system where it can begin producing and generating cash flow for the operator. This process is significantly more involved offshore, where pipes are often required to reach thousands of feet from the wellhead back to the surface, contending with tides, debris, and weather. The development of flexible pipe solved many of the issues associated with linking offshore wells back to their respective FPSOs, which serve as gathering hubs, sometimes in some of the most remote areas of the world. Completion & Production Solutions manufactures flexible subsea pipe in addition to offering turret mooring systems and topside process modules for FPSOs.
Natural decline rates set in as a well ages, and workover procedures and other services may be necessary to extend its life and increase its production rate. Over time, downhole equipment, casing, or tubing may need to be serviced or replaced. When producing wells require anything from routine maintenance to major modifications and repair, a well servicing rig is typically needed. Workover rigs are used to disassemble the wellhead, tubing and other completion components of an existing well in order to stimulate or remediate the well. As a well continues to mature, its natural reservoir pressure may no longer be enough to force fluids to the surface. Artificial lift equipment is then typically installed, which adds energy to the fluid column in a wellbore using one of several types of pumps. In addition to reduced pressure, the water cut of a well’s production tends to increase as the well ages, which typically requires the addition of water treatment and separation equipment. The Company offers a comprehensive range of workover rigs through Rig Technologies. Tubing and sucker rods removed from a well during a well remediation operation are often inspected to determine their suitability to be reused in the well, a service Wellbore Technologies provides. Completion & Production Solutions offers several types of artificial lift and related support systems as well as integrated systems that provide water treatment, separation, hydrate inhibition, and gas processing.
Markets and Competition
The Company’s customers are predominantly service companies, oil and gas companies, and shipyards. Products within Wellbore Technologies and Completion & Production Solutions are sold and rented worldwide through NOV’s sales force and through commissioned representatives. Substantially all of Rig Technologies’ capital equipment and spare parts sales, and a large portion of smaller pumps and parts sales, are made through NOV’s direct sales force and distribution service centers. Sales to foreign oil companies are often made with or through representative arrangements.
The Company’s competition consists primarily of publicly traded oilfield service and equipment companies and smaller independent equipment manufacturers in the oil and gas, industrial, and renewable energy equipment markets.
The Company’s foreign operations, which include significant operations in the Middle East, Africa and Latin America, Russia, the Far East, Canada and Europe are subject to the risks normally associated with conducting business in foreign countries, including foreign currency exchange risks and uncertain political and economic environments, which may limit or disrupt markets, restrict the movement of funds or result in the deprivation of contract rights or the taking of property without fair compensation. Government-owned petroleum companies located in some of the countries in which the Company operates have adopted policies (or are subject to governmental policies) giving preference to the purchase of goods and services from companies that are majority-owned by local nationals. As a result of such policies, the Company relies on joint ventures, license arrangements, and other business combinations with local nationals in these countries. See Note 16 to the Consolidated Financial Statements for information regarding geographic revenue information.
Influence of Oil and Gas Activity Levels on the Company’s Business
The oil and gas industry has historically experienced significant volatility. Demand for the Company’s products and services depends primarily upon the general level of activity in the oil and gas industry worldwide. Oil and gas activity is in turn heavily influenced by, among other factors, oil and gas prices worldwide. High levels of drilling and well remediation generally spurs demand for the Company’s products and services. Additionally, high levels of oil and gas activity increase cash flows available for oil and gas companies, drilling contractors, oilfield service companies, and manufacturers of OCTG to invest in equipment that the Company sells.
See additional discussion on the current worldwide economic environment and related oil and gas activity levels in Item 1A. “Risk Factors” and Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”
Seasonal Nature of the Company’s Business
Historically, activity levels of some of the Company’s segments have followed seasonal trends to some degree. Extremely harsh winter weather can reduce oilfield operations in far northern or high-altitude locations, including parts of Colorado, Canada, Russia and China, and the annual thaw (or “breakup”) in Canada makes some unimproved roads inaccessible to heavy equipment during part of each second quarter. Both situations temporarily reduce demand for the Company’s products and services in the effected geographic area, although revenues generally recover once conditions improve. Fluctuations in customer’s activity levels caused by national or customary holiday seasons and annual budgetary cycles can also affect their spending levels with the Company, leading to both temporary local decreases and increases in sales. Over the past few years, the Company has seen a more pronounced level of spending during the fourth quarter, and a decline in the first quarter, in certain of its businesses, which it believes is related to annual budgetary cycles. While the Company anticipates that the seasonal and other trends described above may continue, there can be no guarantee that spending by the Company’s customers will continue to follow patterns seen in the past.
Research and New Product Development and Intellectual Property
The Company believes that it has been a leader in the development of new technology and equipment to enhance the safety and productivity of drilling and well servicing processes and that its sales and earnings have been dependent, in part, upon the successful introduction of new or improved products. It also invests in new technologies related to its non-oil and gas business as well as renewable energy-related technologies. Through its internal development programs and certain acquisitions, the Company has assembled an extensive array of technologies protected by a substantial number of trademarks, for both goods and services, patents, trade secrets, and other proprietary rights.
As of December 31, 2020, the Company held a substantial number of granted patents and pending patent applications worldwide, including U.S. patents and U.S. patent applications as well as patents and patent applications in a variety of other countries. Expiration dates of such patents range from 2021 to 2040. Additionally, the Company maintains a substantial number of trademarks for both goods and services and maintains a number of trade secrets.
Although the Company believes that this intellectual property has value, competitive products with different designs have been successfully developed and marketed by others. The Company considers the quality and timely delivery of its products, the service it provides to its customers, and the technical knowledge and skills of its personnel to be as important as its intellectual property in its ability to compete. While the Company stresses the importance of its research and development programs, the technical challenges and market uncertainties associated with the development and successful introduction of new products are such that there can be no assurance that the Company will realize future revenue from new products.
Manufacturing and Service Locations
The manufacturing processes for the Company’s products generally consist of machining, welding and fabrication, heat treating, assembly of manufactured and purchased components, and testing. Most equipment is manufactured primarily from alloy steel. The availability and price of alloy steel castings, forgings, purchased components, and bar stock is critical to the production and timing of shipments.
Wellbore Technologies designs, manufactures, rents, and sells a variety of equipment and technologies used to perform drilling operations, and offers services that optimize their performance, including: solids control and waste management equipment and services, drilling fluids, premium drillpipe, wired pipe, drilling optimization services, tubular inspection and coating services, instrumentation, downhole tools, and drill bits. Primary facilities are located in Houston, Conroe, Navasota, and Cedar Park, Texas; Veracruz, Mexico; and Dubai, UAE.
Completion & Production Solutions designs, manufactures, and integrates technologies for well completions, oil and gas production, and industrial markets. This includes equipment and technologies needed for hydraulic fracture stimulation, including pressure pumping trucks, blenders, sanders, hydration units, injection units, flowline, and manifolds; well intervention, including coiled tubing units, coiled tubing, and wireline units and tools; cementing products for pumping, mixing, transport, and storage; onshore production, including fluid processing, composite pipe, surface transfer and progressive cavity pumps, and artificial lift systems; and offshore production, including integrated production systems and subsea production technologies. Primary facilities are located in Houston, and
Fort Worth, Texas; Tulsa, Oklahoma; Senai, Malaysia; Qingdau, Shandong, China; Kalundborg, Denmark; Superporto du Acu, Brazil; Manchester, England; Nisku, Canada; Dammam, Saudi Arabia; Jiangyan, China; and Aberdeenshire, Scotland, UK.
Rig Technologies provides drilling rig components, complete land drilling rigs, and offshore drilling equipment packages. Primary manufacturing and service facilities are located in Houston, Texas; Mexicali, Mexico; Dubai, UAE; Pune, India; Stavanger, Norway; Kristiansand, Norway; New Iberia, Louisiana; Port Elizabeth, South Africa; Macae, Brazil; Ulsan Korea and Singapore.
Raw Materials
The Company believes that materials and components used in its operations are generally available from multiple sources. The prices paid by the Company for its raw materials may be affected by, among other things, energy, steel, and other commodity prices; tariffs and duties on imported materials; and foreign currency exchange rates. The Company has experienced rising, declining, and stable prices for milled steel and standard grades in line with broader economic activity and has generally seen specialty alloy prices continue to rise, driven primarily by escalation in the price of the alloying agents. The Company has generally been successful in its effort to mitigate the financial impact of higher raw materials costs on its operations by applying surcharges to, and adjusting prices on, the products it sells. Higher prices and lower availability of steel and other raw materials the Company uses in its business may adversely impact future periods.
Backlog
The Company monitors its backlog of orders to guide its planning. Backlog includes orders which typically require more than three months to manufacture and deliver.
Backlog measurements are made on the basis of written orders that are firm but may be defaulted upon by the customer in some instances. Most require reimbursement to the Company for costs incurred in such an event. There can be no assurance that the backlog amounts will ultimately be realized as revenue, or that the Company will earn a profit on backlog work. Backlog for Completion & Production Solutions at December 31, 2020, 2019 and 2018 was $0.7 billion, $1.3 billion and $0.9 billion, respectively. Backlog for Rig Technologies at December 31, 2020, 2019 and 2018, was $2.7 billion, $3.0 billion and $3.1 billion, respectively.
Human Capital
NOV’s 27,631 global, diverse employees use their skill and expertise to provide the products and services that help our customers operate safely, efficiently, sustainably, and competitively. NOV’s team designs and manufactures a broad array of equipment and technology, from some of the heaviest, largest and most complex mobile machines on earth (on and offshore drilling rigs, wind turbine installation ships, and FPSOs) to very small precision sensors and measuring devices.
NOV’s employee base includes:
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Inventors, designers, scientists and engineers (including mechanical, electrical, chemical, hydraulic, materials, computer, software, data analytics, and other disciplines) who design and improve the equipment, electronics, software, services and process that bring value to NOV’s customers.
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Technical sales, marketing and training professionals who educate customers, the industry, and our own organization about NOVs’ many products, services and unique capabilities.
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Supply chain, logistics, warehousing, and quality testing professionals who ensure our factories, workshops, repair centers and field technicians have the right materials and tools to do their jobs efficiently.
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Production and service planners and schedulers, project managers, and process design and Quality Health Safety and Environmental professionals who plan, manage and monitor the activities of our workforce to ensure high-quality, efficient, safe, and environmentally compliant operations.
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Machinists, metal fabricators, welders, assemblers, pipe fitters, riggers, electronics technicians, system integrators, composite material fabricators, paint and industrial coatings specialists, and other skilled
trade professionals who use a wide variety of industrial processes, tools, and techniques to transform raw materials and purchased components into the many products NOV sells.
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Field service engineers, mechanics, and technicians who maintain, service, repair, and upgrade NOV equipment and, in some cases, assist customers with its operation.
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Business leaders and managers who create business strategies and targets, assess goals and priorities, and allocate resources to ensure NOV’s employees have the tools they need to get the job done and further build the Company’s competitive advantages.
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Support function professionals, including: Information Technology, Human Resources, Legal, Compliance, Clerical, and Accounting and Finance who support operations to keep the business infrastructure and administrative burdens flowing.
Thirty-five percent of NOV employees work in the United States, 25% in Europe, 13% in the Asia Pacific region, 12% in Latin America, 9% in the Middle East and Africa, and 3% in each of Canada and China. The Company’s 573 physical locations include various size manufacturing plants, research facilities, machine shops, office buildings, warehouses and distribution centers where between 20 to 1,100 people work and repair shops, rental tool bases, sales offices and other small locations where between 5 to 200 people work. Many NOV employees travel to work at customer locations, including onshore and offshore drilling sites, shipyards, and other industrial locations where equipment needs installation, commissioning, service or repair, or where customers need training or technical support.
NOV’s success depends on these dedicated, skilled hardworking employees. The Company strongly believes that safeguarding and supporting the health, safety, diversity, respect, skills, career satisfaction and wellbeing of NOV’s employees are critical to the success of the business. The Company’s Human Resources and Health Safety and Environmental organizations provide policies, oversight, monitoring, resources, training, and assistance companywide that are designed to foster a culture that embraces this belief.
Safety
Protecting the health and safety of all stakeholders is a core value. NOV maintains comprehensive monitoring and tracking of reportable injuries, reviewed each quarter by our operating Segment Presidents with the CEO, CFO, and Chief HSE Officer (including significant injuries, root cause analysis, and remediation measures). Successful safety programs and campaigns are also shared across the Company’s operations, including:
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Stop Work Authority - all NOV employees have the authority, responsibility, and duty to stop an unsafe act, practice, or job.
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Life Saving Rules - standardized rules aligning NOV with industry partners to reduce the risk of serious injury or death associated with critical hazards in the workplace.
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Fresh-Eyes - program coordinating safety walk-throughs, observations, and improvements at peer NOV facilities.
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Safety stand downs - pausing normal operations for general safety meetings or to address a specific risk.
Health and wellbeing
The Company offers locally competitive health benefits, paid holidays and time off, and retirement benefits to our employees. In the US this includes health, vision and dental insurance, life insurance, disability insurance, a 401(k)-retirement savings plan, an employee assistance program, and a wellness program.
During the COVID-19 pandemic NOV has implemented programs tailored to each location that may include, among other things, working from home, virtual meetings, social distancing, masking, contact tracing and quarantining, facility and machine sanitizing, staggered work shifts, and staggered workdays.
Diversity and inclusion
NOV is committed to maintaining a diverse workforce, individual inclusion, and equal opportunities. The Company believes an employee base with different education, training and life experiences (gender, age, religion, race, ethnicity, cultural background, sexual orientation, language, education, abilities, perspectives, etc.) lead to more
innovative and creative business solutions, more informed decision-making, greater employee engagement, and better retention and recruitment of top talent.
In support of this commitment, NOV has communicated a Diversity and Inclusion Statement from the CEO to our employees and has implemented training programs covering the Company’s Code of Conduct and Business Ethics, Unconscious Bias, and Harassment in the Workplace.
Across NOV’s global workforce, women make up 16% of all employees, 23% of salaried employees, 20% of the C-Suite and hold 22% of the Company’s Board of Directors seats.
Career satisfaction and skills
NOV tracks and monitors data on the employee experience including hiring, turnover, and promotion trends. The Company also obtains employee feedback through ‘pulse’ surveys which measure employee satisfaction across several areas. Human resources managers and business managers across the Company review this information to identify areas for improvement and create remediation strategies.
The Company invests in opportunities for employee education, growth, and development, providing comprehensive training opportunities in technical, managerial, and soft skills. Some programs include: Powering Excellence designed for current and potential business leaders, Supervisor Training and Resources (STAR) and Leading Self and Others designed for new managers, as well as many other courses through the Company’s dedicated Technical Training Centers based in Houston, Singapore, UAE, Norway, UK, and South America.
Available Information
The Company’s principal executive offices are located at 7909 Parkwood Circle Drive, Houston, Texas 77036. Its telephone number is (713) 346-7500. Further information about the Company’s products and services can be found on its website at: www.nov.com. The Company’s common stock is traded on the New York Stock Exchange under the symbol “NOV”. The Company’s annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and all related amendments are available free of charge on the Investor Relations portion of the Company’s website, www.nov.com/investor, as soon as reasonably practicable after such material is electronically filed with, or furnished to, the Securities and Exchange Commission (“SEC”). The Company’s Code of Ethics is also posted on its website.

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ITEM 1A. RISK FACTORS
ITEM 1A.
RISK FACTORS
You should carefully consider the risks described below, in addition to other information contained or incorporated by reference herein. Realization of any of the following risks could have a material adverse effect on our business, financial condition, cash flows and results of operations.
Industry Environment and Operations Related
We are dependent upon the level of activity in the oil and gas industry, which is volatile and has caused, and may cause future, fluctuations in our operating results.
The oil and gas industry historically has experienced significant volatility. Demand for our products and services depends primarily upon the number of oil rigs in operation, the number of oil and gas wells being drilled, the depth and drilling conditions of these wells, the volume of production, the number of well completions, capital expenditures of other oilfield service companies and the level of workover activity. Drilling and workover activity can fluctuate significantly in a short period, particularly in the United States and Canada. The willingness of oil and gas operators to make capital expenditures to explore for and produce oil and natural gas and the willingness of oilfield service companies to invest in capital equipment will continue to be influenced by numerous factors over which we have no control, including the:
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current and anticipated future prices for oil and natural gas;
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volatility of prices for oil and natural gas;
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ability or willingness of the members of the Organization of Petroleum Exporting Countries (“OPEC”) and other countries, such as Russia, to maintain or influence price stability through voluntary production limits;
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sanctions and other restrictions placed on certain oil producing countries, such as Russia, Iran, and Venezuela;
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level of production by non-OPEC countries including production from U.S. shale plays;
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level of excess production capacity;
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cost of exploring for and producing oil and gas;
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level of drilling activity and drilling rig dayrates;
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worldwide economic activity and associated demand for oil and gas;
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public health crises and other catastrophic events, such as the COVID-19 pandemic;
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availability and access to potential hydrocarbon resources;
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governmental political requirements, regulation and energy policies;
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fluctuations in political conditions in the United States and abroad;
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currency exchange rate fluctuations and devaluations;
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development of alternate energy sources; and,
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environmental regulations.
Expectations for future oil and gas prices cause many shifts in the strategies and expenditure levels of oil and gas companies, drilling contractors, and other service companies, particularly with respect to decisions to purchase major capital equipment of the type we manufacture. Oil and gas prices, which are determined by the marketplace, may remain below a range that is acceptable to certain of our customers, which could continue the reduced demand for our products and have a material adverse effect on our financial condition, results of operations and cash flows.
There are risks associated with certain contracts for our equipment.
As of December 31, 2020, we had a backlog of capital equipment to be manufactured, assembled, tested and delivered by Completion & Production Solutions and Rig Technologies in the amount of $0.7 billion and $2.7 billion, respectively. The following factors, in addition to others not listed, could reduce our margins on these contracts, adversely impact completion of these contracts, adversely affect our position in the market or subject us to contractual penalties:
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financial challenges for consumers of our capital equipment;
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credit market conditions for consumers of our capital equipment;
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our failure to adequately estimate costs for making this equipment;
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our inability to deliver equipment that meets contracted technical requirements;
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our inability to maintain our quality standards during the design and manufacturing process;
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our inability to secure parts made by third party vendors at reasonable costs and within required timeframes;
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unexpected increases in the costs of raw materials;
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our inability to manage unexpected delays due to weather, shipyard access, labor shortages or other factors beyond our control;
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the imposition of tariffs or duties between countries, which could materially affect our global supply chain. For example, section 232 tariffs on steel may increase our costs, reduce margins or otherwise adversely affect the Company; and,
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export sanctions, controls or other trade restrictions, which could affect our ability to manufacture, sell, or receive payment for our equipment and/or services.
The Company’s existing contracts for rig and production equipment generally carry significant down payment and progress billing terms favorable to the ultimate completion of these projects and the majority do not allow customers to cancel projects for convenience. However, unfavorable market conditions or financial difficulties experienced by our customers may result in cancellation of contracts or the delay or abandonment of projects. Any such developments could have a material adverse effect on our operating results and financial condition.
Competition in our industry, including the introduction of new products and technologies by our competitors, as well as the expiration of the intellectual property rights protecting our products and technologies, could ultimately lead to lower revenue and earnings.
The oilfield products and services industry is highly competitive. We compete with national, regional and foreign competitors in each of our current major product lines. Certain of these competitors may have greater financial, technical, manufacturing and marketing resources than us, and may be in a better competitive position. The following can each affect our revenue and earnings:
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price changes;
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improvements in the availability and delivery of products and services by our competitors;
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the introduction of new products and technologies by our competitors; and,
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the expiration of intellectual property rights protecting our products and technologies.
We are a leader in the development of new technology and equipment to enhance the safety and productivity of drilling and well servicing processes. If we are unable to maintain our technology leadership position, it could adversely affect our competitive advantage for certain products and services. Our revenues and operating results have been dependent, in part, upon the successful introduction of new or improved products. Through our internal development programs and acquisitions, we have assembled an array of technologies protected by a substantial number of trade and service marks, patents, trade secrets, and other proprietary rights, which expire after a prescribed duration, some at varying times in the near future. The expiration of these rights could have a material
adverse effect on our operating results. Furthermore, while the Company stresses the importance of its research and development programs, the technical challenges and market uncertainties associated with the development and successful introduction of new products are such that there can be no assurance that the Company will realize future revenue from new products.
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 and may distract management from running our core business. Royalty payments under licenses from third parties, if available, would increase our costs. Additionally, developing non-infringing technologies 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 and cash flows.
In addition, certain foreign jurisdictions and government-owned petroleum companies located in some of the countries in which we operate have adopted policies or regulations which may give local nationals in these countries competitive advantages. Actions taken by our competitors and changes in local policies, preferences or regulations could impact our ability to compete in certain markets and adversely affect our financial results.
A significant portion of our revenue is derived from our non-United States operations, which exposes us to risks inherent in doing business in each of the 61 countries in which we operate.
Approximately 73% of our revenues in 2020 were derived from operations outside the United States (based on revenue destination). Our foreign operations include significant operations in every oil producing region in the world. Our revenues and operations are subject to the risks normally associated with conducting business in foreign countries, including:
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uncertain political, social and economic environments;
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social unrest, acts of terrorism, war and other armed conflict;
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public health crises and other catastrophic events, such as the coronavirus outbreak at the beginning of 2020;
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trade and economic sanctions, export controls, and other restrictions imposed by the United States, European Union or other countries;
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restrictions under the United States Foreign Corrupt Practices Act (“FCPA”) or similar legislation, as well as foreign anti-bribery and anti-corruption laws;
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confiscatory taxation, tax duties, complex and everchanging tax regimes or other adverse tax policies;
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exposure to expropriation of our assets and other actions by foreign governments;
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deprivation of contract rights;
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restrictions on the repatriation of income or capital;
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inflation; and,
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currency exchange rate fluctuations and devaluations.
The COVID-19 pandemic and related economic repercussions have had, and are expected to continue to have, a significant impact on our business, and depending on the duration of the pandemic and its effect on the oil and gas industry, could have a material adverse effect on our business, liquidity, consolidated results of operations and consolidated financial condition.
As a result of the COVID-19 pandemic, the Company may be exposed to additional liabilities and risks. The COVID-19 pandemic has resulted in unprecedented governmental actions ordering citizens in the United States and countries around the world to “shelter in place,” closing borders and issuing “stay at home orders,” which curtail travel and commerce. In the United States alone, over 26 million have filed for unemployment benefits during the sharp decline in economic activity resulting from governmental orders.
In 2020, oil demand significantly deteriorated as a result of the virus outbreak and corresponding preventative
measures taken around the world to mitigate the spread of the virus. Also in early 2020 aggressive increases in production of oil by Saudi Arabia and Russia created a significant surplus in the supply of oil. Physical markets became distressed as spot prices were negatively impacted by a lack of available storage capacity. The COVID-19 virus continued to spread during 2020, extending depressed demand, uncertainty and additional spending reductions by the entire oil and gas industry as U.S. rig count fell to its lowest level since 1940 in August despite oil prices beginning to stabilize.
The forced shutdown of economic activity has directly affected our business and has exacerbated the potential negative impact from many of the risks described in our Form 10-K for the year ended December 31, 2019, including those relating to our customers’ capital spending and sharply reduced oil and natural gas prices. Demand for our products and services declined as our customers continued to revise their capital budgets downwards and swiftly adjusted their operations in response to lower commodity prices.
The nature, scale, and scope of the above-described events combined with the uncertain duration and extent of governmental actions prevent us from identifying all potential risks to our business. We believe that the well-known impacts described above, and other potential impacts include, but are not limited to, the following:
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Disruption to our supply chain for materials essential to our business, including restrictions on importing and exporting products;
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Customers may attempt to cancel or delay projects or may attempt to invoke force majeure clauses in certain contracts resulting in a decreased on delayed demand for our products and services;
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Customers may also seek to delay payments, may default on payment obligations and/or seek bankruptcy protection that could delay or prevent collections of certain accounts receivable;
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A credit rating downgrade of our corporate debt and potentially higher borrowing costs in the future;
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A need to preserve liquidity;
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Reduction of our global workforce to adjust to market conditions, including severance payments, retention issues, and an inability to hire employees when market conditions improve;
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Liabilities resulting from operational delays due to decreased productivity resulting from stay-at-home orders affecting its work force or facility closures resulting from the COVID-19 pandemic;
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Liabilities resulting from an inability to perform services due to limited manpower availability or an inability to travel to perform the services;
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Other contractual or other legal claims from our customers resulting from the COVID-19 pandemic;
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Costs associated with rationalization of our portfolio of real estate facilities, including possible exit of leases and facility closures to align with expected activity and workforce capacity;
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Additional asset impairments, including an impairment of the carrying value of our goodwill, along with other accounting charges as demand for our services and products decreases; and,
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Infections and quarantining of our employees and the personnel of our customers, suppliers and other third parties.
Cybersecurity risks and threats could adversely affect our business.
We rely heavily on information systems to conduct our business. Any failure, interruption, or breach in security of our information systems could result in failures or disruptions in our customer relationship management, general ledger systems and other systems. While we have policies and procedures designed to prevent or limit the effect of the failure, interruption or security breach of our information systems, there can be no assurance that any such failures, interruptions or security breaches will not occur or, if they do occur, that any breach or interruption will be sufficiently limited. The occurrence of any failures, interruptions or security breaches of our information systems could damage our reputation, result in a loss of our intellectual property or other proprietary information, including customer data, result in a loss of customer business, subject us to additional regulatory scrutiny, or expose us to civil litigation and possible financial liability, any of which could have a material adverse effect on our financial position or results of operations.
Our ability to hire and retain qualified personnel at competitive cost could materially affect our operations and growth potential.
Many of the products we sell, and related services that we provide, are complex and technologically advanced, which enable them to perform in challenging conditions. Our ability to succeed is, in part, dependent on our success in attracting and retaining qualified personnel to provide service and to design, manufacture, use, install and commission our products. A significant increase in wages paid by competitors, both within and outside the energy industry, for such highly skilled personnel could result in insufficient availability of skilled labor or increase our labor costs, or both. If the supply of skilled labor is constrained or our costs increase, our margins could decrease and our growth potential could be impaired.
Severe weather conditions may adversely affect our operations.
Our business may be materially affected by severe weather conditions in areas where we operate. This may entail the evacuation of personnel and stoppage of services. In addition, if particularly severe weather affects platforms or structures, this may result in a suspension of activities. Any of these events could adversely affect our financial condition, results of operations and cash flows.
An impairment of goodwill or other indefinite lived intangible assets could reduce our earnings.
The Company has approximately $1.5 billion of goodwill and $0.2 billion of other intangible assets with indefinite lives as of December 31, 2020. Generally accepted accounting principles require the Company to test goodwill and other indefinite lived intangible assets for impairment on an annual basis or whenever events or circumstances indicate they might be impaired. Events or circumstances which could indicate a potential impairment include (but are not limited to) a significant sustained reduction in worldwide oil and gas prices or drilling; a significant sustained reduction in profitability or cash flow of oil and gas companies or drilling contractors; a significant sustained reduction in capital investment by other oilfield service companies; or a significant increase in worldwide inventories of oil or gas. The timing and magnitude of any goodwill impairment charge, which could be material, would depend on the timing and severity of the event or events triggering the charge and would require a high degree of management judgement. If we were to determine that any of our remaining balance of goodwill or other indefinite lived intangible assets was impaired, we would record an immediate charge to earnings with a corresponding reduction in stockholders’ equity; resulting in a possible increase in balance sheet leverage as measured by debt to total capitalization.
See additional discussion on “Goodwill and Other Indefinite - Lived Intangible Assets” in Critical Accounting Estimates of Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”
We have expanded and grown our businesses through acquisitions and continue to pursue a growth strategy but we cannot assure that attractive acquisitions will be available to us at reasonable prices or at all.
We cannot assure that we will successfully integrate the operations and assets of any acquired business with our own or that our management will be able to manage effectively any new lines of business. Any inability on the part of management to integrate and manage acquired businesses and their assumed liabilities could adversely affect our business and financial performance. In addition, we may need to incur substantial indebtedness to finance future acquisitions. We cannot assure that we will be able to obtain this financing on terms acceptable to us or at all. Future acquisitions may result in increased depreciation and amortization expense, increased interest expense, increased financial leverage or decreased operating income for the Company, any of which could cause our business to suffer.
The adoption of any future federal, state, or local laws or implementing regulations imposing reporting obligations on, or limiting or banning, the hydraulic fracturing process could make it more difficult to complete natural gas and oil wells and could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.
Various federal and state legislative and regulatory initiatives, as well as actions in other countries, have been or could be undertaken which could result in additional requirements or restrictions being imposed on hydraulic fracturing operations. For example, legislation and/or regulations have been adopted in many U.S. states that require
additional disclosure regarding chemicals used in the hydraulic fracturing process but that generally include protections for proprietary information. Legislation, regulations and/or policies have also been adopted at the state level that impose other types of requirements on hydraulic fracturing operations (such as limits on operations in the event of certain levels of seismic activity). Additional legislation and/or regulations are being considered at the state and local level that could impose further chemical disclosure or other regulatory requirements (such as prohibitions on hydraulic fracturing operations in certain areas) that could affect our operations. Three states (New York, Maryland and Vermont) have banned the use of high volume hydraulic fracturing. Local jurisdictions in some states have adopted ordinances that restrict or in certain cases prohibit the use of hydraulic fracturing, although many of these ordinances have been challenged and some have been overturned. In addition, governmental authorities in various foreign countries where we have provided or may provide hydraulic fracturing services have imposed or are considering imposing various restrictions or conditions that may affect hydraulic fracturing operations.
Legal and Regulatory Related
Our failure to comply with existing or future U.S. and foreign laws and regulations could have a material adverse effect on our business and our results of operations.
Our ability to comply with various complex U.S. and foreign laws and regulations, such as the FCPA, the U.K. Bribery Act and other foreign anti-bribery and anti-corruption laws, various trade control regulations, and human rights and anti-slavery legislation is dependent on the success of our ongoing compliance program, including our ability to continue to effectively supervise and train our employees to deter prohibited practices. These various laws and regulations can change frequently and significantly. We may become involved in a governmental investigation even if the Company has complied with these laws. If we fail to comply with applicable laws and regulation, we could be subject to investigations, sanctions and civil and criminal prosecution as well as fines and penalties, which could have a material adverse effect on our reputation and our business, financial condition, results of operations and cash flows. In addition, government disruptions could negatively impact our ability to conduct our business. Supply chain restrictions such as the U.K. Modern Slavery Act and other similar legislation could also materially affect our supply chain, cost of production, and ability to manufacture our products.
We are also required to comply with various complex U.S. and foreign tax laws, regulations and treaties. These laws, regulations and treaties can change frequently and significantly, and it is reasonable to expect changes in the future. If we fail to comply with any of these tax laws, regulations or treaties, we could be subject to, among other things, civil and criminal prosecution, fines, penalties and confiscation of our assets, which could disrupt our ability to provide our products and services to our customers. Any of these events could have a material adverse effect on our business, financial condition, results of operations and cash flows.
Further, in some instances, direct or indirect consumers of our products and services, entities providing financing for purchases of our products and services or members of the supply chain for our products and services may become involved in governmental investigations, internal investigations, political or other enforcement matters. In such circumstances, such investigations may adversely impact the ability of consumers of our products, entities providing financial support to such consumers or entities in the supply chain to timely perform their business plans or to timely perform under agreements with us. The Company could also become involved in investigations of consumers of our products at significant cost to the Company.
Focus and attention by advocacy groups and regulatory agencies on climate change and greenhouse gas (GHG) emissions in the United States and the European Union has accelerated during the COVID-19 Pandemic. Investors, customers, governance pundits and government officials have increased focus on sustainability, stakeholder governance and the energy transition. As a result, there has been increased promotion of alternative energy sources and increased negative attitudes or perceptions of fossil fuels. The combination of these factors may significantly reduce demand for production of oil and gas and for our products and services. Furthermore, we face increased reputational risk and demand for our stock could be negatively impacted based on societal perceptions of our industry sector and our response to sustainability issues.
We could be adversely affected if we fail to comply with any of the numerous federal, state and local laws, regulations and policies that govern environmental protection, zoning and other matters applicable to our businesses.
Our businesses are subject to numerous federal, state and local laws, regulations and policies governing environmental protection, zoning and other matters. These laws and regulations have changed frequently in the past and it is reasonable to expect additional changes in the future. If existing regulatory requirements change, we may be required to make significant unanticipated capital and operating expenditures. We cannot assure you that our operations will continue to comply with future laws and regulations. Governmental authorities may seek to impose fines and penalties on us or to revoke or deny the issuance or renewal of operating permits for failure to comply with applicable laws and regulations. Under these circumstances, we might be required to reduce or cease operations or conduct site remediation or other corrective action which could adversely impact our operations and financial condition.
Our businesses expose us to potential environmental, product or personal injury liability.
Our businesses expose us to the risk that harmful substances may escape into the environment or a product could fail to perform or cause personal injury, or individuals may assert claims due to exposure to chemicals, harmful substances, environmental conditions any of which could result in:
•
personal injury or loss of life;
•
severe damage to or destruction of property; or,
•
environmental damage and suspension of operations.
Our current and past activities, as well as the activities of our former divisions and subsidiaries, could result in our facing substantial environmental, regulatory, personnel injury, class action, mass tort and other litigation and liabilities. These could include the costs of cleanup of contaminated sites and site closure obligations. These liabilities could also be imposed on the basis of one or more of the following theories:
•
negligence;
•
strict liability;
•
products liability;
•
breach of contract with customers; or,
•
as a result of our contractual agreement to indemnify our customers in the normal course of business, which is normally the case.
We may not have adequate insurance for potential environmental, product or personal injury liabilities.
While we maintain liability insurance, this insurance is subject to coverage limits. In addition, certain policies do not provide coverage for damages resulting from environmental contamination or may exclude coverage for other reasons. We face the following risks with respect to our insurance coverage:
•
we may not be able to continue to obtain insurance on commercially reasonable terms;
•
we may be faced with types of liabilities that will not be covered by our insurance;
•
our insurance carriers may not be able to meet their obligations under the policies; or,
•
the dollar amount of any liabilities may exceed our policy limits.
Even a partially uninsured claim, if successful and of significant size, could have a material adverse effect on our consolidated financial statements.
The adoption of climate change legislation, restrictions on emissions of greenhouse gases, or other environmental regulations could increase our operating costs or reduce demand for our products.
Environmental advocacy groups and regulatory agencies in the United States and other countries have been focusing considerable attention on the emissions of carbon dioxide, methane and other greenhouse gases and their potential
role in climate change. The adoption of laws and regulations to implement controls of greenhouse gases, including the imposition of fees or taxes, could adversely impact our operations and financial condition. The U.S. Congress and other governments routinely consider legislation to control and reduce emissions of greenhouse gases and other climate change related legislation, which could require significant reductions in emissions from oil and gas related operations. Changes in the legal and regulatory environment could reduce oil and natural gas drilling activity and result in a corresponding decline in the demand for our products and services, which could adversely impact our operating results and financial condition.
Local content requirements imposed in certain jurisdictions may increase the complexity of our operations and impact the demand for our services.
A growing number of nations are requiring equipment providers and contractors to meet local content requirements or other local standards. To meet many of these local content and other requirements, we are required to attract and retain qualified local personnel. If we are unable to do so because the supply of qualified local personnel is constrained for any reason, the growth and profitability of our business may be adversely affected. In addition, our ability to work in certain jurisdictions is sometimes subject to our ability to successfully negotiate and agree upon acceptable joint venture agreements. The failure to reach acceptable agreements could adversely impact the Company’s operations in certain countries. Additionally, we may share control of joint ventures with unaffiliated third parties. Differences in views, and disagreements, among joint venture parties may result in delayed decision making and disputes on important issues. In some instances, we could suffer a material adverse effect to the results of our joint ventures and our consolidated results of operations.
GLOSSARY OF OILFIELD TERMS
(Sources: Company management; “A Dictionary for the Petroleum Industry,” The University of Texas at Austin, 2001.)
API
Abbr: American Petroleum Institute
Annular Blowout Preventer
A large valve, usually installed above the ram blowout preventers, that forms a seal in the annular space between the pipe and the wellbore or, if no pipe is present, in the wellbore itself.
Annulus
The open space around pipe in a wellbore through which fluids may pass.
Automatic Pipe Handling
Systems (Automatic Pipe
Racker)
A device used on a drilling rig to automatically remove and insert drill stem components from and into the hole. It replaces the need for a person to be in the derrick or mast when tripping pipe into or out of the hole.
Automatic Roughneck
A large, self-contained pipe-handling machine used by drilling crew members to make up and break out tubulars. The device combines a spinning wrench, torque wrench, and backup wrenches.
Beam pump
Surface pump that raise and lowers sucker rods continually, so as to operate a downhole pump.
Bit
The cutting or boring element used in drilling oil and gas wells. The bit consists of a cutting element and a circulating element. The cutting element is steel teeth, tungsten carbide buttons, industrial diamonds, or polycrystalline diamonds (“PDCs”). These teeth, buttons, or diamonds penetrate and gouge or scrape the formation to remove it. The circulating element permits the passage of drilling fluid and utilizes the hydraulic force of the fluid stream to improve drilling rates. In rotary drilling, several drill collars are joined to the bottom end of the drill pipe column, and the bit is attached to the end of the drill collars. Drill collars provide weight on the bit to keep it in firm contact with the bottom of the hole.
Blowout
An uncontrolled flow of gas, oil or other well fluids into the atmosphere. A blowout, or gusher, occurs when formation pressure exceeds the pressure applied to it by the column of drilling fluid. A kick warns of an impending blowout.
Blowout Preventer (BOP)
Series of valves installed at the wellhead while drilling to prevent the escape of pressurized fluids.
Blowout Preventer (BOP) Stack
The assembly of well-control equipment including preventers, spools, valves, and nipples connected to the top of the wellhead.
Borehole Enlargement (“BHE”)
The process of opening up or enlarging the internal diameter of the wellbore. This is typically done with under-reamers, reamers, or hole openers.
Bottomhole Assembly (“BHA”)
The lower portion of the drillstring including (if used): the bit, bit sub, mud motor, stabilizers, drillcollar, heavy-weight drillpipe, jarring devices, and crossovers for various thread forms.
Carbon-Neutral
The state of achieving net zero carbon dioxide emissions with removal or simply eliminating carbon dioxide emissions altogether.
Closed Loop Drilling Systems
A solids control system in which the drilling mud is reconditioned and recycled through the drilling process on the rig itself.
Coiled Tubing
A continuous string of flexible steel tubing, often hundreds or thousands of feet long, that is wound onto a reel, often dozens of feet in diameter. The reel is an integral part of the coiled tubing unit, which consists of several devices that ensure the tubing can be safely and efficiently inserted into the well from the surface. Because tubing can be lowered into a well without having to make up joints of tubing, running coiled tubing into the well is faster and less expensive than running conventional tubing. Rapid advances in the use of coiled tubing make it a popular way in which to run tubing into and out of a well. Also called reeled tubing.
Cuttings
Fragments of rock dislodged by the bit and brought to the surface in the drilling mud. Washed and dried cutting samples are analyzed by geologist to obtain information about the formations drilled.
Directional Well
Well drilled in an orientation other than vertical in order to access broader portions of the formation.
Drawworks
The hoisting mechanism on a drilling rig. It is essentially a large winch that spools off or takes in the drilling line and thus raises or lowers the drill stem and bit.
Drill Pipe Elevator (Elevator)
On conventional rotary rigs and top-drive rigs, hinged steel devices with manual operating handles that crew members latch onto a tool joint (or a sub). Since the elevators are directly connected to the traveling block, or to the integrated traveling block in the top drive, when the driller raises or lowers the block or the top-drive unit, the drill pipe is also raised or lowered.
Drilling jars
A percussion tool operated manually or hydraulically to deliver a heavy downward blow to free a stuck drill stem.
Drilling mud
A specially compounded liquid circulated through the wellbore during rotary drilling operations.
Drilling riser
A conduit used in offshore drilling through which the drill bit and other tools are passed from the rig on the water’s surface to the sea floor.
Drill stem
All members in the assembly used for rotary drilling from the swivel to the bit, including the Kelly, the drill pipe and tool joints, the drill collars, the stabilizers, and various specialty items.
Fiberglass-reinforced spoolable pipe
A spoolable glass fiber-reinforced epoxy composite tubular product for onshore oil and gas gathering and injection systems, with superior corrosion resistant properties and lower installed cost than steel.
Flexible pipe
A dynamic riser that connects subsea production equipment to a topside facility allowing for the flow of oil, gas, and/or water. Also used on the seafloor to tie wells and subsea equipment together.
Formation
A bed or deposit composed throughout of substantially the same kind of rock; often a lithologic unit. Each formation is given a name, frequently as a result of the study of the formation outcrop at the surface and sometimes based on fossils found in the formation.
FPSO
A Floating Production, Storage and Offloading vessel used to receive hydrocarbons from subsea wells, and then produce and store the hydrocarbons until they can be offloaded to a tanker or pipeline.
Hardbanding
A special wear-resistant material often applied to tool joints to prevent abrasive wear to the area when the pipe is being rotated downhole.
Hub Height
The distance from the turbine platform to the rotor of an installed wind turbine and indicates how high the turbine stands above the ground (or water), not including the length of the wind blades.
Hydraulic Fracturing
The process of creating fractures in a formation by pumping fluids, at high pressures, into the reservoir, which allows or enhances the flow of hydrocarbons.
Iron Roughneck
A floor-mounted combination of a spinning wrench and a torque wrench. The Iron Roughneck moves into position hydraulically and eliminates the manual handling involved with suspended individual tools.
Jack-up rig
A mobile bottom-supported offshore drilling structure with columnar or open-truss legs that support the deck and hull. When positioned over the drilling site, the bottoms of the legs penetrate the seafloor.
Jar
A mechanical device placed near the top of the drill stem which allows the driller to strike a very heavy blow upward or downward on stuck pipe.
Joint
1. In drilling, a single length (from 16 feet to 45 feet, or 5 meters to 14.5 meters, depending on its range length) of drill pipe, drill collar, casing or tubing that has threaded connections at both ends. Several joints screwed together constitute a stand of pipe. 2. In pipelining, a single length (usually 40 feet-12 meters) of pipe. 3. In sucker rod pumping, a single length of sucker rod that has threaded connections at both ends.
Kelly
The heavy steel tubular device, four-or six-sided, suspended from the swivel through the rotary table and connected to the top joint of drill pipe to turn the drill stem as the rotary table turns. It has a bored passageway that permits fluid to be circulated into the drill stem and up the annulus, or vice versa. Kellys manufactured to API specifications are available only in four-or six-sided versions, are either 40 or 54 feet (12 or 16 meters) long, and have diameters as small as 2.5 inches (6 centimeters) and as large as 6 inches (15 centimeters).
Kelly bushing
A special device placed around the kelly that mates with the kelly flats and fits into the master bushing of the rotary table. The kelly bushing is designed so that the kelly is free to move up or down through it. The bottom of the bushing may be shaped to fit the opening in the master bushing or it may have pins that fit into the master bushing. In either case, when the kelly bushing is inserted into the master bushing and the master bushing is turned, the kelly bushing also turns. Since the kelly bushing fits onto the kelly, the kelly turns, and since the kelly is made up to the drill stem, the drill stem turns. Also called the drive bushing.
Kelly spinner
A pneumatically operated device mounted on top of the kelly that, when actuated, causes the kelly to turn or spin. It is useful when the kelly or a joint of pipe attached to it must be spun up, that is, rotated rapidly for being made up.
Kick
An entry of water, gas, oil, or other formation fluid into the wellbore during drilling. It occurs because the pressure exerted by the column of drilling fluid is not great enough to overcome the pressure exerted by the fluids in the formation drilled. If prompt action is not taken to control the kick, or kill the well, a blowout may occur.
Levelized Cost of Energy
(“LCOE”)
A measure of the average net present cost of electricity generation for a generating plant over its lifetime. The LCOE is calculated as the ratio between all the discounted costs over the lifetime on an electricity generating plant divided by a discounted sum of the actual energy amounts delivered. LCOE is used to compare different methods of electricity generation on a consistent basis.
Making-up
1. To assemble and join parts to form a complete unit (e.g., to make up a string of drill pipe). 2. To screw together two threaded pieces. 3. To mix or prepare (e.g., to make up a tank of mud). 4. To compensate for (e.g., to make up for lost time).
Manual tongs (Tongs)
The large wrenches used for turning when making up or breaking out drill pipe, casing, tubing, or other pipe; variously called casing tongs, pipe tongs, and so forth, according to the specific use. Power tongs or power wrenches are pneumatically or hydraulically operated tools that serve to spin the pipe up tight and, in some instances to apply the final makeup torque.
Master bushing
A device that fits into the rotary table to accommodate the slips and drive the kelly bushing so that the rotating motion of the rotary table can be transmitted to the kelly. Also called rotary bushing.
Mooring system
The method by which a vessel or buoy is fixed to a certain position, whether permanently or temporarily.
Motion compensation
equipment
Any device (such as a bumper sub or heave compensator) that serves to maintain constant weight on the bit in spite of vertical motion of a floating offshore drilling rig.
Mud pump
A large, high-pressure reciprocating pump used to circulate the mud on a drilling rig.
Nacelle
A cover housing that houses all of the generating components in a wind turbine, including the generator, gearbox, drive train, and brake assembly. The nacelle must be easily accessible for maintenance and repair work.
Plug gauging
The mechanical process of ensuring that the inside threads on a piece of drill pipe comply with API standards.
Pressure control equipment
Equipment used in: 1. The act of preventing the entry of formation fluids into a wellbore. 2. The act of controlling high pressures encountered in a well.
Pressure pumping
Pumping fluids into a well by applying pressure at the surface.
Ram blowout preventer
A blowout preventer that uses rams to seal off pressure on a hole that is with or without pipe. Also called a ram preventer.
Ring gauging
The mechanical process of ensuring that the outside threads on a piece of drill pipe comply with API standards.
Riser pipe
The pipe and special fitting used on floating offshore drilling rigs to establish a seal between the top of the wellbore, which is on the ocean floor, and the drilling equipment located above the surface of the water. A riser pipe serves as a guide for the drill stem from the drilling vessel to the wellhead and as a conductor for drilling fluid from the well to the vessel. The riser consists of several sections of pipe and includes special devices to compensate for any movement of the drilling rig caused by waves. Also called marine riser pipe, riser joint.
Rotary table
The principal piece of equipment in the rotary table assembly; a turning device used to impart rotational power to the drill stem while permitting vertical movement of the pipe for rotary drilling. The master bushing fits inside the opening of the rotary table; it turns the kelly bushing, which permits vertical movement of the kelly while the stem is turning.
Rotating blowout
preventer (Rotating Head)
A sealing device used to close off the annular space around the kelly in drilling with pressure at the surface, usually installed above the main blowout preventers. A rotating head makes it possible to drill ahead even when there is pressure in the annulus that the weight of the drilling fluid is not overcoming; the head prevents the well from blowing out. It is used mainly in the drilling of formations that have low permeability. The rate of penetration through such formations is usually rapid.
Safety clamps
A clamp placed very tightly around a drill collar that is suspended in the rotary table by drill collar slips. Should the slips fail, the clamp is too large to go through the opening in the rotary table and therefore prevents the drill collar string from falling into the hole. Also called drill collar clamp.
Shale shaker
A piece of drilling rig equipment that uses a vibrating screen to remove cuttings from the circulating fluid in rotary drilling operations. The size of the openings in the screen should be selected carefully to be the smallest size possible to allow 100 per cent flow of the fluid. Also called a shaker.
Slim-hole completions
(Slim-hole Drilling)
Drilling in which the size of the hole is smaller than the conventional hole diameter for a given depth. This decrease in hole size enables the operator to run smaller casing, thereby lessening the cost of completion.
Slips
Wedge-shaped pieces of metal with serrated inserts (dies) or other gripping elements, such as serrated buttons, that suspend the drill pipe or drill collars in the master bushing of the rotary table when it is necessary to disconnect the drill stem from the kelly or from the top-drive unit’s drive shaft. Rotary slips fit around the drill pipe and wedge against the master bushing to support the pipe. Drill collar slips fit around a drill collar and wedge against the master bushing to support the drill collar. Power slips are pneumatically or hydraulically actuated devices that allow the crew to dispense with the manual handling of slips when making a connection.
Solids
See “Cuttings”
Spinning wrench
Air-powered or hydraulically powered wrench used to spin drill pipe in making or breaking connections.
Spinning-in
The rapid turning of the drill stem when one length of pipe is being joined to another. “Spinning-out” refers to separating the pipe.
Stand
The connected joints of pipe racked in the derrick or mast when making a trip. On a rig, the usual stand is about 90 feet (about 27 meters) long (three lengths of drill pipe screwed together), or a treble.
Steerable Technologies
Tools that allow for steering the BHA towards a target while rotating from surface.
String
The entire length of casing, tubing, sucker rods, or drill pipe run into a hole.
Sucker rod
A special steel pumping rod. Several rods screwed together make up the link between the pumping unit on the surface and the pump at the bottom of the well.
Tensioner
A system of devices installed on a floating offshore drilling rig to maintain a constant tension on the riser pipe, despite any vertical motion made by the rig. The guidelines must also be tensioned, so a separate tensioner system is provided for them.
Thermal desorption
The process of removing drilling mud from cuttings by applying heat directly to drill cuttings.
Tiebacks (Subsea)
A series of flowlines and pipes that connect numerous subsea wellheads to a single collection point.
Top drive
A device similar to a power swivel that is used in place of the rotary table to turn the drill stem. It also includes power tongs. Modern top drives combine the elevator, the tongs, the swivel, and the hook. Even though the rotary table assembly is not used to rotate the drill stem and bit, the top-drive system retains it to provide a place to set the slips to suspend the drill stem when drilling stops.
Torque wrench
Spinning wrench with a gauge for measuring the amount of torque being applied to the connection.
Trouble cost
Costs incurred as a result of unanticipated complications while drilling a well. These costs are often referred to as contingency costs during the planning phase of a well.
Turret
Mechanical device that allows a floating vessel to rotate around stationary flowlines, umbilicals, and other associated risers.
Well completion
1. The activities and methods of preparing a well for the production of oil and gas or for other purposes, such as injection; the method by which one or more flow paths for hydrocarbons are established between the reservoir and the surface. 2. The system of tubulars, packers, and other tools installed beneath the wellhead in the production casing; that is, the tool assembly that provides the hydrocarbon flow path or paths.
Wellhead
The termination point of a wellbore at surface level or subsea, often incorporating various valves and control instruments.
Well stimulation
Any of several operations used to increase the production of a well, such as acidizing or fracturing.
Well workover
The performance of one or more of a variety of remedial operations on a producing oil well to try to increase production. Examples of workover jobs are deepening, plugging back, pulling and resetting liners, and squeeze cementing.
Wellbore
A borehole; the hole drilled by the bit. A wellbore may have casing in it or it may be open (uncased); or part of it may be cased, and part of it may be open. Also called a borehole or hole.
Wireline
A slender, rodlike or threadlike piece of metal usually small in diameter, that is used for lowering special tools (such as logging sondes, perforating guns, and so forth) into the well. Also called slick line.

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

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ITEM 2. PROPERTIES
ITEM 2.
PROPERTIES
The Company owned or leased approximately 573 facilities worldwide as of December 31, 2020, including the following principal manufacturing, service, distribution and administrative facilities:
Building
Property
Lease
Size
Size
Owned /
Termination
Location
Description
(SqFt)
(Acres)
Leased
Date
Wellbore Technologies:
Navasota, Texas
Manufacturing Facility & Administrative Offices
562,112
Owned
Conroe, Texas
Manufacturing Facility of Drill Bits and
410,623
Owned
Downhole Tools, Administrative & Sales Offices
Houston, Texas
Sheldon Road Inspection Facility
319,365
Owned
Veracruz, Mexico
Manufacturing Facility of Tool Joints,
303,400
Owned
Warehouse & Administrative Offices
Houston, Texas
Holmes Rd Complex: Manufacturing, Warehouse,
300,000
Owned
Coating Manufacturing Plant & Corporate Office
Cedar Park, Texas
Instrumentation Manufacturing Facility, Administrative & Sales Offices
215,778
Owned
Dubai, UAE
Manufacturing Facility of Downhole Tools, Distribution Warehouse
184,492
Leased
1/29/2021
Conroe, Texas
Solids Control Manufacturing Facility, Warehouse,
153,750
Owned
Administrative & Sales Offices, and Engineering Labs
Houston, Texas
Manufacturing of plastic thread products
158,250
Owned
Completion & Production Solutions:
Senai, Malaysia
Manufacturing Facility of Fiber Glass Products
595,965
Owned*
10/31/2027
Kalundborg,
Denmark
Flexibles Manufacturing, Warehouse, Shop & Administrative Offices
485,067
Owned
Superporto du
Acu, Brazil
Flexibles Manufacturing, Warehouse, Shop & Administrative Offices
464,885
Owned*
10/20/2031
Manchester, England
Manufacturing, Assembly & Testing of PC Pumps and Expendable Parts, Administrative & Sales Offices
464,000
Owned
Houston, Texas
Manufacturing of Wireline and Pressure Performance Equipment, Warehouse and Administrative Offices
383,750
Leased
6/30/2041
Fort Worth, Texas
Coiled Tubing Manufacturing Facility,
342,999
`
Owned
Warehouse, Administrative & Sales Offices
Qingdau, Shandong,
China
Manufacturing of fiber-reinforced tubular products
309,150
Leased
10/26/2036
Tulsa, Oklahoma
Manufacturing Facility of Pumps, Warehouse and Administrative & Sales Offices
222,625
Owned
Houston, Texas
Manufacturing of fiber-reinforced tubular products & Administrative Offices
130,873
Leased
4/30/2021
Kintore, Aberdeenshire, Scotland, UK
Manufacturing & Servicing of Elmar, ASEP and Anson Equipment
210,000
Leased
9/3/2037
Dammam, Saudi Arabia
Manufacturing of fiberglass products
213,484
Leased
12/7/2036
Mt. Union, Pennsylvania
Manufacturing of fiberglass products
160,000
Owned
Rig Technologies:
Houston, Texas
Bammel Facility, Repairs, Service, Aftermarket Parts,
602,110
Leased
6/30/2028
Administrative & Sales Offices
Houston, Texas
Manufacturing Plant of Drilling Equipment
511,964
Leased
4/30/2022
Houston, Texas
West Little York Manufacturing Facility,
483,450
Owned
Repairs, Service, Administrative & Sales Offices
New Iberia, Louisiana
Repair, Services and Spares facility
189,000
Leased
10/1/2025
Singapore
Manufacturing, Repairs, Service, Field
133,659
Leased
1/5/2024
Service/Training, Administrative & Sales Offices
Dubai, UAE
Repair & Overhaul of Drilling Equipment,
39,433
Owned
Warehouse & Sales Office
Corporate:
Houston, Texas
Corporate and Shared Administrative Offices
337,019
Leased
5/31/2037
Houston, Texas
Corporate and Shared Administrative Offices
441,029
Leased
1/31/2041
*Building owned but land leased.
We own or lease approximately 325 repair and manufacturing facilities that refurbish and manufacture new equipment and parts, 122 service centers that provide inspection and equipment rental and 126 engineering, sales and administration facilities.

---

ITEM 3. LEGAL PROCEEDINGS
ITEM 3.
LEGAL PROCEEDINGS
See Note 12 - Commitments and Contingencies (Part IV, Item 15 of this Form 10-K) for further discussion.

---

ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4.
MINE SAFETY DISCLOSURES
Information regarding mine safety and other regulatory actions at our mines is included in Exhibit 95 to this Form 10-K.
PART II

---

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
ITEM 5.
MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information
Our common stock is traded on the New York Stock Exchange (NYSE) under the symbol “NOV”. As of February 5, 2021, there were 2,462 holders of record of our common stock. Many stockholders choose to own shares through brokerage accounts and other intermediaries rather than as holders of record (excluding individual participants in securities positions listing) so the actual number of stockholders is unknown but significantly higher.
Cash dividends declared were $0.05 per share in the first quarter of 2020 and $0.05 per share in the first, second, third, and fourth quarters of 2019, aggregating to $19 million and $77 million for the years ended December 31, 2020 and 2019, respectively. We have no plans to pay dividends in the future; however, the declaration and payment of future dividends is at the discretion of the Company’s Board of Directors and will be dependent upon the Company’s results of operations, financial condition, capital requirements, future outlook and other factors deemed relevant by the Company’s Board of Directors.
The information relating to our equity compensation plans required by Item 5. “Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities” is incorporated by reference to such information as set forth in Item 12. “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters” contained herein.
PERFORMANCE GRAPH
The graph below compares the cumulative total shareholder return on our common stock to the S&P 500 Index and the S&P Oil & Gas Equipment & Services Index. The total shareholder return assumes $100 invested on December 31, 2015 in NOV Inc., the S&P Oil & Gas Equipment Select Index, the S&P 500 Index and the S&P Oil & Gas Equipment & Services Index. It also assumes reinvestment of all dividends. The results shown in the graph below are not necessarily indicative of future performance.
12/15
12/16
12/17
12/18
12/19
12/20
NOV Inc.
100.00
113.91
110.23
79.07
77.74
42.85
S&P 500
100.00
111.96
136.40
130.42
171.49
203.04
S&P Oil & Gas Equipment & Services
100.00
131.93
112.56
65.88
72.83
46.45
S&P Oil & Gas Equipment Select
100.00
128.70
100.61
53.30
48.70
27.57
This information shall not be deemed to be ‘‘soliciting material’’ or to be ‘‘filed’’ with the Commission or subject to Regulation 14A (17 CFR 240.14a-1-240.14a-104), other than as provided in Item 201(e) of Regulation S-K, or to the liabilities of section 18 of the Exchange Act (15 U.S.C. 78r).
Purchases of Equity Securities by the Issuer and Affiliated Purchasers
Period
Total number
of shares
purchased*
Average
price paid
per share
Total number of
shares purchased
as part of publicly
announced plans
or programs
Approximate dollar
value of shares that
may yet be purchased
under the plans or
programs*
October 1 through October 31, 2020
-
-
-
-
November 1 through November 30, 2020
-
-
-
-
December 1 through December 31, 2020
-
-
-
-
Total (1)
-
$
-
-
*Amounts in thousands
(1)
No shares were purchased during the three-month period ended December 31, 2020.

---

ITEM 6. SELECTED FINANCIAL DATA

---

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
ITEM 7.
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
General Overview
The Company is a leading independent provider of equipment and technology to the upstream oil and gas industry. With operations in approximately 573 locations across six continents, NOV designs, manufactures and services a comprehensive line of drilling, well servicing and offshore construction equipment; sells and rents drilling motors, specialized downhole tools, and rig instrumentation; performs inspection and internal coating of oilfield tubular products; provides drill cuttings separation, management and disposal systems and services; and provides expendables and spare parts used in conjunction with the Company’s large installed base of equipment. NOV also manufactures coiled tubing and high-pressure fiberglass and composite tubing and sells and rents advanced in-line inspection equipment to makers of oil country tubular goods. More recently, by applying its deep knowledge in technology, the Company has helped advance the transition toward sustainable energy. The Company has a long tradition of pioneering innovations which improve the cost-effectiveness, efficiency, safety, and environmental impact of oil and gas operations.
NOV’s revenue and operating results are principally directly related to the level of worldwide oil and gas drilling and production activities and the profitability and cash flow of oil and gas companies and drilling contractors, which in turn are affected by current and anticipated prices of oil and gas. Oil and gas prices have been and are likely to continue to be volatile. See Item 1A. “Risk Factors”. The Company conducts its operations through three business segments: Wellbore Technologies, Completion & Production Solutions and Rig Technologies. See Item 1. “Business”, for a discussion of each of these business segments.
Unless indicated otherwise, results of operations are presented in accordance with accounting principles generally accepted in the United States (“GAAP”). Certain reclassifications have been made to the prior year financial statements in order for them to conform with the 2020 presentation. The Company discloses Adjusted EBITDA (defined as Operating Profit excluding Depreciation, Amortization and Other Items) in its periodic earnings press releases and other public disclosures to provide investors additional information about the results of ongoing operations. See Non-GAAP Financial Measures and Reconciliations in Results of Operations for an explanation of our use of non-GAAP financial measures and reconciliations to their corresponding measures calculated in accordance with GAAP.
Operating Environment Overview
NOV’s results are dependent on, among other things, the level of worldwide oil and gas drilling, well remediation activity, the price of crude oil and natural gas, capital spending by exploration and production companies and drilling contractors, worldwide oil and gas inventory levels and, to a lesser degree, the level of investment in wind and geothermal energy products . Key industry indicators for the past three years include the following:
% increase (decrease)
2020 v
2020 v
2020*
2019*
2018*
Active Drilling Rigs:
U.S.
1,031
(53.8
%)
(57.7
%)
Canada
(33.3
%)
(52.9
%)
International
1,106
(25.4
%)
(16.5
%)
Worldwide
1,351
2,185
2,210
(38.2
%)
(38.9
%)
West Texas Intermediate Crude Prices (per
barrel)
$
39.33
$
56.98
$
64.94
(31.0
%)
(39.4
%)
Natural Gas Prices ($/mmbtu)
$
2.01
$
2.52
$
3.13
(20.2
%)
(35.8
%)
*
Averages for the years indicated. See sources below.
The following table details the U.S., Canadian, and international rig activity and West Texas Intermediate Oil prices for the past nine quarters ended December 31, 2020 on a quarterly basis:
Source: Rig count: Baker Hughes, Inc. (www.bakerhughes.com); West Texas Intermediate Crude Price, Natural Gas Price: US Department of Energy, Energy Information Administration (www.eia.doe.gov).
The average price per barrel of West Texas Intermediate Crude was $39.33 in 2020, a decrease of 31% over the average price for 2019 of $56.98 per barrel. The average natural gas price in 2020 was $2.01 per mmbtu, a decrease of 20% percent compared to the 2019 average of $2.52 per mmbtu. Average rig activity worldwide decreased 38 percent for the full year in 2020 compared to 2019. The average crude oil price for the fourth quarter of 2020 was $42.46 per barrel, and natural gas was $2.50 per mmbtu.
At February 5, 2021, there were 563 rigs actively drilling in North America, compared to the fourth quarter average of 400 rigs, an increase of 41 percent. The price for West Texas Intermediate Crude Oil was $56.852 per barrel at February 5, 2021, an increase of 34 percent from the fourth quarter of 2020 average. The price for natural gas was $2.86 per mmbtu at February 5, 2021, an increase of 15 percent from the fourth quarter of 2020 average.
EXECUTIVE SUMMARY
NOV Inc. generated revenue of $6.09 billion in 2020, which was lower from the prior year as COVID-19 related restrictions decreased economic activity, sharply lowering oil and gas prices, and declining drilling activity worldwide led to a 28 percent decline in revenue. Average 2020 worldwide rig count (as measured by Baker Hughes) decreased significantly when compared to 2019.
For the year ended December 31, 2020, the Company reported an operating loss of $2,425 million compared to an operating loss of $6,279 million in 2019, and a net loss attributable to the Company of $2,542 million, or $6.62 per share compared to a net loss of $6,095 million or $15.96 per share during 2019.
For the fourth quarter ended December 31, 2020, revenue was $1.33 billion, a $57 million or four percent decrease compared to the third quarter of 2020. The Company reported a net loss of $347 million, or $0.90 per fully diluted share, a decrease of $292 million, or $0.76 per fully diluted share, from the third quarter of 2020. Compared to the fourth quarter of 2019, revenue decreased $954 million or 42 percent, and net income increased $38 million.
During the fourth quarter of 2020, third quarter of 2020, and fourth quarter of 2019, pre-tax other items: goodwill, intangible and long-lived asset impairment charges, inventory charges, severance accruals, and other charges and credits (collectively “Other Items”), were $236 million, $62 million, and $537 million, respectively. Excluding the Other Items from all periods, fourth quarter 2020 Adjusted EBITDA was $17 million, compared to $71 million in the third quarter of 2020 and $288 million in the fourth quarter of 2019.
Segment Performance
Wellbore Technologies
Wellbore Technologies generated revenues of $373 million in the fourth quarter of 2020, an increase of three percent from the third quarter of 2020 and a decrease of 51 percent from the fourth quarter of 2019. The increase in revenues resulted from increased drilling activity levels in North America partially offset by declines in international and offshore markets. Operating loss, which included $46 million in Other Items, was $78 million. Adjusted EBITDA decreased $9 million sequentially and $131 million from the prior year to $12 million, or 3.2 percent of sales.
Completion & Production Solutions
Completion & Production Solutions generated revenues of $546 million in the fourth quarter of 2020, a decrease of nine percent from the third quarter of 2020 and a decrease of 32 percent from the fourth quarter of 2019. Lower backlog and logistical disruptions from COVID-19-related restrictions contributed to the sequential decline. Operating loss, which included $43 million in Other Items, was $31 million. Adjusted EBITDA decreased $35 million sequentially and $68 million from the prior year to $28 million, or 5.1 percent of sales.
New orders booked improved 27 percent sequentially to $215 million, representing a book-to-bill of 66 percent when compared to the $328 million of orders shipped from backlog. Backlog for capital equipment orders for Completion & Production Solutions at December 31, 2020 was $696 million.
Rig Technologies
Rig Technologies generated revenues of $437 million in the fourth quarter of 2020, a decrease of three percent from the third quarter of 2020 and a decrease of 42 percent from the fourth quarter of 2019. Declining offshore drilling activity levels resulting in lower capital equipment backlog contributed to the sequential decline in revenues. Operating loss, which included $132 million in Other Items, was $132 million. Adjusted EBITDA decreased $9 million sequentially and $93 million from the prior year to $19 million, or 4.3 percent of sales.
New orders booked during the quarter totaled $190 million, representing a book-to-bill of 105 percent when compared to the $181 million of orders shipped from backlog. At December 31, 2020, backlog for capital equipment orders for Rig Technologies was $2.7 billion.
Oil & Gas Equipment and Services Market and Outlook
Following approximately two and a half years of steady improvements in oil prices and global drilling activity levels, prices declined sharply during the fourth quarter of 2018 due to stronger than expected growth in U.S. production and concerns regarding the global economy. As a result of reduced budgets, and despite a modest recovery in commodity prices, drilling activity levels in the U.S. declined throughout 2019 resulting in the first double digit percentage decrease in the average annual rig count since 2016. While the North American market deteriorated, the new-found capital austerity and fiscal discipline exhibited by U.S. operators along with declining production from underinvestment in overseas markets and rapidly growing demand for LNG inspired greater levels of confidence from international oil and gas companies. The industry entered 2020 anticipating higher international
and offshore activity levels would mostly offset the ongoing effects of capital austerity in the North American land marketplace.
During the first quarter of 2020, the coronavirus (COVID-19) outbreak rapidly spread across the world, driving sharp demand destruction for crude oil as countries took measures to curtail activity to slow the spread of the outbreak. In response to declining market share, members of the Organization of the Petroleum Exporting Countries and other producing countries (OPEC+), including Russia, increased production into the already oversupplied market, decimating oil prices and rapidly filling worldwide storage facilities. In April 2020, OPEC+ began to reduce production, which had only a muted positive effect on oil prices due to market concerns that the cuts were significantly less than the demand destruction caused by COVID-19. As a result, companies across the industry responded with severe capital spending budget cuts, cost cuts, personnel layoffs, facility closures and bankruptcy filings. The COVID-19 virus continued to spread throughout 2020, extending depressed demand, uncertainty and additional spending reductions by the entire oil and gas industry as the U.S. rig count fell to its lowest level since 1940 in August of 2020. In response to the economic destruction caused by the COVID-19 pandemic, many governments implemented stimulus programs to aid individuals and businesses. The size, method and effectiveness of these programs varies greatly and, although generally helpful to the economy, they have not restored prior levels of demand for oil and gas.
During the fourth quarter of 2020 rising activity levels in the U.S. drove higher revenues for NOV’s short-cycle businesses in North America. These modest improvements were offset by a decline in international drilling activity and limited demand for capital equipment. Management expects industry activity levels and spending by customers to remain depressed during the beginning of 2021, as demand destruction from COVID-19 persists, but is optimistic that improving commodity prices, rising activity, and the actions NOV is taking to position its business for the future will result in improved profitability over the course of 2021. NOV remains committed to streamlining operations and improving organizational efficiencies while focusing on investing in innovative products and services, including environmentally friendly technologies, that are responsive to the longer-term needs of our customers. We believe this strategy will further advance the Company’s competitive position, regardless of the market environment.
Results of Operations
The following table summarizes the Company’s revenue and operating profit (loss) by operating segment (in millions):
Years Ended December 31,
% Change
2020 vs. 2019
2019 vs. 2018
Revenue:
Wellbore Technologies
$
1,867
$
3,214
$
3,235
(41.9
%)
(0.6
%)
Completion & Production Solutions
2,433
2,771
2,931
(12.2
%)
(5.5
%)
Rig Technologies
1,919
2,682
2,575
(28.4
%)
4.2
%
Eliminations
(129
)
(188
)
(288
)
(31.4
%)
(34.7
%)
Total Revenue
$
6,090
$
8,479
$
8,453
(28.2
%)
0.3
%
Operating Profit (Loss):
Wellbore Technologies
$
(858
)
$
(3,551
)
$
(75.8
%)
(2810.7
%)
Completion & Production Solutions
(977
)
(1,934
)
(49.5
%)
(1265.1
%)
Rig Technologies
(362
)
(524
)
(30.9
%)
(346.0
%)
Eliminations and corporate costs
(228
)
(270
)
(299
)
(15.6
%)
(9.7
%)
Total Operating Profit (Loss)
$
(2,425
)
$
(6,279
)
$
(61.4
%)
(3075.8
%)
Operating Profit (Loss)%:
Wellbore Technologies
(46.0
%)
(110.5
%)
4.0
%
Completion & Production Solutions
(40.2
%)
(69.8
%)
5.7
%
Rig Technologies
(18.9
%)
(19.5
%)
8.3
%
Total Operating Profit (Loss) %
(39.8
%)
(74.1
%)
2.5
%
Years Ended December 31, 2020 and December 31, 2019
Wellbore Technologies
Revenue from Wellbore Technologies for the year ended December 31, 2020 was $1,867 million, a decrease of $1,347 million (-42%) compared to the year ended December 31, 2019.
Operating loss from Wellbore Technologies was $858 million for the year ended December 31, 2020, an increase of $2,693 million compared to the year ended December 31, 2019. Operating loss percentage for 2020 was -46.0% compared to an operating loss percentage of -110.5% percent in 2019.
Other Items included in operating loss for Wellbore Technologies were $849 million for the year ended December 31, 2020 and $3,794 million for the year ended December 31, 2019.
Completion & Production Solutions
Revenue from Completion & Production Solutions for the year ended December 31, 2020 was $2,433 million, a decrease of $338 million (-12%) compared to the year ended December 31, 2019.
Operating loss from Completion & Production Solutions was $977 million for the year ended December 31, 2020 compared to an operating loss of $1,934 million for 2019, an increase of $957 million. Operating loss percentage for 2020 was -40.2% compared to -69.8% in 2019.
Included in operating loss are Other Items related to impairment charges, inventory charges, severance accruals and other charges and credits. Other items included in operating loss for Completion & Production Solutions was $1,132 million for the year ended December 31, 2020 and $2,042 million for the year ended December 31, 2019.
The Completion & Production Solutions segment monitors its capital equipment backlog to plan its business. New orders are added to backlog only when the Company receives a firm written order for major completion and production components or a signed contract related to a construction project. The capital equipment backlog was $695 million at December 31, 2020, a decrease of $610 million, or 47 percent from backlog of $1,305 million at December 31, 2019. Numerous factors may affect the timing of revenue out of backlog. Considering these factors, the Company reasonably expects approximately $621 million of revenue out of backlog in 2021 and approximately $74 million of revenue out of backlog in 2022 and thereafter. At December 31, 2020, approximately 63 percent of the capital equipment backlog was for offshore products and approximately 88 percent of the capital equipment backlog was destined for international markets.
Rig Technologies
Revenue from Rig Technologies for the year ended December 31, 2020 was $1,919 million, a decrease of $763 million (-28%) compared to the year ended December 31, 2019.
Operating loss from Rig Technologies was $362 million for the year ended December 31, 2020, a decrease of $162 million compared to 2019. Operating loss percentage for 2020 was -18.9% compared to -19.5% in 2019.
Included in operating loss are Other Items related to severance and facility closures, and asset write-downs. Other Items included in operating loss for Rig Technologies were $402 million for the year ended December 31, 2020 and $784 million for the year ended December 31, 2019.
The Rig Technologies segment monitors its capital equipment backlog to plan its business. New orders are added to backlog only when the Company receives a firm written order for major drilling rig components or a signed contract related to a construction project. The capital equipment backlog was $2.7 billion at December 31, 2020, a decrease of $325 million, or 11 percent, from backlog of $3.0 billion at December 31, 2019. Numerous factors may affect the timing of revenue out of backlog. Considering these factors, the Company reasonably expects approximately $556 million of revenue out of backlog in 2021 and the remaining in 2022 and thereafter. At December 31, 2020, approximately 24% of the capital equipment backlog was for offshore products and approximately 90 percent of the capital equipment backlog was destined for international markets.
Eliminations and corporate costs
Eliminations and corporate costs were $228 million for the year ended December 31, 2020 compared to $270 million for the year ended December 31, 2019. This change is primarily due to a decrease in intersegment sales. Sales from one segment to another generally are priced at estimated equivalent commercial selling prices; however, segments originating an external sale are credited with the full profit to the Company. Eliminations and corporate costs include intercompany transactions conducted between the three reporting segments that are eliminated in consolidation, as well as corporate costs not allocated to the segments. Intercompany transactions within each reporting segment are eliminated within each reporting segment.
Other income (expense), net
Other income (expense), net was income of $17 million for the year ended December 31, 2020 compared to expense of $90 million for the year ended December 31, 2019. The decrease in expense was primarily due to lower foreign exchange losses for 2020.
Provision for income taxes
The effective tax rate for the year ended December 31, 2020 was 8.7%, compared to 5.7% for 2019. For the year ended December 31, 2020 the effective tax rate was negatively impacted by the impairment of nondeductible goodwill and the establishment of additional valuation allowances for current year losses and other tax attributes, partially offset by the release of valuation allowance as a result of (a) the carryback of $591 million of US net operating losses from 2019 to 2014 pursuant to the Coronavirus Aid, Relief, and Economy Security Act (CARES Act) and (b) the filing of an amended US tax return to deduct foreign tax credits and carryback the resulting $287 million US net operating loss from 2016 to 2014. For the year ended December 31, 2019, the effective tax rate was negatively impacted by the impairment of nondeductible goodwill and the establishment of additional valuation allowance partially offset by the reduction in uncertain tax positions due to settlements.
Refer to our 2019 Form 10-K for discussion of 2019 versus 2018.
Non-GAAP Financial Measures and Reconciliations
The Company discloses Adjusted EBITDA (defined as Operating Profit excluding Depreciation, Amortization and, when applicable, Other Items) in its periodic earnings press releases and other public disclosures to provide investors additional information about the results of ongoing operations. The Company uses Adjusted EBITDA internally to evaluate and manage the business. Adjusted EBITDA is not intended to replace GAAP financial measures, such as Net Income.
Other items consist of (in millions):
Three Months Ended
Years Ended
December 31,
September 30,
December 31,
Other items by category:
Goodwill
$
-
$
$
-
$
1,295
$
3,509
Identified intangibles
-
-
2,004
Inventory charges
Long-lived assets
-
-
Voluntary early retirement program
-
(3
)
-
-
Severance, facility closures and other
Total other items
$
$
$
$
2,423
$
6,631
The following tables set forth the reconciliation of Adjusted EBITDA to its most comparable GAAP financial measure (in millions):
Three Months Ended
Years Ended
December 31,
September 30,
December 31,
Operating profit (loss):
Wellbore Technologies
$
(78
)
$
(317
)
$
(50
)
$
(858
)
$
(3,551
)
Completion & Production Solutions
(31
)
(977
)
(1,934
)
Rig Technologies
(132
)
(23
)
(3
)
(362
)
(524
)
Eliminations and corporate costs
(60
)
(66
)
(46
)
(228
)
(270
)
Total operating profit (loss)
$
(301
)
$
(349
)
$
(74
)
$
(2,425
)
$
(6,279
)
Other Items:
Wellbore Technologies
$
$
$
$
$
3,794
Completion & Production Solutions
1,132
2,042
Rig Technologies
Corporate
-
Total Other Items
$
$
$
$
2,423
$
6,631
Depreciation & amortization:
Wellbore Technologies
$
$
$
$
$
Completion & Production Solutions
Rig Technologies
Corporate
Total depreciation & amortization
$
$
$
$
$
Adjusted EBITDA:
Wellbore Technologies
$
$
$
$
$
Completion & Production Solutions
Rig Technologies
Eliminations and corporate costs
(42
)
(63
)
(41
)
(175
)
(247
)
Total Adjusted EBITDA
$
$
$
$
$
Reconciliation of Adjusted EBITDA:
GAAP net income (loss) attributable to Company
$
(347
)
$
(385
)
$
(55
)
$
(2,542
)
$
(6,095
)
Noncontrolling interests
(1
)
-
Provision (benefit) for income taxes
(46
)
(61
)
(242
)
(369
)
Interest expense
Interest income
(2
)
(4
)
-
(7
)
(20
)
Equity loss in unconsolidated affiliate
Other (income) expense, net
(2
)
Depreciation and amortization
Other Items
2,423
6,631
Total Adjusted EBITDA
$
$
$
$
$
Liquidity and Capital Resources
At December 31, 2020, the Company had cash and cash equivalents of $1,692 million, and total debt of $1,834 million. At December 31, 2019, cash and cash equivalents were $1,171 million and total debt was $1,989 million. As of December 31, 2020, approximately $1,037 million of the $1,692 million of cash and cash equivalents was held by our foreign subsidiaries and the earnings associated with this cash could be subject to foreign withholding taxes and incremental U.S. taxation. If opportunities to invest in the U.S. are greater than available cash balances that are not subject to income tax, rather than repatriating cash, the Company may choose to borrow against its revolving credit facility.
The Company has a $2.0 billion, five-year unsecured revolving credit facility, which expires on October 30, 2024. The Company has the right to increase the commitments under this agreement to an aggregate amount of up to $3.0 billion upon the consent of only those lenders holding any such increase. Interest under the multicurrency facility is based upon LIBOR, NIBOR or CDOR plus 1.125% subject to a ratings-based grid or the U.S. prime rate. The credit facility contains a financial covenant regarding maximum debt-to-capitalization ratio of 60%. As of December 31, 2020, the Company was in compliance with a debt-to-capitalization ratio of 28.4% and had no outstanding letters of credit issued under the facility, resulting in $2.0 billion of available funds.
The Company also has a $150 million bank line of credit for the construction of a facility in Saudi Arabia. Interest under the bank line of credit is based upon LIBOR plus 1.40%. The bank line of credit contains a financial covenant regarding maximum debt-to-equity ratio of 75%. As of December 31, 2020, the Company was in compliance.
On August 25, 2020, the Company completed a cash tender offer for $217.3 million of its 2.60% unsecured Senior Notes using available cash balances. The Company paid $226 million, which included a redemption premium of $7.6 million as well as accrued and unpaid interest of $1.3 million. As a result of the redemption, the Company recorded a loss on extinguishment of debt of $8.2 million, which included the redemption premium of $7.6 million and non-cash charges of $0.6 million attributable to the write-off of unamortized discount and debt issuance costs.
The Company’s outstanding debt at December 31, 2020 was $1,834 million and consisted of $182 million in 2.60% Senior Notes, $493 million in 3.60% Senior Notes, $1,089 million in 3.95% Senior Notes, no commercial paper borrowings, and other debt of $70 million. The Company was in compliance with all covenants at December 31, 2020.
The Company had $446 million of outstanding letters of credit at December 31, 2020 that are under various bilateral letter of credit facilities. Letters of credit are issued as bid bonds, advanced payment bonds and performance bonds
The following table summarizes our net cash provided by operating activities, net cash used in investing activities and net cash used in financing activities for the periods presented (in millions):
Years Ended December 31,
Net cash provided by operating activities
$
$
$
Net cash used in investing activities
(144
)
(315
)
(457
)
Net cash used in financing activities
(259
)
(647
)
(30
)
Significant sources and uses of cash during 2020
•
Cash flows provided by operating activities was $926 million. This included changes in the primary components of our working capital (receivables, inventories, and accounts payable), primarily related to strong collections on accounts receivable.
•
Capital expenditures were $226 million.
•
We paid $19 million in dividends to our shareholders.
Oil and Gas Market Downturn and COVID-19 Pandemic
Since the oil and gas market downturn began in late 2014, the Company has maintained a continuous process of actively managing its strategy, structure and resources to the changing market conditions and new realities. The Company has closed or realigned hundreds of facilities, reduced headcount, sharply lowered costs and reviewed all product lines for acceptable returns in the evolved market. Additionally, the Company has proactively reduced the balances and extended the maturity profile of its debt. In the fall of 2019, the Company retired $1 billion of notes
due 2022 for cash, issued $500 million of notes due 2029 and extended the maturity of its undrawn credit facility to 2024. In August 2020, the Company completed a tender on $217 million of the remaining 2022 notes, further reducing its amount of debt outstanding. While aggressively matching size and spend to the market, and protecting its balance sheet, the Company has continued investing in new products and technologies that enable its customers to improve their operational efficiencies.
When the COVID-19 global pandemic and OPEC+ actions further depressed oil prices and industry activity beginning in March of 2020, the Company’s prior prudent actions helped ensure adequate available resources. Management intends to continue managing the business to the market realities to ensure the Company’s access to capital remains sufficient. See Item 1A Risk Factors.
Other
The effect of the change in exchange rates on cash was a decrease of ($2) million, ($8) million and ($44) million for the years ended December 31, 2020, 2019 and 2018, respectively.
We believe that cash on hand, cash generated from operations and amounts available under our credit facilities and from other sources of debt will be sufficient to fund operations, working capital needs, capital expenditure requirements, dividends and financing obligations.
We intend to pursue additional acquisition candidates, but the timing, size or success of any acquisition effort and the related potential capital commitments cannot be predicted. We continue to expect to fund future cash acquisitions primarily with cash flow from operations and borrowings, including the unborrowed portion of the revolving credit facility or new debt issuances, but may also issue additional equity either directly or in connection with acquisitions. There can be no assurance that additional financing for acquisitions will be available at terms acceptable to us.
As of December 31, 2020, the Company had $57 million of unrecognized tax benefits. This represents the tax benefits associated with various tax positions taken, or expected to be taken, on domestic and international tax returns that have not been recognized in our financial statements due to uncertainty regarding their resolution. Due to the uncertainty of the timing of future cash flows associated with these unrecognized tax benefits, we are unable to make reasonably reliable estimates of the period of cash settlement, if any, with the respective taxing authorities. For further information related to unrecognized tax benefits, see Note 15 to the Consolidated Financial Statements.
Critical Accounting Policies and Estimates
In preparing the financial statements, we make assumptions, estimates and judgements that affect the amounts reported. We periodically evaluate our estimates and judgements that are most critical in nature which are related to revenue recognition under long-term construction contracts; allowance for doubtful accounts; inventory reserves; impairments of long-lived assets (excluding goodwill and other indefinite-lived intangible assets); impairment of goodwill and other indefinite-lived intangible assets; purchase price allocation of acquisitions; service and product warranties and income taxes. Our estimates are based on historical experience and on our future expectations that we believe are reasonable. The combination of these factors forms the basis for making judgements about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results are likely to differ from our current estimates and those differences may be material.
Revenue Recognition
The majority of the Company’s revenue streams record revenue at a point in time when a performance obligation has been satisfied by transferring control of promised goods or services to a customer. Products and services are sold or rented based upon a fixed or determinable price and do not generally include significant post-delivery obligations. Payment terms and conditions vary by contract type. We have elected to apply the practical expedient that does not require an adjustment for a financing component if, at contract inception, the period between when we transfer the promised goods or service to the customer and when the customer pays for the goods or service is one year or less. Shipping and handling costs are recognized when incurred and are treated as costs to fulfill the original performance obligation.
Revenue is often generated from contracts that include multiple performance obligations. Using significant judgement, the Company considers the degree of customization, integration and interdependency of the related products and services when assessing distinct performance obligations within one contract. Stand-alone selling price (“SSP”) for each distinct performance obligation is generally determined using the price at which the products and services would be sold separately to the customer. Discounts, when provided, are allocated based on the relative SSP of the various products and services.
For revenue that is not recognized at a point in time, the Company follows accounting guidance for revenue recognized over time, as follows:
Revenue Recognition under Long-term Construction Contracts
Revenue is recognized over-time for certain long-term construction contracts in the Completion & Production Solutions and Rig Technologies segments. These contracts include custom designs for customer-specific applications that are unique and require significant engineering efforts. Revenue is recognized as work progresses on each contract. Right to payment is enforceable for performance completed to date, including a reasonable profit.
We generally use the cost-to-cost (input) measure of progress for our contracts because it best depicts the transfer of assets to the customer which occurs as we incur costs. Under the cost-to-cost measure of progress, progress towards completion of each contract is measured based on the ratio of costs incurred to date to the total estimated costs at completion of the performance obligation. Revenues, including estimated fees or profits, are recorded proportionally as costs are incurred. These costs include labor, materials, subcontractors’ costs, and other direct costs. Any expected losses on a project are recorded in full in the period in which the loss becomes probable.
These long-term construction contracts generally include a significant service of integrating a complex set of tasks and components into a single project or capability, so are accounted for as one performance obligation.
Estimating total revenue and cost at completion of long-term construction contracts is complex, subject to many variables and requires significant judgement. It is common for our long-term contracts to contain late delivery fees, work performance guarantees, and other provisions that can either increase or decrease the transaction price. We estimate variable consideration as the most likely amount we expect to receive. We include variable consideration in the estimated transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur, or when the uncertainty associated with the variable consideration is resolved. Our estimates of variable consideration and determination of whether to include estimated amounts in the transaction price are based on an assessment of our anticipated performance and historical, current and forecasted information that is reasonably available to us. Net revenue recognized from performance obligations satisfied in previous periods was $41 million for the year ended December 31, 2020 primarily due to change orders.
Service and Repair Work
For service and repair contracts, revenue is recognized over time. We generally use the output method to measure progress on service contracts due to the manner in which the customer receives and derives value from the services provided. For repair contracts, we generally use the cost-to-cost measure of progress because it best depicts the transfer of assets to the customer.
Remaining Performance Obligations
Remaining performance obligations represent the transaction price of firm orders for all revenue streams for which work has not been performed on contracts with an original expected duration of one year or more. We do not disclose the remaining performance obligations of royalty contracts, service contracts for which there is a right to invoice, and short-term contracts that are expected to have a duration of one year or less.
As of December 31, 2020, the aggregate amount of the transaction price allocated to remaining performance obligations was $3,693 million. The Company expects to recognize approximately $905 million in revenue for the remaining performance obligations in 2021 and $2,788 million in 2022 and thereafter.
Costs to Obtain and Fulfill a Contract
We recognize an asset for the incremental costs of obtaining a contract, such as sales commissions, with a customer when we expect the benefit of those costs to be longer than one year. Costs to fulfill a contract, such as set-up and mobilization costs, are also capitalized when we expect to recover those costs. These contract costs are deferred and amortized over the period of contract performance. Total capitalized costs to obtain and fulfill a contract and the related amortization were immaterial during the periods presented and are included in other current and long-term assets on our consolidated balance sheets. We apply the practical expedient to expense costs as incurred for costs to obtain a contract with a customer when the amortization period would have been one year or less.
Inventory Reserves
Inventory is carried at the lower of cost or estimated net realizable value. The Company reviews historical usage of inventory on-hand, assumptions about future demand and market conditions, current cost and estimates about potential alternative uses, which are limited, to estimate net realizable value. The Company’s inventory consists of finished goods, spare parts, work in process, and raw materials to support ongoing manufacturing operations and the Company’s large installed base of highly specialized oilfield equipment. The Company’s estimated carrying value of inventory depends upon demand largely driven by levels of oil and gas well drilling and remediation activity, which depends in turn upon oil and gas prices, the general outlook for economic growth worldwide, available financing for the Company’s customers, political stability and governmental regulation in major oil and gas producing areas, and the potential obsolescence of various types of equipment we sell, among other factors.
Based on an update of our assumptions at each point in time related to estimates of future demand, during 2020, 2019, and 2018 we recorded charges for additions to inventory reserves of $367 million, $659 million, and $49 million, respectively, consisting primarily of obsolete and surplus inventories. At December 31, 2020 and 2019, inventory reserves totaled $577 million and $843 million, or 29.1% and 27.7% of gross inventory, respectively.
Throughout the downturn the Company has continued to invest in developing and advancing products and technologies, contributing to the obsolescence of certain older products in a dramatically-shifted and more highly competitive recovering market, but also ensuring that the portfolio of products and services offered by the Company will meet customer needs in 2021 and beyond.
We will continue to assess our inventory levels and inventory offerings for our customers, which could require the Company to record additional allowances to reduce the value of its inventory. Such changes in our estimates or assumptions could be material under weaker market conditions or outlook.
Impairment of Long-Lived Assets (Excluding Goodwill and Other Indefinite-Lived Intangible Assets)
Long-lived assets, which include property, plant and equipment and identified intangible assets, comprise a significant amount of the Company’s total assets. The Company makes judgements and estimates in conjunction with the carrying value of these assets, including amounts to be capitalized, depreciation and amortization methods and estimated useful lives.
The carrying values of these assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. An impairment loss is recorded in the period in which it is determined that the carrying amount is not recoverable based on estimated future undiscounted cash flows. We estimate the fair value of these intangible and fixed assets using an income approach. This requires the Company to
make long-term forecasts of its future revenues and costs related to the assets subject to review. These forecasts require assumptions about demand for the Company’s products and services, future market conditions and technological developments. The forecasts are dependent upon assumptions regarding oil and gas prices, the general outlook for economic growth worldwide, available financing for the Company’s customers, political stability in major oil and gas producing areas, and the potential obsolescence of various types of equipment we sell, among other factors. The financial and credit market volatility directly impacts our fair value measurement through our income forecast. Changes to these assumptions, including, but not limited to: sustained declines in worldwide rig counts below current analysts’ forecasts, collapse of spot and futures prices for oil and gas, significant deterioration of external financing for our customers, higher risk premiums or higher cost of equity, or any other significant adverse economic news could require a provision for impairment in a future period.
For the year ended December 31, 2020, the Company recorded $513 million in impairment charges related to long-lived assets. See Note 6 - Asset Impairments (Part IV, Item 15 of this Form 10-K) for further discussion.
Goodwill and Other Indefinite-Lived Intangible Assets
The Company has approximately $1.5 billion of goodwill and $0.2 billion of other intangible assets with indefinite lives as of December 31, 2020. Generally accepted accounting principles require the Company to test goodwill and other indefinite-lived intangible assets for impairment at least annually or more frequently whenever events or circumstances occur indicating that goodwill or other indefinite-lived intangible assets might be impaired. Events or circumstances which could indicate a potential impairment include (but are not limited to) a significant sustained reduction in worldwide oil and gas prices or drilling; a significant sustained reduction in profitability or cash flow of oil and gas companies or drilling contractors; a sustained reduction in the market capitalization of the Company; a significant sustained reduction in capital investment by drilling companies and oil and gas companies; or a significant sustained increase in worldwide inventories of oil or gas.
The Company performs its goodwill and indefinite-lived intangible asset impairment test based on the Company’s discounted cash flow analysis. The discounted cash flow is based on management’s forecast of operating performance for each reporting unit. The two main assumptions used in measuring goodwill impairment, which bear the risk of change and could impact the Company’s goodwill impairment analysis, include the cash flow from operations from each of the Company’s individual Reporting Units and the weighted average cost of capital. The starting point for each of the reporting unit’s cash flow from operations is the detailed annual plan or updated forecast. Cash flows beyond the specific operating plans were estimated using a terminal value calculation, which incorporated historical and forecasted financial cyclical trends for each reporting unit and considered long-term earnings growth rates. The financial and credit market volatility directly impacts our fair value measurement through our weighted average cost of capital that we use to determine our discount rate. During times of volatility, significant judgement must be applied to determine whether credit changes are a short-term or long-term trend.
While the Company primarily uses the discounted cash flow method to assess fair value, the Company uses the comparable companies and representative transaction methods to validate the discounted cash flow analysis and further support management’s expectations, where possible. The valuation techniques used in the annual test were consistent with those used during previous testing. The inputs used in the annual test were updated for current market conditions and forecasts.
For the year ended December 31, 2019, the Company recorded $3,509 million in impairment charges to goodwill and $103 million in charges to indefinite-lived intangible assets. For the year ended December 31, 2020, the Company recorded a $1,295 million in impairment charges to goodwill and $83 million in charges to indefinite-lived intangible assets. See Note 6 - Asset Impairments (Part IV, Item 15 of this Form 10-K) for further discussion.
Income Taxes
The Company is U.S. registered and is subject to income taxes in the U.S. The Company operates through various subsidiaries in a number of countries throughout the world. Income taxes have been recorded based upon the tax laws and rates of the countries in which the Company operates and income is earned.
The Company’s annual tax provision is based on taxable income, statutory rates and tax planning opportunities available in the various jurisdictions in which it operates. The determination and evaluation of the annual tax provision and tax positions involves the interpretation of the tax laws in the various jurisdictions in which the Company operates. It requires significant judgement and the use of estimates and assumptions regarding significant future events such as the amount, timing and character of income, deductions and tax credits. Changes in tax laws, regulations, and treaties, foreign currency exchange restrictions or the Company’s level of operations or profitability in each jurisdiction could impact the tax liability in any given year. The Company also operates in many jurisdictions where the tax laws relating to the pricing of transactions between related parties are open to interpretation, which could potentially result in aggressive tax authorities asserting additional tax liabilities with no offsetting tax recovery in other countries.
The Company maintains liabilities for estimated tax exposures in jurisdictions of operation. The annual tax provision includes the impact of income tax provisions and benefits for changes to liabilities that the Company considers appropriate, as well as related interest. Tax exposure items primarily include potential challenges to intercompany pricing and certain operating expenses that may not be deductible in foreign jurisdictions. These exposures are resolved primarily through the settlement of audits within these tax jurisdictions or by judicial means. The Company is subject to audits by federal, state and foreign jurisdictions which may result in proposed assessments. The Company believes that an appropriate liability has been established for estimated exposures under the guidance in ASC Topic 740 “Income Taxes” (“ASC Topic 740”). However, actual results may differ materially from these estimates. The Company reviews these liabilities quarterly and to the extent audits or other events result in an adjustment to the liability accrued for a prior year, the effect will be recognized in the period of the event.
The Company currently has recorded valuation allowances that the Company intends to maintain until it is more likely than not the deferred tax assets will be realized. Income tax expense recorded in the future will be reduced to the extent of decreases in the Company’s valuation allowances. The realization of remaining deferred tax assets is primarily dependent on future taxable income. Any reduction in future taxable income including but not limited to any future restructuring activities may require that the Company record an additional valuation allowance against deferred tax assets. An increase in the valuation allowance would result in additional income tax expense in such period and could have a significant impact on future earnings.
After considering the impact of losses incurred in 2020, the Company has determined that it no longer has net undistributed earnings subject to a permanent reinvestment assertion.
Recently Issued and Recently Adopted Accounting Standards
See Note 2 - Summary of Significant Accounting Policies (Part IV, Item 15 of this Form 10-K) for further discussion.
Forward-Looking Statements
Some of the information in this document contains, or has incorporated by reference, forward-looking statements. Statements that are not historical facts, including statements about our beliefs and expectations, are forward-looking statements. Forward-looking statements typically are identified by use of terms such as “may,” “will,” “expect,” “anticipate,” “estimate,” and similar words, although some forward-looking statements are expressed differently. All statements herein regarding expected merger synergies are forward looking statements. You should be aware that our actual results could differ materially from results anticipated in the forward-looking statements due to a number of factors, including but not limited to changes in oil and gas prices, customer demand for our products and worldwide economic activity. You should also consider carefully the statements under “Risk Factors” which address additional factors that could cause our actual results to differ from those set forth in the forward-looking statements. Given these uncertainties, current or prospective investors are cautioned not to place undue reliance on any such forward-looking statements. We undertake no obligation to update any such factors or forward-looking statements to reflect future events or developments.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A.
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We are exposed to changes in foreign currency exchange rates and interest rates. Additional information concerning each of these matters follows:
Foreign Currency Exchange Rates
We have extensive operations in foreign countries. The net assets and liabilities of these operations are exposed to changes in foreign currency exchange rates, although such fluctuations generally do not affect income since their functional currency is typically the local currency. These operations also have net assets and liabilities not denominated in the functional currency, which exposes us to changes in foreign currency exchange rates that impact income. During the years ended December 31, 2020, 2019 and 2018, the Company reported foreign currency losses of $2 million, $36 million and $52 million, respectively. Gains and losses are primarily due to exchange rate fluctuations related to monetary asset balances denominated in currencies other than the functional currency and adjustments to our hedged positions as a result of changes in foreign currency exchange rates. Currency fluctuations may create losses in future periods to the extent we maintain net assets and liabilities not denominated in the functional currency of our subsidiaries using the local currency as their functional currency.
Some of our revenues in foreign countries are denominated in U.S. dollars, and therefore, changes in foreign currency exchange rates impact our earnings to the extent that costs associated with those U.S. dollar revenues are denominated in the local currency. Similarly, some of our revenues are denominated in foreign currencies, but have associated U.S. dollar costs, which also give rise to foreign currency exchange rate exposure. In order to mitigate that risk, we may utilize foreign currency forward contracts to better match the currency of our revenues and associated costs. We do not use foreign currency forward contracts for trading or speculative purposes.
The Company had other financial market risk sensitive instruments (cash balances, overdraft facilities, accounts receivable and accounts payable) denominated in foreign currencies with transactional exposures totaling $509 million and translation exposures totaling $291 million as of December 31, 2020. The Company estimates that a hypothetical 10% movement of all applicable foreign currency exchange rates on the transactional exposures could affect net income by $40 million and the translational exposures could affect Other Comprehensive Income by $29 million.
The counterparties to forward contracts are major financial institutions. The credit ratings and concentration of risk of these financial institutions are monitored on a continuing basis. In the event that the counterparties fail to meet the terms of a foreign currency contract, our exposure is limited to the foreign currency rate differential.
Interest Rate Risk
At December 31, 2020, long term borrowings consisted of $1,089 million in 3.95% Senior Notes, $493 million in 3.60% Senior Notes and $182 million in 2.60% Senior Notes, no commercial paper borrowings and no borrowings against our revolving credit facility. Occasionally a portion of borrowings under our credit facility could be denominated in multiple currencies which could expose us to market risk with exchange rate movements. These instruments carry interest at a pre-agreed upon percentage point spread from either LIBOR, NIBOR or CDOR, or at the U.S. prime rate. Under our credit facility, we may, at our option, fix the interest rate for certain borrowings based on a spread over LIBOR, NIBOR or CDOR for 30 days to six months. Our objective is to maintain a portion of our debt in variable rate borrowings for the flexibility obtained regarding early repayment without penalties and lower overall cost as compared with fixed-rate borrowings.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8.
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Attached hereto and a part of this report are financial statements and supplementary data listed in Item 15. “Exhibits and Financial Statement Schedules.”

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9.
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
None.

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ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A.
CONTROLS AND PROCEDURES
(i) Evaluation of disclosure controls and procedures
As required by SEC Rule 13a-15(b), we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by the Company in reports that it files under the Exchange Act is accumulated and communicated to the Company’s management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Our principal executive officer and principal financial officer have concluded that our current disclosure controls and procedures were effective as of December 31, 2020 at the reasonable assurance level.
Pursuant to section 302 of the Sarbanes-Oxley Act of 2002, our Chief Executive Officer and Chief Financial Officer have provided certain certifications to the Securities and Exchange Commission. These certifications are included herein as Exhibits 31.1 and 31.2.
(ii) Internal Control Over Financial Reporting
(a) Management’s annual report on internal control over financial reporting.
The Company’s management report on internal control over financial reporting is set forth in this annual report on Page 56 and is incorporated herein by reference.
(b) Changes in internal control
There were no changes in the Company’s internal control over financial reporting that occurred during the Company’s last fiscal quarter covered by this report that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
ITEM 9B.
OTHER INFORMATION
None.
PART III

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10.
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Incorporated by reference to the definitive Proxy Statement for the 2020 Annual Meeting of Stockholders.

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ITEM 11. EXECUTIVE COMPENSATION
ITEM 11.
EXECUTIVE COMPENSATION
Incorporated by reference to the definitive Proxy Statement for the 2020 Annual Meeting of Stockholders.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12.
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
Incorporated by reference to the definitive Proxy Statement for the 2020 Annual Meeting of Stockholders.
Securities Authorized for Issuance Under Equity Compensation Plans.
The following table sets forth information as of our fiscal year ended December 31, 2020, with respect to compensation plans under which our common stock may be issued:
Number of securities
Weighted-average
Number of securities
to be issued upon
exercise price of
remaining available for equity
exercise of warrants
outstanding
compensation plans (excluding
and rights
rights
securities reflected in column (a)) ('c')
Plan Category
(a)
(b)
(1)
Equity compensation plans approved
by security holders
21,005,502
$
49.25
10,521,344
Equity compensation plans not approved
by security holders
-
-
-
Total
21,005,502
$
49.25
10,521,344
(1)
Shares could be issued through equity instruments other than stock options, warrants or rights.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13.
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Incorporated by reference to the definitive Proxy Statement for the 2020 Annual Meeting of Stockholders.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14.
PRINCIPAL ACCOUNTING FEES AND SERVICES
Incorporated by reference to the definitive Proxy Statement for the 2020 Annual Meeting of Stockholders.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15.
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
Financial Statements and Exhibits
(1)
Financial Statements
The following financial statements are presented in response to Part II, Item 8:
Page
Consolidated Balance Sheets
Consolidated Statements of Income (Loss)
Consolidated Statements of Comprehensive Income (Loss)
Consolidated Statements of Cash Flows
Consolidated Statements of Stockholders’ Equity
Notes to Consolidated Financial Statements
(2)
Financial Statement Schedule
Schedule II - Valuation and Qualifying Accounts
All schedules, other than Schedule II, are omitted because they are not applicable, not required or the information is included in the financial statements or notes thereto.
(3)
Exhibits
3.1
Sixth Amended and Restated Certificate of Incorporation of NOV Inc. (Exhibit 3.1) (1)
3.2
Amended and Restated By-laws of NOV Inc. (Exhibit 3.2) (1)
4.1
Description of Securities
10.1
Credit Agreement, dated as of June 27, 2017, among National Oilwell Varco, Inc., the financial institutions signatory thereto, including Wells Fargo Bank, N.A., in its capacity, among others, as Administrative Agent, Co-Lead Arranger and Joint Book Runner (Exhibit 3.1)(2)
10.2
Amendment No. 1 to Credit Agreement, dated as of October 30, 2019 (3)
10.3
National Oilwell Varco, Inc. 2018 Long-Term Incentive Plan, as amended and restated. (4)*
10.4
Form of Employee Stock Option Agreement. (Exhibit 10.1) (5)
10.5
Form of Non-Employee Director Stock Option Agreement. (Exhibit 10.2) (5)
10.6
Form of Performance-Based Restricted Stock. (18 Month) Agreement (Exhibit 10.1) (6)
10.7
Form of Performance-Based Restricted Stock. (36 Month) Agreement (Exhibit 10.2) (6)
10.8
Form of Performance Award Agreement (Exhibit 10.1) (7)
10.9
Form of Executive Employment Agreement. (Exhibit 10.1) (8)
10.10
Form of Executive Severance Agreement. (Exhibit 10.2) (9)
10.11
Form of Employee Nonqualified Stock Option Grant Agreement (10)
10.12
Form of Restricted Stock Agreement (10)
10.13
Form of Performance Award Agreement (10)
10.14
Form of Employee Nonqualified Stock Option Grant Agreement (2019) (11)
10.15
Form on Restricted Stock Agreement (2019) (11)
10.16
Form of Performance Award Agreement (2019) (11)
10.17
Form of Performance Award Agreement (2020) (12)
21.1
Subsidiaries of the Registrant
23.1
Consent of Ernst & Young LLP.
24.1
Power of Attorney. (included on signature page hereto)
31.1
Certification pursuant to Rule 13a-14a and Rule 15d-14(a) of the Securities and Exchange Act, as amended.
31.2
Certification pursuant to Rule 13a-14a and Rule 15d-14(a) of the Securities and Exchange Act, as amended.
32.1
Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2
Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
Mine Safety Information pursuant to section 1503 of the Dodd-Frank Act.
101.INS
Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH
Inline XBRL Taxonomy Extension Schema Document
101.CAL
Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF
Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB
Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE
Inline XBRL Taxonomy Extension Presentation Linkbase Document
Cover Page Interactive Data File (formatted as inline XBRL and contained in Exhibit 101)
*
Compensatory plan or arrangement for management or others.
(1)
Filed as an Exhibit to our Current Report on Form 8-K filed on December 22, 2020.
(2)
Filed as an Exhibit to our Current Report on Form 8-K filed on June 28, 2017
(3)
Filed as an Exhibit to our Current Report on Form 8-K filed on November 4, 2019.
(4)
Filed as Appendix I to our Proxy Statement filed on April 9, 2020.
(5)
Filed as an Exhibit to our Current Report on Form 8-K filed on February 23, 2006.
(6)
Filed as an Exhibit to our Current Report on Form 8-K filed on March 27, 2007.
(7)
Filed as an Exhibit to our Current Report on Form 8-K filed on March 27, 2013.
(8)
Filed as an Exhibit to our Current Report on Form 8-K filed on December 4, 2020.
(9)
Filed as an Exhibit to our Current Report on Form S-K filed on November 21, 2014.
(10)
Filed as an Exhibit to our Current Report on Form 8-K filed on February 26, 2016.
(11)
Filed as an Exhibit to our Quarterly Report on Form 10-Q filed on April 26, 2019.
(12)
Filed as an Exhibit to our Quarterly Report on Form 10-Q filed on April 28, 2020.
We hereby undertake, pursuant to Regulation S-K, Item 601(b), paragraph (4) (iii), to furnish to the U.S. Securities and Exchange Commission, upon request, all constituent instruments defining the rights of holders of our long-term debt not filed herewith.