EDGAR 10-K Filing

Company CIK: 1000229
Filing Year: 2021
Filename: 1000229_10-K_2021_0001564590-21-004561.json

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ITEM 1. BUSINESS
ITEM 1. BUSINESS
General
Core Laboratories N.V. is a Netherlands limited liability company. We were established in 1936 and are one of the world's leading providers of proprietary and patented reservoir description and production enhancement services and products to the oil and gas industry. These services and products can enable our clients to improve reservoir performance and increase oil and gas recovery from their producing fields. We have over 70 offices in more than 50 countries and have approximately 3,700 employees.
References to "Core Lab", "the Company", "we", "our", and similar phrases are used throughout this Annual Report on Form 10-K (this "Form 10-K") and relate collectively to Core Laboratories N.V. and its consolidated affiliates.
In a continuing effort to streamline our business and align our business strategy for further integration of services and products, the Company committed to divest the business of our full range of permanent downhole monitoring systems and related services, which had been part of our Production Enhancement segment. We completed the divestment of this business in 2019 and concluded the final adjustment to the purchase agreement in 2020; the disclosure relating to the divestment of this business is included in Note 20 - Discontinued Operations of the Notes to the Consolidated Financial Statements in Part IV of this Form 10-K (“Notes to the Consolidated Financial Statements”). All prior period income statements have been adjusted to reclassify amounts related to this business to discontinued operations to conform to current period presentation. All disclosures on operating income and net income within these statements reflect the results from continuing operations for all periods presented. These reclassifications had no impact on the reported net income attributable to Core Laboratories N.V., financial position or cash flows for any of these prior periods.
Business Strategy
Our business strategy is to provide advanced technologies that improve reservoir performance by (i) continuing the development of proprietary technologies through client-driven research and development, (ii) expanding the services and products offered throughout our global network of offices and (iii) acquiring complementary technologies that add key technologies or market presence and enhance existing services and products.
Development of New Technologies, Services and Products
We conduct research and development to meet the needs of our clients who are continually seeking new services and technologies to lower their costs of finding, developing and producing oil and gas. While the aggregate number of wells being drilled per year has fluctuated relative to market conditions, oil and gas producers have, on a proportional basis, increased expenditures on technology services to improve their understanding of the reservoir and increase production of oil and gas from their producing fields. We intend to continue concentrating our efforts on services and technologies that improve reservoir performance and increase oil and gas recovery.
International Expansion of Services and Products
Another component of our business strategy is to broaden the spectrum of services and products offered to our clients on a global basis. We intend to continue using our worldwide network of offices to offer our services and products that have been developed internally or obtained through acquisitions. This global emphasis allows us to enhance our revenue through efficient utilization of our worldwide network.
Acquisitions
We continually review potential acquisitions to add key services and technologies, enhance market presence or complement existing businesses.
More information relating to any significant acquisitions is included in Note 4 - Acquisitions of the Notes to the Consolidated Financial Statements.
Operations
We derive our revenue from services and product sales to clients primarily in the oil and gas industry.
We operate our business in two reporting segments. These complementary segments provide different services and products and utilize different technologies for evaluating and improving reservoir performance and increasing oil and gas recovery from new and existing fields. Disclosure relating to the operations and financial information of these business segments is included in Note 21 - Segment Reporting and Other Disaggregated Information of the Notes to the Consolidated Financial Statements.
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Reservoir Description: Encompasses the characterization of petroleum reservoir rock, and reservoir fluids samples to increase production and improve recovery of crude oil and natural gas from our clients' reservoirs. We provide laboratory-based analytical and field services to characterize properties of crude oil and crude oil-derived products to the oil and gas industry. We also provide proprietary and joint industry studies based on these types of analyses and manufacture associated laboratory equipment.
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Production Enhancement: Includes services and manufactured products relating to reservoir well completions, perforations, stimulation and production. We provide integrated diagnostic services to evaluate and monitor the effectiveness of well completions and to develop solutions aimed at increasing the effectiveness of enhanced oil recovery projects.
We offer our services worldwide through a global network of offices. Services accounted for 77%, 71% and 69% of our revenue from continuing operations for the years ended December 31, 2020, 2019 and 2018, respectively.
We manufacture products primarily in five facilities for distribution on a global basis. Product sales accounted for 23%, 29% and 31% of our revenue from continuing operations for the years ended December 31, 2020, 2019 and 2018, respectively.
Reservoir Description
Commercial oil and gas fields consist of porous and permeable reservoir rocks that contain crude oil, natural gas and formation water. Due to the density differences of the fluids, natural gas typically caps the field and overlies an oil layer, which overlies the water. We provide services that characterize the porous reservoir rock, all three reservoir fluids and their derived products. Services relating to these fluids include determining the quality and measuring the quantity of the reservoir fluids and their derived products. This includes determining the value of different crude oil and natural gases by analyzing the individual components of complex hydrocarbons. We measure reservoir hydrocarbons at reservoir conditions to determine the changes in their physical properties with changing pressure and temperature. The number of pressure-volume-temperature ("PVT") related projects, has been increasing for the last several years, and reservoir fluid analyses now contribute approximately 60% of Reservoir Description revenue.
We analyze samples of reservoir rocks for their porosity, which determines reservoir storage capacity, and for their permeability, which defines the ability of the fluids to flow through the rock. These measurements are used to determine how much oil and gas are present in a reservoir and the rates at which the oil and gas can be produced. We also use our proprietary services and technologies to correlate the reservoir description data to wireline logs and other subsurface data.
The combined use of both the reservoir rock and fluid data are invaluable to oil companies to determine the most efficient method by which to recover, process and refine these hydrocarbons to produce the maximum value added to crude oil and natural gas fields. Early evaluations and key decisions about well performance and viability are important for optimizing a reservoir. This is accomplished by using proprietary and patented laboratory methods, including both traditional physical measurements and more recently introduced new technologies, such as Core Lab’s Non-Invasive Technologies for Reservoir OptimizationSM (“NITROSM”) services. NITROSM services includes Dual Energy Computed Tomography ("DECT"), Micro Computed Tomography, high and low frequency nuclear magnetic resonance, high-resolution gamma logging and continuous high energy x-ray fluorescence, along with other Core Lab proprietary technologies.
Core Lab's proprietary DECT scanner-based deliverables generate millimeter-scale three dimensional images and accompanying high-resolution petrophysical logs on cored intervals by calibrating DECT information to the vast library of physical measurements in Core Lab's proprietary database. The DECT deliverables from Core Lab are more detailed than down-hole logs and provide better bed resolution as well as accurate information on rock properties such as lithology, porosity, density, rock strength and acoustic velocities.
DECT, when combined with Continuous Dual Gamma and Scanning X-ray Fluorescence (“CS-XRF”), allows Core Lab to assess continuous high-resolution elemental composition of the cored intervals. A proprietary formation-specific “inversion” technique can be used to convert the detailed elemental composition to a continuous mineral log enabling us to generate detailed lithologic descriptions of the reservoir and to perform a comprehensive reservoir characterization.
Core Lab conducts a wide variety of physical laboratory measurements to measure and evaluate fluid flow through the rock, often at in-situ reservoir temperatures and pressures. These are most commonly applied to conventional reservoirs. We have also developed unique analytical processes to understand the flow characteristics and saturation profiles of unconventional reservoir systems including (1) High Frequency Nuclear Magnetic Resonance measurements to gain insights into movable vs.
non-movable fluid saturations of these complex systems; and (2) Enhanced Oil Recovery of shale reservoirs by evaluating the effectiveness of gas cycling in nano-pore structures to significantly increase long-term production rates and volumes.
Core Lab has been at the forefront of digital transformation technologies for more than two decades. Core Lab’s extensive, proprietary databases and analog technologies, coupled with artificial intelligence (“AI”) and machine learning, help our clients improve efficiencies and lower operating costs throughout the upstream value chain. The analysis and integration, of these critical datasets is enhanced because of Core Lab’s proprietary RAPIDTM database. Core Lab’s proprietary World Wide Rock CatalogTM provides a database and analog reference set for predicting properties when physical measurements are unavailable.
Core Lab’s Digital Innovation Group integrates results and interpretations into a comprehensive, web-enabled platform, RAPIDTM, for client access. This allows our clients to gain insight into their core intervals at an accelerated pace, for both non-invasive technologies as well as time-honored physical laboratory measurements. Through this integrated visually interactive platform, key reservoir performance indicators are presented, evaluated and shared within client workgroups.
During 2020, Core Lab’s Digital Innovation Group worked collaboratively with multiple international and national oil companies on projects that utilize several of Core Lab’s proprietary digital technologies and services. Core Lab’s proprietary Advanced Rock Typing technology combines Core Lab’s vast, comprehensive database of physical measurements, and World Wide Rock CatalogTM with its proprietary image acquisition technology and innovative AI image recognition. These technologies provide clients with analog data sets in situations where acquisition of new conventional core may not be possible. High-resolution images of wellbore cuttings and sidewall cores are quickly and efficiently matched with analogs from Core Lab’s proprietary database of samples from around the world. Physically measured data sets from the matching analogs are delivered to our clients in time to make appraisal and development decisions.
Core Lab also applies its rock fluid and data analytical capabilities to CO2 and other gas and liquid projects. These projects may be for enhanced oil recovery in mature fields, or for CO2-Carbon Capture and Sequestration projects.
Core Lab holds various patents, trade secrets, and proprietary designs for laboratory equipment required to analyze reservoir rocks as well as the properties and phase behavior of reservoir fluids and derived products. We manufacture a wide range of ambient and reservoir condition rock and fluid analysis laboratory equipment for our own use throughout our international laboratory network. Among these devices are complex, high-pressure, high temperature, reservoir condition, multi-phase flow systems and full visualization PVT cells, along with the ancillary equipment required to support these laboratory programs. We also sell equipment of this type to universities, government institutes, and client company research labs.
While recognizing the need to optimize the logistical chain of our clients, from producing well to retail sales of petroleum products, a state-of-the-art IT platform CONNECT: was launched to efficiently acquire our field data, laboratory analysis, optimize workflows and any other observations relevant to our client base. The system is designed for single data entry, and that data can be used for further analysis and, more importantly, be shared with our clients by process flow dashboards with key performance indicators. The system can also share real-time data on mobile devices, enabling our clients to make quick decisions. This methodology of sharing data has been embraced by an increasing number of clients, as it has not only saved them costs, but, more importantly, the data can be used for trend analysis in many ways, such as the ability to forecast bottlenecks, thus eliminating waste and increasing efficiency. Two experience centers have been set up, in the U.S. and Europe, where our clients can get acquainted with optimizing the flow of business as well as our advanced systems for data analysis. All initiatives are meant to increase efficiency and add value to our client base. All data is being made available through dashboard technology, which for internal purposes is being used to measure the efficiency of workflows throughout the organization.
Further development continues in 2021, new modules continue to be added to our suite of IT platforms that enhance the distribution chain of our customers, with similar structure of using dashboard technology, enabling the customer to monitor live progress as well as operational data.
We conduct numerous large-scale, multi-company reservoir management projects, applying proprietary and state-of-the-art techniques from the earliest phases of a field development program until the last economic barrel of oil is recovered. We initiate and deliver a group of international and U.S. based consortium studies to evaluate both conventional and unconventional reservoirs. These projects are of increasing importance to oil companies as the incremental barrel is often the lowest cost and most profitable barrel in the reservoir. Producing incremental barrels increases our clients' cash flows which we believe will result in additional capital expenditures by our clients, and ultimately further opportunities for us.
These industry consortium projects provide critical reservoir information to a broad spectrum of clients in a cost effective manner. These studies focus on regions of client interest across the globe, and include both conventional and unconventional reservoir targets. Studies often run for several years and new studies are initiated in response of current or upcoming client activity in a region. Core Lab retains rights of ownership to complete joint industry projects studies, which can be resold at a later date. Many of them examine unconventional reservoirs, particularly in the US and Canada. For example, our Permian
Basin study evaluates the petrophysical, geochemical, completion and production characteristics of this very active play in West Texas. Our clients use this information, not only to improve their drilling and production activities, but also to evaluate potential acquisition and divestiture opportunities.
Production Enhancement
We provide products and diagnostic services to help optimize well completions, reservoir operations and field development strategies in order to increase recoverable reserves in the most efficient way. Our product offerings focus on perforating technologies to establish communication between the wellbore and the reservoir. Our diagnostic services are used to access well completions and field floods. Two production enhancement methods commonly used are (i) hydraulic fracturing of the reservoir rock to improve flow and (ii) flooding a reservoir with water, carbon dioxide, nitrogen or hydrocarbon gases to drive more oil and gas to the producing wellbores. Many oilfields today are hydraulically fractured and/or flooded to maximize oil and gas recovery. Although Core Lab is not a hydraulic fracturing company, we do provide services that are used by others to develop and optimize hydraulic fracturing and field flood projects and to evaluate the success of those projects. Our services, products and expertise play a key role in the success of both methods.
The hydraulic fracturing of a producing formation is achieved by pumping a fluid slurry containing a proppant material into the reservoir zone at extremely high pressures. This fractures the rock and the proppant material "props" or holds the fractures open after the pressure pumping is complete so that reservoir fluids can flow to the production wellbore. Data on rock type and strength generated in our Reservoir Description segment are critical for determining the proper design of the hydraulic fracturing job. In addition, our testing indicates whether the fluid slurry is compatible with the reservoir rock so that damage does not occur that would otherwise restrict production. We also provide testing of various propping agents and software to help pick the best proppant based on net present value calculations of client investments. Our proprietary and patented ZERO WASH® tracer technology is used to determine cluster efficiency and ensure maximum stimulated reservoir volume and increased ultimate recovery.
SPECTRACHEM®, a chemical frac water tracer, is another proprietary and patented technology developed for optimizing hydraulic fracture performance. SPECTRACHEM® is used to aid operators in determining the efficiency of the fracture fluids used. SPECTRACHEM® tracers allow operators to evaluate the quantity of fracture fluid that returns to the wellbore during the clean-up period after a hydraulic fracturing event. This technology also allows our clients to evaluate load recovery, gas breakthrough, fluid leak-off and breaker efficiency, all of which are important factors for optimizing oil and/or natural gas production after the formation is hydraulically fractured.
The SPECTRACHEM® service is used for determining the effectiveness and efficiency of the hydraulic fracture stimulation of long, multi-stage horizontal wells in oil- and gas-shale plays in unconventional reservoirs. SPECTRACHEM® data sets are used to determine how each frac stage is flowing. Frac stages with ineffective flows may warrant further stimulation, remedial actions and guide improvements on future frac designs.
During 2020, our engineers developed and introduced a new application for our proprietary SPECTRACHEM ® to determine whether horizontal wells are unobstructed and flowing through the entire length of a lateral well. Leveraged by operators in the Permian, Eagle Ford, and Haynesville, this technology can identify wellbore obstructions, often caused by inter-well communication or dissolvable plug remnants. By applying this technology, our clients can identify and remediate well obstructions that can negatively impact well performance, reserve calculations and reserve-based lending.
Our unique completion monitoring system, COMPLETION PROFILER™, helps to determine flow rates from reservoir zones after they have been hydraulically fractured. This provides our clients with a baseline of early production information and can be compared to subsequent images later in the life of the well to see how hydrocarbon production from different reservoir layers or different quality rock varies over time.
Our FLOWPROFILERTM service, a proprietary hydrocarbon-based tracer technology, which is a further development of our patented SPECTRACHEM® technology quantifies the hydrocarbon production from discrete segments in multi-stage horizontal well completions and stimulations in unconventional tight-oil or gas plays. We have tracers used for oil reservoirs which are different from our tracers used for gas reservoirs. FLOWPROFILERTM technology and the analytical methodology for identifying the hydrocarbon-soluble tracers are the protected intellectual property of Core Lab.
FLOWPROFILERTM technology employs a unique hydrocarbon-soluble tracer and water-soluble tracer introduced into specific and isolated stages via the stimulating proppant stream. The hydrocarbon-soluble tracers are absorbed by the crude oil and gas associated with each stage, while the water-soluble tracer remains in the stimulation fluid. When the well is flowed, oil, gas and water samples are collected and analyzed in the laboratory to identify and quantify oil or gas flows from each stage as well as the cleanup of the stimulation fluid. Stages not at optimum flow rates can be identified, precipitating remedial efforts to increase flow and recovery rates, and providing valuable insight for future wells. This service is being used to monitor offset
well interference by sampling offset well oil, gas and water production. The amount of tracer detected in offset wells is being used to help our clients optimize both lateral and vertical well spacing and the amount of fracturing fluids for each stage.
We continue to see broadening acceptance of FLOWPROFILERTMEDS, a proprietary technology, which is an engineered delivery system ("EDS"). The break-through EDS technology delivers time-released diagnostics for evaluating the crude-oil flow from each stage of a hydraulically fractured completion. This technology comprises proprietary 40/70 or 100 mesh particles, chemically engineered to bond specifically with our proprietary oil tracers. This allows for precise placement of tracers in the propped fracture providing accurate identification of oil production by stage. Crude-oil production by stage is determined by using this Core Lab-developed technology that enables the diagnostic tracer to be absorbed and chemically-bonded to durable, proppant-size particles that accompany the frac sand. The tracer will release from the engineered particles once they contact the reservoir's crude oil, enabling Core Lab to assess which stages are contributing to crude-oil production.
We conduct dynamic flow tests of the reservoir fluids through the reservoir rock, at actual reservoir pressure and temperature, to realistically simulate the actual flooding of a producing zone. We use patented technologies, such as our Saturation Monitoring by the Attenuation of X-rays ("SMAXTM"), to help design the enhanced recovery project. After a field flood is initiated, we are often involved in monitoring the progress of the flood to ensure the maximum amount of incremental production is being achieved through the use of our SPECTRAFLOODTM technology, which we developed to optimize sweep efficiency during field floods.
Our PACKSCAN® patented technology is used to evaluate gravel pack effectiveness in unconsolidated reservoirs. PACKSCAN® measures the density changes in the gravel pack annulus to verify the completeness of the gravel pack protection of the wellbore without any additional rig time.
In addition to Core Lab's many patented reservoir diagnostic technologies, Production Enhancement has established itself as a global leader in the manufacturing and distribution of high-performance perforating products. Core Lab's unique understanding of complex reservoirs supports our ability to supply perforating systems engineered to maximize well productivity by reducing, eliminating and overcoming formation damage caused during the drilling and completion of oil and gas wells. This "systems" approach to the perforation of an oil or gas well has resulted in numerous patented products.
HEROTM ("High Efficiency Reservoir Optimization") and SuperHEROTM are examples of the patented perforating systems which quickly gained market acceptance and became industry leaders in enhancing reservoir performance. The SuperHEROTM charge evolved from the HEROTM charge technology and use a proprietary and patented design of powdered metal liners and explosives technology resulting in a deeper and cleaner perforating tunnel into the oil and gas reservoir. This allows greater flow of hydrocarbons to the wellbore and helps to maximize hydrocarbon recovery from the reservoir. The more recent charge development of the HERO-HRTM (Hard Rock) charges, resulted in Core Lab also having the deepest penetrating perforating charges on the market as certified by API testing.
HEROTMPerFRAC leverages the HEROTM technology. In addition to the benefits of HEROTM technology, HEROTMPerFRAC charges are designed specifically for optimizing fracture stimulation well completions by providing a uniform hole size which minimizes tortuosity effects. This results in less required surface horsepower and less time which both translate into lower costs needed to complete the fracturing operation. In addition to optimizing stimulation operations with faster, lower cost programs, well production is also enhanced by not only the better well stimulations but the improved near debris free perforation tunnels as the well fluids come back into the casing from the rock. Core Lab's manufacturing operations in the United States and Canada continue to meet the global demand for our perforating systems through facility expansion in addition to gains in efficiency and productivity.
Consistent with the HEROTMPerFRAC uniform hole size option, the ReFRAC product line was also introduced and has experienced increasing client acceptance. The ReFRAC technology is utilized in mechanically isolated re-stimulation programs where the internal string is used to isolate older, depleted stages in previously under-stimulated wells. The ReFRAC technology creates a uniform hole size through two strings of casing. This re-completion method is gaining popularity because it allows operators to perforate, pump and stimulate new rock between the original stages of the well, increasing hydrocarbon recovery without the expense of drilling and completing a new well. Operators using Core Lab’s ReFRAC technology have reported they can now complete twice as many stages per day compared to conventional perforating systems, reducing their operating costs and improving cash flow.
The HEROTM line of perforating charges, HEROTMPerFRAC, SuperHEROTM, HERO-HRTM and ReFRAC charges can eliminate the ineffective perforations that would otherwise limit daily oil and natural gas production and hinder the optimal fracture stimulation programs needed for prolific production from the Permian Basin, Bakken, Eagle Ford, Marcellus, Niobrara and similar oil- and gas-shale formations.
Core Lab acquired Guardian Global Technologies Ltd. ("Guardian") in 2018. Based in Pyle, Wales, Guardian is a technologically sophisticated designer and manufacturer of downhole instrumentation utilized by international oil and gas
operators for well completions. Guardian’s proprietary downhole energetic solutions are designed to systemize, simplify, automate, and de-risk the deployment of perforating systems. The Ballistics Delivery System (“BDSTM”) provides a unique range of perforating tools and equipment, which have been developed to provide a number of advantages over existing technology. The BDSTM tools facilitate perforation accuracy while addressing wellbore assurance concerns and optimizing safety, thus alleviating some of the challenges encountered when perforating. It also assists with issues incurred with high underbalanced perforating, running heavy/long assemblies, oriented perforating, depth control, reduction in fishing risk, and acquiring wellbore pressure data as guns fire. Core Lab’s BDS TM and the Addressable Fire Switch are key differentiators of Core Lab’s preassembled GoGunTM Adaptive Perforating System. The GoGunTM Adaptive Perforating System provides an open architecture design. This allows for optimal utilization of perforating energetics and, importantly, the onsite flexibility of altering completion designs for greater wellsite efficiency and improved Stimulated Reservoir Volume.
During 2020, Core Lab introduced its next generation, best-in-class, HERO®PerFRAC energetic technology, which is now available in combination with the new, patent pending Oriented GoGun™. This new offering provides our clients with a technological solution for achieving: 1) extreme limited entry perforating capability, 2) precisely aligned perforations, and 3) minimized connections and completion string length. Casing erosion around perforations can occur when stimulating unconventional reservoirs. Larger perforating holes preferentially increase in size and take more frac fluid, robbing stimulation from smaller perforating holes, which results in inconsistent breakdown of the formation. The consistent-sized holes generated by the latest HERO®PerFRAC charges reduce this problem. Core Lab partnered with major U.S. operators to design custom, consistent-hole-size charges that can be aligned in a specific orientation in order to achieve uniform breakdown across each stage. By eliminating the need for reusable orientation subassemblies, the Oriented GoGunTM minimizes the number of connections and saves time at the wellsite by not having to recapture and redress the orienting subs.
Core Lab’s Production Enhancement segment commissioned a cutting-edge, Reservoir Optimized Completions Lab (“ROC LabTM”) in Godley, Texas. The ROC LabTM is designed to determine the best energetic solutions for a specific rock type, to maximize productivity of an operator’s reservoir. The ROC LabTM features an industry-leading, Ultra High Pressure/High Temperature perforation test vessel. The test vessel is paired with a proprietary flow system that uses highly specialized, internally developed and manufactured pumps and flow controllers. Combined, these technologies create a proprietary flow loop capable of dynamically displacing oil, brine and gas through rock samples that have been perforated with preselected energetics. Core Lab leverages its multi-decadel expertise in conducting multi-phase fluid flow tests through porous medium to optimize this technological investment.
Core Lab's Production Enhancement team has experienced technical services personnel to support clients through our global network of offices for the everyday use of our perforating systems and the rapid introduction of new products. Our personnel are capable of providing client training and on-site services in the completion of oil and gas wells. The patented X-SPAN® and GTX-SPAN® casing patches are supported by our technical services personnel. Market applications in Canada's steam-assisted gravity drainage environment have resulted in an upgrade in temperature ratings to as much as 600°F. These systems are capable of performing in high temperature as well as high pressure oil and gas environments and are used to seal non-productive reservoir zones from the producing wellbore.
Marketing and Sales
We market and sell our services and products through a combination of sales representatives, technical seminars, trade shows and print advertising. Direct sales and marketing are carried out by our sales force, technical experts and operating managers, as well as by sales representatives and distributors in various markets where we do not have offices. Our Business Development group manages a Large Account Management Program to better serve our largest and most active clients by meeting with key personnel within their organizations to ensure the quality of our services and products are meeting their expectations and addressing any issues or needs in a timely manner.
Research and Development
The market for our services and products is characterized by changing technology and frequent product introduction. As a result, our success is dependent upon our ability to develop or acquire new services and products on a cost-effective basis and to introduce them into the marketplace in a timely manner. Many of our acquisitions have allowed us to obtain the benefits of the acquired company's research and development projects without incurring significant costs if we had attempted to develop the services and products ourselves. We incur costs as part of internal research and development, and these costs are charged to expense as incurred and reflected in the operational results of the associated business segment. We intend to continue committing financial resources and effort to the development and acquisition of new services and products. Over the years, we have made a number of technological advances, including the development of key technologies utilized in our operations. Substantially all of our new technologies are the result of requests and guidance from our clients, particularly major oil companies.
Patents and Trademarks
We believe our patents, trademarks, technology, trade secrets and other intellectual property rights are an important factor in maintaining our technological advantage, although no single one of these is considered essential to our success. Typically, we will seek to protect our intellectual property in all jurisdictions where we believe the cost of such protection is warranted. While we have patented some of our key technologies, we do not patent all of our proprietary technology even where regarded as patentable. We protect our intellectual property, including through the use of appropriate confidentiality agreements, legal enforcement proceedings and by other means.
International Operations
We operate facilities in more than 50 countries. Our non-U.S. operations accounted for 67%, 57% and 54% of our revenue from operations during the years ended December 31, 2020, 2019 and 2018, respectively. We attribute service revenue to the country in which the service was performed rather than where the reservoir or project is located, while we attribute product sales revenue to the country where the product was shipped as we feel this gives a clearer view of our operations. We do, however, have significant levels of service revenue performed and recorded in the U.S. that are sourced from projects on non-U.S. oilfields.
The following graphs and table summarize our reported revenue by geographic region for the years ended December 31, 2020, 2019 and 2018:
United States
Europe/Africa/ Middle East
Asia Pacific
Canada
Former Soviet Union
Latin/ South America
Consolidated
$
158,937
$
208,862
$
44,440
$
16,616
$
31,498
$
26,914
$
487,267
$
289,173
$
223,988
$
59,554
$
25,240
$
36,078
$
34,177
$
668,210
$
324,073
$
211,081
$
68,641
$
34,633
$
35,173
$
27,245
$
700,846
While we are subject to fluctuations and changes in currency exchange rates relating to our international operations, we attempt to limit our exposure to foreign currency fluctuations by limiting the amount in which our foreign contracts are denominated in a currency other than the U.S. dollar. However, the ultimate decision as to the proportion of the foreign currency component within a contract usually resides with our clients. Consequently, we are not always able to eliminate our foreign currency exposure. We have not historically engaged in and are not currently engaged in any significant currency hedging or trading transactions designed to compensate for adverse currency fluctuations.
Environmental and Occupational Safety and Health Regulations
We are subject to stringent governmental laws and regulations, both in the United States and other countries, pertaining to protection of the environment and occupational safety and health. Compliance with environmental legal requirements in the United States at the federal, state or local levels may require acquiring permits to conduct regulated activities, incurring capital expenditures to limit or prevent emissions, discharges and any unauthorized releases, and complying with stringent practices to handle, recycle and dispose of certain wastes. Additionally, our operations in the United Sates are subject to stringent occupational safety and health laws and regulations, which are intended to protect worker health and safety. Foreign countries in which we conduct operations may also have analogous controls that regulate our environmental and worker safety-related activities, which controls may impose additional, or more stringent requirements. Consistent with our quality assurance and
control principles, we have established proactive environmental and worker safety policies in the United States and foreign countries for the management, handling, recycling or disposal of chemicals and gases and other materials and wastes resulting from our operations. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial or corrective obligations, the occurrence of delays or cancellations in the permitting or performance of projects and the issuance of injunctive relief in affected areas. Historically, our environmental and worker safety compliance costs have not had a material adverse effect on our results of operations; however, there can be no assurance that such costs will not be material in the future or that such future compliance will not have a material adverse effect on our business or results of operations.
New, modified or stricter enforcement of environmental laws and regulations could be adopted or implemented that significantly increase our compliance costs, pollution mitigation costs, or the cost of any remediation of environmental contamination that may become necessary, and these costs could be material. Our clients are also subject to most, if not all, of the same laws and regulations relating to environmental protection and occupational safety and health in the United States and in foreign countries where we operate. Consequently, to the extent these environmental compliance costs, pollution mitigation costs or remedial costs are incurred by our clients, those clients could elect to delay, restrict or cancel drilling, exploration or production programs, which could reduce demand for our products and services and, as a result, have a material adverse effect on our business, financial condition, results of operations, or cash flows.
Our and our clients’ compliance with such existing, or any new or amended legal requirements that are placed into effect and applicable in areas where we or our clients conduct operations, could result in our or our clients’ incurring significant additional expense and operating restrictions. Our costs may not be fully recoverable from our clients and, thus, could reduce net income. To the extent any such existing or future legal requirements result in increased costs or restrictions or cancellation in the operation of our clients, to whom we provide our services, such developments could reduce demand for our products and services and have an indirect material adverse effect on our business.
Additionally, our analytical and manufacturing processes involve the handling and use of numerous chemicals and gases as well as the generation of wastes. Spills or other unauthorized releases of these chemicals, gases, and wastes at our facilities, whether by us or prior owners or operators, or at offsite locations where we transport them for recycling or disposal, could subject us to environmental liability, either from the applicable government agency or private landowners or other third parties. Such liabilities could be strict, joint and several, as is applicable in the United States under such laws as the federal Comprehensive Environmental Response, Compensation and Liability Act and the federal Resource Conservation and Recovery Act. This could also include costs of cleaning up chemicals and wastes released into the environment and for damages to persons, properties or natural resources. As a result of such actions, we could be required to remove previously disposed wastes (including wastes disposed of or released by prior owners or operators), remediate environmental contamination (including contaminated groundwater), and undertake measures to prevent future contamination. We may not be able to recover some or any of these remedial or corrective costs from insurance.
Competition
The businesses in which we engage are competitive. Some of our competitors are divisions or subsidiaries of companies that are larger and have greater financial and other resources than we have. While no one company competes with us in all of our product and service lines, we face competition in these lines, primarily from independent regional companies and internal divisions of major integrated oil and gas companies. We compete in different product and service lines to various degrees on the basis of price, technical performance, availability, quality and technical support. Our ability to compete successfully depends on elements both within and outside of our control, including successful and timely development of new services and products, performance and quality, client service, pricing, industry trends and general economic trends.
Reliance on the Oil and Gas Industry
Our business and operations are substantially dependent upon the condition of the global oil and gas industry. Future downturns in the oil and gas industry, or in the oilfield services business as well as the adoption and implementation of legislation, executive orders, and other regulatory initiatives that seek to combat climate change by restricting fossil fuel activities or the locations in which such activities may be conducted, may have a material adverse effect on our financial position, results of operations or cash flows. This risk factor is perhaps amplified given recent pronouncements and actions taken by the executive and/or legislative branches of the U.S. government in an uncertain and shifting political environment.
The oil and gas industry is highly cyclical and has been subject to significant economic downturns at various times as a result of numerous factors affecting the supply of and demand for oil and natural gas, including the level of capital expenditures of the oil and gas industry, the level of drilling activity, the level of production activity, market prices of oil and gas, economic conditions existing in the world, interest rates and the cost of capital, environmental regulations, tax policies, political requirements of national governments, coordination by the Organization of Petroleum Exporting Countries ("OPEC"), cost of producing oil and natural gas, and technological advances.
Human Capital
We are primarily a service provider in the oilfield services industry, so our workforce includes employees who are highly skilled professionals, including engineers and geologists, and other technical personnel, in addition to our administrative employees. As of December 31, 2020, we had approximately 3,700 employees. We do not have any material collective bargaining agreements and consider relations with our employees to be good.
Core Lab values its employees and is committed to providing resources that engage employees, enhance their work experience, and develop them for the future. Our Core Values are the framework that unite us on the path toward achieving our goals and propelling Core Lab forward. These values represent and establish the foundation by which we treat each other, conduct our business and simply define “how we do things around here”. By embedding our Core Values into our operating strategies, we ensure that our company culture and mission also drive our ESG sustainability efforts. We engage our employees on our progress and core values that define us as a company. We keep our employees informed of major business developments through CoreConnect, a communication initiative to drive connection and engagement between employees and executive leadership cascaded via extended leadership teams, periodic emails, quarterly newsletters, quarterly reports, and annual events.
To assist in this pledge, Core Lab has created its talent management strategy based on the employee life cycle. To ensure we have a diverse employee population reflective of our communities and client base, we’ve implemented recruiting practices that support and encourage the hiring and retention of diverse talent. Our total rewards approach is aligned to our business strategy and country-specific market influences. We offer competitive compensation and benefit programs in each country where we operate. Our approach not only encompasses competitive compensation and benefits, but also personal and professional growth opportunities within a global performance culture.
We develop our employees through performance management processes, competency-based development plans and training both in leadership and functional areas while also offering educational assistance programs. Our annual performance management cycle is an ongoing process that enables managers and employees to collaborate throughout the year to set performance goals and development objectives that align to business objectives. This process is designed to help employees understand where they add value to the organization, provide focus on and discussion around career aspirations, and reward employees for high performance.
We promote a culture-centric focus on the health and safety of our employees and the environment with a pro-active approach towards identifying and managing risks through recognition, evaluation, and education. We empower our employees by fostering a sense of responsibility for managing their own work environment through open communication, and a management-supported “zero accident” culture.
Web Site Access to Our Periodic SEC Reports
Our primary internet address is http://www.corelab.com. We file or furnish Quarterly Reports on Form 10-Q, Annual Reports on Form 10-K, Current Reports on Form 8-K, and any amendments to those reports with the U.S. Securities and Exchange Commission ("SEC"). These reports are available free of charge through our web site as soon as reasonably practicable after they are filed or furnished electronically with the SEC. We may from time to time provide important disclosures to investors by posting them in the investor relations section of our web site, as allowed by SEC rules.
The SEC maintains an internet website at http://www.sec.gov that contains reports, proxy and information statements, and other information regarding our company that we file electronically with the SEC.

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ITEM 1A. RISK FACTORS
ITEM 1A. RISK FACTORS
Our forward-looking statements are based on assumptions that we believe to be reasonable but that may not prove to be accurate. All of our forward-looking information is, therefore, subject to risks and uncertainties that could cause actual results to differ materially from the results expected. All known, material risks and uncertainties are discussed below.
Risk factors associated with the industry in which we operate
Events beyond Core Lab’s control, including a global or domestic health crisis, have resulted and may continue to result in unexpected adverse operating and financial results.
The COVID-19 pandemic has significantly reduced demand for our services, and has had, and is likely to continue to have, a material adverse effect on our financial condition, results of operations and cash flows. The effects of the COVID-19 pandemic have resulted in a significant and swift reduction in international and U.S. economic activity. The reduced demand for oil caused by this unprecedented global health and economic crisis, coupled with an oversupply of oil, led to a significant decrease of oil prices in 2020. Government reaction to the pandemic and restrictions and limitations applied by governments, continued
widespread growth in infections, travel restrictions, quarantines, or site closures as a result of the virus could, among other things, impact the ability of Core Lab’s employees and contractors to perform their duties, cause increased technology and security risk due to extended and company-wide telecommuting, lead to disruptions in Core Lab’s logistics and negatively affect customer relationships as a result. All of these factors may impact the timing of the recognition of revenue and results of operations for a particular quarter.
The extent to which our operating and financial results will continue to be affected by COVID-19 will depend on various factors and consequences beyond our control, which will depend on numerous evolving factors and future developments that it is not able to predict, including, but not limited to, the following:
▪
the length of time that the pandemic continues;
▪
its effect on the demand for oil and natural gas;
▪
the response of the overall economy and the financial markets;
▪
the effect of governmental actions taken in response to the pandemic; and
▪
the speed and effectiveness of responses to combat the virus, including vaccine development and distribution.
Any of those outcomes could have a material adverse effect on Core Lab’s business, financial condition, results of operations and cash flows and could perhaps amplify risk factors described in this Form 10-K.
Any cost reduction initiatives that Core Lab undertakes may not deliver the results it expects, and these actions may adversely affect its business.
In response to the financial risks presented by COVID-19, Core Lab implemented a variety of cost-cutting measures which began in March 2020, continued during the second quarter of 2020 and may need to implement additional cost-cutting measures that may adversely affect its business. These cost-cutting measures have included reductions in the quarterly dividend, base salaries of senior executives and annual capital expenditures, employee furloughs, workforce reductions, among other reductions of corporate and operating costs.
In addition, these initiatives could result in disruptions to Core Lab’s operations. Any cost-cutting measures could also negatively impact Core Lab’s business by delaying the introduction of new products or technologies, interrupting service of additional products, or impacting employee retention. In addition, there can be no assurance that additional costs will not offset any such reductions of its operations. If Core Lab’s operating costs are higher than expected, or if it does not maintain adequate control of its costs and expenses, Core Lab’s results of operations will suffer. If Core Lab is unable to mitigate these or other potential risks related to its cost cutting initiatives, it may disrupt Core Lab’s business or could have a material adverse effect on its financial condition and results of operations.
Downturns in the oil and gas industry, or in the oilfield services business, may have a material adverse effect on our financial condition or results of operations.
The oil and gas industry is highly cyclical and demand for the majority of our oilfield services and products is substantially dependent on the level of expenditures by the oil and gas industry for the exploration, development and production of crude oil and natural gas reserves, which are sensitive to oil and natural gas prices and generally dependent on the industry's view of future oil and gas prices. There are numerous factors affecting the supply of and demand for our services and products, which are summarized as:
▪
general and economic business conditions, including market prices of oil and gas and expectations about future prices;
▪
the adoption of legal requirements or taxation;
▪
changes in existing laws, regulations or other governmental actions;
▪
cost of producing and the ability to deliver oil and natural gas;
▪
the level of drilling and production activity;
▪
financial condition of our client base and their ability to fund capital expenditures;
▪
coordination by the OPEC;
▪
weather conditions and the physical effects of climatic change;
▪
civil unrest or political uncertainty in oil producing or consuming countries;
▪
level of consumption of oil, gas and petrochemicals by consumers;
▪
availability of services and materials for our clients to grow their capital expenditures and to deliver product to market; and
▪
availability of materials and equipment from key suppliers.
The oil and gas industry has historically experienced periodic downturns, which have been characterized by diminished demand for our oilfield services and products and downward pressure on the prices we charge. A significant downturn in the oil and gas industry could result in a reduction in demand for oilfield services and could adversely affect our operating results.
Changes in macro-economic factors impacting the oil and gas industry may negatively affect our ability to accurately predict client demand, which could cause us to hold excess or obsolete inventory and experience a reduction in gross margins and financial results.
We cannot accurately predict which or what level of our services and products our clients will need in the future. Orders are placed with our suppliers based on forecasts of client demand and, in some instances, we may establish buffer inventories to accommodate anticipated demand. Our forecasts of client demand are based on multiple assumptions, each of which may introduce errors into the estimates. In addition, many of our suppliers require a longer lead time to provide products than our clients’ demand for delivery of our finished products. If we overestimate client demand, we may allocate resources to the purchase of materials or manufactured products that we may not be able to sell when we expect to, if at all. As a result, we could hold excess or obsolete inventory, which would reduce gross margin and adversely affect financial results. Conversely, if we underestimate client demand or if insufficient manufacturing capacity is available, we could miss revenue opportunities and potentially lose market share and damage our client relationships. In addition, any future significant cancellations or deferrals of service contracts or product orders could materially and adversely affect profit margins, increase product obsolescence and restrict our ability to fund our operations.
Risk factors associated with our international presence
We depend on the results of our international operations, which expose us to risks inherent in doing business abroad.
We conduct our business in over 50 countries. Our operations, and those of our clients, are subject to the various laws, regulations and other legal requirements of those respective countries as well as various risks peculiar to each country, which may include, but are not limited to:
▪
global economic conditions;
▪
political actions and requirements of national governments including trade restrictions, embargoes, seizure, detention, nationalization and expropriations of assets;
▪
interpretation of tax statutes and requirements of taxing authorities worldwide, including the United States, routine examination by taxing authorities and assessment of additional taxes, penalties and/or interest;
▪
trade and economic sanctions, tariffs or other restrictions imposed by the European Union, the United States or other countries;
▪
civil unrest;
▪
acts of terrorism;
▪
fluctuations and changes in currency exchange rates (see section below);
▪
the impact of inflation;
▪
difficulty in repatriating foreign currency received in excess of the local currency requirements; and
▪
current conditions in oil producing countries such as Venezuela, Nigeria, Libya, Iran and Iraq considering their potential impact on the world markets.
Historically, economic downturns and political events have resulted in lower demand for our services and products in certain markets. The continuing instability in the Middle East and North Africa and the potential for activity from terrorist groups that the U.S. government has cautioned against have further heightened our exposure to international risks. The global economy is highly influenced by public confidence in the geopolitical environment and the situation in the Middle East and North Africa continues to be highly fluid; therefore, we expect to experience heightened international risks.
Our results of operations may be significantly affected by foreign currency exchange rate risk.
We are exposed to risks due to fluctuations in currency exchange rates. By the nature of our business, we derive a substantial amount of our revenue from our international operations, subjecting us to risks relating to fluctuations in currency exchange rates.
Our results of operations may be adversely affected because our efforts to comply with applicable anti-corruption laws such as the United States' Foreign Corrupt Practices Act (the "FCPA") and the United Kingdom's Anti-Bribery Act (the "ABA") could restrict our ability to do business in foreign markets relative to our competitors who are not subject to these laws.
We operate in many parts of the world that have experienced governmental corruption to some degree and, in certain circumstances, strict compliance with anti-bribery laws may conflict with local customs and practices. We may be subject to competitive disadvantages to the extent that our competitors are able to secure business, licenses or other preferential treatment by making payments to government officials and others in positions of influence or though other methods that we are prohibited from using.
We are subject to the regulations imposed by the FCPA and the ABA, which generally prohibits us and our intermediaries from making improper payments to foreign officials for the purpose of obtaining or keeping business. In particular, we may be held liable for actions taken by our strategic or local partners even though our partners are not subject to these laws. Any such violations could result in substantial civil and/or criminal penalties and might adversely affect our business, results of operations or financial condition. In addition, our ability to continue to work in these parts of the world discussed above could be adversely affected if we were found to have violated certain laws, including the FCPA and the ABA.
Because we are a Netherlands company, it may be difficult for you to take legal action against our supervisory directors or us and it may not be possible to obtain or enforce judgments against us.
Although we are a Netherlands company, our assets are located in a variety of countries. In addition, not all members of our Board of Supervisory Directors (the “Supervisory Board”) are residents of the same countries as other supervisory directors. As a result, it may not be possible for you to effect service of process within certain countries upon our supervisory directors, or to enforce against our supervisory directors or use judgments of courts of certain countries predicated upon civil liabilities under a country's federal securities laws. Because there is no treaty between certain countries and the Netherlands providing for the reciprocal recognition and enforcement of judgments, some countries' judgments are not automatically enforceable in the Netherlands or in the United States, where the principal market for our shares is located. In addition, there is doubt as to whether a court in one country would impose civil liability on us or on the members of the Supervisory Board in an original action brought against us or our supervisory directors in a court of competent jurisdiction in another country and predicated solely upon the federal securities laws of that other country.
Risk factors associated with technology advancement
If we are not able to develop or acquire new products or our products become technologically obsolete, our results of operations may be adversely affected.
The market for our services and products is characterized by changing technology and product introduction. As a result, our success is dependent upon our ability to develop or acquire new services and products on a cost-effective basis and to introduce them into the marketplace in a timely manner. While we intend to continue committing substantial financial resources and effort to the development of new services and products, we may not be able to successfully differentiate our services and products from those of our competitors. Our clients may not consider our proposed services and products to be of value to them; or if the proposed services and products are of a competitive nature, our clients may not view them as superior to our competitors' services and products. In addition, we may not be able to adapt to evolving markets and technologies, develop new products, or achieve and maintain technological advantages.
If we are unable to continue developing competitive products in a timely manner in response to changes in technology, our businesses and operating results may be materially and adversely affected. In addition, continuing development of new products inherently carries the risk of inventory obsolescence with respect to our older products.
If we are unable to obtain patents, licenses and other intellectual property rights covering our services and products, our operating results may be adversely affected.
Our success depends, in part, on our ability to obtain patents, licenses and other intellectual property rights covering our services and products. To that end, we have obtained certain patents and intend to continue to seek patents on some of our
inventions, services and products. While we have patented some of our key technologies, we do not patent all of our proprietary technology, even when regarded as patentable. The process of seeking patent protection can be long and expensive. There can be no assurance that patents will be issued from currently pending or future applications or that, if patents are issued, they will be of sufficient scope or strength to provide meaningful protection or any commercial advantage to us. In addition, effective copyright and trade secret protection may be unavailable or limited in certain countries. Litigation, which could demand significant financial and management resources, may be necessary to enforce our patents or other intellectual property rights. Also, there can be no assurance that we can obtain licenses or other rights to necessary intellectual property on acceptable terms.
Our operations are subject to the risk of cyber-attacks that could have a material adverse effect on our consolidated results of operations and consolidated financial condition.
Our information technology systems are subject to possible breaches and other threats that could cause us harm. Although we devote significant resources to protect our systems, there can be no assurance that our systems will prevent or limit the effects of cyber-attacks or will be sufficient to prevent or detect, or to avoid a material adverse impact on our systems when such attacks do occur. If our systems for protecting against cyber-attacks prove not to be sufficient, we could be adversely affected by loss or damage of intellectual property, proprietary information, client data, our reputation, interruption of business operations, or additional costs to prevent, respond to, or mitigate cyber-attacks. These risks could have a material adverse effect on our business, results of operations, and financial condition.
Risk factors associated with our supply chain, resources, liquidity and capital management
We are subject to the risk of supplier concentration.
Certain of our product lines depend on a limited number of third party suppliers and vendors available in the marketplace. As a result of this concentration in some of our supply chains, our business and operations could be negatively affected if our key suppliers were to experience significant disruptions affecting the price, quality, availability or timely delivery of their products. For example, we have a limited number of vendors for our manufactured product lines. The partial or complete loss of any one of our key suppliers, or a significant adverse change in the relationship with any of these suppliers, through consolidation or otherwise, would limit our ability to manufacture and sell certain of our products.
There are risks relating to our acquisition strategy. If we are unable to successfully integrate and manage businesses that we have acquired and any businesses acquired in the future, our results of operations and financial condition could be adversely affected.
One of our key business strategies is to acquire technologies, operations and assets that are complementary to our existing businesses. There are financial, operational and legal risks inherent in any acquisition strategy, including:
▪
increased financial leverage;
▪
ability to obtain additional financing;
▪
increased interest expense; and
▪
difficulties involved in combining disparate company cultures and facilities.
The success of any completed acquisition will depend on our ability to effectively integrate the acquired business into our existing operations. The process of integrating acquired businesses may involve unforeseen difficulties and may require a disproportionate amount of our managerial and financial resources. In addition, possible future acquisitions may be larger and for purchase prices significantly higher than those paid for earlier acquisitions. No assurance can be given that we will be able to continue to identify additional suitable acquisition opportunities, negotiate acceptable terms, obtain financing for acquisitions on acceptable terms or successfully acquire identified targets. Our failure to achieve consolidation savings, to incorporate the acquired businesses and assets into our existing operations successfully or to minimize any unforeseen operational difficulties could have a material adverse effect on our financial condition and results of operation.
We may be unable to attract and retain skilled and technically knowledgeable employees, which could adversely affect our business.
Our success depends upon attracting and retaining highly skilled professionals and other technical personnel. A number of our employees are highly skilled engineers, geologists and highly trained technicians, and our failure to continue to attract and retain such individuals could adversely affect our ability to compete in the oilfield services industry. In periods of high utilization, there may be a shortage of skilled and technical personnel available in the market, potentially compounding the
difficulty of attracting and retaining these employees. As a result, our business, results of operations and financial condition may be materially adversely affected.
We require a significant amount of cash to service our indebtedness, make capital expenditures, fund our working capital requirements and pay our dividend, and our ability to generate cash may depend on factors beyond our control.
Our ability to make payments on and to refinance our indebtedness, to fund planned capital expenditures, and pay our dividend depends, in part, on our ability to generate cash in the future. This ability is, to a certain extent, subject to general economic, financial, competitive, legislative, regulatory and other factors that are beyond our control.
No assurance can be given that we will generate sufficient cash flows from operations or that future borrowings will be available to us in an amount sufficient to enable us to service and repay our indebtedness or to fund our other liquidity needs. If we are unable to satisfy our debt obligations, we may have to undertake alternative financing plans, such as refinancing or restructuring our indebtedness, selling assets, reducing or delaying capital investments or seeking to raise additional capital. We cannot assure that any refinancing or debt restructuring would be possible or, if possible, would be completed on favorable or acceptable terms, that any assets could be sold or that, if sold, the timing of the sales and the amount of proceeds realized from those sales would be favorable to us or that additional financing could be obtained on acceptable terms.
Disruptions in the capital and credit markets could adversely affect our ability to refinance our indebtedness, including our ability to borrow under our existing revolving credit facility ("Credit Facility"). Banks that are party to our existing Credit Facility may not be able to meet their funding commitments to us if they experience shortages of capital and liquidity or if they experience excessive volumes of borrowing requests from us and other borrowers within a short period of time.
Risk factors associated with the health, safety and the environment
We are subject to a variety of environmental and occupational safety and health laws and regulations, which may result in increased costs and significant liability to our business.
We are subject to a variety of stringent governmental laws and regulations, both in the United States and foreign countries relating to protection of the environment, and occupational health and safety. Certain of these laws and regulations may impose joint and several, strict liability for environmental liabilities, such as the remediation of historical contamination or recent spills, and failure to comply with such laws and regulations could result in the assessment of damages, fines and penalties, the imposition of remedial or corrective action obligations, the occurrence of delays or cancellations in permitting or development of projects, or the suspension or cessation of some or all of our operations. These stringent laws and regulations could require us to acquire permits or other authorizations to conduct regulated activities, install and maintain costly equipment and pollution control technologies, impose specific safety and health standards addressing work protection, or to incur costs or liabilities to mitigate or remediate pollution conditions caused by our operations or attributable to former owners or operators.
Additionally, our clients are also subject to most, if not all, of the same laws and regulations relating to environmental protection and occupational safety and health in the United States and in foreign countries where we operate. To the extent existing environmental laws and regulations or any new or more stringently enforced environmental legal requirements significantly increase our clients’ compliance costs, pollution mitigation costs or remedial costs, our clients could elect to delay, restrict or cancel drilling, exploration or production programs, which could reduce demand for our products and services and have a material adverse effect on our business, financial condition, results of operations, or cash flows. For example, hydraulic fracturing continues to attract considerable public and governmental attention, both in the United States and in foreign countries, resulting in various controls applied to fracturing activities.
Hydraulic fracturing is a process used by oil and gas exploration and production operators in the completion of certain oil and gas wells whereby water, sand or other proppants and chemical additives are injected under pressure into subsurface formations to stimulate gas and, to a lesser extent, oil production. Some countries outside the United States, such as Bulgaria, the Czech Republic and France, currently have imposed moratoria on hydraulic fracturing while other countries, such as Canada, allow fracturing activities but those activities are not as widely pursued as they are in the United States. In the United States, the fracturing process is typically regulated by state oil and gas commissions, but several federal agencies have asserted regulatory authority over certain aspects of the process.
Additionally, a growing number of states have adopted, and other states are considering adopting, legal requirements that could impose more stringent disclosure, permitting and/or well construction requirements on hydraulic fracturing operations, and local governments may also seek to adopt ordinances within their jurisdictions regulating the time, place and manner of hydraulic fracturing activities.
If new or more stringent federal, state or local legal restrictions related to the hydraulic fracturing process are adopted in areas where our exploration and production clients’ operate, those clients could incur potentially significant added costs to
comply with such requirements and experience delays, curtailment or cancellation in the pursuit of exploration, development or production activities, which could reduce demand for our products and services.
Climate change continues to attract considerable public, political and scientific attention in the United States and in foreign countries. As a result, numerous regulatory initiatives have been made, and are likely to continue to be made, at the international, national, regional and state levels of government to monitor and limit existing emissions of greenhouse gases as well as to restrict or eliminate such future emissions.
See "Environmental and Occupational Safety and Health Regulations", under Item 1 of this Form 10-K for further discussion on environmental and worker safety and health matters.

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

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ITEM 2. PROPERTIES
ITEM 2. PROPERTIES
Currently, we have over 70 offices (totaling approximately 2.5 million square feet of space) in more than 50 countries. In these locations, we lease approximately 1.5 million square feet and own approximately 1.0 million square feet. We serve our worldwide clients through six Advanced Technology Centers ("ATCs") that are located in Aberdeen, Scotland; Abu Dhabi, United Arab Emirates; Calgary, Canada; Houston, Texas; Kuala Lumpur, Malaysia; and Rotterdam, The Netherlands. The ATCs provide support for our more than 50 regional specialty centers located throughout the global energy producing provinces. In addition, our more significant manufacturing facilities are located in Godley, Texas, Red Deer, Alberta, Canada and Pyle, Wales which are included in our Production Enhancement business segment. Our facilities are adequate for our current operations; however, expansion into new facilities or the replacement or modification of existing facilities may be required to accommodate future growth.

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ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
See Note 12 - Commitments and Contingencies of the Notes to the Consolidated Financial Statements.

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ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
PART II

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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
Price Range of Common Shares
Our common shares trade on the New York Stock Exchange ("NYSE") and the Euronext Amsterdam Stock Exchange under the symbol "CLB".
On February 4, 2021, the closing price, as quoted by the NYSE, was $35.76 per share and there were 44,573,622 common shares issued and outstanding held by approximately 219 record holders. These amounts exclude shares held by us as treasury shares.
See Part III, "Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters" for discussion of equity compensation plans.
Performance Graph
The following performance graph compares the performance of our common shares to the Standard & Poor's 500 Index and the Philadelphia Oil Service Index ("OSX") for the period beginning December 31, 2015 and ending December 31, 2020. Core Lab is now an established member of the OSX which includes a greater concentration of our most direct peers.
The graph assumes that the value of the investment in our common shares and each index was $100 at December 31, 2015 and that all dividends were reinvested. The stockholder return set forth below is not necessarily indicative of future performance. The following graph and related information is "furnished" and 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, as amended (the "Exchange Act") except to the extent that Core Laboratories specifically incorporates it by reference into such filing.
Share Repurchases in the Fourth Quarter of 2020
The following table provides information about our purchases of equity securities that are registered by us pursuant to Section 12 of the Exchange Act during the three months ended December 31, 2020:
Total Number Of
Shares Purchased
Maximum Number
As Part Of A
Of Shares That
Publicly
May Be Purchased
Total Number Of
Average Price
Announced
Under The
Period
Shares Purchased
Paid Per Share
Program
Program (3)(4)
October 1, 2020 to October 31, 2020 (1)
-
-
-
4,178,069
November 1, 2020 to November 30, 2020 (2)
$
14.45
-
4,179,396
December 1, 2020 to December 31, 2020 (2)
45,421
$
26.26
-
4,256,174
Total
45,929
$
26.13
-
(1) No shares were repurchased during October 2020.
(2) All shares repurchased during November and December 2020 were surrendered to us by participants in a stock-based
compensation plan to settle any personal tax liabilities which may result from the award.
(3) The maximum number of shares allowed to be purchased under the program was 4,178,069 at September 30, 2020.
(4) During the quarter, 124,034 treasury shares were distributed relating to stock-based awards, including 1,835 in November
and 122,199 in December.
In connection with our initial public offering in September 1995, our shareholders authorized our Management Board to repurchase up to 10% of our issued share capital, the maximum allowed under Dutch law at the time, for a period of 18 months. This authorization was renewed at subsequent annual or special shareholder meetings. At our annual shareholders' meeting on May 20, 2020, our shareholders authorized an extension until November 20, 2021 to purchase up to 10% of our issued share capital. The repurchase of shares in the open market is at the discretion of management pursuant to this shareholder authorization.
From the activation of the share repurchase program through December 31, 2020, we have repurchased 39,790,928 shares for an aggregate purchase price of approximately $1.7 billion, or an average price of $41.54 per share. At December 31, 2020, we held 223,451 shares in treasury and have the authority to repurchase 4,256,174 additional shares under our stock repurchase program as described in the preceding paragraph.

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ITEM 6. SELECTED FINANCIAL DATA
ITEM 6. SELECTED FINANCIAL DATA
The selected consolidated financial information contained below is derived from our Consolidated Financial Statements and should be read in conjunction with "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" and our audited Consolidated Financial Statements each of which is included in this Form 10-K.
For the Years Ended December 31,
(in thousands, except per share and other data)
Financial Statement Data:
Revenue
$
487,267
$
668,210
$
700,846
$
647,819
$
590,232
Income (loss) from continuing operations (1)
(97,073
)
94,284
79,847
80,985
65,024
Working capital
76,098
109,643
128,430
106,851
82,438
Total assets (5)
568,579
774,673
648,827
584,812
573,052
Long-term debt and capital lease obligations
259,433
305,283
289,770
226,989
216,188
Total equity
75,573
182,140
160,900
148,732
155,297
Earnings (Loss) Per Share Information:
Income (loss) from continuing operations:
Basic
$
(2.18
)
$
2.13
$
1.81
$
1.83
$
1.50
Diluted
$
(2.18
)
$
2.11
$
1.80
$
1.83
$
1.49
Weighted average common shares outstanding:
Basic
44,477
44,357
44,206
44,153
43,479
Assuming Dilution
44,477
44,646
44,474
44,264
43,670
Cash dividends declared per common share
$
0.28
$
2.20
$
2.20
$
2.20
$
2.20
Other Data:
Current ratio (2)
1.85:1
2.01:1
2.25:1
2.06:1
1.79:1
Debt to EBITDA ratio (3)
NM
2.47:1
1.97:1
1.59:1
1.79:1
Debt to Adjusted EBITDA ratio (4)
2.82:1
1.93:1
1.59:1
1.36:1
1.50:1
"NM" means not meaningful.
(1) Income (loss) from continuing operations for the year ended December 31, 2020 includes total impairment charges of $122.2
million for goodwill and certain intangible assets, a charge of $10.4 million for inventory write-downs and a reversal of $11.9
million of stock compensation expenses previously recognized that did not vest and were revalued.
(2) Current ratio is calculated as follows: current assets divided by current liabilities.
(3) Debt to EBITDA ratio is calculated as follows: debt less cash divided by the sum of consolidated net income
plus interest, taxes, depreciation, and amortization.
(4) Debt to Adjusted EBITDA ratio is calculated as follows: debt less cash divided by the sum of consolidated net income
plus interest, taxes, depreciation, amortization, severance, and certain non-cash adjustments.
(5) The adoption of ASC Topic 842 - Leases on January 1, 2019 resulted in an increase of $77.5 million to total assets.

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Core Laboratories N.V. is a Netherlands limited liability company. We were established in 1936 and are one of the world's leading providers of proprietary and patented reservoir description and production enhancement services and products to the oil and gas industry, primarily through client relationships with many of the world's major, national and independent oil companies.
We operate our business in two reporting segments. These complementary segments provide different services and products and utilize different technologies for evaluating and improving reservoir performance and increasing oil and gas recovery from new and existing fields:
•
Reservoir Description: Encompasses the characterization of petroleum reservoir rock and reservoir fluids samples to increase production and improve recovery of crude oil and natural gas from our clients' reservoirs. We provide laboratory-based analytical and field services to characterize properties of crude oil and crude oil-derived products to the oil and gas industry. We also provide proprietary and joint industry studies based on these types of analyses and manufacture associated laboratory equipment.
•
Production Enhancement: Includes services and manufactured products relating to reservoir well completions, perforations, stimulation and production. We provide integrated diagnostic services to evaluate and monitor the effectiveness of well completions and to develop solutions aimed at increasing the effectiveness of enhanced oil recovery projects.
General Overview
We provide services as well as design and produce products which enable our clients to evaluate and improve reservoir performance and increase oil and gas recovery from new and existing fields. These services and products are generally in higher demand when our clients are investing capital in their field development programs that are designed to increase productivity from existing fields or when exploring for appraising and developing new fields. Our clients' investment in capital expenditure programs tends to correlate over the longer term to oil and natural gas commodity prices. During periods of higher, stable prices, our clients generally invest more in capital expenditures and, during periods of lower or volatile commodity prices, they tend to invest less. Consequently, the level of capital expenditures by our clients impacts the demand for our services and products.
The following table summarizes the annual average and year-end worldwide and U.S. rig counts for the years ended December 31, 2020, 2019 and 2018, as well as the annual average and year-end spot price of a barrel of WTI crude, Europe Brent crude and an MMBtu of natural gas:
Baker Hughes Worldwide Average Rig Count (1)
1,351
2,177
2,211
Baker Hughes U.S. Average Rig Count (1)
1,032
Baker Hughes Worldwide Year-End Rig Count (2)
1,095
2,043
2,244
Baker Hughes U.S. Year-End Rig Count (2)
1,078
Average Crude Oil Price per Barrel WTI (3)
$
39.17
$
56.98
$
65.23
Average Crude Oil Price per Barrel Brent (4)
$
41.96
$
64.28
$
71.34
Average Natural Gas Price per MMBtu (5)
$
2.02
$
2.56
$
3.15
Year-end Crude Oil Price per Barrel WTI (3)
$
48.35
$
61.14
$
45.15
Year-end Crude Oil Price per Barrel Brent (4)
$
51.22
$
67.77
$
50.57
Year-end Natural Gas Price per MMBtu (5)
$
2.36
$
2.09
$
3.25
(1) Twelve month average rig count as reported by Baker Hughes - Worldwide Rig Count.
(2) Year-end rig count as reported by Baker Hughes - Worldwide Rig Count.
(3) Average daily and year-end West Texas Intermediate crude spot price as reported by the U.S. Energy Information Administration ("EIA").
(4) Average daily and year-end Europe Brent crude spot price as reported by the EIA.
(5) Average daily and year-end Henry Hub natural gas spot price as reported by the EIA.
The prices for both WTI and Brent crude oil declined from 2018 to 2019 and decreased significantly at the end of the first quarter of 2020 and throughout the second quarter of 2020, due to the outbreak of COVID-19. The COVID-19 pandemic and associated government mandated shut-downs around the world, home sheltering and social distancing policies, have caused a significant decline in the demand for crude oil and associated products. Crude-oil prices improved during the second half of 2020, and became more stable during the fourth quarter of the year. The end result was the average price for crude oil in 2020 was approximately 33% lower than the average price for 2019. In general, activities associated with the exploration of oil and
gas in the U.S. onshore market are more sensitive to changes in the crude-oil commodity prices, as opposed to larger international and offshore projects which take multiple years to plan and develop, and once announced and started, will continue through completion, despite changes in the current price of crude oil. Crude-oil prices in 2018 and 2019 remained at levels sufficient to support more stable levels in U.S. onshore activities associated with both the exploration and production of crude oil. Additionally, during the 2018 - 2019 time period, public announcements of investments in larger international and offshore projects increased and activity levels on these larger international and offshore projects began to improve in 2018 and continued to improve into 2019. However, in early 2020, the impact of COVID-19 to global economies caused a significant and sharp decline in demand for crude oil, which resulted in a significant and sharp decrease in the price of crude oil. Activity levels in the U.S. onshore market also responded immediately and decreased significantly to historically low levels, which bottomed in the summer of 2020, but showed some recovery in the second half of the year as global demand partially recovered, global production of crude oil was reduced and crude oil prices showed some recovery. Information published by the EIA, shows that the inventory of wells drilled but uncompleted (a “DUC” well) was 7,543 as of December 31, 2018, increasing to a peak in July 2019 at approximately 8,533, however, it subsequently declined to 7,782 and 7,592 at end of 2019 and 2020, respectively. This data indicates that during the period of higher activity in 2018, operators were drilling wells but not completing them as the DUC inventory grew. However, as activity levels began to fall in the second half of 2019, and a sharper decline in 2020, primarily due to the impact of COVID-19, the operators began to drill fewer new wells, but were completing some of the wells that had been previously drilled, which is reflected in the lower DUC inventory at December 2019 and 2020.
In North America, the land-based rig count decreased over 11% from 2018 to 2019. There was subsequently a significant decline of 51% in 2020 due to the impact of COVID-19. Consequently, the magnitude of decline in demand for both services and product sales to this market responded in line with the changes over this time period. The increase in activities on development projects and producing fields in the U.S. unconventional reservoirs during 2018 showed a decline when the commodity price weakened and activity levels decreased in 2019. In the U.S., the lower commodity prices led to a 54% decrease in the annual average land-based rig count and a decline in U.S. based activities in 2020.
Outside of North America, activities associated with the exploration for and production of oil were showing modest improvement in 2018 and 2019 until the global pandemic emerged in early 2020. The decrease in global demand for crude oil caused by the global pandemic also had a significant impact on exploration and production activities in the international markets as the number of active rigs outside the United States decreased almost 39% during 2020. Long-term international and offshore projects which are commonly announced through Final Investment Decisions and subsequently initiated are not susceptible or at-risk to delay or suspension due to short-term volatility in crude-oil commodity price, however the extreme negative market conditions caused by the COVID-19 pandemic and efforts to reduce the spread of the virus have negatively impacted the entire energy market in 2020.
Results of Operations
Operating Results for the Year Ended December 31, 2020 Compared to the Years Ended December 31, 2019 and 2018
We evaluate our operating results by analyzing revenue, operating income and operating income margin (defined as operating income divided by total revenue). Since we have a relatively fixed cost structure, decreases in revenue generally translate into lower operating income results. Results for the years ended December 31, 2020, 2019 and 2018 are summarized in the following chart:
Results of operations as a percentage of applicable revenue for the years ended December 31, 2020, 2019 and 2018 are as follows (in thousands, except for per share information):
2020 / 2019
2019 / 2018
Revenue:
% Change
Services
$
376,421
77.3
%
$
474,193
71.0
%
$
486,820
69.5
%
(20.6
)%
(2.6
)%
Product Sales
110,846
22.7
%
194,017
29.0
%
214,026
30.5
%
(42.9
)%
(9.3
)%
TOTAL REVENUE
487,267
100.0
%
668,210
100.0
%
700,846
100.0
%
(27.1
)%
(4.7
)%
OPERATING EXPENSES:
Cost of services* (1)
279,281
74.2
%
345,641
72.9
%
343,833
70.6
%
(19.2
)%
0.5
%
Cost of product sales* (1)
95,486
86.1
%
149,938
77.3
%
153,131
71.5
%
(36.3
)%
(2.1
)%
Total cost of services and product
sales
374,767
76.9
%
495,579
74.2
%
496,964
70.9
%
(24.4
)%
(0.3
)%
General and administrative expenses (1)
34,033
7.0
%
48,023
7.2
%
62,910
9.0
%
(29.1
)%
(23.7
)%
Depreciation and amortization
20,867
4.3
%
22,605
3.4
%
23,087
3.3
%
(7.7
)%
(2.1
)%
Impairments and other charges
122,204
25.1
%
-
-
-
-
NM
NM
Inventory write-down
10,375
2.1
%
-
-
-
-
NM
NM
Other (income) expense, net
1,826
0.4
%
5,319
0.8
%
(737
)
(0.1
)%
NM
NM
OPERATING INCOME (LOSS)
(76,805
)
(15.8
)%
96,684
14.5
%
118,622
16.9
%
NM
(18.5
)%
Interest expense
14,372
2.9
%
14,690
2.2
%
13,328
1.9
%
(2.2
)%
10.2
%
Income (loss) before income tax
(91,177
)
(18.7
)%
81,994
12.3
%
105,294
15.0
%
NM
(22.1
)%
Income tax expense (benefit)
5,896
1.2
%
(12,290
)
(1.8
)%
25,447
3.6
%
NM
NM
Income (loss) from continuing operations
(97,073
)
(19.9
)%
94,284
14.1
%
79,847
11.4
%
NM
18.1
%
Income (loss) from discontinued
operations
(424
)
(0.1
)%
7,833
1.2
%
(58
)
-
NM
NM
Net income (loss)
(97,497
)
(20.0
)%
102,117
15.3
%
79,789
11.4
%
NM
28.0
%
Net income (loss) attributable to
non-controlling interest
-
-
-
NM
NM
Net income (loss) attributable to
Core Laboratories N.V.
$
(97,637
)
(20.0
)%
$
101,983
15.3
%
$
79,526
11.3
%
NM
28.2
%
Diluted earnings (loss) per share from
continuing operations
$
(2.18
)
$
2.11
$
1.80
NM
17.2
%
Diluted earnings (loss) per share
attributable to Core
Laboratories N.V.
$
(2.20
)
$
2.28
$
1.79
NM
27.4
%
Diluted weighted average common
shares outstanding
44,477
44,646
44,474
* Percentage based on applicable revenue rather than total revenue.
"NM" means not meaningful.
(1) Excludes depreciation.
Services Revenue
Services revenue, which is primarily tied to activities associated with the exploration and production of oil and gas outside the U.S., decreased to $376.4 million in 2020 from $474.2 million in 2019 and $486.8 million in 2018. In 2020, the adverse impact of the COVID-19 pandemic, and government mandated shut-down around the world, home sheltering and social distancing policies caused a sharp decline in the demand for crude-oil and associated products. The average crude-oil price in 2020 was 33% lower than the average price of 2019. This resulted in decreased and disrupted activity by our clients and disruptions to our revenue generating operational activities leading to a sharp decrease in service revenue in both the U.S. and international markets during most of 2020. Crude-oil prices weakened in 2019 with the average price of 10% lower than the average price in 2018. This resulted in decreased activity by our clients leading to lower service revenue in the North America onshore market during 2019 compared to 2018. However, improvement in the level of work performed for offshore and international exploration and production projects partially offset some of the decline in the U.S. market.
We continue to focus on large-scale core analyses and reservoir fluids characterization studies in the Eagle Ford, the Permian Basin and the Gulf of Mexico, along with Guyana, Surinam, Malaysia and other international locations such as offshore South America, Australia, and the Middle East, including Kuwait, Saudi Arabia, Qatar, the United Arab Emirates and other countries. Analysis of crude oil and crude oil-derived products also occurs in every major producing region of the world.
Product Sales Revenue
Product sales revenue, which is primarily tied to the completion of onshore wells in North America, was $110.8 million in 2020, a decrease from $194.0 million and $214 million in 2019 and 2018, respectively. Rig count is one indicator of activity levels associated with the exploration and production of oil and gas. The rig count for North America significantly decreased in excess of 50% from 2019 to 2020 and decreased from 2018 to 2019 by 12%. Our products sales revenue decreased 43% from 2019 to 2020, and decreased 9% from 2018 to 2019, primarily due to our differentiated well completion products.
Cost of Services, excluding depreciation
Cost of services decreased to $279.3 million in 2020 compared to $345.6 million and $343.8 million in 2019 and 2018, respectively. As a percentage of services revenue, cost of services increased to 74% in 2020 from 73% and 71% in 2019 and 2018, respectively. The decrease in cost of services in 2020 from 2019 was primarily due to a significant decline in client activity levels and employee compensation and related charges associated with cost reduction initiatives implemented by the Company during the year. A slight increase in cost of services in 2019 from 2018, was primarily due to employee compensation and related charges. Cost of services expressed as a percentage of services revenue, is primarily reflective of how our cost structure is absorbed by revenue, and the timing of implementation of cost reduction initiatives executed by the Company in responding to the adverse changes in client activity levels.
Cost of Product Sales, excluding depreciation
Cost of product sales of $95.5 million in 2020 decreased from $150.0 million and $153.1 million in 2019 and 2018, respectively. Given product sales are primarily associated with our Production Enhancement segment and the North American market, cost of sales is impacted by decreased activities associated with clients operating in these segments and geographic markets. As a percentage of product sales revenue, cost of sales increased to 86% for 2020 from 77% and 72% for 2019 and 2018, respectively. Cost of product sales expressed as a percentage of product sales revenue is primarily reflective of how our fixed costs are absorbed by revenue. Due to the significant decrease in product sales revenue in 2020, fixed costs increased as a percentage of total cost of product sales and product sales revenue.
General and Administrative Expense, excluding depreciation
General and administrative ("G&A") expenses include corporate management and centralized administrative services that benefit our operations. G&A expenses were $34.0 million in 2020 compared to $48.0 million and $62.9 million during 2019 and 2018, respectively. The variances are primarily due to changes in compensation expense during those periods, including accelerated stock compensation expense of $6.7 million in 2020, $7.2 million in 2019 and $9.9 million in 2018 recorded for retirement eligible employees. During 2020, due to the significant adverse impact caused by the COVID-19 pandemic, certain performance metrics associated with long-term stock-based performance awards were not achieved, resulting in potential employee stock awards above the target level not vesting or being issued in 2020. However, the Company’s Compensation Committee approved a modification to the methodology of measuring performance conditions associated with target level long-term employee stock-based compensation awards, which vested at target levels on December 31, 2020. As a result of the stock-based awards not vesting above the target levels and modifications to the performance measures, the value of the stock-based awards that did vest on December 31, 2020 were revalued, and $11.9 million of previously recognized stock compensation expense was reversed in 2020, out of which $11.3 million was recorded in G&A expenses and $0.6 million recorded in cost of sales. See Note 14 - Stock-Based Compensation of the Notes to the Consolidated Financial Statements for further details.
Depreciation and Amortization Expense
Depreciation and amortization expense of $20.9 million in 2020 is down compared to $22.6 million and $23.1 million in 2019 and 2018, respectively, as a result of decreased capital expenditures.
Impairments, inventory write-down and other charges
During the year ended December 31, 2020, the events associated with the COVID-19 pandemic and the resulting sharp decrease in the price of crude oil, which caused a sharp decrease in the consumption and demand for crude oil, led to a triggering event in March 2020. In response to the triggering event, the Company updated its analysis associated with future cash flows and the valuation of assets and potential impairment of goodwill and intangible assets. Our updated analysis resulted in the Company recording a charge of $114.0 million for impairment of goodwill and $8.2 million for impairments to
intangible assets in March 2020 in our Production Enhancement segment. In addition, we recorded a charge of $10.4 million associated with inventory obsolescence and a valuation write-down related to our Production Enhancement segment.
There were no other triggering events during the year, and based on our annual assessment for the year ended December 31, 2020, we determined there was no further impairment for any of our reporting units or asset groups.
Other (Income) Expense, net
The components of Other (income) expense, net were as follows (in thousands):
For the Years Ended December 31,
Gain on sale of assets
$
(1,254
)
$
(583
)
$
(1,078
)
Results of non-consolidated subsidiaries
(125
)
(208
)
(203
)
Foreign exchange (gain) loss
1,160
1,725
2,598
Rents and royalties
(466
)
(607
)
(510
)
Employment related charges
-
2,998
-
Return on pension assets and other pension costs
(1,502
)
(1,501
)
(644
)
Acquisition-related costs
-
-
Gain on sale of business
-
(1,154
)
-
Insurance settlement
-
-
(707
)
Loss on lease abandonment
-
-
Cost reduction and other charges
3,943
5,555
-
Other, net
(434
)
(906
)
(816
)
Total Other (income) expense, net
$
1,826
$
5,319
$
(737
)
Foreign exchange gains and losses are summarized in the following table (in thousands):
For the Years Ended December 31,
Australian Dollar
$
$
$
British Pound
Canadian Dollar
Euro
Other currencies, net
(715
)
1,591
Foreign exchange (gain) loss, net
$
1,160
$
1,725
$
2,598
Interest Expense
Interest expense of $14.4 million in 2020 compared to $14.7 million and $13.3 million in 2019 and 2018, respectively. In 2020, the Company reduced outstanding debt under its Credit Facility by $46.0 million, however additional interest expense was incurred to modify the revolving credit agreement in 2020 which also includes higher interest rate spreads when compared to the previous terms under revolving credit agreement. The increase in interest expense in 2019 when compared to 2018 is primarily due to increased average borrowing under our Credit Facility in 2019 compared to 2018.
Income Tax Expense
Our effective tax rate was (6.5)%, (15.0)%, and 24.2% for 2020, 2019 and 2018, respectively. Income tax expense of $5.9 million in 2020 increased by $18.1 million compared to a $12.3 million benefit in 2019 primarily due to a large impairment charge of $122.2 million in the first quarter of 2020, of which a substantial portion was not deductible for tax purposes. A $5.5 million benefit was recognized associated with this impairment. In contrast, a benefit of $60.7 million was recognized in 2019 related to corporate restructuring which was partially offset by a charge of $26.7 million related to unremitted earnings of foreign subsidiaries that we no longer consider to be indefinitely reinvested.
See Note 10 - Income Taxes of the Notes to the Consolidated Financial Statements for further detail of income tax expense.
Discontinued Operations
In a continuing effort to streamline our business and align our business strategy for further integration of services and products, the Company committed to divest our full range of permanent downhole monitoring systems and related services, which had been part of our Production Enhancement segment. We entered into the definitive purchase agreement on June 7, 2019 for the divestiture of this business, and during the year ended December 31, 2020, we concluded final adjustments to the purchase agreement of the sold business.
See Note 20 - Discontinued Operations of the Notes to the Consolidated Financial Statements for additional information.
Segment Analysis
The following charts and tables summarize the annual revenue and operating results for our two complementary business segments.
Segment Revenue
Segment Revenue
For the Years Ended December 31,
(dollars in thousands)
% Change
% Change
Reservoir Description
$
355,041
(15.6)%
$
420,897
1.9%
$
413,082
Production Enhancement
132,226
(46.5)%
247,313
(14.1)%
287,764
Total Revenue
$
487,267
(27.1)%
$
668,210
(4.7)%
$
700,846
Segment Operating Income (Loss)
For the Years Ended December 31,
(dollars in thousands)
% Change
% Change
Reservoir Description
$
55,044
(0.2)%
$
55,140
0.5%
$
54,847
Production Enhancement
(133,449)
NM
38,378
(39.1)%
63,039
Corporate and other (1)
1,600
NM
3,166
NM
Operating Income (Loss)
$
(76,805)
NM
$
96,684
(18.5)%
$
118,622
(1) "Corporate and other" represents those items that are not directly relating to a particular segment.
"NM" means not meaningful.
Segment Operating Income (Loss) Margins (1)
For the Years Ended December 31,
Margin
Margin
Margin
Reservoir Description
15.5%
13.1%
13.3%
Production Enhancement
(100.9)%
15.5%
21.9%
Total Company
(15.8)%
14.5%
16.9%
(1) Calculated by dividing "Operating Income (Loss)" by "Revenue".
Reservoir Description
Revenue for our Reservoir Description segment decreased to $355.0 million in 2020 compared to $420.9 million and $413.1 million in 2019 and 2018, respectively. Reservoir Description’s operations are heavily exposed to international and offshore project activity levels, with approximately 80% of its revenue sourced outside the U.S. In 2019, our client’s activity levels in the international markets had modestly increased when compared to 2018. However, in early 2020 when the COVID-19 pandemic began, global economies were locked down in an effort to reduce the spread of the virus and demand for crude oil decreased sharply. The sharp decrease in demand and challenges to remain operational during the global pandemic caused many adverse impacts to the energy industry, our clients and the Company. Revenue was also adversely impacted in 2020 due to the COVID-19 pandemic. We continue to focus on large-scale core analyses and reservoir fluids characterization studies in the Eagle Ford, the Permian Basin and the Gulf of Mexico, along with Guyana, Suriname, Malaysia and other international locations such as offshore South America, Australia, and the Middle East, including Kuwait, Saudi Arabia, Qatar, the United Arab Emirates and other countries. Analysis of crude oil and crude oil-derived products also occurs in every major producing region of the world.
Operating income of $55.0 million remained relatively flat in 2020 compared to $55.1 million in 2019 and from $54.8 million in 2018. Although there was a significant decline in our client’s activity levels and the Company’s revenue in 2020 caused by the factors indicated above, operating income was less affected as the Company implemented significant cost reductions in 2020, and as a result of reversing previously recognized stock compensation expense for certain employees’ PSAP awards of $7.6 million. See Note 14 - Stock-Based Compensation of the Notes to the Consolidated Financial Statements for further detail. The increased operating income in 2019 from 2018 was primarily due to improved activity levels associated with large projects in international markets. However, the improved operating income for 2019 was partially offset by additional expenses associated with employee severance and other cost reduction initiatives of $4.0 million. Included in both 2019 and 2018 are additional stock compensation expense of $4.7 million in 2019 for retirement eligible employees compared to $6.3 million in 2018. See Note 14 - Stock-Based Compensation of the Notes to the Consolidated Financial Statements for further detail. Operating margins improved to 15.5% in 2020 compared to 13.1% and 13.3% in 2019 and 2018, respectively. Operating margins in 2020 improved due to a significant decrease in costs of services as a result of cost reduction initiatives implemented and the reduction of stock-based compensation expense described above.
Production Enhancement
Revenue for our Production Enhancement segment of $132.2 million in 2020 decreased compared to $247.3 million and $287.8 million in 2019 and 2018, respectively. In 2020, a sharp decrease of drilling and well completion activities in the U.S. onshore market was primarily due to impact of the global pandemic as described above. The U.S. rig count decreased in excess of 50% during 2020 as compared to 2019 and decreased 12% in 2019 when compared to 2018. Our clients continue to seek technological solutions for increasing daily production and estimated ultimate recoveries from their reservoirs and we continue to benefit from our clients’ acceptance of new services and products which were led by the HERO® PerFRAC, GoGunTM, FLOWPROFILER EDSTM and ReFRAC technologies.
Our Production Enhancement segment had operating loss of $133.4 million in 2020 compared to operating income of $38.4 million and $63.0 million in 2019 and 2018, respectively. The operating loss in 2020 was primarily the result of non-cash charges of $122.2 million for impairment of goodwill and certain intangible assets, a charge in excess of $10.0 million for inventory valuation write-down and obsolescence, and severance expense of $2.6 million recorded during the year. This operating loss was partially offset by the benefit of cost reduction initiatives implemented during 2020 and reversal of previously recognized stock compensation expense associated with certain employees’ long term stock-based performance awards of $3.6 million. See Note 14 - Stock-Based Compensation of the Notes to the Consolidated Financial Statements. The decrease in operating income from 2018 to 2019, is primarily due to a decrease in exploration and production activity in the U.S. onshore market over this time period.
Operating margin was negative 101% in 2020, which was the result of a significant decrease in revenue combined with the goodwill impairment, asset impairments and inventory charges recorded as described above. Operating margin for 2020 were breakeven, when excluding the non-cash charges associated with the goodwill impairment, asset impairment and inventory write down. Operating margins in 2019 and 2018 were 15.5% and 21.9%, respectively, and decreased primarily due to lower revenue in 2019.
Liquidity and Capital Resources
General
We have historically financed our activities through cash on hand, cash flows from operations, bank credit facilities, equity financing and the issuance of debt. Cash flows from operating activities provide the primary source of funds to finance operating needs, capital expenditures and our dividend and share repurchase programs. We believe our future cash flows from
operations, supplemented by our borrowing capacity under our Credit Facility and the ability to issue additional equity and debt, should be sufficient to fund our debt requirements, capital expenditures, working capital, dividend payments and future acquisitions. The Company will continue to monitor and evaluate the availability of debt and equity markets.
In response to market conditions, Core Lab’s Supervisory Board approved a plan to reduce the Company’s quarterly dividends to $0.01 per share beginning with the second quarter of 2020 and to focus excess free cash flow on debt reduction. In March 2020, the Company implemented cost reduction initiatives and expanded these initiatives in June 2020, which included: (i) corporate and operating cost reductions; (ii) annual capital expenditures reduced to approximately $12 million, and (iii) eliminating all non-essential costs. The corporate and operating cost reductions included reductions in workforce and reduction of senior executive and employee compensation. Specifically, the Company has reduced senior executives’ annual base salary by 20% for the foreseeable future. On June 22, 2020, also in response to market conditions, we entered into Amendment No. 1 (the “Amendment”) to the Credit Facility. The Amendment provides, among other things, an increase to the maximum leverage ratio permitted under the Credit Facility for certain periods. See Note 9 - Long-Term Debt, Net of the Notes to the Consolidated Financial Statements for additional information. Additionally, on October 16, 2020, the Company entered into an agreement (the “2020 Notes Purchase Agreement”) to issue $60 million in notes (the “2020 Senior Notes”) in a private placement, which were issued and funded at the closing on January 12, 2021. The Company used the net proceeds from the 2020 Senior Notes to reduce outstanding debt under the Company’s Credit Facility, which increased the available borrowing capacity and liquidity for Core Lab. We intend to maintain sufficient borrowing capacity under the Credit Facility to both retire the maturing debt obligations in September 2021, and provide additional liquidity, should the company require it for other purposes. See Note 9 - Long-Term Debt, Net of the Notes to the Consolidated Financial Statements for additional information.
As we are a Netherlands holding company, we conduct substantially all of our operations through subsidiaries. Our cash availability is largely dependent upon the ability of our subsidiaries to pay cash dividends or otherwise distribute or advance funds to us and on the terms and conditions of our existing and future credit arrangements. There are no restrictions preventing any of our subsidiaries from repatriating earnings, and there are no restrictions or income taxes associated with distributing cash to the parent company through loans or advances. As of December 31, 2020, $8.8 million of our $13.8 million of cash was held by our foreign subsidiaries, including the U.S.
Our financial statements are prepared in conformity with generally accepted accounting principles in the U.S. ("U.S. GAAP" or "GAAP"). We utilize the non-GAAP financial measure of free cash flow to evaluate our cash flows and results of operations. Free cash flow is defined as net cash provided by operating activities (which is the most directly comparable GAAP measure) less cash paid for capital expenditures. Management believes that free cash flow provides useful information to investors regarding the cash that was available in the period that was in excess of our needs to fund our capital expenditures and operating activities. Free cash flow is not a measure of operating performance under GAAP, and should not be considered in isolation nor construed as an alternative to operating profit, net income (loss) or cash flows from operating, investing or financing activities, each as determined in accordance with GAAP. Free cash flow does not represent residual cash available for distribution because we may have other non-discretionary expenditures that are not deducted from the measure. Moreover, since free cash flow is not a measure determined in accordance with GAAP and thus is susceptible to varying interpretations and calculations, free cash flow, as presented, may not be comparable to similarly titled measures presented by other companies. The following table reconciles this non-GAAP financial measure to the most directly comparable measure calculated and presented in accordance with U.S. GAAP (in thousands):
For the Years Ended December 31,
Free Cash Flow Calculation
Net cash provided by operating activities
$
57,868
$
89,527
$
111,827
Less: cash paid for capital expenditures
(11,880
)
(22,269
)
(21,741
)
Free cash flow
$
45,988
$
67,258
$
90,086
The decrease in free cash flow in 2020 compared to 2019 was primarily attributable to a decrease in activity levels and cash generated from operations, and cash payments for employee post-retirement benefits funded by previously purchased company-owned life insurance policies, offset by a decrease in working capital and capital spending. The decrease in free cash flow in 2019 compared to 2018 was also due to lower operational activity levels in 2019, but also an increase in working capital and a slight increase in capital expenditures in 2019.
Cash Flows
The following table summarizes cash flows (in thousands):
For the Years Ended December 31,
Cash provided by/(used in):
Operating activities
$
57,868
$
89,527
$
111,827
Investing activities
7,851
(5,677
)
(70,639
)
Financing activities
(63,005
)
(85,874
)
(42,472
)
Net change in cash and cash equivalents
$
2,714
$
(2,024
)
$
(1,284
)
The decreases in cash provided by operating activities in 2020 compared to 2019 was primarily due to significant decreases in activity levels and operating income due to the impact of the COVID-19 and cash payments for employee post-retirement benefits funded by previously purchased company-owned life insurance policies, partially offset by benefits from cost reduction initiatives implemented in 2020 and a decrease in working capital. The decrease in cash provided by operating activities in 2019 compared to 2018 was primarily due to decreased operating income as the activity levels for the U.S. onshore oil and gas market declined.
Cash provided by investing activities was $7.9 million in 2020 compared to cash used in investing activities of $5.7 million in 2019. The increase in cash flows from investing activities in 2020 was primarily due to lower capital expenditures in 2020 of $11.9 million, a decrease of $10.4 million when compared to 2019 capital expenditures, and cash received from company-owned life insurance policies of $20.4 million in 2020, compared to proceeds from the divesture of two businesses totaling $17.8 million in 2019. Cash used in investing activities in 2019 decreased $65.0 million compared to 2018, as 2018 included an acquisition, net of cash, for $47.3 million, and 2019 includes proceeds from the divestiture of two businesses as indicated above.
Cash used in financing activities in 2020 decreased $22.9 million compared to 2019. In 2020, dividends paid were reduced by $85.1 million, of which $46 million were used to repay of debt borrowings, which compares to $15 million provided by proceeds from debt borrowings in 2019. Cash used in financing activities in 2019 increased $43.4 million compared to 2018. During 2019, we used $3.3 million to repurchase our common shares, $97.6 million to pay dividends, and increased our debt balance by $15 million. During 2018, we used $7.5 million to repurchase our common shares, $97.3 million to pay dividends, and increased our debt balance by $64 million, primarily to fund the acquisition of a business in 2018 for $48.9 million.
During 2020, we repurchased 100,929 shares of our common stock for an aggregate amount of $2.8 million, or an average price of $27.68 per share. The repurchase of shares in the open market is at the discretion of management pursuant to shareholder authorization. We regard these treasury shares as a temporary investment which may be used to fund long-term employee stock-based compensation plans or to finance future acquisitions. Under Dutch law and subject to certain Dutch statutory provisions and shareholder approval, we can hold a maximum of 50% of our issued shares in treasury. We currently have shareholder approval to hold 10% of our issued share capital in treasury. On May 20, 2020 at our annual shareholders meeting, our shareholders authorized the extension of our share repurchase program until November 20, 2021 to purchase up to 10% of our issued share capital. We believe this share repurchase program has been beneficial to our shareholders. Our share price has increased from $4.03 per share in 2002, when we began to repurchase shares, to $26.51 per share on December 31, 2020, an increase of 558%.
Credit Facility and Available Future Liquidity
In 2011, we issued two series of senior notes with an aggregate principal amount of $150 million ("2011 Senior Notes") in a private placement transaction. Series A consists of $75 million in aggregate principal amount of notes that bear interest at a fixed rate of 4.01% and are due in full on September 30, 2021. Series B consists of $75 million in aggregate principal amount of notes that bear interest at a fixed rate of 4.11% and are due in full on September 30, 2023. Interest on each series of the 2011 Senior Notes is payable semi-annually on March 30 and September 30.
On June 22, 2020, we entered into the Amendment to the Credit Facility. The Amendment increases the maximum leverage ratio permitted under the Credit Facility for certain periods. Pursuant to the terms of the Amendment, the maximum leverage ratio permitted under the Credit Facility is as follows:
Quarter ending
Maximum leverage ratio permitted
June 30, 2020 up to and including June 30, 2021
3.00
September 30, 2021
2.75
December 31, 2021 and thereafter
2.50
Moreover, the Amendment modified the range of variable interest rates that the Credit Facility may bear to be a range from LIBOR plus 1.500% to LIBOR plus 2.875% and included the addition of a LIBOR floor of 0.50%. The Amendment also reduced the aggregate borrowing commitment under the Credit Facility to $225 million and the amount by which we may elect to increase the facility size, known as the “accordion” feature, to $50 million, subject to the satisfaction of certain conditions. Interest payment terms are variable depending upon the specific type of borrowing under this facility.
Any outstanding balance under the Credit Facility is due on maturity on June 19, 2023. Our available capacity at any point in time is reduced by outstanding borrowings and outstanding letters of credit which totaled $12.9 million, resulting in an available borrowing capacity under the Credit Facility of $101.1 million, at December 31, 2020. In addition to indebtedness under the Credit Facility, we had $6.1 million of outstanding letters of credit and performance guarantees and bonds from other sources as of December 31, 2020.
The Credit Facility remains unsecured, and contains customary representations, warranties, terms and conditions for similar types of facilities. The terms of the Credit Facility and 2011 Senior Notes require us to meet certain covenants, including, but not limited to, an interest coverage ratio (calculated as consolidated EBITDA divided by interest expense) and a leverage ratio (calculated as consolidated net indebtedness divided by consolidated EBITDA), where consolidated EBITDA (as defined in each agreement) and interest expense are calculated using the most recent four fiscal quarters. The Credit Facility and 2011 Senior Notes each include a cross-default provision, whereby a default under one agreement may trigger a default in the other agreement. The Credit Facility has the more restrictive covenants with a minimum interest coverage ratio of 3.0 to 1.0 and permits a maximum leverage ratio as described above. The Credit Facility allows non-cash charges such as impairment of assets, stock compensation and other non-cash charges to be added back in the calculation of consolidated EBITDA. The terms of our Credit Facility also allow us to negotiate in good faith to amend any ratio or requirement to preserve the original intent of the agreement if any change in accounting principles would affect the computation of any financial ratio or covenant of the Credit Facility. In accordance with the terms of the Credit Facility, our leverage ratio is 2.82, and our interest coverage ratio is 6.09, each for the period ended December 31, 2020. We believe that we are in compliance with all covenants contained in our Credit Facility and 2011 Senior Notes. Our parent, Core Laboratories N.V., together with certain of our material, wholly-owned subsidiaries are guarantors or co-borrowers under the Credit Facility and 2011 Senior Notes.
We entered into two interest rate swap agreements for a total notional amount of $50 million to hedge changes in the variable rate interest expense on $50 million of our existing or replacement LIBOR-priced debt. Under the first swap agreement of $25 million, we have fixed the LIBOR portion of the interest rate at 2.50% through August 29, 2024. In February 2020, we entered into the second swap agreement of $25 million, under which we have fixed the LIBOR portion of the interest rate at 1.3% through February 28, 2025. Each swap is measured at fair value and recorded in our consolidated balance sheet as an asset or liability. They are designated and qualify as cash flow hedging instruments and are highly effective. Unrealized losses are deferred to shareholders' equity as a component of accumulated other comprehensive income (loss) and are recognized in income as an increase or decrease to interest expense in the period in which the related cash flows being hedged are recognized in expense On October 16, 2020, we, along with Core Laboratories (U.S.) Interests Holdings, Inc. as issuer, entered into the 2020 Notes Purchase Agreement. The 2020 Senior Notes were issued and funded on January 12, 2021. The Company used the $60 million in proceeds from issuing the 2020 Senior Notes to reduce the outstanding borrowings under the Credit Facility. Series A of the 2020 Senior Notes consists of $45 million in aggregate principal amount that bear interest at a fixed rate of 4.09% and are due in full on January 12, 2026. Series B of the 2020 Senior Notes consists of $15 million in aggregate principal amount that bear interest at a fixed rate of 4.38% and are due in full on January 12, 2028. Interest on each series of the 2020 Senior Notes is payable semi-annually on June 30 and December 30, commencing on June 30, 2021.
The terms of the 2020 Senior Notes require us to meet certain covenants, including, but not limited to, an interest coverage ratio (calculated as consolidated EBITDA divided by interest expense) and a leverage ratio (calculated as consolidated net indebtedness divided by consolidated EBITDA), where consolidated EBITDA (as defined in the 2020 Notes Purchase Agreement) and interest expense are calculated using the most recent four fiscal quarters; and a priority indebtedness ratio (calculated as Priority Indebtedness divided by Consolidated Total Assets (as defined in the 2020 Notes Purchase Agreement.) The financial covenants for the 2020 Notes Purchase Agreement are aligned with the Credit Facility and the associated 2020 Notes Purchase Agreement also allows renegotiation of the ratios in consideration of changes in accounting principles. We along with certain of our material, wholly-owned subsidiaries, are guarantors or co-borrowers under the 2020 Senior Notes.
On December 17, 2020, we entered into an Equity Distribution Agreement with Wells Fargo Securities, LLC for the issuance and sale of up to $60.0 million of our common shares. Under terms of the Equity Distribution Agreement, the sales of our common shares may be made by any method deemed to be an “at-the-market offering” as defined in Rule 415 under the Securities Act of 1933. The Company elects when to issue a placement notice which may, among other sales parameters, specify the number of shares to be sold, the minimum price per share to be accepted, the daily volume of shares that may be sold and the range of dates when shares may be sold. There have been no sales under the agreement as of December 31, 2020, or for the time period from January 1, 2021 through February 5, 2021.
In addition to our repayment commitments under our Credit Facility and our 2011 Senior Notes, we have non-cancellable operating lease arrangements under which we lease office and lab space, machinery, equipment and vehicles.
The following table summarizes our future contractual obligations under these arrangements (in thousands):
Total
Less than
1 year
1-3 Years
3-5 Years
More than
5 Years
Contractual Obligations:
Debt (1)
$
261,000
$
75,000
$
186,000
$
-
$
-
Operating leases (2)
67,545
11,437
18,107
12,167
25,834
Pension (3)
-
-
-
Total contractual obligations
$
329,136
$
87,028
$
204,107
$
12,167
$
25,834
(1) Not included in the above balances are anticipated cash payments for interest of $6.1 million a year for 2020-2021 and cash
payments for interest of $3.1 million a year for 2022-2023 for a total of $18.4 million. Series A 2011 Seniors due in September
2021 are refinanced by the proceeds of the 2020 Senior Notes and the Credit Facility.
(2) Non-cancellable operating lease commitments in accordance to ASC Topic 842 - Leases.
(3) Our Dutch pension plan requires annual employer contributions. Amounts payable in the future will be based on future
workforce factors which cannot be projected beyond one year.
We have no significant purchase commitments or similar obligations outstanding at December 31, 2020. Not included in the table above are uncertain tax positions of $6.3 million that we have accrued for at December 31, 2020, as the amounts and timing of payment, if any, are uncertain. See Note 10 - Income Taxes of the Notes to the Consolidated Financial Statements for further detail of this amount.
At December 31, 2020, we had tax net operating loss carry-forwards in various jurisdictions of $62.3 million. Although we cannot be certain that these operating loss carry-forwards will be utilized, we anticipate that we will have sufficient taxable income in future years to allow us to fully utilize the carry-forwards that are not subject to a valuation allowance as of December 31, 2020. If unused, those carry-forwards which are subject to expiration may expire during the years 2021-2030. During 2020, we have no net operating loss carry-forwards, which carried a full valuation allowance, that expired unused.
We expect our investment in capital expenditures to track client demand for our services and products. Given the uncertain trend in industry activity levels, we have not determined, at this time, the level of investment that will be made in 2021. We will, however, continue to invest to fund the purchase of instrumentation, tools and equipment along with expenditures to replace obsolete or worn-out instrumentation, tools and equipment, to consolidate certain facilities to gain operational efficiencies, and to increase our presence where requested by our clients.
Outlook
The events occurring during 2020 associated with the COVID-19 pandemic and government mandated business shut-downs around the world, home sheltering and social distancing policies have caused a significant decline in the demand for crude oil and associated products. The significant decline in demand has resulted in a significant decline in the price of crude oil, which has also resulted in a high degree of uncertainty about future demand and the future price for crude oil as long as the virus concerns persist. U.S. onshore drilling and completion activity have experienced the most significant impact, as the rig count and completion of wells have declined significantly during 2020 from previous year levels. International activity has also been impacted by disruption to our clients’ operations and a significant decline in the international rig count. Additionally, our clients experienced disruptions from a record number of named tropical weather systems in the Gulf of Mexico during 2020. Although physical damage to Core Lab’s facilities was minor; our clients experienced interruptions of business activity due to pre-storm preparations, offshore facility evacuations, local area flooding, power outages, and post-storm clean-up.
While the full impact of COVID-19 on our business and the long-term worldwide impact still remains unknown, Core Laboratories has continued to operate as an essential business with timely delivery of products and services to our clients during the COVID-19 pandemic. Continued government restrictions, widespread growth in infections, travel restrictions, quarantines, and mandated site closures have led to disruptions in business workflows, which are expected to continue into 2021. These disruptions have primarily been associated with operational workflows stemming from travel, product delivery and installation, as well as suspensions and delays in client projects. We have not experienced any significant disruptions in our supply chain, and do not anticipate significant disruption in our supply chain. We also maintained and refreshed our continuity plan across our global organization to protect the health of employees while servicing clients.
As part of our long-term growth strategy, we continue our efforts to expand our market presence by opening or expanding facilities in strategic areas and realizing synergies within our business lines subject to client demand and market conditions. We
believe our market presence provides us a unique opportunity to service clients who have global operations whether they are international oil companies, national oil companies, or independent oil companies.
Our major clients continue to focus on capital management, return on invested capital (“ROIC”), free cash flow, and returning capital back to their shareholders, as opposed to a heavier focus on growing production. The companies adopting value versus volume metrics tend to be the more technologically sophisticated operators and form the foundation of Core Lab’s worldwide client base. Considering a longer-term strategy, we expect to be well positioned as our clients continue their focus on employing higher technological solutions in their efforts to optimize production and estimated ultimate recovery ("EUR") in the most cost efficient, environmentally responsible, manner. We believe operators will continue to manage their capital spending within reduced budgets and maintain their focus on strengthening their balance sheets and generating positive free cash flow.
International field development spending was impacted by reduced operating budgets in response to declines in demand tied to COVID-19. Reservoir Description continues to work with clients and discuss the progression of longer-term international projects. Longer-term international and offshore projects are expected to continue and are not as susceptible or at-risk due to shorter-term volatility in crude oil commodity price. International and offshore activity are expected to gradually improve as the pandemic abates, but the timing of this improvement remains unclear. Additionally, the reservoir fluids analysis that is performed on projects associated with current producing fields, continues to be critical and will be less affected by lower commodity prices for crude oil. The adverse impact from COVID-19 and the depression of crude-oil prices has resulted in increased uncertainty associated with the activity levels and revenue opportunities from these international and offshore projects, however most of the larger projects, especially the projects that have already been commissioned and are in development, are focused on a longer term forecast versus a short to mid-term assessment of the crude oil commodity prices.
U.S. onshore actively levels were most significantly impacted and reached historically low levels by mid-2020. However, U.S. onshore activity levels began to recover during the second half of the year, although not to the same levels preceding the COVID-19 pandemic. Assuming the situation with the COVID-19 virus improves across the globe and crude oil commodity prices remain at current levels or improve, we believe the U.S. onshore activity will gradually improve during 2021.
In response to market conditions, Core Lab’s Supervisory Board approved a plan to reduce the Company’s quarterly dividends to $0.01 per share beginning with the second quarter of 2020 and to focus excess free cash flows towards the reduction of debt. In March 2020, the Company implemented cost reduction initiatives and expanded these initiatives in June 2020, which included: (i) corporate and operating cost reductions; (ii) annual capital expenditures reduced to approximately $12 million, and (iii) eliminating all non-essential costs. The corporate and operating cost reductions included reductions in workforce and reduction of senior executive and employee compensation. Specifically, the Company has reduced senior executives’ annual base salary by 20% for the foreseeable future. Although activities have declined and remained low in second half of 2020 due to the factors discussed above, this decline has been partially offset by the effectiveness of the Company’s cost control initiatives. Lastly, the net proceeds from the 2020 Senior Notes, issued on January 12, 2021, were used exclusively to reduce outstanding debt and increase liquidity under the Company’s Credit Facility as we work towards our long-term strategy of reducing debt.
Core Lab believes these immediate actions, as well as continued assessment of market conditions, will allow Core Lab, as it has for over 83 years, to navigate through these challenging times. Core Lab remains focused on preserving the quality of service for its clients and producing returns for its shareholders.
Critical Accounting Estimates
The preparation of financial statements in accordance with U.S. GAAP requires us to make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. We evaluate our estimates on an ongoing basis and determine the adequacy of our estimates based on our historical experience and various other assumptions that we believe are reasonable under the circumstances. By nature, these judgments are subject to an inherent degree of uncertainty. We consider an accounting estimate to be critical if it is highly subjective and if changes in the estimate under different assumptions would result in a material impact on our financial condition and results of operations. The following transaction types require significant judgment and, therefore, are considered critical accounting policies as of December 31, 2020.
Income Taxes
Our income tax expense includes income taxes of the Netherlands, the U.S. and other foreign countries as well as local, state and provincial income taxes. We recognize deferred tax assets or liabilities for the differences between the financial statement carrying amount and tax basis of assets and liabilities using enacted tax rates in effect for the years in which the asset is expected to be recovered or the liability is expected to be settled. We estimate the likelihood of the recoverability of our
deferred tax assets (particularly, net operating loss carry-forwards). Any valuation allowance recorded is based on estimates and assumptions of taxable income into the future and a determination is made of the magnitude of deferred tax assets which are more likely than not to be realized. Valuation allowances of our net deferred tax assets aggregated to $6.3 million and $6.2 million at December 31, 2020 and 2019, respectively. If these estimates and related assumptions change in the future, we may be required to record additional valuation allowances against our deferred tax assets and our effective tax rate may increase which could result in a material adverse effect on our financial position, results of operations and cash flows. We have not provided for deferred taxes on the unremitted earnings of certain subsidiaries that we consider to be indefinitely reinvested. Should we make a distribution of the unremitted earnings of these subsidiaries, we may be required to record additional taxes. We record a liability for unrecognized tax benefits resulting from uncertain tax positions taken or expected to be taken in our tax return. We also recognize interest and penalties, if any, related to unrecognized tax benefits in income tax expense.
Long-Lived Assets, Intangibles and Goodwill
Property, plant and equipment are carried at cost less accumulated depreciation. Major renewals and improvements are capitalized while maintenance and repair costs are charged to expense as incurred. They are depreciated using the straight-line method based on their individual estimated useful lives, except for leasehold improvements, which are depreciated over the remaining lease term, if shorter. We estimate the useful lives and salvage values of our assets based on historical data of similar assets. When long-lived assets are sold or retired, the remaining costs and related accumulated depreciation are removed from the accounts and any resulting gain or loss is included in income. These capitalized long-lived assets could become impaired if our operating plans or business environment changes.
Intangible assets, including patents, trademarks and technology, are carried at cost less accumulated amortization. Intangibles with determinable lives are amortized using the straight-line method based on the estimated useful life of the intangible. Intangibles with indeterminable lives, which consist primarily of corporate trade names, are not amortized, but are tested for impairment annually or whenever events or changes in circumstances indicate that impairment is possible. We recorded an impairment charge of $8.2 million for certain intangible assets during the year ended December 31, 2020. We did not record any material impairment charges relating to intangible assets during the years ended December 31, 2019 and 2018.
We review our long-lived assets, including definite-lived intangible and right-of-use assets, for impairment when events or changes in circumstances indicate that their net book value may not be recovered over their remaining service lives. Indicators of possible impairment may include significant declines in activity levels in regions where specific assets or groups of assets are located, extended periods of idle use, declining revenue or cash flow or overall changes in general market conditions.
Whenever possible impairment is indicated, we compare the carrying value of the assets to the sum of the estimated undiscounted future cash flows expected from use, plus salvage value, less the costs of the subsequent disposition of the assets. If impairment is still indicated, we compare the fair value of the assets to the carrying amount, and recognize an impairment loss for the amount by which the carrying value exceeds the fair value. We did not record any material impairment charges relating to our long-lived assets held for use during the years ended December 31, 2020, 2019 and 2018.
We record goodwill as the excess of the purchase price over the fair value of the net assets acquired in acquisitions accounted for under the purchase method of accounting. We test goodwill for impairment annually, or more frequently if circumstances indicate a possible impairment.
We evaluated our goodwill for impairment by comparing the fair value of each of our reporting units, which are our reportable segments, to their net carrying value as of the balance sheet date. We estimated the fair value of each reporting unit using a discounted future cash flow analysis. Estimated future cash flows were based on the Company's best estimate of future performance. Our impairment analysis is both qualitative and quantitative, and includes subjective estimates based on assumptions regarding future revenue growth rates, discount rate and expected margins. If the carrying value of the reporting unit exceeds the fair value determined, an impairment loss is recorded to the extent that the implied fair value of the goodwill of the reporting unit is less than its carrying value. We recorded an impairment charge of $114.0 million for goodwill of one of our reporting units during the year ended December 31, 2020. We did not record impairment charges relating to our goodwill or our indefinite-lived intangible assets during the years ended December 31, 2019 and 2018.
Stock-Based Compensation
We have two stock-based compensation plans, as described in further detail in Note 14 - Stock-Based Compensation of the Notes to the Consolidated Financial Statements. We evaluate the probability that certain of our stock-based plans will meet targets established within the respective agreements and result in the vesting of such awards. For new awards issued and awards modified, repurchased or canceled, the compensation expense is equal to the fair value of the award at the date of the grant and is recognized in the Consolidated Statements of Operations for those awards over the requisite service period of the
award. The fair value is determined by calculating the share price on the date of grant less the discounted value of the expected dividends to be paid over the vesting period.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet financing arrangements such as securitization agreements, liquidity trust vehicles or special purpose entities. As such, we are not materially exposed to any financing, liquidity, market or credit risk that could arise if we had engaged in such financing arrangements.
Forward-Looking Statements
This Form 10-K and the documents incorporated in this Form 10-K by reference contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Exchange Act. These "forward-looking statements" are based on an analysis of currently available competitive, financial and economic data and our operating plans. They are inherently uncertain and investors should recognize that events and actual results could turn out to be significantly different from our expectations. By way of illustration, when used in this document, words such as "anticipate", "believe", "expect", "intend", "estimate", "project", "will", "should", "could", "may", "predict" and similar expressions are intended to identify forward-looking statements. You are cautioned that actual results could differ materially from those anticipated in forward-looking statements. Any forward-looking statements, including statements regarding the intent, belief or current expectations of us or our management, are not guarantees of future performance and involve risks, uncertainties and assumptions about us and the industry in which we operate, including, among other things:
•
our ability to continue to develop or acquire new and useful technology;
•
the realization of anticipated synergies from acquired businesses and future acquisitions;
•
our dependence on one industry, oil and gas, and the impact of commodity prices on the expenditure levels of our clients;
•
competition in the markets we serve;
•
the risks and uncertainties attendant to adverse industry, political, economic and financial market conditions, including stock prices, government regulations, interest rates and credit availability;
•
unsettled political conditions, war, civil unrest, currency controls and governmental actions in the numerous countries in which we operate;
•
changes in the price of oil and natural gas;
•
major outbreak of global pandemic and restricting mobilization of field personnel;
•
weather and seasonal factors;
•
integration of acquired businesses; and
•
the effects of industry consolidation.
Our businesses depend, to a large degree, on the level of spending by oil and gas companies for exploration, development and production activities. Therefore, a sustained increase or decrease in the price of natural gas or oil, which could have a material impact on exploration, development and production activities, could also materially affect our financial position, results of operations and cash flows.
The above description of risks and uncertainties is by no means all-inclusive, but is designed to highlight what we believe are important factors to consider. For a more detailed description of risk factors, please see "Item 1A. Risk Factors" in this Form 10-K and our reports and registration statements filed from time to time with the SEC.
All forward-looking statements in this Form 10-K are based on information available to us on the date of this Form 10-K. We do not intend to update or revise any forward-looking statements that we may make in this Form 10-K or other documents, reports, filings or press releases, whether as a result of new information, future events or otherwise, unless required by law.
Recent Accounting Pronouncements
Pronouncements Adopted in 2019
In February 2016, the FASB issued ASU 2016-02 ("Leases"), which introduces the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous guidance. The new standard establishes a
right-of-use ("ROU") model that requires a lessee to record an ROU asset and a lease liability on the balance sheet for all leases with terms longer than 12 months. In July 2018, the FASB issued ASU 2018-11 ("Targeted Improvements to Leases"), which provides companies with an additional transition method that allows the effects of the adoption of the new standard to be recognized as a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. We elected this optional transition method for adoption. The adoption of this standard on January 1, 2019 had a material impact to our Consolidated Balance Sheet, but not to our Consolidated Statement of Operations or Cash Flows. The most significant impact was the recognition of $77.5 million of ROU assets and liabilities for operating leases, while our accounting for finance leases remained substantially unchanged.
Pronouncements Adopted in 2020
In June 2016, the FASB issued ASU 2016-13 ("Measurement of Credit Losses on Financial Instruments") which replaces the incurred loss impairment methodology in current U.S. GAAP with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The new standard is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. We adopted this standard on January 1, 2020, and there has been no significant impact on our consolidated financial statements or on our accounting policies and processes.
In January 2017, the FASB issued ASU 2017-04 (“Simplifying the Test for Goodwill Impairment”) which eliminates a step in computing the implied fair value of goodwill with a new methodology of an entity performing an annual goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. We adopted this standard on January 1, 2020. The new methodology was applied for the interim goodwill impairment analysis performed upon the triggering event of the COVID-19 pandemic during the three month period ended March 31, 2020, and it did not change the conclusion that goodwill had been impaired. There has been no significant impact on our consolidated financial statements or on our accounting policies and processes as a result of adopting this updated accounting standard.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Market Risk
We are exposed to market risk, which is the potential loss arising from adverse changes in market prices and rates. We do not believe that our exposure to market risks, which are primarily related to interest rate changes, is material.
Interest Rate Risk
We maintain certain debt instruments at a fixed rate whose fair value will fluctuate based on changes in interest rates and market perception of our credit risk. The fair value of our debt at December 31, 2020 and 2019 approximated the book value.
We entered into two interest rate swap agreements for a total notional amount of $50 million to hedge changes in the variable rate interest expense on $50 million of our existing or replacement LIBOR-priced debt. Under the first swap agreement of $25 million, we have fixed the LIBOR portion of the interest rate at 2.50% through August 29, 2024. In February 2020, we entered into the second swap agreement of $25 million, under which we have fixed the LIBOR portion of the interest rate at 1.3% through February 28, 2025. Each swap is measured at fair value and recorded in our consolidated balance sheet as an asset or liability. They are designated and qualify as cash flow hedging instruments and are highly effective. Unrealized losses are deferred to shareholders' equity as a component of accumulated other comprehensive income (loss) and are recognized in income as an increase or decrease to interest expense in the period in which the related cash flows being hedged are recognized in expense.
Our Credit Facility bears interest at variable rates from LIBOR plus 1.500% to a maximum of LIBOR plus 2.875% and includes a LIBOR floor of 0.500%. As a result of the two interest rate swap agreements, we are subject to interest rate risk on debt in excess of $50 million drawn on our Credit Facility. At December 31, 2020, we had an outstanding balance of $111 million. A 10% change in interest rates would not have a material impact on our results of operations or cash flows.
Foreign Currency Risk
We operate in a number of international areas which exposes us to foreign currency exchange rate risk. We do not currently hold or issue forward exchange contracts or other derivative instruments for hedging or speculative purposes (a foreign exchange contract is an agreement to exchange different currencies at a given date and at a specified rate). Foreign exchange gains and losses are the result of fluctuations in the U.S. dollar ("USD") against foreign currencies and are included in other (income) expense in the statements of operations. We recognized foreign exchange losses in countries where the USD weakened against the local currency and we had net monetary liabilities denominated in the local currency, as well as in countries where the USD strengthened against the local currency and we had net monetary assets denominated in the local
currency. We recognized foreign exchange gains in countries where the USD strengthened against the local currency and we had net monetary liabilities denominated in the local currency, as well as in countries where the USD weakened against the local currency and we had net monetary assets denominated in the local currency.
Credit Risk
Our financial instruments that potentially subject us to concentrations of credit risk consist primarily of cash and cash equivalents and accounts receivable. Substantially all cash and cash equivalents are on deposit at commercial banks or investment firms. Our trade receivables are with a variety of domestic, international and national oil and gas companies. Management considers this credit risk to be limited due to the creditworthiness and financial resources of these financial institutions and companies.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
For the financial statements and supplementary data required by this Item 8, see Part IV "Item 15. Exhibits, Financial Statement Schedules."

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

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ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
Our management, under the supervision of and with the participation of our Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures, as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, as of the end of the period covered by this report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in our reports filed or submitted under the Exchange Act is accumulated and communicated to management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based on such evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures were effective as of December 31, 2020 at the reasonable assurance level.
Our management does not expect that our disclosure controls and procedures or our internal control over financial reporting will prevent all errors and all fraud. Further, the design of disclosure controls and internal control over financial reporting must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within a company have been detected.
Management's Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as that term is defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act. Our 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 GAAP.
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.
Our management, under the supervision of and with the participation of our Chief Executive Officer and Chief Financial Officer, conducted an evaluation of our internal control over financial reporting as of December 31, 2020. In making this assessment, management used the criteria set forth in Internal Control − Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this assessment using these criteria, our management determined that our internal control over financial reporting was effective as of December 31, 2020.
The effectiveness of our internal control over financial reporting as of December 31, 2020, has been audited by KPMG LLP, an independent registered public accounting firm, as stated in their report which appears herein.
Changes in Internal Control over Financial Reporting
There was no change in our system of internal control over financial reporting, as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act, during our fiscal quarter ended December 31, 2020 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
None.
PART III
The information required by Part III (Items 10 through 14) is incorporated by reference from our definitive proxy statement (the "2021 Proxy Statement") to be filed in connection with our 2021 annual meeting of shareholders pursuant to Regulation 14A under the Exchange Act. We expect to file our definitive proxy statement with the SEC within 120 days after the close of the year ended December 31, 2020.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Incorporated by reference to the definitive Proxy Statement for the 2021 Annual Meeting of Shareholders.
Core Lab has a Code of Ethics and Corporate Responsibility that applies to all of its directors, officers and employees, including its principal executive, financial and accounting officers, or persons performing similar functions. Core Lab's Code of Ethics and Corporate Responsibility is posted on its website at www.corelab.com/cr/cms/docs/code_of_ethics_and_corporate_ responsibility.pdf.

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ITEM 11. EXECUTIVE COMPENSATION
ITEM 11. EXECUTIVE COMPENSATION
The information set forth under the captions “Compensation Discussion and Analysis,” “Information About our Named Executive Officers and Executive Compensation” in Core Lab's 2021 Proxy Statement is incorporated herein by reference.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
The information under the captions “Ownership of Securities-Security Ownership by Certain Beneficial Owners and Management" and “Compensation Discussion and Analysis-2020 Compensation Program Details” in Core Lab's 2021 Proxy Statement is incorporated herein by reference.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE
The information under the captions “Information About our Supervisory Directors and Director Compensation-Supervisory Director Independence” and “Information About our Supervisory Directors and Director Compensation-Related Person Transactions” in Core Lab's 2021 Proxy Statement is incorporated herein by reference.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
The information under the caption “Information About our Independent Registered Public Accounting Firm” in Core Lab's 2021 Proxy Statement is incorporated herein by reference.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a)
Financial Statements
1. The following reports, financial statements and schedules are filed herewith on the pages indicated:
Page
Reports of Independent Registered Public Accounting Firm-KPMG LLP
Consolidated Balance Sheets as of December 31, 2020 and 2019
Consolidated Statements of Operations for the Years Ended December 31, 2020, 2019 and 2018
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2020, 2019 and 2018
Consolidated Statements of Changes in Equity for the Years Ended December 31, 2020, 2019 and 2018
Consolidated Statements of Cash Flows for the Years Ended December 31, 2020, 2019 and 2018
Notes to the Consolidated Financial Statements
2. Financial Statement Schedule
Schedule II - Valuation and Qualifying Account
(b)
Exhibits
The exhibits listed in the accompanying "Index to Exhibits" are incorporated by reference to the filing indicated or are filed herewith.