EDGAR 10-K Filing

Company CIK: 45012
Filing Year: 2022
Filename: 45012_10-K_2022_0000045012-22-000013.json

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ITEM 1. BUSINESS
Item 1 | Business
PART I
Item 1. Business.
Description of business and strategy
Halliburton Company is one of the world's largest providers of products and services to the energy industry. Its predecessor was established in 1919 and incorporated under the laws of the State of Delaware in 1924. Inspired by the past and leading into the future, what started with a single product from a single location is now a global enterprise. Our value proposition is to collaborate and engineer solutions to maximize asset value for our customers. We strive to achieve strong cash flows and returns for our shareholders by delivering technology and services that improve efficiency, increase recovery, and maximize production for our customers. We are proud of our over 100 years of operation, innovation, collaboration, and execution. Halliburton has fostered a culture of unparalleled service to the world's major, national, and independent oil and gas producers. With over 40,000 employees, representing 130 nationalities in more than 70 countries, we help our customers maximize asset value throughout the lifecycle of the reservoir - from locating hydrocarbons and managing geological data, to drilling and formation evaluation, well construction and completion, and optimizing production throughout the life of the asset.
2021 Highlights
- Financial: Internationally we delivered profitable growth with revenue and operating income increasing every quarter in 2021. In North America, strong operating leverage allowed us to maximize the value of our business as U.S. land activity rebounded. Overall, our Completion and Production and Drilling and Evaluation operating segments finished the year with 15% and 12% operating margins, respectively, and generated strong cash flows from operations.
- Digital: Our accelerated deployment and integration of digitally enabled technologies created technical differentiation in the market and contributed to our higher margins.
- Capital efficiency: We advanced technologies and made strategic choices that kept our capital expenditures to 5.2% of revenue, which is in the range of our 5-6% of revenue target.
- Sustainable energy: We announced our science-based emission reduction targets, added eleven new participating companies to Halliburton Labs, our clean energy accelerator, and were named to the Dow Jones Sustainability Index North America for Energy Equipment and Services, which highlights the top 10% most sustainable North America companies in identified industries as determined by S&P Global through their Corporate Sustainability Assessment.
2022 Focus
- International: Allocate our capital to the highest return opportunities, continue investing in digital technologies that maximize our asset value to drive profitable growth, and increase our international growth in our specialty chemicals and artificial lift businesses.
- North America: Continue to build on the operating leverage we have created, maximize cash flow by utilizing our premium low-emissions equipment, and continue developing differentiated technologies focused around the wellbore.
- Digital: Continue to accelerate the deployment and integration of digitalization and automation technologies that create differentiation, both internally and for our customers.
- Capital efficiency: Maintain our capital expenditures in the range of 5-6% of revenue while focusing on technological advancements and process changes that reduce our manufacturing and maintenance costs and improve how we move equipment and respond to market opportunities.
- Sustainable energy: Leverage the increasing number of participants in and scope of Halliburton Labs to gain insight into developing value chains in the clean energy space and continue to develop and deploy low-carbon solutions to help oil and gas operators lower their current emissions profiles while also using our existing technologies in renewable energy applications.
For further discussion on our business strategies, see "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Business Environment and Results of Operations-Business Outlook."
Operating segments
We operate under two divisions, which form the basis for the two operating segments we report, the Completion and Production segment and the Drilling and Evaluation segment.
Completion and Production delivers cementing, stimulation, intervention, pressure control, artificial lift, and completion products and services. The segment consists of the following product service lines:
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- Production Enhancement: includes stimulation services and sand control services. Stimulation services optimize oil and natural gas reservoir production through a variety of pressure pumping services, and chemical processes, commonly known as hydraulic fracturing and acidizing. Sand control services include fluid and chemical systems for the prevention of formation sand production.
- Cementing: involves bonding the well and well casing while isolating fluid zones and maximizing wellbore stability. Our cementing product service line also provides casing equipment.
- Completion Tools: provides downhole solutions and services to our customers to complete their wells, including well completion products and services, intelligent well completions, liner hanger systems, sand control systems, multilateral systems, and service tools.
- Production Solutions: provides customized well intervention solutions to increase well performance, which includes coiled tubing, hydraulic workover units, downhole tools, pumping services, and nitrogen services.
- Artificial Lift: provides services to maximize reservoir and wellbore recovery by applying lifting technology, intelligent field management solutions, and related services throughout the life of the well, including electrical submersible pumps.
- Pipeline & Process Services: provides a complete range of pre-commissioning, commissioning, maintenance, and decommissioning services to the onshore and offshore pipeline and process plant construction commissioning and maintenance industries.
Drilling and Evaluation provides field and reservoir modeling, drilling, fluids and specialty chemicals, evaluation and precise wellbore placement solutions that enable customers to model, measure, drill, and optimize their well construction activities. The segment consists of the following product service lines:
- Baroid: provides drilling fluid systems, performance additives, completion fluids, solids control, specialized testing equipment, and waste management services for oil and natural gas drilling, completion, and workover operations. It also provides customized specialty oilfield completion, production, and downstream water and process treatment chemicals and services.
- Sperry Drilling: provides drilling systems and services that offer directional control for precise wellbore placement while providing important measurements about the characteristics of the drill string and geological formations while drilling wells. These services include directional and horizontal drilling, measurement-while-drilling, logging-while-drilling, surface data logging, and rig site information systems.
- Wireline and Perforating: provides open-hole logging services that supply information on formation evaluation and reservoir fluid analysis, including formation lithology, rock properties, and reservoir fluid properties. Also offered are cased-hole and slickline services, including perforating, pipe recovery services, through-casing formation evaluation and reservoir monitoring, casing and cement integrity measurements, and well intervention services.
- Drill Bits and Services: provides roller cone rock bits, fixed cutter bits, hole enlargement and related downhole tools and services used in drilling oil and natural gas wells. In addition, coring equipment and services are provided to acquire cores of the formation drilled for evaluation.
- Landmark Software and Services: provides cloud based digital services and artificial intelligence solutions on an open architecture for subsurface insights, integrated well construction, and reservoir and production management for the upstream oil and natural gas industry.
- Testing and Subsea: provides acquisition and analysis of dynamic reservoir information and reservoir optimization solutions to the oil and natural gas industry through a broad portfolio of test tools, data acquisition services, fluid sampling, surface well testing, subsea safety systems, and underbalanced applications.
- Halliburton Project Management: provides integrated solutions to our customers by leveraging the full line of our oilfield services, products, and technologies to solve customer challenges throughout the oilfield lifecycle, including project management and integrated asset management.
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The following charts depict our revenue split between our two operating segments for the years ended December 31, 2021 and 2020.
See Note 3 to the consolidated financial statements for further financial information related to each of our business segments.
Markets and competition
We are one of the world’s largest diversified energy services companies. Our services and products are sold in highly competitive markets throughout the world. Competitive factors impacting sales of our services and products include: price; service delivery; health, safety, and environmental standards and practices; service quality; global talent retention; understanding the geological characteristics of the hydrocarbon reservoir; product quality; warranty; and technical proficiency.
We conduct business worldwide in more than 70 countries. The business operations of our divisions are organized around four primary geographic regions: North America, Latin America, Europe/Africa/CIS, and Middle East/Asia. In 2021, 2020, and 2019, based on the location of services provided and products sold, 40%, 38%, and 51%, respectively, of our consolidated revenue was from the United States. No other country accounted for more than 10% of our consolidated revenue during these periods. See "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” for additional information about our geographic operations. Because the markets for our services and products are vast and cross numerous geographic lines, it is not practicable to provide a meaningful estimate of the total number of our competitors. The industries we serve are highly competitive, and we have many substantial competitors. Most of our services and products are marketed through our service and sales organizations.
The following charts depict our revenue split between our four primary geographic regions for the years ended December 31, 2021 and 2020.
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Our operations in some countries may be adversely affected by unsettled political conditions, acts of terrorism, civil unrest, force majeure, war or other armed conflict, health or similar issues, sanctions, expropriation or other governmental actions, inflation, changes in foreign currency exchange rates, foreign currency exchange restrictions and highly inflationary currencies, as well as other geopolitical factors. We believe the geographic diversification of our business activities reduces the risk that an interruption of operations in any one country, other than the United States, would be materially adverse to our business, consolidated results of operations, or consolidated financial condition.
Information regarding our exposure to foreign currency fluctuations, risk concentration, and financial instruments used to minimize risk is included in "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Instrument Market Risk” and in Note 15 to the consolidated financial statements.
Customers
Our revenue during the past three years was derived from the sale of services and products to the energy industry. No single customer represented more than 10% of our consolidated revenue in any period presented.
Raw materials
Raw materials essential to our business are normally readily available. Market conditions can trigger constraints in the supply of certain raw materials, such as proppants (primarily sand), hydrochloric acid, and gels. We are always striving to ensure the availability of resources and manage raw material costs. Our procurement department uses our relationships and buying power to enhance our access to key materials at competitive prices.
Patents
We own a large number of patents and have pending a substantial number of patent applications covering various products and processes. We are also licensed to utilize technology covered by patents owned by others, and we license others to utilize technology covered by our patents. We do not consider any particular patent to be material to our business operations.
Seasonality
Weather and natural phenomena can temporarily affect the performance of our services, but the widespread geographical locations of our operations mitigate those effects. Examples of how weather can impact our business include:
- the severity and duration of the winter in North America can have a significant impact on drilling activity and on natural gas storage levels;
- the timing and duration of the spring thaw in Canada directly affects activity levels due to road restrictions;
- typhoons and hurricanes can disrupt coastal and offshore operations; and
- severe weather during the winter normally results in reduced activity levels in the North Sea and Russia.
Additionally, customer spending patterns for completion tools typically result in higher activity in the fourth quarter of the year. We recognize revenue on customer software contract sales predominantly in the first and fourth quarters of the year.
Our workforce
Our workforce is our top asset in enabling us to accomplish innovative, high-quality work for our customers and to address the world’s energy challenges. To attract and retain talent, we strive to provide a safe and inclusive working environment along with competitive benefits. As of December 31, 2021, we employed over 40,000 people worldwide representing 130 nationalities, operated in more than 70 countries, and approximately 18% of our employees were subject to collective bargaining agreements. Based upon the geographic diversification of our employees, we do not believe any risk of loss from employee strikes or other collective actions are material to the conduct of our operations taken as a whole.
Recruiting and Turnover
Given the size and geographic scope of our workforce, we have a robust world-wide recruiting apparatus, which includes personnel devoted to recruiting and retention, online job postings, and recruiting programs we have established at academic institutions for internships and entry-level roles. In order to increase the number of diverse employees, we have developed relationships with diversity-focused student organizations, provide professional development sessions to students, engage our Employee Resource Groups (ERGs) to participate in select university events, and participate in outreach efforts through programs supported by our Educational Advisory Board.
Our attrition in 2021 was down significantly compared to 2020 and we were able to rehire more than 2,800 former employees in 2021, despite a tight labor market. We have found that hiring former employees allows us to add needed personnel who are able to apply their experience and contribute quickly.
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Diversity, equity, and inclusion
With our large employee base and global breadth, we are one of the world’s most diverse companies. Our Code of Business Conduct describes our commitment to diversity, equity, and inclusion, which is supported by our recruitment and employment practices. It is a priority to continue to increase the diversity of our workforce, both in general and in leadership positions. Furthermore, we strive to increase the percentage of local nationals that we employ in each region of operations to better communicate with local customers and other contractors, share knowledge of the culture and values of the local population, improve local economies, and make our workforce more representative of the populations where we provide our services. In 2021, 92% of our workforce and 86% of management was localized. In 2021, 13% of our workforce and 13% of our managers were female.
Leadership
We have more than 8,000 employees in management roles. The ongoing identification and development of leadership talent ensures business continuity and strengthens our competitive advantage, both of which are critical for our short and long-term success. In 2021, we identified approximately 18,000 potential successors for our managers during succession management planning. One of our most significant investments in the development of our future leaders is our executive education programs. In 2021, approximately 25% of the participants in these programs were female and 40 different nationalities were represented, despite travel restrictions impacting many countries.
As part of our commitment to employee engagement, we solicit feedback from employees on their workplace challenges, and empower them to share their perspectives and ideas to improve the overall employee experience, including performance, development, and work-life balance. Notably, according to a survey we conducted in 2021, 87% of our employees felt that Halliburton and their colleagues value their unique traits and ways of working.
Benefits and well-being
We provide our employees around the world with benefits that address the needs of our workforce and their families. We evaluate our benefits package to identify opportunities for improvement and to remain competitive. In 2021, we enhanced healthcare benefits for United States employees to help them better plan for medical expenditures and to obtain additional support in getting second medical opinions and navigating health plans. In response to ongoing mental health concerns related to the COVID-19 pandemic, we expanded our Employee Assistance Program (EAP) from six countries to 43 countries worldwide. By the end of 2021, more than 32,000 employees had access to the EAP compared to approximately 14,500 in 2020.
Safety
Safety in the workplace is one of our highest priorities. We have many safety programs in place, including our Journey to ZERO initiative, to maintain our strong performance and improve proactive identification and management of safety risks. In 2021, we enhanced risk management processes, incident investigations, and training, including options for virtual training when feasible. As a result of our focus on safety, for the years ended December 31, 2021 and December 31, 2020, our recordable incident rates were 0.25% and 0.20%, non-productive times were 0.30% and 0.30%, lost-time incident rates were 0.09% and 0.06%, preventable recordable vehicle incident rates were 0.16% and 0.06%, respectively, and there were no job related fatalities in either year.
Government regulation
We are subject to numerous environmental, legal, and regulatory requirements related to our operations worldwide. For further information related to environmental matters and regulation, see Note 10 to the consolidated financial statements and "Item 1(a). Risk Factors.”
Hydraulic fracturing
Hydraulic fracturing is a process that creates fractures extending from the well bore into the rock formation to enable natural gas or oil to move more easily from the rock pores to a production conduit. A significant portion of our Completion and Production segment provides hydraulic fracturing services to customers developing shale natural gas and shale oil. From time to time, questions arise about the scope of our operations in the shale natural gas and shale oil sectors, and the extent to which these operations may affect human health and the environment.
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At the direction of our customer, we design and generally implement a hydraulic fracturing operation to stimulate the well's production, once the well has been drilled, cased, and cemented. Our customer is generally responsible for providing the base fluid (usually water) used in the hydraulic fracturing of a well. We frequently supply the proppant (primarily sand) and at least a portion of the additives used in the overall fracturing fluid mixture. In addition, we mix the additives and proppant with the base fluid and pump the mixture down the wellbore to create the desired fractures in the target formation. The customer is responsible for disposing and/or recycling for further use any materials that are subsequently produced or pumped out of the well, including flowback fluids and produced water.
As part of the process of constructing the well, the customer will take a number of steps designed to protect drinking water resources. In particular, the casing and cementing of the well are designed to provide 'zonal isolation' so that the fluids pumped down the wellbore and the oil and natural gas and other materials that are subsequently pumped out of the well will not come into contact with shallow aquifers or other shallow formations through which those materials could potentially migrate to freshwater aquifers or the surface.
The potential environmental impacts of hydraulic fracturing have been studied by numerous government entities and others. In 2004, the United States Environmental Protection Agency (EPA) conducted an extensive study of hydraulic fracturing practices, focusing on coalbed methane wells, and their potential effect on underground sources of drinking water. The EPA’s study concluded that hydraulic fracturing of coalbed methane wells poses little or no threat to underground sources of drinking water. In December 2016, the EPA released a final report, “Hydraulic Fracturing for Oil and Gas: Impacts from the Hydraulic Fracturing Water Cycle on Drinking Water Resources in the United States” representing the culmination of a six-year study requested by Congress. While the EPA report noted a potential for some impact to drinking water sources caused by hydraulic fracturing, the agency confirmed the overall incidence of impacts is low. Moreover, a number of the areas of potential impact identified in the report involve activities for which we are not generally responsible, such as potential impacts associated with withdrawals of surface water for use as a base fluid and management of wastewater.
We have proactively developed processes to provide our customers with the chemical constituents of our hydraulic fracturing fluids to enable our customers to comply with state laws as well as voluntary standards established by the Chemical Disclosure Registry, www.fracfocus.org. We have invested considerable resources in developing hydraulic fracturing technologies, in both the equipment and chemistry portions of our business, which offer our customers a variety of environment-friendly options related to the use of hydraulic fracturing fluid additives and other aspects of our hydraulic fracturing operations. We created a hydraulic fracturing fluid system comprised of materials sourced entirely from the food industry. In addition, we have engineered a process that uses ultraviolet light to control the growth of bacteria in hydraulic fracturing fluids, allowing customers to minimize the use of chemical biocides. We are committed to the continued development of innovative chemical and mechanical technologies that allow for more economical and environment-friendly development of the world’s oil and natural gas reserves, and that reduce noise while complying with Tier 4 lower emission legislation.
In evaluating any environmental risks that may be associated with our hydraulic fracturing services, it is helpful to understand the role that we play in the development of shale natural gas and shale oil. Our principal task generally is to manage the process of injecting fracturing fluids into the borehole to stimulate the well. Thus, based on the provisions in our contracts and applicable law, the primary environmental risks we face are potential pre-injection spills or releases of stored fracturing fluids and potential spills or releases of fuel or other fluids associated with pumps, blenders, conveyors, or other above-ground equipment used in the hydraulic fracturing process.
Although possible concerns have been raised about hydraulic fracturing, the circumstances described above have helped to mitigate those concerns. To date, we have not been obligated to compensate any indemnified party for any environmental liability arising directly from hydraulic fracturing, although there can be no assurance that such obligations or liabilities will not arise in the future. For further information on risks related to hydraulic fracturing, see "Item 1(a). Risk Factors.”
Working capital
We fund our business operations through a combination of available cash and equivalents, short-term investments, and cash flow generated from operations. In addition, our revolving credit facility is available for additional working capital needs.
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Web site access - www.halliburton.com
Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnished to the Securities and Exchange Commission (SEC) pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 are available at www.halliburton.com soon thereafter. The SEC website www.sec.gov contains our reports, proxy and information statements and our other SEC filings. Our Code of Business Conduct, which applies to all our employees and Directors and serves as a code of ethics for our principal executive officer, principal financial officer, principal accounting officer, and other persons performing similar functions, can be found at www.halliburton.com. Any amendments to our Code of Business Conduct or any waivers from provisions of our Code of Business Conduct granted to the specified officers above are also disclosed on our web site within four business days after the date of any amendment or waiver pertaining to these officers. There have been no waivers from provisions of our Code of Business Conduct for the years 2021, 2020, or 2019. Except to the extent expressly stated otherwise, information contained on or accessible from our web site or any other web site is not incorporated by reference into this annual report on Form 10-K and should not be considered part of this report.
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Executive Officers of the Registrant
The following table indicates the names and ages of the executive officers of Halliburton Company as of February 4, 2022, including all offices and positions held by each in the past five years:
Name and Age Offices Held and Term of Office
Van H. Beckwith
(Age 56) Executive Vice President, Secretary and Chief Legal Officer of Halliburton Company, since December 2020
Senior Vice President and General Counsel, January 2020 to December 2020
Partner, Baker Botts L.L.P., January 1999 to December 2019
Eric J. Carre
(Age 55) Executive Vice President, Global Business Lines of Halliburton Company, since May 2016
Charles E. Geer, Jr.
(Age 51) Senior Vice President and Chief Accounting Officer of Halliburton Company, since December 2019
Vice President and Corporate Controller of Halliburton Company, January 2015 to December 2019
Myrtle L. Jones
(Age 62) Senior Vice President, Tax of Halliburton Company, since March 2013
Lance Loeffler
(Age 44) Executive Vice President and Chief Financial Officer of Halliburton Company, since November 2018
Vice President of Investor Relations of Halliburton Company, April 2016 to November 2018
Timothy M. McKeon
(Age 49) Senior Vice President and Treasurer of Halliburton Company, since January 2022
Vice President and Treasurer of Halliburton Company, January 2014 to December 2021
Jeffrey A. Miller
(Age 58) Chairman of the Board, President and Chief Executive Officer of Halliburton Company, since January 2019
Member of the Board of Directors, President and Chief Executive Officer of Halliburton Company, June 2017 to December 2018
Member of the Board of Directors and President of Halliburton Company, August 2014 to May 2017
Lawrence J. Pope
(Age 53) Executive Vice President of Administration and Chief Human Resources Officer of Halliburton Company, since January 2008
Joe D. Rainey
(Age 65) President, Eastern Hemisphere of Halliburton Company, since January 2011
Mark J. Richard
(Age 60) President, Western Hemisphere of Halliburton Company, since February 2019
Senior Vice President, Northern U.S. Region of Halliburton Company, August 2018 to January 2019
Senior Vice President, Business Development and Marketing of Halliburton Company, November 2015 to July 2018
Jill D. Sharp
(Age 51) Senior Vice President, Internal Assurance Services of Halliburton Company, since January 2022
Vice President, Internal Assurance Services of Halliburton Company, September 2021 to December 2021
Vice President, Finance - Western Hemisphere of Halliburton Company, October 2016 to August 2021
There are no family relationships between the executive officers of the registrant or between any director and any executive officer of the registrant.
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Item 1(a) | Risk Factors
Item 1(a). Risk Factors.
When considering an investment in Halliburton Company, all of the risk factors described below and other information included and incorporated by reference in this annual report should be carefully considered. Any of these risk factors could have a significant or material adverse effect on our business, results of operations, financial condition, or cash flows. Additional risks and uncertainties not currently known to us or that we currently deem immaterial may also adversely affect our business, financial condition, results of operations, or cash flows.
Industry Environment Related
Trends in oil and natural gas prices affect the level of exploration, development, and production activity of our customers and the demand for our services and products, which could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Demand for our services and products is particularly sensitive to the level of exploration, development, and production activity of, and the corresponding capital spending by, oil and natural gas companies. The level of exploration, development, and production activity is directly affected by trends in oil and natural gas prices, which historically have been volatile and are likely to continue to be volatile. Prices for oil and natural gas are subject to large fluctuations in response to relatively minor changes in the supply of and demand for oil and natural gas, market uncertainty, and a variety of other economic factors that are beyond our control. Given the long-term nature of many large-scale development projects, even the perception of longer-term lower oil and natural gas prices by oil and natural gas companies can cause them to reduce or defer major expenditures. Any prolonged reductions of commodity prices or expectations of such reductions could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition, and could result in asset impairments and severance costs.
Factors affecting the prices of oil and natural gas include:
- the level of supply and demand for oil and natural gas;
- the ability or willingness of the Organization of Petroleum Exporting Countries and the expanded alliance collectively known as OPEC+ to set and maintain oil production levels;
- the level of oil production in the U.S. and by other non-OPEC+ countries;
- oil refining capacity and shifts in end-customer preferences toward fuel efficiency and the use of natural gas;
- the cost of, and constraints associated with, producing and delivering oil and natural gas;
- governmental regulations, including the policies of governments regarding the exploration for and production and development of their oil and natural gas reserves;
- weather conditions, natural disasters, and health or similar issues, such as pandemics or epidemics;
- worldwide political, military, and economic conditions; and
- increased demand for alternative energy and electric vehicles and increased emphasis on decarbonization, including government initiatives to promote the use of renewable energy sources and public sentiment around alternatives to oil and gas.
Our business is dependent on capital spending by our customers, and reductions in capital spending could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Our business is directly affected by changes in capital expenditures by our customers, and reductions in their capital spending could reduce demand for our services and products and have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition. Some of the items that may impact our customer's capital spending include:
- oil and natural gas prices, including volatility of oil and natural gas prices and expectations regarding future prices;
- the inability of our customers to access capital on economically advantageous terms, which may be impacted by, among other things, a decrease of investors' interest in hydrocarbon producers because of environmental and sustainability initiatives;
- changes in customers' capital allocation, including an increased allocation to the production of renewable energy, leading to less focus on oil and natural gas production growth;
- restrictions on our customers' ability to get their produced oil and natural gas to market due to infrastructure limitations;
- the consolidation of our customers;
- customer personnel changes; and
- adverse developments in the business or operations of our customers, including write-downs of oil and natural gas reserves and borrowing base reductions under customers' credit facilities.
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Item 1(a) | Risk Factors
Liabilities arising out of our products and services could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Events can occur at sites where our products and equipment are produced or installed, or where we conduct our operations or provide our services, or at chemical blending or manufacturing facilities, including well blowouts and equipment or materials failures, which could result in explosions, fires, personal injuries, property damage (including surface and subsurface damage), pollution, and potential legal responsibility. Generally, we rely on liability insurance coverage and on contractual indemnities, releases, and limitations of liability with our customers to protect us from potential liability related to such occurrences. However, we do not have these contractual provisions in all contracts, and even where we do, it is possible that the respective customer or insurer could seek to avoid or be financially unable to meet its obligations, or a court may decline to enforce such provisions. Damages that are not indemnified or released could greatly exceed available insurance coverage and could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Our business could be materially and adversely affected by severe or unseasonable weather where we have operations.
Our business could be materially and adversely affected by severe weather, particularly in Canada, the Gulf of Mexico, Russia, and the North Sea. Many experts believe global climate change could increase the frequency and severity of extreme weather conditions. Repercussions of severe or unseasonable weather conditions may include:
- evacuation of personnel and curtailment of services;
- weather-related damage to offshore drilling rigs resulting in suspension of operations;
- weather-related damage to our facilities and project work sites;
- inability to deliver materials to jobsites in accordance with contract schedules;
- decreases in demand for oil and natural gas during unseasonably warm winters; and
- loss of productivity.
Our failure to protect our proprietary information and any successful intellectual property challenges or infringement proceedings against us could materially and adversely affect our competitive position.
We rely on a variety of intellectual property rights that we use in our services and products. We may not be able to successfully preserve these intellectual property rights in the future, and these rights could be invalidated, circumvented, or challenged. In addition, the laws of some foreign countries in which our services and products may be sold do not protect intellectual property rights to the same extent as the laws of the United States. Courts could find that others infringe our patent rights or that our products and services may infringe the intellectual property rights of others. Our failure to protect our proprietary information and any successful intellectual property challenges or infringement proceedings against us could materially and adversely affect our competitive position.
If we are not able to design, develop and produce commercially competitive products and to implement commercially competitive services in a timely manner in response to changes in the market, customer requirements, competitive pressures, and technology trends, our business and consolidated results of operations could be materially and adversely affected, and the value of our intellectual property may be reduced.
The market for our services and products is characterized by continual technological developments to provide better and more reliable performance and services. If we are not able to design, develop, and produce commercially competitive products and to implement commercially competitive services in a timely manner in response to changes in the market, customer requirements, competitive pressures, and technology trends, our business and consolidated results of operations could be materially and adversely affected, and the value of our intellectual property may be reduced. Likewise, if our proprietary technologies, equipment, facilities, or work processes become obsolete, we may no longer be competitive, and our business and consolidated results of operations could be materially and adversely affected.
We sometimes provide integrated project management services in the form of long-term, fixed price contracts that may require us to assume additional risks associated with cost over-runs, operating cost inflation, labor availability and productivity, supplier and contractor pricing and performance, and potential claims for liquidated damages.
We sometimes provide integrated project management services outside our normal discrete business in the form of long-term, fixed price contracts. Some of these contracts are required by our customers, primarily national oil companies (NOCs). These services include acting as project managers as well as service providers and may require us to assume additional risks associated with cost over-runs. These customers may provide us with inaccurate information in relation to their reserves, which is a subjective process that involves location and volume estimation, that may result in cost over-runs, delays, and project losses. In addition, NOCs often operate in countries with unsettled political conditions, war, civil unrest, or other types of community issues. These issues may also result in cost over-runs, delays, and project losses.
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Item 1(a) | Risk Factors
Providing services on an integrated basis may also require us to assume additional risks associated with operating cost inflation, labor availability and productivity, supplier pricing and performance, and potential claims for liquidated damages. We rely on third-party subcontractors and equipment providers to assist us with the completion of these types of contracts. To the extent that we cannot engage subcontractors or acquire equipment or materials in a timely manner and on reasonable terms, our ability to complete a project in accordance with stated deadlines or at a profit may be impaired. If the amount we are required to pay for these goods and services exceeds the amount we have estimated in bidding for fixed-price work, we could experience losses in the performance of these contracts. These delays and additional costs may be substantial, and we may be required to compensate our customers for these delays. This may reduce the profit to be realized or result in a loss on a project.
Constraints in the supply of, prices for and availability of transportation of raw materials can have a material adverse effect on our business and consolidated results of operations.
Raw materials essential to our business, such as proppants (primarily sand), hydrochloric acid, and gels, including guar gum, are normally readily available. Shortage of raw materials as a result of high levels of demand or loss of suppliers during market challenges can trigger constraints in the supply chain of those raw materials, particularly where we have a relationship with a single supplier for a particular resource. Many of the raw materials essential to our business require the use of rail, storage, and trucking services to transport the materials to our jobsites. These services, particularly during times of high demand, may cause delays in the arrival of or otherwise constrain our supply of raw materials. These constraints could have a material adverse effect on our business and consolidated results of operations. In addition, price increases imposed by our vendors for raw materials and transportation providers used in our business, and the inability to pass these increases through to our customers could have a material adverse effect on our business and consolidated results of operations.
Our ability to operate and our growth potential could be materially and adversely affected if we cannot attract, employ, and retain technical personnel at a competitive cost.
Many of the services that we provide and the products that we sell are complex and highly engineered and often must perform or be performed in harsh conditions. We believe that our success depends upon our ability to attract, employ, and retain technical personnel with the ability to design, utilize, and enhance these services and products. A significant increase in the wages paid by competing employers could result in a reduction of our skilled labor force, increases in the wage rates that we must pay, or both. If either of these events were to occur, our cost structure could increase, our margins could decrease, and any growth potential could be impaired.
Laws and Regulations Related
Our operations outside the United States require us to comply with a number of United States and international regulations, violations of which could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Our operations outside the United States require us to comply with a number of United States and international regulations. For example, our operations in countries outside the United States are subject to the United States Foreign Corrupt Practices Act (FCPA), which prohibits United States companies and their agents and employees from providing anything of value to a foreign official for the purposes of influencing any act or decision of these individuals in their official capacity to help obtain or retain business, direct business to any person or corporate entity, or obtain any unfair advantage. Our activities create the risk of unauthorized payments or offers of payments by our employees, agents, or joint venture partners that could be in violation of anti-corruption laws, even though some of these parties are not subject to our control. We have internal control policies and procedures and have implemented training and compliance programs for our employees and agents with respect to the FCPA. However, we cannot assure that our policies, procedures, and programs will always protect us from reckless or criminal acts committed by our employees or agents. We are also subject to the risks that our employees, joint venture partners and agents outside of the United States may fail to comply with other applicable laws. Allegations of violations of applicable anti-corruption laws have resulted and may in the future result in internal, independent, or government investigations. Violations of anti-corruption laws may result in severe criminal or civil sanctions, and we may be subject to other liabilities, which could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.
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Item 1(a) | Risk Factors
In addition, the shipment of goods, services, and technology across international borders subjects us to extensive trade laws and regulations. Our import activities are governed by the unique customs laws and regulations in each of the countries where we operate. Moreover, many countries, including the United States, control the export, re-export, and in-country transfer of certain goods, services, and technology and impose related export recordkeeping and reporting obligations. Governments may also impose economic sanctions against certain countries, persons, and entities that may restrict or prohibit transactions involving such countries, persons, and entities, which may limit or prevent our conduct of business in certain jurisdictions. During 2014, the United States and European Union imposed sectoral sanctions directed at Russia’s oil and gas industry. Among other things, these sanctions restrict the provision of U.S. and EU goods, services, and technology in support of exploration or production for deep water, Arctic offshore, or shale projects that have the potential to produce oil in Russia. These sanctions resulted in our winding down and ending work on two projects in Russia in 2014 and have prevented us from pursuing certain other projects in Russia. In 2017 and 2018, the U.S. Government imposed additional sanctions against Russia, Russia’s oil and gas industry, and certain Russian companies. In connection with increasing tensions between Russia and the United States regarding Russia’s intentions with respect to Ukraine, the United States has threatened to impose aggressive additional sanctions against Russia if Russia invades Ukraine. Our ability to engage in certain future projects in Russia or involving certain Russian customers is dependent upon whether or not our involvement in such projects is restricted under U.S. or EU sanctions laws and the extent to which any of our current or prospective operations in Russia or with certain Russian customers may be subject to those laws. Those laws may change from time to time, and any expansion of sanctions against Russia’s oil and gas industry could further hinder our ability to do business in Russia or with certain Russian customers, which could have a material adverse effect on our consolidated results of operations.
The U.S. Government imposed sanctions against Venezuela that have effectively required us to discontinue our operations there. Consequently, in connection with us winding down our operations in Venezuela, we wrote down all of our remaining investment in Venezuela in 2020. As of December 29, 2020, we no longer had any employees in Venezuela, although we continue to maintain our local entity, facilities, and equipment in-country, as permitted under applicable law. We are not currently conducting any other operational activities in Venezuela.
The laws and regulations concerning import activity, export recordkeeping and reporting, export control and economic sanctions are complex and constantly changing. These laws and regulations can cause delays in shipments and unscheduled operational downtime. Moreover, any failure to comply with applicable legal and regulatory trading obligations could result in criminal and civil penalties and sanctions, such as fines, imprisonment, debarment from governmental contracts, seizure of shipments, and loss of import and export privileges. In addition, investigations by governmental authorities and legal, social, economic, and political issues in these countries could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.
Changes in, compliance with, or our failure to comply with laws in the countries in which we conduct business may negatively impact our ability to provide services in, make sales of equipment to, and transfer personnel or equipment among some of those countries and could have a material adverse effect on our business and consolidated results of operations.
In the countries in which we conduct business, we are subject to multiple and, at times, inconsistent regulatory regimes, including those that govern our use of radioactive materials, explosives, and chemicals in the course of our operations. Various national and international regulatory regimes govern the shipment of these items. Many countries, but not all, impose special controls upon the export and import of radioactive materials, explosives, and chemicals. Our ability to do business is subject to maintaining required licenses and complying with these multiple regulatory requirements applicable to these special products. In addition, the various laws governing import and export of both products and technology apply to a wide range of services and products we offer. In turn, this can affect our employment practices of hiring people of different nationalities because these laws may prohibit or limit access to some products or technology by employees of various nationalities. Changes in, compliance with, or our failure to comply with these laws may negatively impact our ability to provide services in, make sales of equipment to, and transfer personnel or equipment among some of the countries in which we operate and could have a material adverse effect on our business and consolidated results of operations.
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Item 1(a) | Risk Factors
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 that could result in additional requirements or restrictions being imposed on hydraulic fracturing operations. For example, the United States may seek to adopt federal regulations or enact federal laws that would impose additional regulatory requirements on or even prohibit hydraulic fracturing in some areas. 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 have been adopted or 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. Four states (New York, Maryland, Vermont, and Washington) have banned the use of high volume hydraulic fracturing, Oregon has adopted a five-year moratorium, and Colorado has enacted legislation providing local governments with regulatory authority over hydraulic fracturing operations. 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. The adoption of any future federal, state, local, or foreign laws or 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.
Liability for cleanup costs, natural resource damages and other damages arising as a result of environmental laws and regulations could be substantial and could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
We are subject to numerous environmental laws and regulations in the United States and the other countries where we do business. We evaluate and address the environmental impact of our operations by assessing and remediating contaminated properties to avoid future liabilities and comply with legal and regulatory requirements. From time to time, claims have been made against us under environmental laws and regulations. In the United States, environmental laws and regulations typically impose strict liability. Strict liability means that in some situations we could be exposed to liability for cleanup costs, natural resource damages, and other damages as a result of our conduct that was lawful at the time it occurred or the conduct of prior operators or other third parties. We are periodically notified of potential liabilities at federal and state superfund sites. These potential liabilities may arise from both historical Halliburton operations and the historical operations of companies that we have acquired. Our exposure at these sites may be materially impacted by unforeseen adverse developments both in the final remediation costs and with respect to the final allocation among the various parties involved at the sites. The relevant regulatory agency may bring suit against us for amounts in excess of what we have accrued and what we believe is our proportionate share of remediation costs at any superfund site. We also could be subject to third-party claims, including punitive damages, with respect to environmental matters for which we have been named as a potentially responsible party. Liability for damages arising as a result of environmental laws or related third-party claims could be substantial and could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Failure on our part to comply with, and the costs of compliance with, applicable health, safety, and environmental requirements could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
In addition to the numerous environmental laws and regulations that apply to our operations, we are subject to a variety of laws and regulations in the United States and other countries relating to health and safety. Among those laws and regulations are those covering hazardous materials and requiring emission performance standards for facilities. For example, our well service operations routinely involve the handling of significant amounts of waste materials, some of which are classified as hazardous substances. We also store, transport, and use radioactive and explosive materials in certain of our operations. Applicable regulatory requirements include those concerning:
- the containment and disposal of hazardous substances, oilfield waste, and other waste materials;
- the production, storage, transportation and use of explosive materials;
- the importation and use of radioactive materials;
- the use of underground storage tanks;
- the use of underground injection wells; and
- the protection of worker safety both onshore and offshore.
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Item 1(a) | Risk Factors
These and other requirements generally are becoming increasingly strict. The failure to comply with the requirements, many of which may be applied retroactively, may result in:
- administrative, civil, and criminal penalties;
- revocation of permits to conduct business; and
- corrective action orders, including orders to investigate and/or clean up contamination.
Failure on our part to comply with applicable health, safety, and environmental laws and regulations or costs arising from regulatory compliance, including compliance with changes in or expansion of applicable regulatory requirements, could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Existing or future laws, regulations, treaties, or international agreements related to greenhouse gases, climate change, and alternative energy sources could have a negative impact on our business and may result in additional compliance obligations that could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Changes in or the adoption or enactment of laws, regulations, treaties or international agreements related to greenhouse gases, climate change, and alternative energy sources, including changes that may make it more expensive to explore for and produce oil and natural gas, may negatively impact demand for our services and products. For example, oil and natural gas exploration and production may decline as a result of environmental requirements, including land use policies responsive to environmental concerns. State, national, and international governments and agencies in areas in which we conduct business continue to evaluate, and in some instances adopt, climate-related legislation and other regulatory initiatives that would restrict emissions of greenhouse gases. The President of the United States has issued Executive Orders seeking to adopt new regulations and policies to address climate change and to suspend, revise, or rescind prior agency actions that the administration identified as conflicting with its climate policies. These include Executive Orders requiring a review of current U.S. federal lands leasing and permitting practices, as well as a temporary halt of new leasing of U.S. federal lands and offshore waters available for oil and gas exploration. The Executive Orders halting the leasing of U.S. federal lands were challenged in court and remain subject to litigation. As a result of the review of leasing and permitting practices, the U.S. Department of the Interior has recommended increasing the royalty rate payable to the U.S. government by operators, as well as bonding requirements and emissions requirements for operators. Some form of these recommendations may become applicable to operations on U.S. federal leases, which could have a negative effect on exploration and production of oil and natural gas given the increased costs associated with any such changes. In February 2021, the United States formally re-joined the Paris Agreement. The Paris Agreement requires countries to review and “represent a progression” in their intended nationally determined contributions, which set greenhouse gases emission reduction goals, every five years. Though we are closely following developments in this area and changes in the regulatory landscape in the United States, we cannot predict how or when those challenges may ultimately impact our business. Because our business depends on the level of activity in the oil and natural gas industry, existing or future laws, regulations, treaties, or international agreements related to greenhouse gases and climate change, including incentives to conserve energy or use alternative energy sources, may reduce demand for oil and natural gas and could have a negative impact on our business. Likewise, such restrictions may result in additional compliance obligations with respect to the release, capture, sequestration, and use of carbon dioxide. The efforts we have taken, and may undertake in the future, to respond to these evolving or new regulations and to environmental initiatives of customers, investors, and others may increase our costs. These and other environmental requirements could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
The Company could be subject to changes in its tax rates, the adoption of new tax legislation, tax audits, or exposure to additional tax liabilities that could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
We are subject to taxes in the U.S. and numerous jurisdictions where we operate and our subsidiaries are organized. Due to economic and political conditions, tax rates in the U.S. and other jurisdictions may be subject to significant change. In addition, our tax returns are subject to examination by the U.S. and other tax authorities and governmental bodies. We regularly assess the likelihood of an adverse outcome resulting from these examinations to determine the adequacy of our provision for taxes. There can be no assurance as to the outcome of the examinations. An increase in tax rates, particularly in the U.S., changes in our ability to realize our deferred tax assets, or adverse outcomes resulting from examinations of our tax returns could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
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Item 1(a) | Risk Factors
Our operations are subject to political and economic instability and risk of government actions that could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
We are exposed to risks inherent in doing business in each of the countries in which we operate. Our operations are subject to various risks unique to each country that could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition. With respect to any particular country, these risks may include:
- political and economic instability, including:
•civil unrest, acts of terrorism, war, and other armed conflict;
•inflation; and
•currency fluctuations, devaluations, and conversion restrictions; and
- governmental actions that may:
•result in expropriation and nationalization of our assets in that country;
•result in confiscatory taxation or other adverse tax policies;
•limit or disrupt markets or our customers and our operations, restrict payments, or limit the movement of funds;
•impose sanctions on our ability to conduct business with certain customers or persons;
•result in the deprivation of contract rights; and
•result in the inability to obtain or retain licenses required for operation.
For example, due to the unsettled political conditions in many oil-producing countries, our operations, revenue, and profits are subject to the adverse consequences of war, terrorism, civil unrest, strikes, currency controls, and governmental actions. These, and other risks described above, could result in the loss of our personnel or assets, cause us to evacuate our personnel from certain countries, cause us to increase spending on security worldwide, cause us to cease operating in certain countries, disrupt financial and commercial markets, including the supply of and pricing for oil and natural gas, and generate greater political and economic instability in some of the geographic areas in which we operate. Areas where we operate that have significant risk include, but are not limited to: the Middle East, North Africa, Angola, Argentina, Azerbaijan, Brazil, Indonesia, Kazakhstan, Mexico, Mozambique, Nigeria, Papa New Guinea, Russia, and Ukraine. In addition, any possible reprisals as a consequence of military or other action, such as acts of terrorism in the United States or elsewhere, could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
General Risk Factors
The COVID-19 pandemic and related economic repercussions could have a material adverse effect on our business, liquidity, consolidated results of operations, and consolidated financial condition.
The COVID-19 pandemic and related economic repercussions created significant volatility, uncertainty, and turmoil in the oil and gas industry during the last two years. Since the onset of the pandemic in early 2020, these events directly affected our business and exacerbated the negative impact from many of the risks our business is subject to, including those relating to the worldwide demand for oil and natural gas, our customers' capital spending and the impact on oil and natural gas prices. In addition, the pandemic and efforts to mitigate its spread have resulted in logistical challenges to our operations, including travel restrictions that prevent our personnel from commuting to certain facilities and job sites. These logistical challenges could increase if the pandemic worsens or persists.
Oil demand during 2020 and 2021 was substantially less than demand in 2019 as a result of the virus and corresponding measures taken around the world to mitigate its spread. Though demand began to increase during the latter part of 2021, a worsening of the virus could result in an increase in mitigation efforts and a reduction in demand for oil and gas and our services and products.
Given the nature and significance of the events described above, we are not able to enumerate all related potential risks to our business; however, we believe that in addition to the impacts described above, other current and potential impacts of these recent events include, but are not limited to:
•disruption to our supply chain for raw materials essential to our business, including restrictions on importing and exporting products and inflationary pressures;
•notices from customers, suppliers, and other third parties arguing that their non-performance under our contracts with them is permitted as a result of force majeure or other reasons;
•liquidity challenges, including impacts related to delayed customer payments and payment defaults associated with customer liquidity issues and bankruptcies;
•a credit rating downgrade of our corporate debt and potentially higher borrowing costs in the future;
•cybersecurity issues, as digital technologies may become more vulnerable and experience a higher rate of cyberattacks in the current environment of remote connectivity;
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Item 1(a) | Risk Factors
•litigation risk and possible loss contingencies related to COVID-19 and its impact, including with respect to commercial contracts, employee matters, and insurance arrangements;
•additional 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;
•additional asset impairments, including an impairment of the carrying value of our goodwill, along with other accounting charges;
•infections and quarantining of our employees and the personnel of our customers, suppliers, and other third parties in areas in which we operate;
•actions undertaken by national, regional, and local governments and health officials to contain COVID-19 or treat its effects; and
•a structural shift in the global economy and its demand for oil and natural gas as a result of changes in the way people work, travel, and interact, or in connection with a global recession or depression.
Given the dynamic nature of these events, we cannot reasonably estimate the period of time that the COVID-19 pandemic and related market conditions will persist or any changes in their severity, the full extent of the impact they will have on our business, financial condition, results of operations or cash flows or the pace or extent of any recovery. For more information, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Executive Overview.”
Our operations are subject to cyberattacks that could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
We are increasingly dependent on digital technologies and services to conduct our business. We use these technologies for internal purposes, including data storage, processing, and transmissions, as well as in our interactions with our business associates, such as customers and suppliers. Examples of these digital technologies include analytics, automation, and cloud services. Our digital technologies and services, and those of our business associates, are subject to the risk of cyberattacks and, given the nature of such attacks, some incidents can remain undetected for a period of time despite efforts to detect and respond to them in a timely manner. We routinely monitor our systems for cyber threats and have processes in place to detect and remediate vulnerabilities. Nevertheless, we have experienced occasional cyberattacks and attempted breaches over the past year, including attacks resulting from phishing emails and malware infections. We detected and remediated all of these incidents. Even if we successfully defend our own digital technologies and services, we also rely on our business associates, with whom we may share data and services, to defend their digital technologies and services against attack. No known leakage of material financial, technical or customer data occurred as a result of cyberattacks against us and none of the incidents mentioned above had a material adverse effect on our business, operations, reputation, or consolidated results of operations or consolidated financial condition.
If our systems, or our business associates' systems, for protecting against cybersecurity risks prove not to be sufficient, we could be adversely affected by, among other things: loss of or damage to intellectual property, proprietary, or confidential information, or customer, supplier, or employee data; interruption of our business operations; and increased costs required to prevent, respond to, or mitigate cybersecurity attacks. These risks could harm our reputation and our relationships with our business associates, employees, and other third parties, and may result in claims against us. These risks could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.
We are subject to foreign currency exchange risks and limitations on our ability to reinvest earnings from operations in one country to fund the capital needs of our operations in other countries or to repatriate assets from some countries.
A sizable portion of our consolidated revenue and consolidated operating expenses is in foreign currencies. As a result, we are subject to significant risks, including:
- foreign currency exchange risks resulting from changes in foreign currency exchange rates and the implementation of exchange controls; and
- limitations on our ability to reinvest earnings from operations in one country to fund the capital needs of our operations in other countries.
As an example, we conduct business in countries that have restricted or limited trading markets for their local currencies and restrict or limit cash repatriation. We may accumulate cash in those geographies, but we may be limited in our ability to convert our profits into United States dollars or to repatriate the profits from those countries.
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Item 1(a) | Risk Factors
If we lose one or more of our significant customers or if our customers delay paying or fail to pay a significant amount of our outstanding receivables, it could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
We depend on a limited number of significant customers. While no single customer represented more than 10% of consolidated revenue in any period presented, the loss of one or more significant customers could have a material adverse effect on our business and our consolidated results of operations.
In most cases, we bill our customers for our services in arrears and are, therefore, subject to our customers delaying or failing to pay our invoices. We may experience increased delays and failures due to, among other reasons, a reduction in our customers’ cash flow from operations and their access to the credit markets, particularly in weak economic or commodity price environments. If our customers delay paying or fail to pay us a significant amount of our outstanding receivables, it could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.
Our acquisitions, dispositions and investments may not result in anticipated benefits and may present risks not originally contemplated, which may have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
We continually seek opportunities to maximize efficiency and value through various transactions, including purchases or sales of assets, businesses, investments, or joint venture interests. These transactions are intended to (but may not) result in the realization of savings, the creation of efficiencies, the offering of new products or services, the generation of cash or income, or the reduction of risk. Acquisition transactions may use cash on hand or be financed by additional borrowings or by the issuance of our common stock. These transactions may also affect our business, consolidated results of operations, and consolidated financial condition.
These transactions also involve risks, and we cannot ensure that:
- any acquisitions we attempt will be completed on the terms announced, or at all;
- any acquisitions would result in an increase in income or provide an adequate return of capital or other anticipated benefits;
- any acquisitions would be successfully integrated into our operations and internal controls;
- the due diligence conducted prior to an acquisition would uncover situations that could result in financial or legal exposure, including under the FCPA, or that we will appropriately quantify the exposure from known risks;
- any disposition would not result in decreased earnings, revenue, or cash flow;
- use of cash for acquisitions would not adversely affect our cash available for capital expenditures and other uses; or
- any dispositions, investments, or acquisitions, including integration efforts, would not divert management resources.
Actions of and disputes with our joint venture partners could have a material adverse effect on the business and results of operations of our joint ventures and, in turn, our business and consolidated results of operations.
We conduct some operations through joint ventures in which unaffiliated third parties may control the operations of the joint venture or we may share control. As with any joint venture arrangement, differences in views among the joint venture participants may result in delayed decisions, the joint venture operating in a manner that is contrary to our preference or in failures to agree on major issues. We also cannot control the actions of our joint venture partners, including any nonperformance, default, or bankruptcy of our joint venture partners. These factors could have a material adverse effect on the business and results of operations of our joint ventures and, in turn, our business and consolidated results of operations.
The loss or unavailability of any of our executive officers or other key employees could have a material adverse effect on our business.
We depend greatly on the efforts of our executive officers and other key employees to manage our operations. The loss or unavailability of any of our executive officers or other key employees could have a material adverse effect on our business.
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Item 1(b) | Unresolved Staff Comments
Item 1(b). Unresolved Staff Comments.
None.

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ITEM 1A. RISK FACTORS

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ITEM 1B. UNRESOLVED STAFF COMMENTS

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ITEM 2. PROPERTIES
Item 2. Properties.
We own or lease numerous properties in domestic and foreign locations. Our principal properties include manufacturing facilities, research and development laboratories, technology centers, and corporate offices. We also have numerous small facilities that include sales, project and support offices, and bulk storage facilities throughout the world. Our owned properties have no material encumbrances. We believe all properties that we currently occupy are suitable for their intended use.
The following locations represent our major facilities by segment:
-Completion and Production: Arbroath, United Kingdom; Duncan, Oklahoma; Johor Bahru, Malaysia; Lafayette, Louisiana; Rio de Janeiro, Brazil; and Singapore
-Drilling and Evaluation: Alvarado, Texas and The Woodlands, Texas
-Shared/corporate facilities: Bangalore, India; Carrollton, Texas; Dhahran, Saudi Arabia; Dubai, United Arab Emirates; Houston, Texas (corporate executive offices); Kuala Lumpur, Malaysia; London, England; Moscow, Russia; Panama City, Panama; Pune, India; and Tananger, Norway

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings.
Information related to Item 3. Legal Proceedings is included in Note 10 to the consolidated financial statements.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. Mine Safety Disclosures.
Our barite and bentonite mining operations, in support of our fluid services business, are subject to regulation by the U.S. Mine Safety and Health Administration under the Federal Mine Safety and Health Act of 1977. Information concerning mine safety violations or other regulatory matters required by section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95 to this annual report.
HAL 2021 FORM 10-K | 18

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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
PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.
Halliburton Company’s common stock is traded on the New York Stock Exchange under the symbol "HAL." Information related to dividend payments is included in "Item 8. Financial Statements and Supplementary Data". The declaration and payment of future dividends will be at the discretion of the Board of Directors and will depend on, among other things, future earnings, general financial condition and liquidity, success in business activities, capital requirements, and general business conditions.
The following graph and table compare total shareholder return on our common stock for the five-year period ended December 31, 2021, with the Philadelphia Oil Service Index (OSX) and the Standard & Poor’s 500 ® Index over the same period. This comparison assumes the investment of $100 on December 31, 2016 and the reinvestment of all dividends. The shareholder return set forth is not necessarily indicative of future performance. The following graph and related information shall not be deemed “soliciting material” or to be “filed” with the SEC, nor shall such information be incorporated by reference into any future filing under the Securities Act of 1933 or the Securities Exchange Act of 1934, except to the extent that Halliburton specifically incorporates it by reference into such filing.
December 31
2016 2017 2018 2019 2020 2021
Halliburton $ 100.00 $ 91.76 $ 80.87 $ 47.96 $ 37.94 $ 45.64
Philadelphia Oil Service Index (OSX) 100.00 82.80 45.36 45.11 26.13 31.55
Standard & Poor’s 500 ® Index 100.00 121.83 116.49 153.17 181.35 233.41
HAL 2021 FORM 10-K | 19
Item 5 | Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
At January 28, 2022, we had 10,582 shareholders of record. In calculating the number of shareholders, we consider clearing agencies and security position listings as one shareholder for each agency or listing.
The following table is a summary of repurchases of our common stock during the three-month period ended December 31, 2021.
Period Total Number
of Shares Purchased (a) Average
Price Paid per Share Total Number
of Shares
Purchased as
Part of Publicly
Announced Plans or Programs (b) Maximum
Number (or
Approximate
Dollar Value) of
Shares that may yet
be Purchased Under the Program (b)
October 1 - 31 23,040 $23.68 - $5,100,008,081
November 1 - 30 24,133 $25.05 - $5,100,008,081
December 1 - 31 166,791 $22.22 - $5,100,008,081
Total 213,964 $22.69 -
(a) All of the 213,964 shares purchased during the three-month period ended December 31, 2021 were acquired from employees in connection with the settlement of income tax and related benefit withholding obligations arising from vesting in restricted stock grants. These shares were not part of a publicly announced program to purchase common stock.
(b) Our Board of Directors has authorized a plan to repurchase a specified dollar amount of our common stock from time to time. Approximately $5.1 billion remained authorized for repurchases as of December 31, 2021. From the inception of this program in February 2006 through December 31, 2021, we repurchased approximately 224 million shares of our common stock for a total cost of approximately $9.0 billion.

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. (Reserved)
HAL 2021 FORM 10-K | 20

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
Item 7 | Executive Overview
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Management's Discussion and Analysis of Financial Condition and Results of Operations (MD&A) should be read in conjunction with the consolidated and combined financial statements included in "Item 8. Financial Statements and Supplementary Data" contained herein.
EXECUTIVE OVERVIEW
Financial results
The oil and gas industry continued to be impacted from shutdowns and mitigation efforts related to the COVID-19 pandemic during 2021, though there are signs that business activity around the world has adjusted and continues to improve. Despite these difficulties, in 2021 we demonstrated resilience and a strong commitment to our execution culture and delivered increased revenues, operating income, and cash flows from operations. The following graph illustrates our revenue and operating margins for each operating segment over the past three years.
During 2021, we generated total company revenue of $15.3 billion, a 6% increase from the $14.4 billion of revenue generated in 2020, with our Completion and Production (C&P) segment increasing by 7% and our Drilling and Evaluation (D&E) segment increasing by 4%. These increases were driven primarily by increased demand for our products and services in North America land tied to a substantial improvement in the North America land rig count during 2021. We reported total company operating income of approximately $1.8 billion in 2021. This compares to operating loss of $2.4 billion in 2020 that was driven by $3.8 billion of impairments and other charges as a result of the unprecedented downturn in the oil and gas industry, including a significant decline in pressure pumping services in North America land, caused by the COVID-19 pandemic.
Internationally, revenue improved 2% in 2021 compared to 2020, primarily driven by higher activity for drilling and completions related services in Latin America which were partly offset by lower activity in the Eastern Hemisphere. Despite an 8% reduction in the international rig count during 2021, we improved our overall international margin.
Our North America revenue increased 11% in 2021 compared to 2020, resulting from higher activity and pricing in North America land primarily associated with increased stimulation and well construction services. While the North America land rig count is increasing, it is still below pre-pandemic levels. Even without improved pricing, we took advantage of the recovery in completions and drilling activity in 2021 and delivered margin improvement, demonstrating the operating leverage from our cost reductions and service delivery improvements in North America.
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Item 7 | Executive Overview
Sustainability and Energy Advancement
In the first quarter of 2021, we announced our target to achieve 40% reduction in Scope 1 and 2 emissions by 2035 from the 2018 baseline. This is consistent with our goal to reduce the carbon footprint and environmental impact of our operations and follows our commitment to set science-based targets. We continue to pursue our strategic initiatives around advancing cleaner, affordable energy, and using innovation and technology to reduce the environmental impact of producing oil and gas. We are continuing to develop and deploy low-carbon solutions to help oil and gas operators lower their current emissions profiles while also using our existing technologies in renewable energy applications. In addition, Halliburton Labs added eleven participating companies during 2021. Through Halliburton Labs, we gain insight into the energy transition value chain and foster the development of technologies that may help reduce the world’s carbon footprint. Also, for 2021, we were named to the Dow Jones Sustainability Index North America for Energy Equipment and Services, which highlights the top 10% most sustainable North America companies in identified industries, as determined by S&P Global through their Corporate Sustainability Assessment.
Our operating performance and liquidity are described in more detail in “Liquidity and Capital Resources” and “Business Environment and Results of Operations.”
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Item 7 | Liquidity and Capital Resources
LIQUIDITY AND CAPITAL RESOURCES
As of December 31, 2021, we had $3.0 billion of cash and equivalents, compared to $2.6 billion of cash and equivalents at December 31, 2020.
Significant sources and uses of cash in 2021
Sources of cash:
•Cash flows from operating activities were $1.9 billion. This included a positive impact from the primary components of our working capital (receivables, inventories, and accounts payable) of a net $285 million, primarily associated with increased payables.
Uses of cash:
•In February of 2021, we repaid the $185 million principal balance of our 8.75% senior debentures at maturity.
•In August of 2021, we redeemed the entire $500 million aggregate principal amount outstanding of our 3.25% senior notes at par.
•Capital expenditures were $799 million.
•We paid $161 million of dividends to our shareholders.
Future sources and uses of cash
We manufacture most of our own equipment, which provides us with some flexibility to increase or decrease our capital expenditures based on market conditions. Capital spending for 2022 is currently expected to be $1.0 billion, remaining within our target of approximately 5-6% of revenue. We believe this level of spend will allow us to invest in our key strategic areas. However, we will continue to maintain capital discipline and monitor the rapidly changing market dynamics, and we may adjust our capital spend accordingly.
In 2022, we expect to pay approximately $443 million of interest on debt and approximately $351 million under our leasing arrangements. Payments for interest on our debt arrangements are expected to remain relatively flat for the foreseeable future. See Note 6 and Note 9 to the consolidated financial statements for additional information on expected future payments under our leasing arrangements and debt maturities.
We are not able to reasonably estimate the timing of cash outflows associated with our uncertain tax positions, in part because we are unable to predict the timing of potential tax settlements with applicable taxing authorities. As of December 31, 2021, we had $352 million of gross unrecognized tax benefits, excluding penalties and interest, of which we estimate $266 million may require us to make a cash payment. We estimate that approximately $198 million of the cash payment will not be settled within the next 12 months.
In January of 2022, we announced that our Board of Directors declared a dividend of $0.12 per share for the first quarter of 2022, or approximately $107 million, which represents a $0.075 increase from the quarterly dividend paid during 2021.
Our Board of Directors has authorized a program to repurchase our common stock from time to time. Approximately $5.1 billion remained authorized for repurchases as of December 31, 2021 and may be used for open market and other share purchases.
In January of 2022, we announced that on February 23, 2022, we will redeem $600 million aggregate principal amount of our 3.8% senior notes that mature in November 2025. The aggregate principal amount currently outstanding is approximately $1.0 billion. We plan to use cash on hand to fund the redemption.
We do not intend to incur additional debt in 2022, as we believe our cash on hand and earnings from operations are sufficient to cover our obligations for the year.
HAL 2021 FORM 10-K | 23
Item 7 | Liquidity and Capital Resources
Other factors affecting liquidity
Financial position in current market. As of December 31, 2021, we had $3.0 billion of cash and equivalents and $3.5 billion of available committed bank credit under our revolving credit facility. We believe we have a manageable debt maturity profile, with approximately $1.6 billion coming due through 2026, which includes the $600 million debt we will redeem on February 23, 2022 as described above. Furthermore, we have no financial covenants or material adverse change provisions in our bank agreements, and our debt maturities extend over a long period of time. We believe our cash on hand, cash flows generated from operations, and our available credit facility will provide sufficient liquidity to address the challenges and opportunities of the current market and our global cash needs, including capital expenditures, working capital investments, dividends, if any, debt repayment, and contingent liabilities.
Guarantee agreements. In the normal course of business, we have agreements with financial institutions under which approximately $1.9 billion of letters of credit, bank guarantees, or surety bonds were outstanding as of December 31, 2021. Some of the outstanding letters of credit have triggering events that would entitle a bank to require cash collateralization, however, none of these triggering events have occurred. As of December 31, 2021, we had no material off-balance sheet liabilities and were not required to make any material cash distributions to our unconsolidated subsidiaries.
Credit ratings. Our credit ratings with Standard & Poor’s (S&P) remain BBB+ for our long-term debt and A-2 for our short-term debt, with a stable outlook. Our credit ratings with Moody’s Investors Service (Moody's) remain Baa1 for our long-term debt and P-2 for our short-term debt, with a stable outlook.
Customer receivables. In line with industry practice, we bill our customers for our services in arrears and are, therefore, subject to our customers delaying or failing to pay our invoices. We may experience increased delays and failures to pay our invoices due to, among other reasons, a reduction in our customers’ cash flow from operations and their access to the credit markets, particularly in weak economic environments, as well as unsettled political conditions. Given the nature and significance of the pandemic and disruption in the oil and gas industry, we have experienced delayed customer payments and payment defaults associated with customer liquidity issues and bankruptcies.
Receivables from our primary customer in Mexico accounted for approximately 10% of our total receivables as of December 31, 2021. While we have experienced payment delays in Mexico, these amounts are not in dispute and we have not
historically had, and we do not expect, any material write-offs due to collectability of receivables from this customer.
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Item 7 | Business Environment and Results of Operations
BUSINESS ENVIRONMENT AND RESULTS OF OPERATIONS
We operate in more than 70 countries throughout the world to provide a comprehensive range of services and products to the energy industry. Our revenue is generated from the sale of services and products to major, national, and independent oil and natural gas companies worldwide. The industry we serve is highly competitive with many substantial competitors in each segment of our business. In 2021, 2020, and 2019, based on the location of services provided and products sold, 40%, 38%, and 51%, respectively, of our consolidated revenue was from the United States. No other country accounted for more than 10% of our revenue.
Activity within our business segments is significantly impacted by spending on upstream exploration, development, and production programs by our customers. Also impacting our activity is the status of the global economy, which impacts oil and natural gas consumption. The COVID-19 pandemic and efforts to mitigate its effect had a substantial negative impact on the global economy and demand for oil in 2020 and 2021. As discussed earlier, although there are signs of improvement in many areas around the world, the potential for new lockdowns and other mitigation efforts to deal with an increase in infection rates or new variants remains a key risk for oil demand.
Some of the more significant determinants of current and future spending levels of our customers are oil and natural gas prices and our customers' expectations about future prices, global oil supply and demand, completions intensity, the world economy, the availability of capital, government regulation, and global stability, which together drive worldwide drilling and completions activity. Additionally, many of our customers in North America have shifted their strategy from production growth to operating within cash flow and generating returns, and we generally expect that to continue in 2022. Lower oil and natural gas prices usually translate into lower exploration and production budgets and lower rig count, while the opposite is usually true for higher oil and natural gas prices. Our financial performance is therefore significantly affected by oil and natural gas prices and worldwide rig activity, which are summarized in the tables below.
The table below shows the average oil and natural gas prices for West Texas Intermediate (WTI), United Kingdom Brent crude oil, and Henry Hub natural gas.
2021 2020 2019
Oil price - WTI (1)
$ 67.99 $ 39.23 $ 56.98
Oil price - Brent (1)
70.68 41.76 64.36
Natural gas price - Henry Hub (2)
3.91 2.04 2.54
(1) Oil price measured in dollars per barrel.
(2) Natural gas price measured in dollars per million British thermal units (Btu), or MMBtu.
The historical average rig counts based on the weekly Baker Hughes rig count data were as follows:
2021 2020 2019
U.S. Land 465 418 920
U.S. Offshore 15 15 23
Canada 132 89 134
North America 612 522 1,077
International 755 825 1,098
Worldwide total 1,367 1,347 2,175
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Item 7 | Business Environment and Results of Operations
Business outlook
We believe that commodity prices will remain supportive of our business through 2022. According to the United States Energy Information Administration (EIA) January 2022 "Short Term Energy Outlook," the EIA expects Brent crude oil spot prices to average $75 per barrel for the full year of 2022, an increase of approximately 6% over the full year of 2021 average price per barrel. The EIA expects the WTI spot prices to average $71 per barrel for the full year of 2022, an increase of approximately 4% over full year of 2021 average price per barrel. On January 31, 2022, the Brent crude oil spot price was $89 per barrel and the WTI spot price was $88 per barrel.
The EIA's report projects Henry Hub natural gas prices to average $3.79 per MMBtu for the full year of 2022, a slight decrease over full year of 2021 averages. On January 31, 2022, the Henry Hub natural gas price was $4.87 per MMBtu.
The International Energy Agency's (IEA) January 2022 "Oil Market Report" (OMR) forecasts 2022 global oil demand to reach 100.8 million barrels per day, an increase of 4% from 2021. The EIA reported crude oil production in the United States averaged 11.2 million barrels per day in 2021, and the EIA expects production to average 11.8 million barrels per day in 2022, an approximate 5% increase. In addition, the EIA expects crude oil production in the United States to rise to 12.4 million barrels per day in 2023.
The recent surge of new COVID-19 cases related to the Omicron variant dampened the expectations of some economists regarding economic recovery and increasing demand for oil. For example, due to travel restrictions put in place as a result of Omicron, the global oil demand forecast for 2022 was originally revised down by forecasters, including the IEA and EIA, primarily to account for projected reduced jet fuel use. However, the wave of infections related to the Omicron variant appears to be less severe and potentially of shorter duration than prior waves. Consequently, we and the IEA, do not believe that this surge should overturn the recovery in oil demand that is underway. With widespread vaccination campaigns, and the apparent lower rates of serious illness, and hospitalization resulting from the recent wave, we expect that this wave is likely to have a more muted impact on the economy and demand for oil than previous COVID-19 waves.
Based on our expectations regarding the Omicron variant's impact on the demand for oil and assuming a more severe variant does not become widespread during 2022, we expect international activity growth to maintain momentum and customer spending to increase in the range of 14-16% in 2022, led by operators with shorter-cycle production opportunities committing additional capital to meet increasing oil demand. Internationally, we anticipate projects in the Middle East, Russia, and Latin America to attract the most investment, with lower levels of activity increases in Africa and Europe. While large tenders remain competitive, we see pricing traction on new work and contract renewals, including integrated contracts. We also expect to accelerate work on projects that were delayed or slowed due to pandemic-related travel restrictions.
In North America, consistent with historical trends, the recovery in activity was faster and more pronounced than in the international markets. North America drilling activity outpaced completions as operators prepared well inventory for 2022. Given the stronger commodity price environment, we anticipate customer spending to grow more than 25% in 2022, as compared to 2021, with the highest increase coming from private operators. We expect this will enable us to secure net pricing gains for our fracturing fleet as well as our drilling, cementing, drill bits, and artificial lift businesses. We expect most publicly traded exploration and production (E&Ps) companies to continue to prioritize returns, while delivering production into a supportive market.
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Item 7 | Results of Operations in 2021 Compared to 2020
RESULTS OF OPERATIONS IN 2021 COMPARED TO 2020
Revenue: Favorable Percentage
Millions of dollars 2021 2020 (Unfavorable) Change
Completion and Production $ 8,410 $ 7,839 $ 571 7 %
Drilling and Evaluation 6,885 6,606 279 4
Total revenue $ 15,295 $ 14,445 $ 850 6 %
By geographic region:
North America $ 6,371 $ 5,731 $ 640 11 %
Latin America 2,362 1,668 694 42
Europe/Africa/CIS 2,719 2,813 (94) (3)
Middle East/Asia 3,843 4,233 (390) (9)
Total $ 15,295 $ 14,445 $ 850 6 %
Operating income (loss): Favorable Percentage
Millions of dollars 2021 2020 (Unfavorable) Change
Completion and Production $ 1,238 $ 995 $ 243 24 %
Drilling and Evaluation 801 569 232 41
Total 2,039 1,564 475 30
Corporate and other (227) (201) (26) (13)
Impairments and other charges (12) (3,799) 3,787 100
Total operating income (loss) $ 1,800 $ (2,436) $ 4,236 n/m
n/m = not meaningful
Consolidated revenue in 2021 was $15.3 billion, an increase of $850 million, or 6%, compared to 2020, mainly due to higher activity and pricing in North America land and Latin America, primarily associated with stimulation services and well construction services. Also, artificial lift activity in North America land and wireline activity in Latin America showed improvements. Partially offsetting these increases were declines in completion tool sales and drilling-related services in the Eastern Hemisphere and lower stimulation activity in Middle East/Asia. Revenue from North America was 42% of consolidated revenue in 2021 and 40% of consolidated revenue in 2020.
We reported consolidated operating income of $1.8 billion in 2021. This compares to an operating loss of $2.4 billion in 2020, driven by $3.8 billion of impairments and other charges taken in 2020. An increase in activity and pricing for stimulation and well construction services in North America land and Latin America during 2021 positively impacted operating results. Also, global wireline activity and project management activity in Latin America and Middle East/Asia improved. These increases were partially offset by lower software sales globally. See Note 2 to the consolidated financial statements for further discussion on impairments and other charges.
OPERATING SEGMENTS
Completion and Production
Completion and Production revenue was $8.4 billion in 2021, an increase of $571 million, or 7%, compared to 2020. Operating income was $1.2 billion in 2021, a 24% increase from $995 million in 2020. These results were primarily driven by increased activity and pricing for pressure pumping services in North America land, Latin America, and Europe Africa/CIS, higher artificial lift activity in North America land, increased well intervention services in Latin America, and increased pipeline services in China, Russia, and the United Kingdom. Partially offsetting these results were decreases in completion tool sales in the Eastern Hemisphere, Canada, and the Gulf of Mexico, along with lower pressure pumping services in Middle East/Asia, the Gulf of Mexico, and Canada.
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Item 7 | Results of Operations in 2021 Compared to 2020
Drilling and Evaluation
Drilling and Evaluation revenue was $6.9 billion in 2021, an increase of $279 million, or 4%, from 2020. Operating income was $801 million in 2021, an increase of $232 million, or 41%, compared to 2020. These results were primarily related to increased drilling-related services in the Western Hemisphere, improved project management activity in Ecuador, Mexico, Oman, Saudi Arabia, increased well control activity in Nigeria, and increased wireline activity and testing services in Latin America. These improvements were partially offset by reduced drilling-related services in the Eastern Hemisphere, lower wireline activity and testing services in Saudi Arabia, a decline in software sales globally, and lower project management activity in India and Iraq.
GEOGRAPHIC REGIONS
North America
North America revenue was $6.4 billion in 2021, an 11% increase compared to 2020, resulting from higher activity and pricing in North America land, primarily associated with pressure pumping services, drilling-related services, and artificial lift activity. These increases were partially offset by lower pressure pumping services in Canada and completion tool sales in Canada and the Gulf of Mexico. Also, software sales and wireline activity were lower across the region.
Latin America
Latin America revenue was $2.4 billion in 2021, a 42% increase compared to 2020, resulting primarily from improvements in stimulation activity, well construction services, wireline activity, completion tool sales, and testing services in Argentina, coupled with increased fluid services in the Caribbean and Brazil. Also improving were pressure pumping services, project management activity, testing services, drilling services, and completion tool sales in Mexico, along with improved drilling services in Brazil and increased well intervention services across the region. In addition, project management activity was higher in Ecuador. Partly offsetting these increases were lower completion tool sales in Trinidad and reduced software sales across the region.
Europe/Africa/CIS
Europe/Africa/CIS revenue was $2.7 billion in 2021, a 3% decrease compared to 2020. The decrease was driven by lower activity across multiple product service lines in Russia combined with lower fluid services and completion tool sales across the region, coupled with reduced cementing activity in Nigeria. These declines were partially offset by increases in completion tool sales and cementing activity in Norway, testing services in Algeria, project management activity in Nigeria, pressure pumping services in Angola, pipeline services in the United Kingdom, and wireline activity across the region.
Middle East/Asia
Middle East/Asia revenue was $3.8 billion in 2021, a 9% decrease compared to 2020. The decrease was primarily from reduced activity across multiple product service lines in Saudi Arabia, Indonesia, and United Arab Emirates, lower completion tool sales and pressure pumping services across the region, and reduced project management activity in India and Iraq. Partially offsetting these decreases were higher project management activity and drilling services in Oman and increased pipeline services in China.
OTHER OPERATING ITEMS
Impairments and other charges. During 2021, we recognized $12 million of net charges. This includes $36 million of depreciation catch-up expense related to assets previously classified as held for sale related to our Pipeline and Process Services business, $15 million of severance costs, and $35 million of other items, partially offset by a $74 million gain related to the closing of the structured transaction for our North America real estate assets. This compares to $3.8 billion of impairments and other charges recorded in 2020, consisting of asset impairments primarily associated with pressure pumping and drilling equipment, as well as severance and other costs incurred as we adjusted our cost structure during the year. See Note 2 to the consolidated financial statements for further discussion on these charges.
NONOPERATING ITEMS
Loss on early extinguishment of debt. During the year ended December 31, 2020, we recorded a $168 million loss on the early extinguishment of debt, which included a tender premium, unamortized discounts and costs on the retired notes, and tender fees. See Note 9 to the consolidated financial statements for further information.
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Item 7 | Results of Operations in 2021 Compared to 2020
Income tax (provision) benefit. Our tax (provisions) benefits are sensitive to the geographic mix of earnings and our ability to use our deferred tax assets. During 2021, we recorded a total income tax benefit of $216 million on pre-tax income of $1.3 billion, resulting in an effective tax rate of -17.2%. We recorded a tax benefit of approximately $500 million during 2021, primarily due to the partial release of a valuation allowance on our deferred tax assets. This release was based on improved market conditions and reflects our expectation to utilize these deferred tax assets. During 2020, we recorded a total income tax benefit of $278 million on pre-tax loss of $3.2 billion, resulting in an effective tax rate of 8.6%. See Note 11 to the consolidated financial statements for significant drivers of these tax (provisions) benefits.
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Item 7 | Results of Operations in 2020 Compared to 2019
RESULTS OF OPERATIONS IN 2020 COMPARED TO 2019
Information related to the comparison of our operating results between the years 2020 and 2019 is included in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" of our 2020 Form 10-K filed with the SEC and is incorporated by reference into this annual report on Form 10-K.
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Item 7 | Critical Accounting Estimates
CRITICAL ACCOUNTING ESTIMATES
The preparation of financial statements requires the use of judgments and estimates. Our critical accounting policies are described below to provide a better understanding of how we develop our assumptions and judgments about future events and related estimates and how they can impact our financial statements. A critical accounting estimate is one that requires our most difficult, subjective, or complex judgments and assessments and is fundamental to our results of operations. We identified our most critical accounting estimates to be:
- forecasting our income tax (provision) benefit, including our future ability to utilize foreign tax credits and the realizability of deferred tax assets (including net operating loss carryforwards), and providing for uncertain tax positions;
- legal and investigation matters;
- valuations of long-lived assets, including intangible assets and goodwill; and
- allowance for credit losses.
We base our estimates on historical experience and on various other assumptions we believe to be reasonable according to the current facts and circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. We believe the following are the critical accounting policies used in the preparation of our consolidated financial statements, as well as the significant estimates and judgments affecting the application of these policies. This discussion and analysis should be read in conjunction with our consolidated financial statements and related notes included in this report.
Income tax accounting
We recognize the amount of taxes payable or refundable for the current year and use an asset and liability approach in recognizing the amount of deferred tax liabilities and assets for the future tax consequences of events that have been recognized in our financial statements or tax returns. We apply the following basic principles in accounting for our income taxes:
- a current tax liability or asset is recognized for the estimated taxes payable or refundable on tax returns for the current year;
- a deferred tax liability or asset is recognized for the estimated future tax effects attributable to temporary differences and carryforwards;
- the measurement of current and deferred tax liabilities and assets is based on provisions of the enacted tax law, and the effects of potential future changes in tax laws or rates are not considered; and
- the value of deferred tax assets is reduced, if necessary, by the amount of any tax benefits that, based on available evidence, are not expected to be realized.
We determine deferred taxes separately for each tax-paying component (an entity or a group of entities that is consolidated for tax purposes) in each tax jurisdiction. That determination includes the following procedures:
- identifying the types and amounts of existing temporary differences;
- measuring the total deferred tax liability for taxable temporary differences using the applicable tax rate;
- measuring the total deferred tax asset for deductible temporary differences and operating loss carryforwards using the applicable tax rate;
- measuring the deferred tax assets for each type of tax credit carryforward; and
- reducing the deferred tax assets by a valuation allowance if, based on available evidence, it is more likely than not that some portion or all of the deferred tax assets will not be realized.
Our methodology for recording income taxes requires a significant amount of judgment and the use of assumptions and estimates. Additionally, we use forecasts of certain tax elements, such as taxable income and foreign tax credit utilization, as well as evaluate the feasibility of implementing tax planning strategies. Given the inherent uncertainty involved with the use of such variables, there can be significant variation between anticipated and actual results that could have a material impact on our income tax accounts related to continuing operations.
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Item 7 | Critical Accounting Estimates
We have operations in more than 70 countries. Consequently, we are subject to the jurisdiction of a significant number of taxing authorities. The income earned in these various jurisdictions is taxed on differing bases, including net income actually earned, net income deemed earned, and revenue-based tax withholding. Our tax filings are routinely examined in the normal course of business by tax authorities. The final determination of our income tax liabilities involves the interpretation of local tax laws, tax treaties and related authorities in each jurisdiction, as well as the significant use of estimates and assumptions regarding the scope of future operations and results achieved, the timing and nature of income earned and expenditures incurred. The final determination of tax audits or changes in the operating environment, including changes in tax law and currency/repatriation controls, could impact the determination of our income tax liabilities for a tax year and have an adverse effect on our financial statements.
Tax filings of our subsidiaries, unconsolidated affiliates and related entities are routinely examined in the normal course of business by tax authorities. These examinations may result in assessments of additional taxes, which we work to resolve with the tax authorities and through the judicial process. Predicting the outcome of disputed assessments involves some uncertainty. Factors such as the availability of settlement procedures, willingness of tax authorities to negotiate, and the operation and impartiality of judicial systems vary across the different tax jurisdictions and may significantly influence the ultimate outcome. We review the facts for each assessment, and then utilize assumptions and estimates to determine the most likely outcome and provide taxes, interest, and penalties, as needed based on this outcome. We provide for uncertain tax positions pursuant to current accounting standards, which prescribe a minimum recognition threshold and measurement methodology that a tax position taken or expected to be taken in a tax return is required to meet before being recognized in the financial statements. The standards also provide guidance for derecognition classification, interest and penalties, accounting in interim periods, disclosure, and transition.
Legal and investigation matters
As discussed in Note 10 of our consolidated financial statements, we are subject to various legal and investigation matters arising in the ordinary course of business. As of December 31, 2021, we have accrued an estimate of the probable and estimable costs for the resolution of some of our legal and investigation matters, which is not material to our consolidated financial statements. For other matters for which the liability is not probable and reasonably estimable, we have not accrued any amounts. Attorneys in our legal department monitor and manage all claims filed against us and review all pending investigations. Generally, the estimate of probable costs related to these matters is developed in consultation with internal and outside legal counsel representing us. Our estimates are based upon an analysis of potential results, assuming a combination of litigation and settlement strategies. The accuracy of these estimates is impacted by, among other things, the complexity of the issues and the amount of due diligence we have been able to perform. We attempt to resolve these matters through settlements, mediation, and arbitration proceedings when possible. If the actual settlement costs, final judgments, or fines, after appeals, differ from our estimates, there may be a material adverse effect on our future financial results. We have in the past recorded significant adjustments to our initial estimates of these types of contingencies.
Value of long-lived assets, including intangible assets and goodwill
We carry a variety of long-lived assets on our balance sheet including property, plant and equipment, goodwill, and other intangibles. Impairment is the condition that exists when the carrying amount of a long-lived asset exceeds its fair value, and any impairment charge that we record reduces our operating income. Goodwill is the excess of the cost of an acquired entity over the net of the amounts assigned to assets acquired and liabilities assumed. We conduct impairment tests on goodwill annually, during the third quarter, or more frequently whenever events or changes in circumstances indicate an impairment may exist. We conduct impairment tests on long-lived assets, other than goodwill, whenever events or changes in circumstances indicate that the carrying value may not be recoverable.
When conducting an impairment test on long-lived assets, other than goodwill, we first group individual assets based on the lowest level for which identifiable cash flows are largely independent of the cash flows from other assets. This requires some judgment. We then compare estimated future undiscounted cash flows expected to result from the use and eventual disposition of the asset group to its carrying amount. If the undiscounted cash flows are less than the asset group’s carrying amount, we then determine the asset group's fair value by using a discounted cash flow analysis. This analysis is based on estimates such as management’s short-term and long-term forecast of operating performance, including revenue growth rates and expected profitability margins, estimates of the remaining useful life and service potential of the assets within the asset group, and a discount rate based on our weighted average cost of capital. An impairment loss is measured and recorded as the amount by which the asset group's carrying amount exceeds its fair value. See Note 2 to the consolidated financial statements for further discussion of impairments and other charges.
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Item 7 | Critical Accounting Estimates
We perform our goodwill impairment assessment for each reporting unit, which is the same as our reportable segments, the Completion and Production division and the Drilling and Evaluation division, comparing the estimated fair value of each reporting unit to the reporting unit’s carrying value, including goodwill. We estimate the fair value for each reporting unit using a discounted cash flow analysis based on management’s short-term and long-term forecast of operating performance. This analysis includes significant assumptions regarding discount rates, revenue growth rates, expected profitability margins, forecasted capital expenditures, and the timing of expected future cash flows based on market conditions. If the estimated fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered impaired. If the carrying amount of a reporting unit exceeds its estimated fair value, an impairment loss is measured and recorded.
The impairment assessments discussed above incorporate inherent uncertainties, including projected commodity pricing, supply and demand for our services, and future market conditions, which are difficult to predict in volatile economic environments and could result in impairment charges in future periods if actual results materially differ from the estimated assumptions utilized in our forecasts. If market conditions deteriorate, including crude oil prices significantly declining and remaining at low levels for a sustained period of time, we could be required to record additional impairments of the carrying value of our long-lived assets in the future which could have a material adverse impact on our operating results. See Note 1 to the consolidated financial statements for our accounting policies related to long-lived assets.
Allowance for credit losses
We evaluate our global accounts receivable through a continuous process of assessing our portfolio on an individual customer and overall basis. This process consists of a thorough review of historical collection experience, current aging status of the customer accounts, financial condition of our customers, and whether the receivables involve retainages. We also consider the economic environment of our customers, both from a marketplace and geographic perspective, in evaluating the need for an allowance. Based on our review of these factors, we establish or adjust allowances for specific customers. This process involves judgment and estimation, and frequently involves significant dollar amounts. Accordingly, our results of operations can be affected by adjustments to the allowance due to actual write-offs that differ from estimated amounts.
At December 31, 2021, our allowance for credit losses totaled $754 million, or 17.8% of notes and accounts receivable before the allowance. At December 31, 2020, our allowance for credit losses totaled $824 million, or 22.5% of notes and accounts receivable before the allowance. The allowance for credit losses in both years is primarily comprised of accounts receivable from our primary customer in Venezuela. A hypothetical 100 basis point change in our estimate of the collectability of our notes and accounts receivable balance as of December 31, 2021 would have resulted in a $42 million adjustment to 2021 total operating costs and expenses. See Note 5 to the consolidated financial statements for further information.
FINANCIAL INSTRUMENT MARKET RISK
We are exposed to market risk from changes in foreign currency exchange rates and interest rates. We selectively manage these exposures through the use of derivative instruments, including forward foreign exchange contracts, foreign exchange options, and interest rate swaps. The objective of our risk management strategy is to minimize the volatility from fluctuations in foreign currency and interest rates. We do not use derivative instruments for trading purposes. The counterparties to our forward contracts, options, and interest rate swaps are global commercial and investment banks.
We use a sensitivity analysis model to measure the impact of potential adverse movements in foreign currency exchange rates and interest rates. With respect to foreign exchange sensitivity, after consideration of the impact from our foreign forward contracts and options, a hypothetical 10% adverse change in the value of all our foreign currency positions relative to the United States dollar as of December 31, 2021 would result in a $83 million, pre-tax, loss for our net monetary assets denominated in currencies other than United States dollars. As of December 31, 2021, we did not have any interest rate swaps outstanding.
There are certain limitations inherent in the sensitivity analysis presented, primarily due to the assumption that exchange rates and interest rates change instantaneously in an equally adverse fashion. In addition, the analyses are unable to reflect the complex market reactions that normally would arise from the market shifts modeled. While this is our best estimate of the impact of the various scenarios, these estimates should not be viewed as forecasts.
For further information regarding foreign currency exchange risk, interest rate risk, and credit risk, see Note 15 to the consolidated financial statements.
HAL 2021 FORM 10-K | 33
Item 7 | Environmental Matters
ENVIRONMENTAL MATTERS
We are subject to numerous environmental, legal, and regulatory requirements related to our operations worldwide. For information related to environmental matters, see Note 10 to the consolidated financial statements and "Part I, Item 1(a). “Risk Factors.”
FORWARD-LOOKING INFORMATION
The Private Securities Litigation Reform Act of 1995 provides safe harbor provisions for forward-looking information. Forward-looking information is based on projections and estimates, not historical information. Some statements in this Form 10-K are forward-looking and use words like “may,” “may not,” “believe,” “do not believe,” “plan,” “estimate,” “intend,” “expect,” “do not expect,” “anticipate,” “do not anticipate,” “should,” “likely,” and other expressions. We may also provide oral or written forward-looking information in other materials we release to the public. Forward-looking information involves risk and uncertainties and reflects our best judgment based on current information. Our results of operations can be affected by inaccurate assumptions we make or by known or unknown risks and uncertainties. In addition, other factors may affect the accuracy of our forward-looking information. As a result, no forward-looking information can be guaranteed. Actual events and the results of our operations may vary materially.
We do not assume any responsibility to publicly update any of our forward-looking statements regardless of whether factors change as a result of new information, future events or for any other reason. You should review any additional disclosures we make in our press releases and Forms 10-K, 10-Q, and 8-K filed with or furnished to the SEC. We also suggest that you listen to our quarterly earnings release conference calls with financial analysts.
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Item 7(a) | Quantitative and Qualitative Disclosures About Market Risk
Item 7(a). Quantitative and Qualitative Disclosures About Market Risk.
Information related to market risk is included in "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Instrument Market Risk” and Note 15 to the consolidated financial statements.
HAL 2021 FORM 10-K | 35

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. Financial Statements and Supplementary Data.
PAGE
Financial Statements
Management’s Report on Internal Control Over Financial Reporting
Reports of Independent Registered Public Accounting Firm
Consolidated Statements of Operations for the years ended December 31, 2021, 2020 and 2019
Consolidated Statements of Comprehensive Income (Loss) for the years ended December 31, 2021, 2020 and 2019
Consolidated Balance Sheets at December 31, 2021 and 2020
Consolidated Statements of Cash Flows for the years ended December 31, 2021, 2020 and 2019
Consolidated Statements of Shareholders’ Equity for the years ended December 31, 2021, 2020 and 2019
Notes to Consolidated Financial Statements
Note 1. Description of Company and Significant Accounting Policies
Note 2. Impairments and Other Charges
Note 3. Business Segment and Geographic Information
Note 4. Revenue
Note 5. Receivables
Note 6. Leases
Note 7. Inventories
Note 8. Property, Plant and Equipment
Note 9. Debt
Note 10. Commitments and Contingencies
Note 11. Income Taxes
Note 12. Shareholders’ Equity
Note 13. Stock-based Compensation
Note 14. Income per Share
Note 15. Financial Instruments and Risk Management
Note 16. Retirement Plans
HAL 2021 FORM 10-K | 36
MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
The management of Halliburton Company is responsible for establishing and maintaining adequate internal control over financial reporting as defined in the Securities Exchange Act Rule 13a-15(f).
Internal control over financial reporting, no matter how well designed, has inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Further, because of changes in conditions, the effectiveness of internal control over financial reporting may vary over time.
Under the supervision and with the participation of our management, including our chief executive officer and chief financial officer, we conducted an evaluation to assess the effectiveness of our internal control over financial reporting as of December 31, 2021 based upon criteria set forth in the Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
Based on our assessment, we believe that, as of December 31, 2021, our internal control over financial reporting is effective. The effectiveness of Halliburton’s internal control over financial reporting as of December 31, 2021 has been audited by KPMG LLP, an independent registered public accounting firm, as stated in their report that is included herein.
HALLIBURTON COMPANY
by
/s/ Jeffrey A. Miller /s/ Lance Loeffler
Jeffrey A. Miller Lance Loeffler
Chairman of the Board, President and Executive Vice President and
Chief Executive Officer Chief Financial Officer
HAL 2021 FORM 10-K | 37
Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors
Halliburton Company:
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of Halliburton Company and subsidiaries (the Company) as of December 31, 2021 and 2020, the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2021, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2021, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 4, 2022 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of a critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Evaluation of the Realizability of Deferred Tax Assets
As discussed in Notes 1 and 11 to the consolidated financial statements, the Company recognizes deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in the financial statements. A valuation allowance is provided for deferred tax assets if it is more likely than not that these items will not be realized, which is dependent upon the generation of future taxable income. As of December 31, 2021, the Company had gross deferred tax assets of $3.8 billion and a related valuation allowance of $0.9 billion.
We identified the evaluation of the realizability of domestic deferred tax assets as a critical audit matter. The evaluation of the realizability of domestic deferred tax assets, specifically related to domestic net operating loss carryforwards and foreign tax credits, required subjective auditor judgment to assess the forecasts of future taxable income over the periods in which those temporary differences become deductible. Changes in assumptions regarding forecasted taxable income, specifically revenue growth rates, could have an impact on the Company’s evaluation of the realizability of the domestic deferred tax assets.
HAL 2021 FORM 10-K | 38
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls related to the critical audit matter. This included controls related to the development of forecasts of future taxable income. We evaluated the assumptions used in the development of forecasts of future taxable income, specifically revenue growth rates, by comparing to historical actuals while considering current and anticipated future commodity prices or market events. We also evaluated the Company’s history of realizing domestic deferred tax assets by evaluating the expiration of domestic net operating loss carryforwards and foreign tax credits.
/s/ KPMG LLP
We have served as the Company’s auditor since 2002.
Houston, Texas
February 4, 2022
HAL 2021 FORM 10-K | 39
Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors
Halliburton Company:
Opinion on Internal Control Over Financial Reporting
We have audited Halliburton Company and subsidiaries' (the Company) internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 2021 and 2020, the related consolidated statements of operations, comprehensive income (loss), shareholders' equity, and cash flows for each of the years in the three-year period ended December 31, 2021, and the related notes (collectively, the consolidated financial statements), and our report dated February 4, 2022 expressed an unqualified opinion on those consolidated financial statements.
Basis for Opinion
The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ KPMG LLP
Houston, Texas
February 4, 2022
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HALLIBURTON COMPANY
Consolidated Statements of Operations
Year Ended December 31
Millions of dollars and shares except per share data 2021 2020 2019
Revenue:
Services $ 10,989 $ 10,203 $ 16,884
Product sales 4,306 4,242 5,524
Total revenue 15,295 14,445 22,408
Operating costs and expenses:
Cost of services 9,745 9,458 15,684
Cost of sales 3,534 3,442 4,439
Impairments and other charges 12 3,799 2,506
General and administrative 204 182 227
Total operating costs and expenses 13,495 16,881 22,856
Operating income (loss) 1,800 (2,436) (448)
Interest expense, net of interest income of $60, $38, and $23
(469) (505) (569)
Loss on early extinguishment of debt - (168) -
Other, net (79) (111) (105)
Income (loss) before income taxes 1,252 (3,220) (1,122)
Income tax benefit (provision) 216 278 (7)
Net income (loss) $ 1,468 $ (2,942) $ (1,129)
Net income attributable to noncontrolling interest (11) (3) (2)
Net income (loss) attributable to company $ 1,457 $ (2,945) $ (1,131)
Basic and diluted income (loss) per share attributable to company shareholders:
Net income (loss) per share $ 1.63 $ (3.34) $ (1.29)
Basic and diluted weighted average common shares outstanding 892 881 875
See notes to consolidated financial statements.
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HALLIBURTON COMPANY
Consolidated Statements of Comprehensive Income (Loss)
Year Ended December 31
Millions of dollars 2021 2020 2019
Net income (loss) $ 1,468 $ (2,942) $ (1,129)
Other comprehensive income (loss), net of income taxes:
Defined benefit and other post retirement plans adjustment 179 (24) (11)
Other - 24 3
Other comprehensive income (loss), net of income taxes 179 - (8)
Comprehensive income (loss) $ 1,647 $ (2,942) $ (1,137)
Comprehensive income attributable to noncontrolling interest (11) (3) (2)
Comprehensive income (loss) attributable to company shareholders $ 1,636 $ (2,945) $ (1,139)
See notes to consolidated financial statements.
HAL 2021 FORM 10-K | 42
HALLIBURTON COMPANY
Consolidated Balance Sheets
December 31
Millions of dollars and shares except per share data 2021 2020
Assets
Current assets:
Cash and equivalents $ 3,044 $ 2,563
Receivables (net of allowances for credit losses of $754 and $824)
3,666 3,071
Inventories 2,361 2,349
Other current assets 872 1,492
Total current assets 9,943 9,475
Property, plant, and equipment (net of accumulated depreciation of $11,442 and $11,039)
4,326 4,325
Goodwill 2,843 2,804
Deferred income taxes 2,695 2,166
Operating lease right-of-use assets 934 786
Other assets 1,580 1,124
Total assets $ 22,321 $ 20,680
Liabilities and Shareholders’ Equity
Current liabilities:
Accounts payable $ 2,353 $ 1,573
Accrued employee compensation and benefits 493 517
Taxes other than income 292 292
Income Taxes Payable 261 216
Current portion of operating lease liabilities 240 251
Current maturities of long-term debt 7 695
Other current liabilities 660 877
Total current liabilities 4,306 4,421
Long-term debt 9,127 9,132
Operating lease liabilities 845 758
Employee compensation and benefits 492 562
Other liabilities 823 824
Total liabilities 15,593 15,697
Shareholders’ equity:
Common stock, par value $2.50 per share (authorized 2,000 shares, issued 1,066 and 1,066 shares)
2,665 2,666
Paid-in capital in excess of par value 32 -
Accumulated other comprehensive loss (183) (362)
Retained earnings 9,710 8,691
Treasury stock, at cost (170 and 181 shares)
(5,511) (6,021)
Company shareholders’ equity 6,713 4,974
Noncontrolling interest in consolidated subsidiaries 15 9
Total shareholders’ equity 6,728 4,983
Total liabilities and shareholders’ equity $ 22,321 $ 20,680
See notes to consolidated financial statements.
HAL 2021 FORM 10-K | 43
HALLIBURTON COMPANY
Consolidated Statements of Cash Flows
Year Ended December 31
Millions of dollars 2021 2020 2019
Cash flows from operating activities:
Net income (loss) $ 1,468 $ (2,942) $ (1,129)
Adjustments to reconcile net income (loss) to cash flows from operating activities:
Depreciation, depletion, and amortization 904 1,058 1,625
Deferred income tax benefit (486) (444) (396)
Impairments and other charges 12 3,799 2,506
Cash impact of impairments and other charges - severance payments (47) (350) (144)
Changes in assets and liabilities:
Accounts payable 795 (934) (595)
Receivables (500) 1,394 636
Inventories (10) 340 (202)
Other operating activities (225) (40) 144
Total cash flows provided by operating activities 1,911 1,881 2,445
Cash flows from investing activities:
Capital expenditures (799) (728) (1,530)
Proceeds from sales of property, plant, and equipment 257 286 190
Proceeds from a structured real estate transaction 87 - -
Other investing activities (79) (44) (105)
Total cash flows used in investing activities (534) (486) (1,445)
Cash flows from financing activities:
Payments on long-term borrowings (700) (1,654) (13)
Dividends to shareholders (161) (278) (630)
Proceeds from issuance of common stock 79 87 118
Proceeds from issuance of long-term debt, net - 994 -
Stock repurchase program - (100) (100)
Other financing activities (56) (56) (70)
Total cash flows used in financing activities (838) (1,007) (695)
Effect of exchange rate changes on cash (58) (93) (45)
Increase in cash and equivalents 481 295 260
Cash and equivalents at beginning of year 2,563 2,268 2,008
Cash and equivalents at end of year $ 3,044 $ 2,563 $ 2,268
Supplemental disclosure of cash flow information:
Cash payments during the period for:
Interest $ 517 $ 509 $ 534
Income taxes $ 214 $ 300 $ 363
See notes to consolidated financial statements.
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HALLIBURTON COMPANY
Consolidated Statements of Shareholders' Equity
Company Shareholders’ Equity
Millions of dollars Common Stock Paid-in Capital in Excess of Par Value Treasury Stock Retained Earnings Accumulated Other Comprehensive Income (Loss) Noncontrolling Interest in Consolidated Subsidiaries Total
Balance at December 31, 2018 $ 2,671 $ 211 $ (6,744) $ 13,739 $ (355) $ 22 $ 9,544
Comprehensive income (loss):
Net income (loss) - - - (1,131) - 2 (1,129)
Other comprehensive loss - - - - (8) - (8)
Cash dividends ($0.72 per share)
- - - (630) - - (630)
Stock plans (2) (67) 417 - - - 348
Stock repurchase program - - (100) - - - (100)
Other - (1) - 11 1 (11) -
Balance at December 31, 2019 $ 2,669 $ 143 $ (6,427) $ 11,989 $ (362) $ 13 $ 8,025
Comprehensive income (loss):
Net income (loss) - - - (2,945) - 3 (2,942)
Cash dividends ($0.315 per share)
- - - (278) - - (278)
Stock plans (3) (143) 506 (75) - - 285
Stock repurchase program - - (100) - - - (100)
Other - - - - - (7) (7)
Balance at December 31, 2020 $ 2,666 $ - $ (6,021) $ 8,691 $ (362) $ 9 $ 4,983
Comprehensive income (loss):
Net income - - - 1,457 - 11 1,468
Other comprehensive income - - - - 179 - 179
Cash dividends ($0.18 per share)
- - - (161) - - (161)
Stock plans (1) 32 510 (277) - - 264
Other - - - - (5) (5)
Balance at December 31, 2021 $ 2,665 $ 32 $ (5,511) $ 9,710 $ (183) $ 15 $ 6,728
See notes to consolidated financial statements.
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Item 8 | Notes to Consolidated Financial Statements
HALLIBURTON COMPANY
Notes to Consolidated Financial Statements
Note 1. Description of Company and Significant Accounting Policies
Description of Company
Halliburton Company is one of the world's largest providers of products and services to the energy industry. Its predecessor was established in 1919 and incorporated under the laws of the State of Delaware in 1924. We help our customers maximize asset value throughout the lifecycle of the reservoir - from locating hydrocarbons and managing geological data, to drilling and formation evaluation, well construction and completion, and optimizing production throughout the life of the asset. We serve major, national, and independent oil and natural gas companies throughout the world and operate under two divisions, which form the basis for the two operating segments we report, the Completion and Production segment and the Drilling and Evaluation segment.
Use of estimates
Our financial statements are prepared in conformity with United States generally accepted accounting principles, requiring us to make estimates and assumptions that affect:
- the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements; and
- the reported amounts of revenue and expenses during the reporting period.
We believe the most significant estimates and assumptions are associated with the forecasting of our income tax (provision) benefit and the valuation of deferred taxes, legal reserves, long-lived asset valuations, and allowance for credit losses. Ultimate results could differ from our estimates.
Basis of presentation
The consolidated financial statements include the accounts of our company and all of our subsidiaries that we control or variable interest entities for which we have determined that we are the primary beneficiary. All material intercompany accounts and transactions are eliminated. Investments in companies in which we do not have a controlling interest, but over which we do exercise significant influence, are accounted for using the equity method of accounting, unless we elect the fair value option. If we do not have significant influence and the investment has no readily determinable fair value, we elect the measurement alternative. In addition, certain reclassifications of prior period balances have been made to conform to the current period presentation.
Revenue recognition
Our services and products are generally sold based upon purchase orders or contracts with our customers that include fixed or determinable prices but do not include right of return provisions or other significant post-delivery obligations. The vast majority of our service and product contracts are short-term in nature. We recognize revenue based on the transfer of control or our customers' ability to benefit from our services and products in an amount that reflects the consideration we expect to receive in exchange for those services and products. We also assess our customers' ability and intention to pay, which is based on a variety of factors, including our historical payment experience with, and the financial condition of our customers. Rates for services are typically priced on a per day, per meter, per man-hour, or similar basis. See Note 4 for further information on revenue recognition.
Research and development
We maintain an active research and development program. The program improves products, processes, and engineering standards and practices that serve the changing needs of our customers, such as those related to high pressure and high temperature environments, and also develops new products and processes. Research and development costs are expensed as incurred and were $321 million in 2021, $309 million in 2020, and $404 million in 2019.
Cash equivalents
We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Inventories
Inventories are stated at the lower of cost and net realizable value. Cost represents invoice or production cost for new items and original cost. Production cost includes material, labor, and manufacturing overhead. Our inventory is recorded on the weighted average cost method. We regularly review inventory quantities on hand and record provisions for excess or obsolete inventory based primarily on historical usage, estimated product demand, and technological developments.
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Item 8 | Notes to Consolidated Financial Statements
Allowance for credit losses
We establish an allowance for credit losses through a review of several factors, including historical collection experience, current aging status of the customer accounts, and current financial condition of our customers. Losses are charged against the allowance when the customer accounts are determined to be uncollectible.
Property, plant, and equipment
Other than those assets that have been written down to their fair values due to impairment, property, plant, and equipment are reported at cost less accumulated depreciation, which is generally provided on the straight-line method over the estimated useful lives of the assets. Accelerated depreciation methods are often used for tax purposes, when permitted. Upon sale or retirement of an asset, the related costs and accumulated depreciation are removed from the accounts and any gain or loss is recognized. Planned major maintenance costs are generally expensed as incurred. Expenditures for additions, modifications, and conversions are capitalized when they increase the value or extend the useful life of the asset.
Goodwill and other intangible assets
We record as goodwill the excess purchase price over the fair value of the tangible and identifiable intangible assets acquired in a business acquisition. Changes in the carrying amount of goodwill are detailed below by reportable segment.
Millions of dollars Completion and Production Drilling and Evaluation Total
Balance at December 31, 2019: $ 2,039 $ 773 $ 2,812
Other (66) 58 (8)
Balance at December 31, 2020: $ 1,973 $ 831 $ 2,804
Current year acquisitions 12 - 12
Other 27 - 27
Balance at December 31, 2021: $ 2,012 $ 831 $ 2,843
The reported amounts of goodwill for each reporting unit are reviewed for impairment on an annual basis, during the third quarter, and more frequently when circumstances indicate an impairment may exist. As a result of our goodwill impairment assessments performed in the years ended December 31, 2021, 2020, and 2019, we determined that the fair value of each reporting unit exceeded its net book value and, therefore, no goodwill impairments were deemed necessary.
We amortize other identifiable intangible assets with a finite life on a straight-line basis over the period which the asset is expected to contribute to our future cash flows, ranging from one year to twenty-eight years. The components of these other intangible assets generally consist of patents, license agreements, non-compete agreements, trademarks, and customer lists and contracts.
Evaluating impairment of long-lived assets
When events or changes in circumstances indicate that long-lived assets other than goodwill may be impaired, an evaluation is performed. For assets classified as held for use, we first group individual assets based on the lowest level for which identifiable cash flows are largely independent of the cash flows from other assets. We then compare estimated future undiscounted cash flows expected to result from the use and eventual disposition of the asset group to its carrying amount. If the asset group's undiscounted cash flows are less than its carrying amount, we then determine the asset group's fair value by using a discounted cash flow analysis and recognize any resulting impairment. When an asset is classified as held for sale, the asset’s book value is evaluated and adjusted to the lower of its carrying amount or fair value less cost to sell. In addition, depreciation and amortization is ceased while it is classified as held for sale. See Note 2 for further information on impairments and other charges.
Income taxes
We recognize the amount of taxes payable or refundable for the year. In addition, deferred tax assets and liabilities are recognized for the expected future tax consequences of events that have been recognized in the financial statements or tax returns. A valuation allowance is provided for deferred tax assets if it is more likely than not that these items will not be realized.
HAL 2021 FORM 10-K | 47
Item 8 | Notes to Consolidated Financial Statements
In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax planning strategies in making this assessment. Based upon the level of historical taxable income and projections for future taxable income over the periods in which the deferred tax assets are deductible, management believes it is more likely than not that we will realize the benefits of these deductible differences, net of the existing valuation allowances.
We recognize interest and penalties related to unrecognized tax benefits within the provision for income taxes on continuing operations in our consolidated statements of operations.
Derivative instruments
At times, we enter into derivative financial transactions to hedge existing or projected exposures to changing foreign currency exchange rates and interest rates. We do not enter into derivative transactions for speculative or trading purposes. We recognize all derivatives on the balance sheet at fair value. Derivatives that are not hedges are adjusted to fair value and reflected through the results of operations. If the derivative is designated as a hedge, depending on the nature of the hedge, changes in the fair value of derivatives are either offset against:
- the change in fair value of the hedged assets, liabilities, or firm commitments through earnings; or
- recognized in other comprehensive income until the hedged item is recognized in earnings.
The ineffective portion of a derivative’s change in fair value is recognized in earnings. Recognized gains or losses on derivatives entered into to manage foreign currency exchange risk are included in “Other, net” on the consolidated statements of operations. Gains or losses on interest rate derivatives are included in “Interest expense, net.”
Foreign currency translation
Foreign entities whose functional currency is the United States dollar translate monetary assets and liabilities at year-end exchange rates, and nonmonetary items are translated at historical rates. Revenue and expense transactions are translated at the average rates in effect during the year, except for those expenses associated with nonmonetary balance sheet accounts, which are translated at historical rates. Gains or losses from remeasurement of monetary assets and liabilities due to changes in exchange rates are recognized in our consolidated statements of operations in “Other, net” in the year of occurrence.
Stock-based compensation
Stock-based compensation cost is measured at the date of grant, based on the calculated fair value of the award and is recognized as expense over the employee’s service period, which is generally the vesting period of the equity grant. Additionally, compensation cost is recognized based on awards ultimately expected to vest, therefore, we have reduced the cost for estimated forfeitures based on historical forfeiture rates. Forfeitures are estimated at the time of grant and revised in subsequent periods to reflect actual forfeitures. See Note 13 for additional information related to stock-based compensation.
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Item 8 | Notes to Consolidated Financial Statements
Note 2. Impairments and Other Charges
The following table presents various pre-tax charges we recorded during the years ended December 31, 2021, 2020, and 2019 which are reflected within "Impairments and other charges" on our consolidated statements of operations.
Year Ended December 31
Millions of dollars 2021 2020 2019
Catch-up depreciation $ 36 $ - $ -
Severance costs 15 384 172
Long-lived asset impairments - 2,629 1,603
Inventory costs and write-downs - 505 458
Joint venture costs - - 154
Gain on real estate transaction (74) - -
Other 35 281 119
Total impairments and other charges $ 12 $ 3,799 $ 2,506
Of the $12 million net charges recorded during the year ended December 31, 2021, a $42 million charge was attributable to our Completion and Production segment, a $9 million charge was attributable to our Drilling and Evaluation segment, and a $39 million net gain was attributable to Corporate and other. During the year ended December 31, 2021, we decided to discontinue the proposed sale of our Pipeline and Process Services business and as a result recorded a $36 million charge for accumulated unrecognized depreciation and amortization expense during the period the associated assets were classified as held for sale. We reclassified this business to assets held and used in the consolidated balance sheet as of September 30, 2021. Beginning October 1, 2021, all depreciation and amortization expense associated with this business was included in operating costs and expenses on our consolidated statements of operations. Additionally, we finalized a structured transaction relating to most of our owned United States real estate. As a result of the transaction, we derecognized $358 million of assets previously held for sale included in Other current assets and recognized an investment in an unconsolidated subsidiary of $349 million included in Other Assets, which resulted in a gain of $74 million, due to specific assets with a carrying amount less than the fair value. We elected to account for our investment under the fair value option using an income approach. We believe the election of the fair value option aligns the accounting treatment with our interest in the real estate held by the unconsolidated subsidiary. As part of the transaction, we completed the sale-leaseback of the same United States real estate, which resulted in an increase of our operating right-of-use assets and operating lease liabilities of $276 million and we received gross cash proceeds of $87 million. Pursuant to a master lease agreement, the properties are subject to initial lease terms of either twelve or fifteen years, we have the option to extend the term on each property for two additional terms of five years each thereafter and the rent payments are subject to an annual rent escalator of 1.35%.
For the year ended December 31, 2020, the $2.6 billion of long-lived asset impairments consisted of the following: $1.0 billion attributable to hydraulic fracturing equipment, the majority of which was located in North America; $297 million related to drilling-related services equipment; $191 million related to right-of-use assets, primarily operating leases; $131 million related to intangible assets; and $394 million associated with other fixed asset impairments. Also included in "Long-lived asset impairments" was $616 million for a fair value adjustment on real estate properties held for sale, primarily related to a contemplated structured transaction for its North America real estate assets due to specific assets with a fair value less than the carrying amount.
For the year ended December 31, 2019, the $1.6 billion of long-lived asset impairments consisted of the following: $759 million attributable to hydraulic fracturing equipment, the majority of which was located in North America; $243 million related to legacy drilling equipment; $215 million related to real estate owned and classified as held for sale; $139 million related to right-of-use assets associated with operating leases; $98 million related to intangible assets; and $148 million of other fixed asset impairments. We also rationalized our portfolio of existing joint ventures and recorded resulting charges within "Joint venture costs" in the table above.
Inventory costs and write-downs in the table above primarily represent disposal of excess inventory, including drilling fluids and other chemicals, and write-downs in which some of our inventory cost exceeded its market value.
HAL 2021 FORM 10-K | 49
Item 8 | Notes to Consolidated Financial Statements
Note 3. Business Segment and Geographic Information
We operate under two divisions, which form the basis for the two operating segments we report: the Completion and Production segment and the Drilling and Evaluation segment. Our equity in earnings and losses of unconsolidated affiliates that are accounted for using the equity method of accounting are included within cost of services and cost of sales on our statements of operations, which is part of operating income of the applicable segment.
Operations by business segment
The following tables present financial information on our business segments.
Year Ended December 31
Millions of dollars 2021 2020 2019
Revenue:
Completion and Production $ 8,410 $ 7,839 $ 14,031
Drilling and Evaluation 6,885 6,606 8,377
Total revenue $ 15,295 $ 14,445 $ 22,408
Operating income:
Completion and Production $ 1,238 $ 995 $ 1,671
Drilling and Evaluation 801 569 642
Total operations 2,039 1,564 2,313
Corporate and other (a) (227) (201) (255)
Impairments and other charges (b) (12) (3,799) (2,506)
Total operating income (loss) $ 1,800 $ (2,436) $ (448)
Interest expense, net of interest income $ (469) $ (505) $ (569)
Loss on early extinguishment of debt - (168) -
Other, net (79) (111) (105)
Income (loss) before income taxes $ 1,252 $ (3,220) $ (1,122)
Capital expenditures:
Completion and Production $ 402 $ 314 $ 800
Drilling and Evaluation 392 410 728
Corporate and other 5 4 2
Total $ 799 $ 728 $ 1,530
Depreciation, depletion, and amortization:
Completion and Production $ 502 $ 615 $ 1,049
Drilling and Evaluation 388 430 552
Corporate and other 14 13 24
Total $ 904 $ 1,058 $ 1,625
(a) Includes certain expenses not attributable to a business segment, such as costs related to support functions and corporate executives, operating lease assets, and also includes amortization expense associated with intangible assets recorded as a result of acquisitions.
(b) Impairments and other charges are as follows:
-For the year ended December 31, 2021, amount includes approximately $42 million attributable to Completion and Production, $9 million attributable to Drilling and Evaluation, and a $39 million net gain attributable to Corporate and other.
-For the year ended December 31, 2020, amount includes approximately $2.4 billion attributable to Completion and Production, $1.4 billion attributable to Drilling and Evaluation, and $62 million attributable to Corporate and other.
-For the year ended December 31, 2019, amount includes approximately $1.6 billion attributable to Completion and Production, $849 million attributable to Drilling and Evaluation, and $56 million attributable to Corporate and other.
HAL 2021 FORM 10-K | 50
Item 8 | Notes to Consolidated Financial Statements
December 31
Millions of dollars 2021 2020
Total assets:
Completion and Production (a) $ 8,186 $ 7,924
Drilling and Evaluation (a) 6,606 6,371
Corporate and other (b) 7,529 6,385
Total $ 22,321 $ 20,680
(a) Assets associated with specific segments primarily include receivables, inventories, property, plant, and equipment, operating lease right-of-use assets, equity in and advances to related companies, and goodwill.
(b) Includes primarily cash and equivalents and deferred tax assets.
Operations by geographic region
The following tables present information by geographic area. In 2021, 2020, and 2019, based on the location of services provided and products sold, 40%, 38%, and 51%, respectively, of our consolidated revenue was from the United States. No other country accounted for more than 10% of our revenue or property, plant, and equipment during the periods presented. As of December 31, 2021 and December 31, 2020, 50% and 49% of our property, plant, and equipment was located in the United States.
Year Ended December 31
Millions of dollars 2021 2020 2019
Revenue:
North America $ 6,371 $ 5,731 $ 11,884
Latin America 2,362 1,668 2,364
Europe/Africa/CIS 2,719 2,813 3,285
Middle East/Asia 3,843 4,233 4,875
Total $ 15,295 $ 14,445 $ 22,408
December 31
Millions of dollars 2021 2020
Net property, plant, and equipment:
North America $ 2,238 $ 2,211
Latin America 510 544
Europe/Africa/CIS 584 602
Middle East/Asia 994 968
Total $ 4,326 $ 4,325
Note 4. Revenue
Revenue is recognized based on the transfer of control or our customers' ability to benefit from our services and products in an amount that reflects the consideration we expect to receive in exchange for those services and products. Most of our service and product contracts are short-term in nature. In recognizing revenue for our services and products, we determine the transaction price of purchase orders or contracts with our customers, which may consist of fixed and variable consideration. We also assess our customers' ability and intention to pay, which is based on a variety of factors, including our historical payment experience with, and the financial condition of our customers. Payment terms and conditions vary by contract type, although terms generally include a requirement of payment within 20 to 60 days. Other judgments involved in recognizing revenue include an assessment of progress towards completion of performance obligations for certain long-term contracts, which involve estimating total costs to determine our progress towards contract completion, and calculating the corresponding amount of revenue to recognize.
Disaggregation of revenue
We disaggregate revenue from contracts with customers into types of services or products, consistent with our two reportable segments, in addition to geographical area. Based on the location of services provided and products sold, 40%, 38%, and 51% of our consolidated revenue was from the United States for the years ended December 31, 2021, 2020, and 2019, respectively. No other country accounted for more than 10% of our revenue.
HAL 2021 FORM 10-K | 51
Item 8 | Notes to Consolidated Financial Statements
The following table presents information on our disaggregated revenue.
Year Ended December 31
Millions of dollars 2021 2020 2019
Revenue by segment:
Completion and Production $ 8,410 $ 7,839 $ 14,031
Drilling and Evaluation 6,885 6,606 8,377
Total revenue $ 15,295 $ 14,445 $ 22,408
Revenue by geographic region:
North America $ 6,371 $ 5,731 $ 11,884
Latin America 2,362 1,668 2,364
Europe/Africa/CIS 2,719 2,813 3,285
Middle East/Asia 3,843 4,233 4,875
Total revenue $ 15,295 $ 14,445 $ 22,408
Contract balances
We perform our obligations under contracts with our customers by transferring services and products in exchange for consideration. The timing of our performance often differs from the timing of our customer’s payment, which results in the recognition of receivables and deferred revenue. Deferred revenue represents advance consideration received from customers for contracts where revenue is recognized on future performance of service. Deferred revenue, as well as revenue recognized during the period relating to amounts included as deferred revenue at the beginning of the period, was not material to our consolidated financial statements.
Transaction price allocated to remaining performance obligations
Remaining performance obligations represent firm contracts for which work has not been performed and future revenue recognition is expected. We have elected the practical expedient permitting the exclusion of disclosing remaining performance obligations for contracts that have an original expected duration of one year or less. We have some long-term contracts related to software and integrated project management services such as lump sum turnkey contracts. For software contracts, revenue is generally recognized over time throughout the license period when the software is considered to be a right to access our intellectual property. For lump sum turnkey projects, we recognize revenue over time using an input method, which requires us to exercise judgment. Revenue allocated to remaining performance obligations for these long-term contracts is not material.
Note 5. Receivables
As of December 31, 2021, 34% of our net trade receivables were from customers in the United States and 11% were from customers in Mexico. As of December 31, 2020, 32% of our net trade receivables were from customers in the United States. Receivables from our primary customer in Mexico accounted for approximately 10% of our total receivables as of December 31, 2021. While we have experienced payment delays in Mexico, these amounts are not in dispute and we have not historically had, and we do not expect, any material write-offs due to collectability from this customer. No other country or single customer accounted for more than 10% of our receivables at those dates.
We routinely monitor the financial stability of our customers and employ an extensive process to evaluate the collectability of outstanding receivables. This process, which involves judgment utilizing significant assumptions, includes analysis of our customers’ historical time to pay, financial condition and various financial metrics, debt structure, credit agency ratings, and production profile, as well as political and economic factors in countries of operations and other customer-specific factors.
HAL 2021 FORM 10-K | 52
Item 8 | Notes to Consolidated Financial Statements
The table below presents a rollforward of our allowance for credit losses for 2019, 2020 and 2021.
Millions of dollars Balance at Beginning of Period Provision (a) Other (b) Balance at End of Period (c)
Year ended December 31, 2019 $ 738 $ 50 $ (12) $ 776
Year ended December 31, 2020 776 58 (10) 824
Year ended December 31, 2021 824 (19) (51) 754
(a) Represents increases to allowance for credit losses charged to costs and expenses, net of recoveries.
(b) Includes write-offs, balance sheet reclassifications, and other activity.
(c) The allowance for credit losses in all years is primarily comprised of a full reserve against accounts receivable with our primary customer in Venezuela.
Note 6. Leases
We adopted a comprehensive new lease accounting standard effective January 1, 2019. The details of the significant changes to our accounting policies resulting from the adoption of the new standard are set out below. We adopted the standard using the optional modified retrospective transition method. The adoption of this standard did not materially impact our consolidated results of operations for the year ended December 31, 2019.
Beginning January 1, 2019, for operating leases, lease expense for lease payments is recognized on a straight-line basis over the lease term and accretion of the lease liability, while finance leases include both an operating expense and an interest expense component. For all leases with a term of 12 months or less, we recognize lease expense for these short-term leases on a straight-line basis over the lease term.
We are a lessee for numerous operating leases, primarily related to real estate, transportation, and equipment. The vast majority of our operating leases have remaining lease terms of 10 years or less, some of which include options to extend the leases, and some of which include options to terminate the leases. We generally do not include renewal or termination options in our assessment of the leases unless extension or termination for certain assets is deemed to be reasonably certain. The accounting for some of our leases may require judgment, which includes determining whether a contract contains a lease, determining the incremental borrowing rates to utilize in our net present value calculation of lease payments for lease agreements which do not provide an implicit rate, and assessing the likelihood of renewal or termination options. We also have some lease agreements with lease and non-lease components, which are generally accounted for as a single lease component. For certain equipment leases, such as offshore vessels and drilling rigs, we account for the lease and non-lease components separately.
The following tables illustrate the financial impact of our leases as of and for the years ended December 31, 2021, 2020, and 2019, along with other supplemental information about our existing leases:
Year Ended December 31
Millions of dollars 2021 2020 2019
Components of lease expense:
Finance lease cost:
Amortization of right-of-use assets $ 20 $ 19 $ 19
Interest on lease liabilities 38 32 51
Operating lease cost 274 296 355
Short-term lease cost 27 31 110
Sublease income (4) (4) (5)
Total lease cost $ 355 $ 374 $ 530
HAL 2021 FORM 10-K | 53
Item 8 | Notes to Consolidated Financial Statements
As of December 31
Millions of dollars 2021 2020
Components of balance sheet:
Operating leases:
Operating lease right-of-use assets (non-current) $ 934 $ 786
Current portion of operating lease liabilities 240 251
Operating lease liabilities (non-current) 845 758
Finance leases:
Other assets (non-current) $ 85 $ 113
Other current liabilities 26 24
Other liabilities (non-current) 85 118
During the year ended December 31, 2021, we completed a sale-leaseback transaction, which resulted in an increase of our operating right-of-use assets and operating lease liabilities of $276 million. During the year ended December 31, 2020, impairment charges were recorded related to operating and finance lease right-of-use assets totaling $191 million. See Note 2 to the consolidated financial statements for further discussion on impairments and other charges and the sale-leaseback transaction.
Year Ended December 31
Millions of dollars except years and percentages 2021 2020 2019
Other supplemental information:
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases $ 307 $ 299 $ 316
Operating cash flows from finance leases 38 32 51
Financing cash flows from finance leases 24 21 24
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $ 433 $ 447 $ 1,362
Finance leases 6 39 74
Weighted-average remaining lease term:
Operating leases 9.8 years 8.6 years 9.5 years
Finance leases 6.3 years 6.4 years 5.4 years
Weighted-average discount rate for operating leases 4.9 % 4.1 % 4.4 %
The following table summarizes the maturity of our operating and finance leases as of December 31, 2021:
Millions of dollars Operating Leases Finance Leases
2022 $ 288 $ 63
2023 198 61
2024 136 47
2025 105 36
2026 91 34
Thereafter 624 15
Total lease payments 1,442 256
Less imputed interest (357) (145)
Total $ 1,085 $ 111
HAL 2021 FORM 10-K | 54
Item 8 | Notes to Consolidated Financial Statements
Note 7. Inventories
Inventories consisted of the following:
December 31
Millions of dollars 2021 2020
Finished products and parts $ 1,380 $ 1,330
Raw materials and supplies 890 952
Work in process 91 67
Total $ 2,361 $ 2,349
All amounts in the table above are reported net of obsolescence reserves of $114 million at December 31, 2021 and $150 million at December 31, 2020.
During the year ended December 31, 2020, we recorded $505 million of impairment charges related to inventory. These charges primarily consisted of the disposal of excess inventory, including drilling fluids and other chemicals, and write-downs in which some of our inventory cost exceeded its market value.
Note 8. Property, Plant, and Equipment
Property, plant, and equipment were composed of the following:
December 31
Millions of dollars 2021 2020
Land $ 120 $ 120
Buildings and property improvements 1,608 1,652
Machinery, equipment, and other 14,040 13,592
Total 15,768 15,364
Less accumulated depreciation 11,442 11,039
Net property, plant, and equipment $ 4,326 $ 4,325
During the year ended December 31, 2020, a $2.3 billion impairment charge was recorded related to property, plant, and equipment. See Note 2 to the consolidated financial statements for further discussion on impairments and other charges.
Classes of assets are depreciated over the following useful lives:
Buildings and Property
Improvements
2021 2020
1 - 10 years 17% 13%
11 - 20 years 39% 41%
21 - 30 years 24% 21%
31 - 40 years 20% 25%
Machinery, Equipment,
and Other
2021 2020
1 - 5 years 49% 49%
6 - 10 years 41% 41%
11 - 20 years 10% 10%
HAL 2021 FORM 10-K | 55
Item 8 | Notes to Consolidated Financial Statements
Note 9. Debt
Our total debt, including short-term borrowings and current maturities of long-term debt, consisted of the following:
December 31
Millions of dollars 2021 2020
5.0% senior notes due November 2045 $ 2,000 $ 2,000
3.8% senior notes due November 2025 1,000 1,000
4.85% senior notes due November 2035 1,000 1,000
7.45% senior notes due September 2039 1,000 1,000
2.92% senior notes due March 2030 1,000 1,000
4.75% senior notes due August 2043 900 900
6.7% senior notes due September 2038 800 800
3.5% senior notes due August 2023 600 600
4.5% senior notes due November 2041 500 500
3.25% senior notes due November 2021 - 500
7.6% senior debentures due August 2096 300 300
8.75% senior debentures due February 2021 - 185
6.75% notes due February 2027 104 104
Other 11 20
Unamortized debt issuance costs and discounts (77) (82)
Total 9,138 9,827
Short-term borrowings and current maturities of long-term debt (11) (695)
Total long-term debt $ 9,127 $ 9,132
$1.0 billion issuance
On March 3, 2020, we issued $1.0 billion aggregate principal amount of 2.92% senior notes due March 2030. Subsequently, on March 5, 2020, we completed a tender offer to purchase $1.5 billion aggregate principal amount of senior notes using proceeds from the debt issuance and cash on hand. In the tender offer, we purchased $500 million aggregate principal amount of our 3.50% senior notes due August 2023 and $1.0 billion aggregate principal amount of our 3.80% senior notes due November 2025. This early debt repurchase resulted in a $168 million loss on extinguishment, which included a tender premium, unamortized discounts and costs on the retired notes, and other tender fees. These costs are included in "Loss on early extinguishment of debt" on our consolidated statements of operations for the year ended December 31, 2020.
Senior debt
The $1.0 billion of senior notes issued in March 2020 rank equally with our existing and future senior unsecured indebtedness, have semiannual interest payments and have no sinking fund requirements. We may redeem all of our senior notes from time to time or all of the notes of each series at any time at the applicable redemption prices, plus accrued and unpaid interest. Our 6.75% notes due February 2027 and 7.6% senior debentures due August 2096 may not be redeemed prior to maturity.
We repaid the $185 million principal balance of our 8.75% senior debentures when they matured in February of 2021. In August of 2021, we redeemed the entire $500 million aggregate principal amount outstanding of our 3.25% senior notes at par. The redemption price for the notes consisted of 100% of the principal amount of the notes outstanding, plus accrued and unpaid interest on the notes. We used cash on hand to fun the redemption of the notes.
3.8% senior notes due November 2025 redemption
In January of 2022, we announced that on February 23, 2022, we will redeem $600 million aggregate principal amount of our 3.8% senior notes that mature in November 2025. The aggregate principal amount currently outstanding is approximately $1.0 billion. The redemption price for the notes will consist of the sum of (1) the greater of (a) 100% of the principal amount of the notes outstanding or (b) the sum of the present values of the remaining scheduled payments of principal and interest on the outstanding notes discounted to the redemption date on a semi-annual basis at the treasury rate plus 25 basis points, as determined by an independent investment banker, and (2) accrued and unpaid interest on the notes, if any, up to, but excluding, the redemption date. We plan to use cash on hand to fund the redemption of the notes.
HAL 2021 FORM 10-K | 56
Item 8 | Notes to Consolidated Financial Statements
Revolving credit facilities
We have a revolving credit facility with a capacity of $3.5 billion, which expires in March 2024. The facility is for working capital or general corporate purposes. The full amount of the revolving credit facility was available as of December 31, 2021.
Debt maturities
Our long-term debt matures as follows: $7 million in 2022, $600 million in 2023, no amounts in 2024, $1.0 billion in 2025, which includes the $600 million debt we will redeem on February 23, 2022 as described above, no amounts in 2026, and the remainder thereafter.
Note 10. Commitments and Contingencies
The Company is subject to various legal or governmental proceedings, claims or investigations, including personal injury, property damage, environmental, intellectual property, commercial, tax-related matters, and other matters arising in the ordinary course of business, the resolution of which, in the opinion of management, will not have a material adverse effect on our consolidated results of operations or consolidated financial position. There is inherent risk in any legal or governmental proceeding, claim or investigation, and no assurance can be given as to the outcome of these proceedings.
Guarantee arrangements
In the normal course of business, we have agreements with financial institutions under which approximately $1.9 billion of letters of credit, bank guarantees, or surety bonds were outstanding as of December 31, 2021. Some of the outstanding letters of credit have triggering events that would entitle a bank to require cash collateralization. None of these off balance sheet arrangements either has, or is likely to have, a material effect on our consolidated financial statements.
Note 11. Income Taxes
The components of the (provision) benefit for income taxes on continuing operations were:
Year Ended December 31
Millions of dollars 2021 2020 2019
Current income taxes:
Federal $ 6 $ 1 $ 32
Foreign (270) (167) (426)
State (6) - (9)
Total current (270) (166) (403)
Deferred income taxes:
Federal 533 372 383
Foreign (47) 2 (36)
State - 70 49
Total deferred 486 444 396
Income tax (provision) benefit $ 216 $ 278 $ (7)
The United States and foreign components of income (loss) from continuing operations before income taxes were as follows:
Year Ended December 31
Millions of dollars 2021 2020 2019
United States $ 283 $ (3,031) $ (1,517)
Foreign 969 (189) 395
Total $ 1,252 $ (3,220) $ (1,122)
HAL 2021 FORM 10-K | 57
Item 8 | Notes to Consolidated Financial Statements
Reconciliations between the actual (provision) benefit for income taxes on continuing operations and that computed by applying the United States statutory rate to income (loss) from continuing operations before income taxes were as follows:
Year Ended December 31
2021 2020 2019
United States statutory rate 21.0 % 21.0 % 21.0 %
Valuation allowance against tax assets (44.5) 0.9 (10.7)
Impact of foreign income taxed at different rates 2.5 (1.1) 0.8
Adjustments of prior year taxes 1.3 0.7 13.0
State income taxes 0.1 - (1.3)
Impact of impairments and other charges - (12.3) (20.9)
Other items, net 2.4 (0.6) (2.5)
Total effective tax rate on continuing operations (17.2) % 8.6 % (0.6) %
During the year ended December 31, 2021, we recorded a total income tax benefit of $216 million on pre-tax income of $1.3 billion, resulting in an effective tax rate of -17.2%. The effective tax rate for 2021 was primarily impacted by our geographic mix of earnings, tax adjustments related to the reassessment of prior year tax accruals, and valuation allowances on some of our deferred tax assets. The decrease in our valuation allowances results from increased future years’ forecasted taxable income before the expiration of foreign tax credits and net operating losses as a direct result of improved energy market conditions that led to the release of approximately $519 million valuation allowance on foreign tax credits.
The primary components of our deferred tax assets and liabilities were as follows:
December 31
Millions of dollars 2021 2020
Gross deferred tax assets:
Foreign tax credit carryforwards $ 1,041 $ 945
Intangible assets 924 -
Net operating loss carryforwards 736 1,691
Accrued liabilities 292 263
Research and development tax credit carryforwards 203 196
Employee compensation and benefits 166 237
Other 457 469
Total gross deferred tax assets 3,819 3,801
Gross deferred tax liabilities:
Operating lease right-of-use assets 160 86
Depreciation and amortization 131 7
Other 9 155
Total gross deferred tax liabilities 300 248
Valuation allowances 885 1,394
Net deferred income tax asset $ 2,634 $ 2,159
At December 31, 2021, we had $795 million of domestic and foreign tax-effected net operating loss carryforwards, with approximately $59 million estimated to be utilized against our unrecognized tax benefits. In addition, we had approximately $1.2 billion of foreign tax credits carryforwards, the majority of which will begin expiring in tax years after 2024. The ultimate realization of these deferred tax assets depends on our ability to generate sufficient taxable income in the appropriate taxing jurisdiction. Our deferred tax assets from net operating losses, foreign tax credits, and research and development credits will expire as follows:
HAL 2021 FORM 10-K | 58
Item 8 | Notes to Consolidated Financial Statements
Millions of dollars U.S. Net Operating Loss Foreign Net Operating Loss Foreign Tax Credits Research and Development Credit Total
2022-2026 $ 2 $ 133 $ 668 $ - $ 803
2027-2031 8 73 510 - 591
2032-2041 52 108 - 203 363
Non-Expiring 9 410 - - 419
$ 71 $ 724 $ 1,178 $ 203 $ 2,176
During the year ended December 31, 2021, our valuation allowance on deferred tax assets decreased by $509 million, primarily attributable to the release of $519 million associated with foreign tax credits as discussed above.
We have not provided incremental United States income taxes or foreign withholding taxes on undistributed foreign subsidiaries' earnings after December 31, 2017. We generally do not provide for taxes related to its undistributed earnings because such earnings either would not be taxable when remitted or they are considered to be indefinitely reinvested.
The following table presents a rollforward of our unrecognized tax benefits and associated interest and penalties.
Millions of dollars Unrecognized Tax Benefits Interest
and Penalties
Balance at January 1, 2019 $ 417 $ 67
Change in prior year tax positions 25 11
Change in current year tax positions 29 -
Cash settlements with taxing authorities (4) -
Lapse of statute of limitations (42) (8)
Balance at December 31, 2019 $ 425 $ 70
Change in prior year tax positions (66) 6
Change in current year tax positions 16 -
Cash settlements with taxing authorities (3) -
Lapse of statute of limitations (17) (5)
Balance at December 31, 2020 $ 355 (a) $ 71
Change in prior year tax positions 14 4
Change in current year tax positions 14 2
Cash settlements with taxing authorities (10) -
Lapse of statute of limitations (21) (5)
Balance at December 31, 2021 $ 352 (a)(b) $ 72
(a) Includes $20 million as of December 31, 2021 and $18 million as of December 31, 2020 in foreign unrecognized tax benefits that would give rise to a United States tax credit. As of December 31, 2021 and December 31, 2020, a net $272 million and $224 million without a net operating loss carryforward offset, respectively, of unrecognized tax benefits would positively impact the effective tax rate and be recognized as additional tax benefits in our statement of operations if resolved in our favor.
(b) Includes $69 million that could be resolved within the next 12 months.
Our tax returns are subject to review by the taxing authorities in the jurisdictions where we file tax returns. In most cases we are no longer subject to examination by tax authorities for years before 2010. The only significant operating jurisdiction that has tax filings under review or subject to examination by the tax authorities is the United States. The United States federal income tax filings for tax years 2016 through 2020 are currently under review or remain open for review by the U.S. Internal Revenue Service.
HAL 2021 FORM 10-K | 59
Item 8 | Notes to Consolidated Financial Statements
Note 12. Shareholders’ Equity
Shares of common stock
The following table summarizes total shares of common stock outstanding:
December 31
Millions of shares 2021 2020
Issued 1,066 1,066
In treasury (170) (181)
Total shares of common stock outstanding 896 885
Our Board of Directors has authorized a program to repurchase a specified dollar amount of our common stock from time to time. The program does not require a specific number of shares to be purchased and the program may be effected through solicited or unsolicited transactions in the market or in privately negotiated transactions. The program may be terminated or suspended at any time. There were no repurchases made under the program during the year ended December 31, 2021. There were 7.4 million repurchases made under the program during the year ended December 31, 2020. Approximately $5.1 billion remained authorized for repurchases as of December 31, 2021. From the inception of this program in February 2006 through December 31, 2021, we repurchased approximately 224 million shares of our common stock for a total cost of approximately $9.0 billion.
Paid-in Capital in Excess of Par Value
During 2021 and 2020, we issued common stock from treasury shares under our employee stock purchase plan awards and for restricted stock grants. As a result, additional paid in capital was reduced below zero, which resulted in a reduction of retained earnings by $277 million and $75 million, respectively. Additional issuances from treasury shares could similarly impact additional paid in capital and retained earnings.
Preferred stock
Our preferred stock consists of five million total authorized shares at December 31, 2021, of which none are issued.
Accumulated other comprehensive loss
Accumulated other comprehensive loss consisted of the following:
December 31
Millions of dollars 2021 2020
Cumulative translation adjustment $ (85) $ (83)
Defined benefit and other postretirement liability adjustments (a) (47) (226)
Other (51) (53)
Total accumulated other comprehensive loss $ (183) $ (362)
(a) Included net actuarial losses for our international pension plans of $49 million at December 31, 2021 and $212 million at December 31, 2020.
HAL 2021 FORM 10-K | 60
Item 8 | Notes to Consolidated Financial Statements
Note 13. Stock-based Compensation
The following table summarizes stock-based compensation costs for the years ended December 31, 2021, 2020, and 2019.
.
Year Ended December 31
Millions of dollars 2021 2020 2019
Stock-based compensation cost $ 214 $ 218 $ 257
Tax benefit (32) (35) (48)
Stock-based compensation cost, net of tax $ 182 $ 183 $ 209
Our Stock and Incentive Plan, as amended (Stock Plan), provides for the grant of any or all of the following types of stock-based awards:
- stock options, including incentive stock options and nonqualified stock options;
- restricted stock awards;
- restricted stock unit awards;
- stock appreciation rights; and
- stock value equivalent awards.
There are currently no stock appreciation rights, stock value equivalent awards, or incentive stock options outstanding. Under the terms of the Stock Plan, approximately 264 million shares of common stock have been reserved for issuance to employees and non-employee directors. At December 31, 2021, approximately 29 million shares were available for future grants under the Stock Plan. The stock to be offered pursuant to the grant of an award under the Stock Plan may be authorized but unissued common shares or treasury shares.
In addition to the provisions of the Stock Plan, we also have stock-based compensation provisions under the Restricted Stock Plan for Non-Employee Directors and the Employee Stock Purchase Plan (ESPP).
Each of the active stock-based compensation arrangements is discussed below.
Stock options
There were no stock options granted during 2021 and there are no plans to grant stock options in 2022. The majority of our options have generally been issued during the second quarter of the year. All stock options under the Stock Plan were granted at the fair market value of our common stock at the grant date. Employee stock options generally vest ratably over a period of three years and expire 10 years from the grant date. Compensation expense for stock options is generally recognized on a straight line basis over the entire vesting period.
The following table represents our stock options activity during 2021.
Number
of Shares
(in millions) Weighted
Average
Exercise
Price
per Share Weighted
Average
Remaining
Contractual Term (years) Aggregate
Intrinsic
Value
(in millions)
Outstanding at January 1, 2021 25.9 $ 40.36
Exercised (0.1) 23.88
Forfeited/expired (1.6) 41.54
Outstanding at December 31, 2021 24.2 $ 40.42 4.6 $ 0.5
Exercisable at December 31, 2021 21.3 $ 42.53 4.2 $ 0.3
The total intrinsic value of options exercised was $315,000 in 2021, $7,000 in 2020, and $2 million in 2019. As of December 31, 2021, there was $5 million of unrecognized compensation cost, net of estimated forfeitures, related to nonvested stock options, which is expected to be recognized over a weighted average period of approximately one year.
Cash received from issuance of common stock was $79 million of which $4 million related to proceeds from exercises of stock options during 2021. Cash received from issuance of common stock was $87 million during 2020 and $118 million during 2019, of which $6 million related to proceeds from exercises of stock options in 2019. The remainder relates to cash proceeds from the issuance of shares related to our employee stock purchase plan.
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Item 8 | Notes to Consolidated Financial Statements
The fair value of options at the date of grant was estimated using the Black-Scholes option pricing model. The expected volatility of options granted was a blended rate based upon implied volatility calculated on actively traded options on our common stock and upon the historical volatility of our common stock. The expected term of options granted was based upon historical observation of actual time elapsed between date of grant and exercise of options for all employees. The assumptions and resulting fair values of options granted were as follows:
Year Ended December 31
2021 2020 2019
Expected term (in years) 0.00 5.39 5.31
Expected volatility - 33% 31%
Expected dividend yield - 2.92 - 3.23% 2.25 - 3.88%
Risk-free interest rate - 1.43 - 1.69% 1.35 - 2.51%
Weighted average grant-date fair value of option - $5.41 $5.91
There were no stock options granted for the year ended December 31, 2021.
Restricted stock
Restricted shares issued under the Stock Plan are restricted as to sale or disposition. These restrictions lapse periodically generally over a period of five years. Restrictions may also lapse for early retirement and other conditions in accordance with our established policies. Upon termination of employment, shares on which restrictions have not lapsed must be returned to us, resulting in restricted stock forfeitures. The fair market value of the stock on the date of grant is amortized and charged to income on a straight-line basis over the requisite service period for the entire award.
In 2021, we also granted performance based restricted stock units, with the actual number of shares earned to be determined at the end of a three year performance period based on our achievement of certain predefined targets. These targets are based upon our average return on capital employed as compared to certain competitors and a modifier based upon stock performance compared to the Oilfield Services Index (OSX). A Monte Carlo simulation that uses a probabilistic approach was performed by an actuary to measure grant date fair value. The fair value of these performance based restricted stock units is recognized on a straight-line basis over the three year performance cycle.
The following table represents our restricted stock awards and restricted stock units granted, vested, and forfeited during 2021.
.
Number of Shares
(in millions) Weighted Average
Grant-Date Fair
Value per Share
Nonvested shares at January 1, 2021 19.0 $ 26.32
Granted 9.6 20.94
Vested (5.4) 30.29
Forfeited (0.5) 28.32
Nonvested shares at December 31, 2021 22.7 $ 23.16
The weighted average grant-date fair value of shares granted was $20.94 during 2021, $16.53 during 2020, and $24.75 during 2019. The total fair value of shares vested was $117 million during 2021, $79 million during 2020, and $107 million during 2019. As of December 31, 2021, there was $330 million of unrecognized compensation cost, net of estimated forfeitures, related to nonvested restricted stock, which is expected to be recognized over a weighted average period of three years.
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Item 8 | Notes to Consolidated Financial Statements
Employee Stock Purchase Plan
Under the ESPP, eligible employees may have up to 10% of their earnings withheld, subject to some limitations, to be used to purchase shares of our common stock. The ESPP contains four three-month offering periods commencing on January 1, April 1, July 1, and October 1 of each year. The price at which common stock may be purchased under the ESPP in 2021 is equal to 90% (90% in 2020 and 85% in 2019) of the lower of the fair market value of the common stock on the commencement date or last trading day of each offering period. Under the ESPP, 104 million shares of common stock have been reserved for issuance, of which 69 million shares have been sold through the ESPP since the inception of the plan through December 31, 2021 and 35 million shares are available for future issuance. The stock to be offered may be authorized but unissued common shares or treasury shares.
The fair value of ESPP shares was estimated using the Black-Scholes option pricing model. The expected volatility was a one-year historical volatility of our common stock. The assumptions and resulting fair values were as follows:
Year Ended December 31
2021 2020 2019
Expected volatility 69 % 68 % 34 %
Expected dividend yield 0.84 % 4.89 % 3.06 %
Risk-free interest rate 0.05 % 0.65 % 2.20 %
Weighted average grant-date fair value per share $ 5.01 $ 3.18 $ 5.22
Note 14. Income per Share
Basic income or loss per share is based on the weighted average number of common shares outstanding during the period. Diluted income per share includes additional common shares that would have been outstanding if potential common shares with a dilutive effect had been issued. Antidilutive securities represent potentially dilutive securities which are excluded from the computation of diluted income or loss per share as their impact was antidilutive.
A reconciliation of the number of shares used for the basic and diluted income per share computations is as follows:
Year Ended December 31
Millions of shares 2021 2020 2019
Basic weighted average common shares outstanding 892 881 875
Dilutive effect of awards granted under our stock incentive plans - - -
Diluted weighted average common shares outstanding 892 881 875
Antidilutive shares:
Options with exercise price greater than the average market price 22 27 24
Options which are antidilutive due to net loss position - 1 1
Total antidilutive shares 22 28 25
Note 15. Financial Instruments and Risk Management
The carrying amount of cash and equivalents, receivables, and accounts payable, as reflected in the consolidated balance sheets, approximates fair value due to the short maturities of these instruments.
The carrying amount and fair value of our total debt, including short-term borrowings and current maturities of long-term debt, is as follows:
December 31, 2021 December 31, 2020
Millions of dollars Level 1 Level 2 Total fair value Carrying value Level 1 Level 2 Total fair value Carrying value
Total debt $ 10,518 $ 527 $ 11,045 $ 9,138 $ 10,856 $ 700 $ 11,556 $ 9,827
The total fair value of our debt decreased during 2021 primarily due to the repayment of senior debentures and notes, the effect of which was partially offset by lower debt yields. The carrying value of our debt decreased as a result of the repayment of senior debentures and notes. See Note 9 for further information.
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Item 8 | Notes to Consolidated Financial Statements
Our debt categorized within level 1 on the fair value hierarchy is calculated using quoted prices in active markets for identical liabilities with transactions occurring on the last two days of period-end. Our debt categorized within level 2 on the fair value hierarchy is calculated using significant observable inputs for similar liabilities where estimated values are determined from observable data points on our other bonds and on other similarly rated corporate debt or from observable data points of transactions occurring prior to two days from period-end and adjusting for changes in market conditions. Differences between the periods presented in our level 1 and level 2 classification of our long-term debt relate to the timing of when transactions are executed. We have no debt categorized within level 3 on the fair value hierarchy based on unobservable inputs.
We are exposed to market risk from changes in foreign currency exchange rates and interest rates. We selectively manage these exposures through the use of derivative instruments, including forward foreign exchange contracts, foreign exchange options and interest rate swaps. The objective of our risk management strategy is to minimize the volatility from fluctuations in foreign currency and interest rates. We do not use derivative instruments for trading purposes. The fair value of our forward contracts, options, and interest rate swaps was not material as of December 31, 2021 or December 31, 2020. The counterparties to our derivatives are primarily global commercial and investment banks.
Foreign currency exchange risk
We have operations in many international locations and are involved in transactions denominated in currencies other than the United States dollar, our functional currency, which exposes us to foreign currency exchange rate risk. Techniques in managing foreign currency exchange risk include, but are not limited to, foreign currency borrowing and investing, and the use of currency exchange instruments. We attempt to selectively manage significant exposures to potential foreign currency exchange losses based on current market conditions, future operating activities, and the associated cost in relation to the perceived risk of loss. The purpose of our foreign currency risk management activities is to minimize the risk that our cash flows from the purchase and sale of products and services in foreign currencies will be adversely affected by changes in exchange rates.
We use forward contracts and options to manage our exposure to fluctuations in the currencies of certain countries in which we do business internationally. These instruments are not treated as hedges for accounting purposes, generally have an expiration date of one year or less, and are not exchange traded. While these instruments are subject to fluctuations in value, the fluctuations are generally offset by the value of the underlying exposures being managed. The use of some of these instruments may limit our ability to benefit from favorable fluctuations in foreign currency exchange rates.
Derivatives are not utilized to manage exposures in some currencies due primarily to the lack of available markets, cost considerations, or immaterial exposures (non-hedged currencies). We attempt to minimize foreign currency exposure in non-hedged currencies and recognize that pricing for the services and products offered in these countries should account for the cost of exchange rate devaluations. We have historically incurred transaction losses in non-hedged currencies.
The notional amounts of open foreign exchange derivatives were $637 million at December 31, 2021 and $817 million at December 31, 2020. The notional amounts of these instruments do not generally represent amounts exchanged by the parties, and thus are not a measure of our exposure or of the cash requirements related to these contracts. The fair value of our foreign exchange derivatives as of December 31, 2021 and December 31, 2020 is included in “Other current assets” in our consolidated balance sheets and was immaterial. The fair value of these instruments is categorized within level 2 on the fair value hierarchy and was determined using a market approach with certain inputs, such as notional amounts hedged, exchange rates, and other terms of the contracts that are observable in the market or can be derived from or corroborated by observable data.
Interest rate risk
We are subject to interest rate risk on our existing long-term debt. Our short-term borrowings do not give rise to significant interest rate risk due to their short-term nature. We had fixed rate long-term debt totaling $9.1 billion at December 31, 2021 and $9.8 billion at December 31, 2020. We maintain an interest rate management strategy that is intended to mitigate the exposure to changes in interest rates in the aggregate for our debt portfolio.
Credit risk
Financial instruments that potentially subject us to concentrations of credit risk are primarily cash equivalents and trade receivables. It is our practice to place our cash equivalents in high quality investments with various institutions. Our trade receivables are from a broad and diverse group of customers and are generally not collateralized. As of December 31, 2021, 34% of net trade receivables were from customers in the United States and 11% were from customers in Mexico. As of December 31, 2020, 32% of net trade receivables were from customers in the United States. We maintain an allowance for credit losses based upon several factors, including historical collection experience, current aging status of the customer accounts and financial condition of our customers. See Note 5 for further information.
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Item 8 | Notes to Consolidated Financial Statements
We do not have any significant concentrations of credit risk with any individual counterparty to our derivative contracts. We select counterparties to those contracts based on our belief that each counterparty’s profitability, balance sheet, and capacity for timely payment of financial commitments is unlikely to be materially adversely affected by foreseeable events.
Note 16. Retirement Plans
Our company and subsidiaries have various plans that cover a significant number of our employees. These plans include defined contribution plans, defined benefit plans, and other postretirement plans:
- our defined contribution plans provide retirement benefits in return for services rendered. These plans provide an individual account for each participant and have terms that specify how contributions to the participant’s account are to be determined rather than the amount of pension benefits the participant is to receive. Contributions to these plans are based on a percentage of pre-tax income, after-tax income, or discretionary amounts determined on an annual basis. Our expense for the defined contribution plans totaled $136 million in 2021, $100 million in 2020, and $206 million in 2019. The increase in expense from 2020 to 2021 was due to a headcount increase and the payment of a discretionary contribution for the year ended December 31, 2021.
- our defined benefit plans, which include both overfunded and underfunded pension plans, define an amount of pension benefit to be provided, usually as a function of age, years of service and/or compensation. The underfunded obligations and net periodic benefit cost of our United States defined benefit plans were not material for the periods presented; and
- our postretirement plans other than pensions are offered to specific eligible employees. The accumulated benefit obligations and net periodic benefit cost for these plans were not material for the periods presented.
Funded status
For our international pension plans, at December 31, 2021, the projected benefit obligation was $1.1 billion and the fair value of plan assets was $1.2 billion, which resulted in an overfunded obligation of $80 million. At December 31, 2020, the projected benefit obligation was $1.2 billion and the fair value of plan assets was $1.1 billion, which resulted in an underfunded obligation of $152 million. The accumulated benefit obligation for our international plans was $1.0 billion at December 31, 2021 and $1.1 billion at December 31, 2020.
The following table presents additional information about our international pension plans.
December 31
Millions of dollars 2021 2020
Amounts recognized on the Consolidated Balance Sheets
Other Assets $ 265 $ 45
Accrued employee compensation and benefits 7 8
Employee compensation and benefits 178 189
Pension plans in which projected benefit obligation exceeded plan assets
Projected benefit obligation $ 199 $ 228
Fair value of plan assets 14 31
Pension plans in which accumulated benefit obligation exceeded plan assets
Accumulated benefit obligation $ 114 $ 126
Fair value of plan assets 9 25
Fair value measurements of plan assets
The fair value of our plan assets categorized within level 1 on the fair value hierarchy is based on quoted prices in active markets for identical assets. The fair value of our plan assets categorized within level 2 on the fair value hierarchy is based on significant observable inputs for similar assets. The fair value of our plan assets categorized within level 3 on the fair value hierarchy is based on significant unobservable inputs.
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Item 8 | Notes to Consolidated Financial Statements
The following table sets forth the fair values of assets held by our international pension plans by level within the fair value hierarchy.
Millions of dollars Level 1 Level 2 Level 3 Net Asset Value (a) Total
Cash and equivalents $ - $ 251 $ - $ - $ 251
Equity funds (b) - 120 - - 120
Bond funds (c) - 405 - 143 548
Alternatives funds (d) - - - 176 176
Real estate funds (e) - 23 - 23 46
Other investments (f) 3 21 3 - 27
Fair value of plan assets at December 31, 2021 $ 3 $ 820 $ 3 $ 342 $ 1,168
Cash and equivalents $ - $ 136 $ - $ - $ 136
Equity funds (b) - 170 - - 170
Bond funds (c) - 319 - 149 468
Alternatives funds (d) - 4 - 163 167
Real estate funds (e) - 68 - 28 96
Other investments (f) 5 21 14 - 40
Fair value of plan assets at December 31, 2020 $ 5 $ 718 $ 14 $ 340 $ 1,077
(a) Represents investments measured at fair value using the Net Asset Value (NAV) per share practical expedient and thus has not been categorized in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the total value of our international pension plans assets.
(b) Strategy of equity funds is to invest in diversified funds of global common stocks.
(c) Strategy of bond funds is to invest in diversified funds of fixed income securities of varying geographies and credit quality.
(d) Strategy of alternative funds is to invest in a fund of diversifying investments, including but not limited to reinsurance, commodities, and currencies.
(e) Strategy of real estate funds is to invest in diversified funds of real estate investment trusts and private real estate.
(f) Other investments primarily include investments in insurance contracts, balanced funds, and government bonds.
Risk management practices for these plans include diversification by issuer, industry, and geography, as well as the use of multiple asset classes and investment managers within each asset class. Our investment strategy for our United Kingdom pension plan, which constituted 81% of our international pension plans’ projected benefit obligation at December 31, 2021 and is no longer accruing service benefits, aims to achieve full funding of the benefit obligation, with the plan's assets increasingly composed of investments whose cash flows match the projected liabilities of the plan.
Net periodic benefit cost
Net periodic benefit cost for our international pension plans was $25 million in 2021, $30 million in 2020, and $23 million in 2019.
Actuarial assumptions
Certain weighted-average actuarial assumptions used to determine benefit obligations of our international pension plans at December 31 were as follows:
2021 2020
Discount rate 2.3% 1.8%
Rate of compensation increase 5.3% 5.9%
Certain weighted-average actuarial assumptions used to determine net periodic benefit cost of our international pension plans for the years ended December 31 were as follows:
2021 2020 2019
Discount rate 1.8% 2.5% 3.3%
Expected long-term return on plan assets 2.7% 3.5% 4.4%
Rate of compensation increase 5.9% 6.0% 5.8%
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Item 8 | Notes to Consolidated Financial Statements
Assumed long-term rates of return on plan assets, discount rates for estimating benefit obligations, and rates of compensation increases vary by plan according to local economic conditions. Where possible, discount rates were determined based on the prevailing market rates of a portfolio of high-quality debt instruments with maturities matching the expected timing of the payment of the benefit obligations. Expected long-term rates of return on plan assets were determined based upon an evaluation of our plan assets and historical trends and experience, taking into account current and expected market conditions.
Other information
Contributions. Funding requirements for each plan are determined based on the local laws of the country where such plan resides. In certain countries the funding requirements are mandatory, while in other countries they are discretionary. We currently expect to contribute $18 million to our international pension plans in 2022.
Benefit payments. Expected benefit payments over the next 10 years for our international pension plans are as follows: $43 million in 2022, $41 million in 2023, $42 million in 2024, $44 million in 2025, $46 million in 2026, and an aggregate $256 million in years 2027 through 2031.
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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
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.
None.
Item 9(a). Controls and Procedures.
In accordance with the Securities Exchange Act of 1934 Rules 13a-15 and 15d-15, we carried out an evaluation, under the supervision and with the participation of management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of December 31, 2021 to provide reasonable assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Our disclosure controls and procedures include controls and procedures designed to ensure that information required to be disclosed in reports filed or submitted under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.
There has been no change in our internal control over financial reporting that occurred during the three months ended December 31, 2021 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
See page 37 for Management’s Report on Internal Control Over Financial Reporting and page 38 for Report of Independent Registered Public Accounting Firm on its assessment of our internal control over financial reporting.
Item 9(b). Other Information.
None.
Item 9(c). Disclosure Regarding Foreign Jurisdictions that Prevent Inspections
Not applicable.
HAL 2021 FORM 10-K | 68

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ITEM 9A. CONTROLS AND PROCEDURES

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ITEM 9B. OTHER INFORMATION

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10 | Directors, Executive Officers and Corporate Governance
PART III
Item 10. Directors, Executive Officers, and Corporate Governance.
The information required for the directors of the Registrant is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the captions “Election of Directors” and “Involvement in Certain Legal Proceedings.” The information required for the executive officers of the Registrant is included under Part I on page 8 of this annual report. The information required for a delinquent form required under Section 16(a) of the Securities Exchange Act of 1934 is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “Delinquent Section 16(a) Reports,” to the extent any disclosure is required. The information for our code of ethics is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “Corporate Governance.” The information regarding our Audit Committee and the independence of its members, along with information about the audit committee financial expert(s) serving on the Audit Committee, is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “The Board of Directors and Standing Committees of Directors.”

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation.
This information is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the captions “Compensation Discussion and Analysis,” “Compensation Committee Report,” “Summary Compensation Table,” “Grants of Plan-Based Awards in Fiscal 2021,” “Outstanding Equity Awards at Fiscal Year End 2021,” “2021 Option Exercises and Stock Vested,” “2021 Nonqualified Deferred Compensation,” “Employment Contracts and Change-in-Control Arrangements,” “Post-Termination or Change-in-Control Payments,” “Equity Compensation Plan Information,” and “Directors’ Compensation.”

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12(a). Security Ownership of Certain Beneficial Owners.
This information is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “Stock Ownership of Certain Beneficial Owners and Management.”
Item 12(b). Security Ownership of Management.
This information is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “Stock Ownership of Certain Beneficial Owners and Management.”
Item 12(c). Changes in Control.
Not applicable.
Item 12(d). Securities Authorized for Issuance Under Equity Compensation Plans.
This information is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “Equity Compensation Plan Information.”

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions, and Director Independence.
This information is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “Corporate Governance” to the extent any disclosure is required, and under the caption “The Board of Directors and Standing Committees of Directors.”

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accounting Fees and Services.
This information is incorporated by reference to the Halliburton Company Proxy Statement for our 2022 Annual Meeting of Shareholders (File No. 001-03492) under the caption “Fees Paid to KPMG LLP.” Our independent registered public accounting firm is KPMG LLP, Houston, TX PCAOB ID:185.
HAL 2021 FORM 10-K | 69

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15 | Exhibits
PART IV
Item 15. Exhibits.
1. Financial Statements:
The reports of the Independent Registered Public Accounting Firm and the financial statements of Halliburton Company are included within Part II, Item 8 of this Annual Report on Form 10-K.
2. Financial Statement Schedules:
The schedules listed in Rule 5-04 of Regulation S-X (17 CFR 210.5-04) have been omitted because they are not applicable or the required information is shown in the consolidated financial statements or notes thereto.
3. Exhibits:
Exhibit
Number Exhibits
3.1 Restated Certificate of Incorporation of Halliburton Company filed with the Secretary of State of Delaware on May 30, 2006 (incorporated by reference to Exhibit 3.1 to Halliburton’s Form 8-K filed June 5, 2006, File No. 001-03492).
3.2 By-laws of Halliburton Company revised effective December 7, 2017 (incorporated by reference to Exhibit 3.1 to Halliburton’s Form 8-K filed December 12, 2017, File No. 001-03492).
4.1 Form of debt security of 8.75% Debentures due February 12, 2021 (incorporated by reference to Exhibit 4(a) to the Form 8-K of Halliburton Company, now known as Halliburton Energy Services, Inc. (the Predecessor), dated as of February 20, 1991, File No. 001-03492).
4.2 Senior Indenture dated as of January 2, 1991 between the Predecessor and The Bank of New York Trust Company, N.A. (as successor to Texas Commerce Bank National Association), as Trustee (incorporated by reference to Exhibit 4(b) to the Predecessor’s Registration Statement on Form S-3 (Registration No. 33-38394) originally filed with the Securities and Exchange Commission on December 21, 1990), as supplemented and amended by the First Supplemental Indenture dated as of December 12, 1996 among the Predecessor, Halliburton and the Trustee (incorporated by reference to Exhibit 4.1 of Halliburton’s Registration Statement on Form 8-B dated December 12, 1996, File No. 001-03492).
4.3 Resolutions of the Predecessor’s Board of Directors adopted at a meeting held on February 11, 1991 and of the special pricing committee of the Board of Directors of the Predecessor adopted at a meeting held on February 11, 1991 and the special pricing committee’s consent in lieu of meeting dated February 12, 1991 (incorporated by reference to Exhibit 4(c) to the Predecessor’s Form 8-K dated as of February 20, 1991, File No. 001-03492).
4.4 Second Senior Indenture dated as of December 1, 1996 between the Predecessor and The Bank of New York Trust Company, N.A. (as successor to Texas Commerce Bank National Association), as Trustee, as supplemented and amended by the First Supplemental Indenture dated as of December 5, 1996 between the Predecessor and the Trustee and the Second Supplemental Indenture dated as of December 12, 1996 among the Predecessor, Halliburton and the Trustee (incorporated by reference to Exhibit 4.2 of Halliburton’s Registration Statement on Form 8-B dated December 12, 1996, File No. 001-03492).
4.5 Third Supplemental Indenture dated as of August 1, 1997 between Halliburton and The Bank of New York Trust Company, N.A. (as successor to Texas Commerce Bank National Association), as Trustee, to the Second Senior Indenture dated as of December 1, 1996 (incorporated by reference to Exhibit 4.7 to Halliburton’s Form 10-K for the year ended December 31, 1998, File No. 001-03492).
4.6 Fourth Supplemental Indenture dated as of September 29, 1998 between Halliburton and The Bank of New York Trust Company, N.A. (as successor to Texas Commerce Bank National Association), as Trustee, to the Second Senior Indenture dated as of December 1, 1996 (incorporated by reference to Exhibit 4.8 to Halliburton’s Form 10-K for the year ended December 31, 1998, File No. 001-03492).
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Item 15 | Exhibits
4.7 Resolutions of Halliburton’s Board of Directors adopted by unanimous consent dated December 5, 1996 (incorporated by reference to Exhibit 4(g) of Halliburton’s Form 10-K for the year ended December 31, 1996, File No. 001-03492).
4.8 Form of debt security of 6.75% Notes due February 1, 2027 (incorporated by reference to Exhibit 4.1 to Halliburton’s Form 8-K dated as of February 11, 1997, File No. 001-03492).
4.9 Copies of instruments that define the rights of holders of miscellaneous long-term notes of Halliburton Company and its subsidiaries have not been filed with the Commission. Halliburton Company agrees to furnish copies of these instruments upon request.
4.10 Form of Indenture dated as of April 18, 1996 between Dresser and The Bank of New York Trust Company, N.A. (as successor to Texas Commerce Bank National Association), as Trustee (incorporated by reference to Exhibit 4 to Dresser’s Registration Statement on Form S-3/A filed on April 19, 1996, Registration No. 333-01303), as supplemented and amended by Form of First Supplemental Indenture dated as of August 6, 1996 between Dresser and The Bank of New York Trust Company, N.A. (as successor to Texas Commerce Bank National Association), Trustee, for 7.60% Debentures due 2096 (incorporated by reference to Exhibit 4.1 to Dresser’s Form 8-K filed on August 9, 1996, File No. 1-4003).
4.11 Second Supplemental Indenture dated as of October 27, 2003 between DII Industries, LLC and The Bank of New York Trust Company, N.A. (as successor to JPMorgan Chase Bank), as Trustee, to the Indenture dated as of April 18, 1996 (incorporated by reference to Exhibit 4.15 to Halliburton’s Form 10-K for the year ended December 31, 2003, File No. 001-03492).
4.12 Third Supplemental Indenture dated as of December 12, 2003 among DII Industries, LLC, Halliburton Company and The Bank of New York Trust Company, N.A. (as successor to JPMorgan Chase Bank), as Trustee, to the Indenture dated as of April 18, 1996, (incorporated by reference to Exhibit 4.16 to Halliburton’s Form 10-K for the year ended December 31, 2003, File No. 001-03492).
4.13 Indenture dated as of October 17, 2003 between Halliburton Company and The Bank of New York Trust Company, N.A. (as successor to JPMorgan Chase Bank), as Trustee (incorporated by reference to Exhibit 4.1 to Halliburton’s Form 10-Q for the quarter ended September 30, 2003, File No. 001-03492).
4.14 Second Supplemental Indenture dated as of December 15, 2003 between Halliburton Company and The Bank of New York Trust Company, N.A. (as successor to JPMorgan Chase Bank), as Trustee, to the Senior Indenture dated as of October 17, 2003 (incorporated by reference to Exhibit 4.27 to Halliburton’s Form 10-K for the year ended December 31, 2003, File No. 001-03492).
4.15 Form of note of 7.6% debentures due 2096 (included as Exhibit A to Exhibit 4.14 above).
4.16 Fourth Supplemental Indenture, dated as of September 12, 2008, between Halliburton Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee to JPMorgan Chase Bank, to the Senior Indenture dated as of October 17, 2003 (incorporated by reference to Exhibit 4.2 to Halliburton’s Form 8-K filed September 12, 2008, File No. 001-03492).
4.17 Form of Global Note for Halliburton’s 6.70% Senior Notes due 2038 (included as part of Exhibit 4.16).
4.18 Fifth Supplemental Indenture, dated as of March 13, 2009, between Halliburton Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee to JPMorgan Chase Bank, to the Senior Indenture dated as of October 17, 2003 (incorporated by reference to Exhibit 4.2 to Halliburton’s Form 8-K filed March 13, 2009, File No. 001-03492).
4.19 Form of Global Note for Halliburton’s 7.45% Senior Notes due 2039 (included as part of Exhibit 4.18).
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4.20 Sixth Supplemental Indenture, dated as of November 14, 2011, between Halliburton Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee to JPMorgan Chase Bank, to the Senior Indenture dated as of October 17, 2003 (incorporated by reference to Exhibit 4.2 to Halliburton’s Form 8-K filed November 14, 2011, File No. 001-03492).
4.21 Form of Global Note for Halliburton’s 3.25% Senior Notes due 2021 (included as part of Exhibit 4.20).
4.22 Form of Global Note for Halliburton’s 4.50% Senior Notes due 2041 (included as part of Exhibit 4.20).
4.23 Seventh Supplemental Indenture, dated as of August 5, 2013, between Halliburton Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee to JPMorgan Chase Bank (incorporated by reference to Exhibit 4.2 of Halliburton’s Form 8-K filed August 5, 2013, File No. 001-03492).
4.24 Form of Global Note for Halliburton’s 3.50% Senior Notes due 2023 (included as part of Exhibit 4.23).
4.25 Form of Global Note for Halliburton’s 4.75% Senior Notes due 2043 (included as part of Exhibit 4.23).
4.26 Eighth Supplemental Indenture, dated as of November 13, 2015, between Halliburton Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee to JPMorgan Chase Bank (incorporated by reference to Exhibit 4.2 to Halliburton’s Form 8-K filed November 13, 2015, File No. 001-03492).
4.27 Form of Global Note for Halliburton’s 3.800% Senior Notes due 2025 (included as part of Exhibit 4.26).
4.28 Form of Global Note for Halliburton’s 4.850% Senior Notes due 2035 (included as part of Exhibit 4.26).
4.29 Form of Global Note for Halliburton’s 5.000% Senior Notes due 2045 (included as part of Exhibit 4.26).
4.30 Description of Registrant's Securities (incorporated by reference to Exhibit 4.30 to Halliburton's Form 10-K for the year ended December 31, 2020, File No. 001-03492).
4.31 Ninth Supplemental Indenture, dated as of March 3, 2020, between the Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee to JPMorgan Chase Bank (incorporated by reference to Exhibit 4.2 to Halliburton’s Form 8-K filed March 3, 2020, File No. 001-03492).
4.32 Form of Global Note for the Company’s 2.920% Senior Notes due 2030 (included as part of Exhibit 4.31).
† 10.1 Halliburton Company Restricted Stock Plan for Non-Employee Directors (incorporated by reference to Appendix B of the Predecessor’s proxy statement dated March 23, 1993, File No. 001-03492).
† 10.2 Dresser Industries, Inc. Deferred Compensation Plan, as amended and restated effective January 1, 2000 (incorporated by reference to Exhibit 10.16 to Halliburton’s Form 10-K for the year ended December 31, 2000, File No. 001-03492).
† 10.3 ERISA Excess Benefit Plan for Dresser Industries, Inc., as amended and restated effective June 1, 1995 (incorporated by reference to Exhibit 10.7 to Dresser’s Form 10-K for the year ended October 31, 1995, File No. 1-4003).
10.4 Form of Indemnification Agreement for Officers (incorporated by reference to Exhibit 10.1 to Halliburton’s Form 8-K filed August 3, 2007, File No. 001-03492).
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10.5 Form of Indemnification Agreement for Directors (incorporated by reference to Exhibit 10.2 to Halliburton’s Form 8-K filed August 3, 2007, File No. 001-03492).
10.6 Form of Indemnification Agreement for Officers (first elected after January 1, 2013) (incorporated by reference to Exhibit 10.2 to Halliburton's Form 10-Q for the quarter ended March 31, 2013, File No. 001-03492).
10.7 Form of Indemnification Agreement for Directors (first elected after January 1, 2013) (incorporated by reference to Exhibit 10.1 of Halliburton’s Form 8-K filed March 22, 2013, File No. 001-03492).
† 10.8 Halliburton Company Pension Equalizer Plan, as amended and restated effective March 1, 2007 (incorporated by reference to Exhibit 10.8 to Halliburton’s Form 10-Q for the quarter ended September 30, 2007, File No. 001-03492).
† 10.9 Halliburton Company Directors' Deferred Compensation Plan, as amended and restated effective May 16, 2012 (incorporated by reference to Exhibit 10.5 to Halliburton's Form 10-Q for the quarter ended June 30, 2012, File No. 001-03492).
† 10.10 Halliburton Company Employee Stock Purchase Plan, as amended and restated effective February 17, 2021 (incorporated by reference to Appendix B of Halliburton’s proxy statement filed April 6, 2021, File No. 001-03492).
† 10.11 First Amendment to Restricted Stock Plan for Non-Employee Directors of Halliburton Company, effective December 7, 2011 (incorporated by reference to Exhibit 10.41 to Halliburton’s Form 10-K for the year ended December 31, 2011, File No. 001-03492).
† 10.12 Second Amendment to Restricted Stock Plan for Non-Employee Directors of Halliburton Company, effective May 16, 2012 (incorporated by reference to Exhibit 10.4 to Halliburton's Form 10-Q for the quarter ended June 30, 2012, File No. 001-03492).
† 10.13 Third Amendment to Restricted Stock Plan for Non-Employee Directors of Halliburton Company, effective December 1, 2012 (incorporated by reference to Exhibit 10.44 to Halliburton’s Form 10-K for the year ended December 31, 2012, File No. 001-03492).
† 10.14 First Amendment dated December 1, 2012 to Halliburton Company Directors' Deferred Compensation Plan, as amended and restated effective May 16, 2012 (incorporated by reference to Exhibit 10.45 to Halliburton’s Form 10-K for the year ended December 31, 2012, File No. 001-03492).
† 10.15 Executive Agreement (Myrtle L. Jones) (incorporated by reference to Exhibit 10.1 to Halliburton's Form 10-Q for the quarter ended March 31, 2013, File No. 001-03492).
† 10.16 Executive Agreement (Timothy McKeon) (incorporated by reference to Exhibit 10.49 to Halliburton’s Form 10-K for the year ended December 31, 2013, File No. 001-03492).
† 10.17 Executive Agreement (Charles E. Geer, Jr.) (incorporated by reference to Exhibit 10.2 to Halliburton’s Form 8-K filed December 9, 2014, File No. 001-03492).
† 10.18 Halliburton Annual Performance Pay Plan, as amended and restated effective January 1, 2019) (incorporated by reference to Exhibit 10.7 to Halliburton's Form 10-Q for the quarter ended June 30, 2019, File No. 001-03492).
† 10.19 Form of Non-Employee Director Restricted Stock Agreement (Directors Plan) (incorporated by reference as Exhibit 99.5 of Halliburton's Form S-8 filed May 21, 2009, Registration No. 333-159394).
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† 10.20 Form of Non-Employee Director Restricted Stock Agreement (Stock and Incentive Plan) (incorporated by reference to Exhibit 10.43 to Halliburton's Form 10-K for the year ended December 31, 2011, File No. 001-03492).
† 10.21 Executive Agreement (Joe D. Rainey) (incorporated by reference to Exhibit 10.1 to Halliburton's Form 8-K filed December 12, 2017, File No. 001-03492).
† 10.22 Executive Agreement (Jeffrey A. Miller) (incorporated by reference to Exhibit 10.1 to Halliburton's Form 8-K filed June 5, 2017, File No. 001-03492).
† 10.23 Halliburton Company Stock and Incentive Plan, as amended and restated effective February 17, 2021 (incorporated by reference to Appendix A of Halliburton's proxy statement filed April 6, 2021, File No. 001-03492.
† 10.24 Form of Nonstatutory Stock Option Agreement (U.S.) (incorporated by reference as Exhibit 99.2 of Halliburton's Form S-8 filed May 17, 2019, Registration No. 333-231571).
† 10.25 Form of Nonstatutory Stock Option Agreement (International) (incorporated by reference as Exhibit 99.3 of Halliburton's Form S-8 filed May 17, 2019, Registration No. 333-231571).
† 10.26 Form of Restricted Stock Agreement (incorporated by reference as Exhibit 99.3 of Halliburton's Form S-8 filed July 23, 2021, Registration No. 333-258123).
† 10.27 Form of Restricted Stock Unit Agreement (International) (incorporated by reference as Exhibit 99.4 of Halliburton's Form S-8 filed July 23, 2021, Registration No. 333-258123).
† 10.28 Form of Restricted Stock Unit Agreement (U.S. Expat) (incorporated by reference as Exhibit 99.5 of Halliburton's Form S-8 filed July 23, 2021, Registration No. 333-258123).
† 10.29 Executive Agreement (Eric J. Carre) (incorporated by reference as Exhibit 10.46 of Halliburton's Form 10-K for the year ended December 31, 2017, File No. 001-03492).
† 10.30 Executive Agreement (Lawrence J. Pope) (incorporated by reference as Exhibit 10.47 of Halliburton's Form 10-K for the year ended December 31, 2017, File No. 001-03492).
† 10.31 Executive Agreement (Lance Loeffler) (incorporated by reference as Exhibit 10.1 of Halliburton’s Form 8-K filed December 11, 2018, File No. 001-03492).
† 10.32 Second Amendment dated January 1, 2019, to Halliburton Company Directors’ Deferred Compensation Plan, as amended and restated effective May 16, 2012 (incorporated by reference as Exhibit 10.47 of Halliburton's Form 10-K for the year ended December 31, 2018, File No. 001-03492).
† 10.33 Executive Agreement (Mark J. Richard) (incorporated by reference as Exhibit 10.48 of Halliburton’s Form 10-K for the year ended December 31, 2018, File No. 001-03492).
† 10.34 Halliburton Company Performance Unit Program, as amended and restated effective January 1, 2019 (incorporated by reference as Exhibit 10.8 of Halliburton's Form 10-Q for the quarter ended June 30, 2019, File No. 001-03492).
10.35 U.S. $3,500,000,000 Five Year Revolving Credit Agreement among Halliburton, as Borrower, the Banks party thereto, and Citibank, N.A., as Agent (incorporated by reference to Exhibit 10.1 to Halliburton’s Form 8-K filed March 7, 2019, File No. 001-03492).
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† 10.36 Halliburton Company Supplemental Executive Retirement Plan, as amended and restated effective December 5, 2019 (incorporated by reference as Exhibit 10.41 of Halliburton's Form 10-K for the year ended December 31, 2019, File No. 001-03492).
† 10.37 Halliburton Company Benefit Restoration Plan, as amended and restated effective December 5, 2019 (incorporated by reference as Exhibit 10.42 of Halliburton's Form 10-K for the year ended December 31, 2019, File No. 001-03492).
† 10.38 Halliburton Elective Deferral Plan, as amended and restated effective December 5, 2019 (incorporated by reference as Exhibit 10.43 of Halliburton's Form 10-K for the year ended December 31, 2019, File No. 001-03492).
† 10.39 Executive Agreement (Van H. Beckwith) (incorporated by reference as Exhibit 10.42 of Halliburton’s Form 10-K for the year ended December 31, 2020, File No. 001-03492).
*† 10.40 Executive Agreement (Jill D. Sharp).
*† 10.41 Form of Non-Management Director Restricted Stock Unit Agreement (Stock and Incentive Plan).
* 21.1 Subsidiaries of the Registrant.
* 23.1 Consent of KPMG LLP.
* 24.1 Powers of attorney for the following directors signed in January 2022:
Abdulaziz F. Al Khayyal
William E. Albrecht
M. Katherine Banks
Alan M. Bennett
Milton Carroll
Murry S. Gerber
Patricia Hemingway Hall
Robert A. Malone
Bhavesh V. Patel
* 31.1 Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
* 31.2 Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
** 32.1 Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
** 32.2 Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
* 95 Mine Safety Disclosures.
* 101.INS XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
* 101.SCH XBRL Taxonomy Extension Schema Document
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* 101.CAL XBRL Taxonomy Extension Calculation Linkbase Document
* 101.LAB XBRL Taxonomy Extension Label Linkbase Document
* 101.PRE XBRL Taxonomy Extension Presentation Linkbase Document
* 101.DEF XBRL Taxonomy Extension Definition Linkbase Document
* 104 Cover Page Interactive Data File - the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
* Filed with this Form 10-K.
** Furnished with this Form 10-K.
† Management contracts or compensatory plans or arrangements.