RPC INC - Annual Report: 2019 (Form 10-K)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

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For the fiscal year ended December 31, 2019

Commission File No. 1-8726

RPC, INC.

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2801 BUFORD HIGHWAY NE, SUITE 300

ATLANTA, GEORGIA 30329

(404) 321-2140

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

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☒ Yes ◻ No

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. ◻ Yes ☒ No

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

Indicate by check mark whether the registrant has submitted electronically every interactive data file required to be submitted pursuant to Rule 405 of Regulations S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ⌧ No ◻

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

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If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

The aggregate market value of RPC, Inc. Common Stock held by non-affiliates on June 30, 2019, the last business day of the registrant’s most recently completed second fiscal quarter, was $410,695,775 based on the closing price on the New York Stock Exchange on June 28, 2019 of $7.21 per share.

RPC, Inc. had 214,432,084 shares of Common Stock outstanding as of February 14, 2020.

Documents Incorporated by Reference

Portions of the Proxy Statement for the 2020 Annual Meeting of Stockholders of RPC, Inc. are incorporated by reference into Part III, Items 10 through 14 of this report.

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PART I

Throughout this report, we refer to RPC, Inc., together with its subsidiaries, as “we,” “us,” “RPC” or “the Company.”

Forward-Looking Statements

Certain statements made in this report that are not historical facts are “forward-looking statements” under the Private Securities Litigation Reform Act of 1995. Such forward-looking statements may include, without limitation, statements that relate to our business strategy, plans and objectives, and our beliefs and expectations regarding future demand for our equipment and services and other events and conditions that may influence the oilfield services market and our performance in the future. Forward-looking statements made elsewhere in this report include without limitation statements regarding natural gas prices, production levels and drilling activities; our belief that oil-directed drilling will continue to represent the majority of the total drilling rig activity; our belief that the long-term demand outlook for natural gas is favorable and that natural gas-directed drilling will increase over the long-term; our continued belief in the long-term growth opportunities for our business; our expectation to continue to focus on the development of international business opportunities in current and other international markets; our expectations regarding acquisition targets in our industry; our belief that the passing of the proposed ban on hydraulic fracturing would reduce the demand for our services; the adequacy of our insurance coverage; the impact of lawsuits, legal proceedings and claims on our business and financial condition; our belief that industry factors will continue to depress natural gas directed drilling activity during the near-term; our belief that U.S. oilfield activity will have a negative impact on RPC’s revenues and earnings during the near-term; our belief that oil-directed drilling will remain the majority of domestic drilling and that natural gas-directed drilling will remain a low percentage of U.S. domestic drilling in the near-term; our belief that oilfield well completion activity will decline during the near-term; the fact that drilling and completion activities continue to be highly service-intensive and require a large amount of equipment and raw materials carries favorable implications for our activity levels; higher industry efficiencies have caused the market for several oil completion services including pressure pumping to be oversupplied and that this development carries negative consequences for pricing of our services, utilization of our equipment and our financial results during the near-term; our belief that newly acquired and ordered equipment will provide acceptable financial returns when placed in service at high utilization levels; our plans to undertake moderate fleet expansions which will allow us to maintain a strong balance sheet; our belief that declining activity levels may reduce the costs of providing our services and reduce logistical constraints; our expectations about contributions to the defined benefit pension plan in 2020; our ability to fund capital requirements in the future; the estimated amount of our capital expenditures and contractual obligations for future periods; our expectations to resume payments of cash dividends; our expectations regarding the costs of skilled labor and many of the raw materials used in providing our services; estimates made with respect to our critical accounting policies; the effect of new accounting standards; and the effect of the changes in foreign exchange rates on our consolidated results of operations or financial condition.

The words “may,” “will,” “expect,” “believe,” “anticipate,” “project,” “estimate,” and similar expressions generally identify forward-looking statements. Such statements are based on certain assumptions and analyses made by our management in light of its experience and its perception of historical trends, current conditions, expected future developments and other factors it believes to be appropriate. We caution you that such statements are only predictions and not guarantees of future performance and that actual results, developments and business decisions may differ from those envisioned by the forward-looking statements. See “Risk Factors” contained in Item 1A. for a discussion of factors that may cause actual results to differ from our projections.

Item 1. Business

Organization and Overview

RPC is a Delaware corporation originally organized in 1984 as a holding company for several oilfield services companies and is headquartered in Atlanta, Georgia.

RPC provides a broad range of specialized oilfield services and equipment primarily to independent and major oil and gas companies engaged in the exploration, production and development of oil and gas properties throughout the United States, including the southwest, mid-continent, Gulf of Mexico, Rocky Mountain and Appalachian regions, and in selected international markets. RPC acts as a holding company for the following legal entity groupings: Cudd Energy Services, Thru Tubing Solutions and Patterson Services. Selected overhead including centralized support services and regulatory compliance are classified as Corporate. RPC is further organized into Technical Services and Support Services which are its operating segments. As of December 31, 2019, RPC had approximately 2,700 employees.

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Business Segments

RPC manages its business as either services offered on the well site with equipment and personnel (Technical Services) or services and equipment offered off the well site (Support Services). The businesses under Technical Services generate revenues based on equipment, personnel operating the equipment and the materials utilized to provide the service. They are all managed, analyzed and reported based on the similarities of the operational characteristics and costs associated with providing the service. The businesses under Support Services are primarily able to generate revenues through equipment or services offered off the well site. During 2019, approximately four percent of RPC’s consolidated revenues were generated from offshore operations in the U.S. Gulf of Mexico. In 2019, we also estimate that 82 percent of our revenues were related to drilling and production activities for oil, while 18 percent of revenues were related to drilling and production activities for natural gas.

Technical Services include RPC’s oil and gas services that utilize people and equipment to perform value-added completion, production and maintenance services directly to a customer’s well. The demand for these services is generally influenced by customers’ decisions to invest capital toward initiating production in a new oil or natural gas well, improving production flows in an existing formation, or to address well control issues. This operating segment consists primarily of pressure pumping, downhole tools, coiled tubing, snubbing, nitrogen, well control, wireline and fishing. Customers include major multi-national and independent oil and gas producers, and selected nationally owned oil companies. The services offered under Technical Services are high capital and personnel intensive businesses. The common drivers of operational and financial success of these services include diligent equipment maintenance, strong logistical processes, and appropriately trained personnel who function well in a team environment. The Company considers all of these services to be closely integrated oil and gas well servicing businesses, and makes resource allocation and performance assessment decisions based on this operating segment as a whole across these various services. The principal markets for this business segment include the United States, including the southwest, mid-continent, Gulf of Mexico, Rocky Mountain and Appalachian regions, and selected international markets.

Support Services include all of the services that provide (i) equipment offered off the well site without RPC personnel and (ii) services that are provided in support of customer operations off the well site such as classroom and computer training, and other consulting services. The primary drivers of operational success for services and equipment provided off the well site without RPC personnel are offering safe, high quality and in-demand equipment appropriate for the well design characteristics. The drivers of operational success for the other Support Services relate to meeting customer needs off the well site and competitive marketing of such services. The equipment and services offered include rental tools, drill pipe and related tools, pipe handling, pipe inspection and storage services, and oilfield training and consulting services. The demand for these services tends to be influenced primarily by customer drilling-related activity levels. The principal markets for this segment include the United States, including the Gulf of Mexico, mid-continent, Rocky Mountain and Appalachian regions and project work in selected international locations in the last three years, including primarily Canada, Latin America and the Middle East. Customers primarily include domestic operations of independent oil and gas producers and major multi-nationals and selected nationally owned oil companies.

A brief description of the primary services conducted within each of the operating segments follows:

Technical Services

Pressure Pumping. Pressure pumping services, which accounted for 42 percent of 2019 revenues, 55 percent of 2018 revenues and 62 percent of 2017 revenues are provided to customers throughout Texas, and the mid-continent and Rocky Mountain regions of the United States. We primarily provide these services to customers in order to enhance the initial production of hydrocarbons in formations that have low permeability. Pressure pumping services involve using complex, truck or skid-mounted equipment designed and constructed for each specific pumping service offered. The mobility of this equipment permits pressure pumping services to be performed in varying geographic areas. Principal materials utilized in pressure pumping operations include fracturing proppants, acid and bulk chemical additives. Generally, these items are available from several suppliers, and the Company utilizes more than one supplier for each item. Pressure pumping services offered include:

Fracturing — Fracturing services are performed to stimulate production of oil and natural gas by increasing the permeability of a formation. Fracturing is particularly important in shale formations, which have low permeability, and unconventional completion, because the formation containing hydrocarbons is not concentrated in one area and requires multiple fracturing operations. The fracturing process consists of pumping fluid gel and sometimes nitrogen into a cased well at sufficient pressure to fracture the formation at desired locations and depths. Sand, ceramics, or synthetic materials, which are often coated with a material to increase their resistance to crushing, are pumped into the fracture. When the pressure is released at the surface, the fluid gel returns to the well surface, but the proppant remains in the fracture, thus keeping it open so that oil and natural gas can flow through the fracture into the production tubing and ultimately to the well surface. In some cases, fracturing is performed in formations with a high amount of carbonate rock by an acid solution pumped under pressure without a proppant or with small amounts of proppant.

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Acidizing — Acidizing services are also performed to stimulate production of oil and natural gas, but they are used in wells that have undergone formation damage due to the buildup of various materials that block the formation. Acidizing entails pumping large volumes of specially formulated acids into reservoirs to dissolve barriers and enlarge crevices in the formation, thereby eliminating obstacles to the flow of oil and natural gas. Acidizing services can also enhance production in limestone formations. Acid is also frequently used in the beginning of a fracturing operation.

Cementing — Cementing services are used at the completion stage of an oil or natural gas well to seal the wellbore after the casing string has been run. The process of cementing includes developing a cement slurry formulated for a well’s unique characteristics, pumping the cement through the wellbore and into the space between the well casing and well bore, and allowing it to harden. In addition to completion uses, cementing can also be used to seal a lost circulation zone in an existing well, and to plug a well at the end of its life cycle.

Downhole Tools. Thru Tubing Solutions (“TTS”) accounted for 34 percent of 2019 revenues, 25 percent of 2018 revenues and 19 percent of 2017 revenues. TTS provides services and proprietary downhole motors, fishing tools and other specialized downhole tools and processes to operators and service companies in drilling and production operations, including casing perforation and bridge plug drilling at the completion stage of an oil or gas well. The services that TTS provides are especially suited for unconventional drilling and completion activities. TTS’ experience providing reliable tool services allows it to work in a pressurized environment with virtually any coiled tubing unit or snubbing unit.

Coiled Tubing. Coiled tubing services, which accounted for seven percent of revenues in 2019, six percent of revenues in 2018 and seven percent of revenues in 2017, involve the injection of coiled tubing into wells to perform various applications and functions for use principally in well-servicing operations and to facilitate completion of horizontal wells. Coiled tubing is a flexible steel pipe with a diameter of less than four inches manufactured in continuous lengths of thousands of feet and wound or coiled around a large reel. It can be inserted through existing production tubing and used to perform workovers without using a larger, costlier workover rig. Principal advantages of employing coiled tubing in a workover operation include: (i) not having to “shut-in” the well during such operations, (ii) the ability to reel continuous coiled tubing in and out of a well significantly faster than conventional pipe, (iii) the ability to direct fluids into a wellbore with more precision, and (iv) enhanced access to remote or offshore fields due to the smaller size and mobility of a coiled tubing unit compared to a workover rig. Coiled tubing units are also used to support completion activities in directional and horizontal wells. Such completion activities usually require multiple entrances in a wellbore in order to complete multiple fractures during a pressure pumping operation. A coiled tubing unit can accomplish this type of operation because its flexibility allows it to be steered in a direction other than vertical, which is necessary in this type of wellbore. At the same time, the strength of the coiled tubing string allows various types of tools or motors to be conveyed into the well effectively. The uses for coiled tubing in directional and horizontal wells have been enhanced by improved fabrication techniques and higher-diameter coiled tubing which allows coiled tubing units to be used effectively over greater distances, thus allowing them to function in more of the completion activities currently taking place in the U.S. domestic market. There are several manufacturers of flexible steel pipe used in coiled tubing, and the Company believes that its sources of supply are adequate.

Snubbing. Snubbing (also referred to as hydraulic workover services), which accounted for one percent of revenues in 2019, one percent of revenues in 2018 and two percent of revenues in 2017, involves using a hydraulic workover rig that permits an operator to repair damaged casing, production tubing and downhole production equipment in a high-pressure environment. A snubbing unit makes it possible to remove and replace downhole equipment while maintaining pressure on the well. Customers benefit because these operations can be performed without removing the pressure from the well, which stops production and can damage the formation, and because a snubbing unit can perform many applications at a lower cost than other alternatives. Because this service involves a very hazardous process that entails high risk, the snubbing segment of the oil and gas services industry is limited to a relative few operators who have the experience and knowledge required to perform such services safely and efficiently. Increasingly, snubbing units are used for unconventional completions at the outer reaches of long wellbores which cannot be serviced by coiled tubing because coiled tubing has a more limited range than drill pipe conveyed by a snubbing unit.

Nitrogen. Nitrogen accounted for four percent of revenues in 2019, three percent of revenues in 2018 and two percent of revenues in 2017. There are a number of uses for nitrogen, an inert, non-combustible element, in providing services to oilfield customers and industrial users outside of the oilfield. For our oilfield customers, nitrogen can be used to clean drilling and production pipe and displace fluids in various drilling applications. Increasingly, it is used as a displacement medium to increase production in older wells in which production has depleted. It also can be used to create a fire-retardant environment in hazardous blowout situations and as a fracturing medium for our fracturing service. In addition, nitrogen can be complementary to our snubbing and coiled tubing services, because it is a non-corrosive medium and is frequently injected into a well using coiled tubing. Nitrogen is complementary to our pressure pumping service as well, because foam-based nitrogen stimulation is appropriate in certain sensitive formations in which the fluids used in fracturing or acidizing would damage a customer's well.

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For non-oilfield industrial users, nitrogen can be used to purge pipelines and create a non-combustible environment. RPC stores and transports nitrogen and has a number of pumping unit configurations that inject nitrogen in its various applications. Some of these pumping units are set up for use on offshore platforms or inland waters. RPC purchases its nitrogen in liquid form from several suppliers and believes that these sources of supply are adequate.

Well Control. Cudd Energy Services specializes in responding to and controlling oil and gas well emergencies, including blowouts and well fires, domestically and internationally. In connection with these services, Cudd Energy Services, along with Patterson Services, has the capacity to supply the equipment, expertise and personnel necessary to restore affected oil and gas wells to production. During the past several years, the Company has responded to numerous well control situations in the domestic U.S. oilfield and in various international locations.

The Company’s professional firefighting staff has many years of aggregate industry experience in responding to well fires and blowouts. This team of experts responds to well control situations where hydrocarbons are escaping from a wellbore, regardless of whether a fire has occurred. In the most critical situations, there are explosive fires, the destruction of drilling and production facilities, substantial environmental damage and the loss of hundreds of thousands of dollars per day in well operators’ production revenue. Since these events ordinarily arise from equipment failures or human error, it is impossible to predict accurately the timing or scope of this work. Additionally, less critical events frequently occur in connection with the drilling of new wells in high-pressure reservoirs. In these situations, the Company is called upon to supervise and assist in the well control effort so that drilling operations can resume as promptly as safety permits.

Wireline Services. Wireline is classified into two types of services: slick or braided line and electric line. In both, a spooled wire is unwound and lowered into a well, conveying various types of tools or equipment. Slick or braided line services use a non-conductive line primarily for jarring objects into or out of a well, as in fishing or plug-setting operations. Electric line services lower an electrical conductor line into a well allowing the use of electrically-operated tools such as perforators, bridge plugs and logging tools. Wireline services can be an integral part of the plug and abandonment process near the end of the life cycle of a well.

Pump Down Services. Pump down services are an integral part of the well completion process and are critical in multiple-stage, unconventional well completions which use various types of bridge plugs and perforation techniques. Pump down services use fluids and low-capacity pressure pumping equipment, and work in coordination with wireline services, to place completion equipment at the desired location in a well bore. This process is repeated for each stage, moving from the most distant end of the wellbore to the end that is closest to the wellhead.

Fishing. Fishing involves the use of specialized tools and procedures to retrieve lost equipment from a well drilling operation and producing wells. It is a service required by oil and gas operators who have lost equipment in a well. Oil and natural gas production from an affected well typically declines until the lost equipment can be retrieved. In some cases, the Company creates customized tools to perform a fishing operation. The customized tools are maintained by the Company after the particular fishing job for future use if a similar need arises.

Support Services

Rental Tools. Rental tools accounted for four percent of revenues in 2019, three percent of revenues in 2018 and two percent of revenues in 2017. The Company rents specialized equipment for use with onshore and offshore oil and gas well drilling, completion and workover activities. The drilling and subsequent operation of oil and gas wells generally require a variety of equipment. The equipment needed is in large part determined by the geological features of the production zone and the size of the well itself. As a result, operators and drilling contractors often find it more economical to supplement their tool and tubular assets with rental items instead of owning a complete set of assets. The Company’s facilities are strategically located to serve the major staging points for oil and gas activities in Texas, the Gulf of Mexico, mid-continent region, Appalachian region and the Rocky Mountains.

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Patterson Rental Tools offers a broad range of rental tools including:

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Oilfield Pipe Inspection Services, Pipe Management and Pipe Storage. Pipe inspection services include Full Body Electromagnetic and Phased Array Ultrasonic inspection of pipe used in oil and gas wells. These services are provided at both the Company’s inspection facilities and at independent tubular mills in accordance with negotiated sales and/or service contracts. Our customers are major oil companies and steel mills, for which we provide in-house inspection services, inventory management and process control of tubing, casing and drill pipe. Our locations in Channelview, Texas and Morgan City, Louisiana are equipped with large capacity cranes, specially designed forklifts and a computerized inventory system to serve a variety of storage and handling services for both oilfield and non-oilfield customers.

Well Control School. Well Control School provides industry and government accredited training for the oil and gas industry both in the United States and in limited international locations. Well Control School provides training in various formats including conventional classroom training, interactive computer training including training delivered over the internet, and mobile simulator training.

Energy Personnel International. Energy Personnel International provides drilling and production engineers, well site supervisors, project management specialists, and workover and completion specialists on a consulting basis to the oil and gas industry to meet customers’ needs for staff engineering and well site management.

Refer to Note 14 in the Notes to the Consolidated Financial Statements for additional financial information on our business segments.

Industry

United States. RPC provides its services to its domestic customers through a network of facilities strategically located to serve oil and gas drilling and production activities of its customers in Texas, the mid-continent, the southwest, the Gulf of Mexico, the Rocky Mountains and the Appalachian regions. Demand for RPC’s services in the U.S. tends to be extremely volatile and fluctuates with current and projected price levels of oil and natural gas and activity levels in the oil and gas industry. Customer activity levels are influenced by their decisions about capital investment toward the development and production of oil and gas reserves.

Due to aging oilfields and lower-cost sources of oil internationally, the drilling rig count in the U.S. has declined by approximately 83 percent from its peak in 1981. However, due to continuously enhanced rig and other technologies, more wells are drilled during periods of strong industry activity, and these wells are increasingly productive. For these reasons, the domestic production of both oil and natural gas rose to record levels in the fourth quarter of 2019. Oil and gas industry activity levels have historically been volatile, experiencing multiple cycles, including six down cycle troughs between 1981 and 2016, with May 2016 marking the lowest U.S. domestic rig count in U.S. oilfield history. In the current cycle, the rig count peaked late in the fourth quarter of 2018, and by early in the first quarter of 2020, had fallen by approximately 27 percent.

Because of the increased efficiency of drilling rigs, the Company also monitors well completions in the U.S. domestic oilfield. Well completions are particularly important to RPC because the majority of its services are utilized during the completion stage of an oil or gas well’s life cycle, so they are an important indicator of the demand for RPC’s services. As reported by the U.S. Energy Information Administration during the first quarter of 2020, annual well completions fell from a cyclical peak of 21,381 in 2014 to 8,123 in 2016. Between 2016 and 2019, annual well completions increased by 7,684 or 94.6 percent. In spite of the increase in well completions during the past three years, annual well completions in 2019 were 26.1 percent lower than the 2014 cyclical peak.

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The fluctuations in domestic drilling and completions activity since the recent cyclical peak in late 2018 are consistent with the prices of oil and natural gas, global supply and demand for oil and natural gas, the domestic supply of natural gas, capital availability to fund the operations of exploration and production companies, projected near-term economic growth and fluctuations in the value of the U.S. dollar on world currency markets. Following a cyclical peak in the fourth quarter of 2018, the price of oil had fallen by approximately 25 percent as of the first quarter of 2020. Although total world oil production was unchanged in 2019, and production increased slightly during this period, expectations for slowing global economic growth have caused the price of oil to decline.

The average price of natural gas decreased by approximately 19.2 percent during 2019 as compared with 2018 and early in the first quarter of 2020, the price of natural gas was approximately 4.9 percent lower than the price at the end of 2019. RPC does not believe that the current price of natural gas is sufficient to encourage natural gas-directed drilling, and we note that many oil-directed wells produce a great deal of natural gas and natural gas liquids as well. In addition to oil and natural gas, the price of natural gas liquids plays a minor role in determining our customers’ activity levels, since it is produced in many of the shale resource plays which also produce oil, and production of various natural gas liquids has increased to a level comparable to that of natural gas. During 2019 the average price of natural gas liquids decreased by approximately 37.9 percent compared with 2018. Early in the first quarter of 2020, the price of natural gas liquids decreased by approximately 26.1 percent compared to the average price in 2019. During 2019, the declining price of oil began to discourage drilling and production activity as our customers increasingly began to scrutinize their projected financial returns. This scrutiny has increased early in 2020 due to continued lower commodity prices and budget pressure imposed by capital sources. Fluctuations in the prices of these commodities, particularly the price of oil, significantly impact RPC’s financial results.

From 2001 to 2009, gas drilling rigs represented over 80 percent of the drilling rig count. In 2010, the percentage of drilling rigs drilling for natural gas began to decline, and by early in the first quarter of 2015 had fallen to approximately 18 percent of total drilling activity. In absolute terms, the natural gas drilling rig count in the third quarter of 2016 was the lowest natural gas drilling rig count ever recorded. During this time period the natural gas drilling rig count as a percentage of the total rig count remained steady at approximately 18 percent of total drilling, though it declined to approximately 15 percent of total drilling early in 2020. Although U.S. domestic demand for natural gas has increased, and U.S. exports of liquified natural gas have become approximately three percent of U.S. natural gas production, the price of natural gas has fallen in recent years due to increased domestic reserves, productivity of new wells, and high associated natural gas production from oil-directed wells. In spite of these unfavorable near-term dynamics, the long-term demand outlook for natural gas is still favorable because, unlike oil, foreign imports of natural gas do not compete with domestic production to a meaningful degree. In addition, liquified natural gas exports, which began in 2013, have increased tremendously and now account for a meaningful use of U.S. natural gas production. We anticipate that oil-directed drilling will continue to represent the majority of the total drilling rig count for the foreseeable future. We do not believe that natural gas-directed drilling will increase during the near term because of the tremendous productivity of existing natural gas wells, as well as the associated production of natural gas in wells that are directed towards oil drilling. We continue to believe in the long-term growth opportunities for our business due to the continued high demand for hydrocarbons generally and the growing production of oil in the domestic U.S. market in particular.

Unconventional wells generate a higher demand for RPC’s services because they are difficult and costly to complete. They comprise the majority of U.S. domestic drilling and during the fourth quarter of 2019 and early in the first quarter of 2020, have reached a historical high of approximately 95 percent of total drilling. Because they are drilled through a typically narrow and relatively impermeable formation such as shale, they require additional stimulation when they are completed. Also, many of these formations require high pumping rates of stimulation fluids under high pressures, which in turn require a great deal of pressure pumping horsepower on location to complete the well. Furthermore, since they are not drilled in a straight vertical direction from the Earth’s surface, they require tools and drilling mechanisms that are flexible, rather than rigid, and can be steered once they are downhole. Specifically, these types of wells require RPC’s pressure pumping and coiled tubing services, as well as our downhole tools and services.

International.RPC has historically operated in several countries outside of the United States, and international revenues accounted for five percent of RPC’s consolidated revenues in 2019, five percent in 2018 and four percent in 2017. RPC’s allocation of growth capital over the last several years have emphasized domestic rather than international expansion because of higher domestic activity levels and expected financial returns. International revenues increased 61.9 percent in 2019 compared to the prior year primarily due to higher customer activity levels in Algeria and to a lesser extent, Mexico and Pakistan, partially offset by lower activity in Gabon. During 2019, RPC provided downhole motors and tools in Argentina, Canada, Mexico and Oman, as well as rental tools in Pakistan. We also provided snubbing services in Gabon. We continue to focus on the selected development of international opportunities in these and other markets, although we believe that it will continue to be less than ten percent of total revenues in 2020.

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RPC provides services to its international customers through branch locations or wholly owned foreign subsidiaries. The international market is prone to political uncertainties, including the risk of civil unrest and conflicts. However, due to the significant investment requirement and complexity of international projects, customers’ drilling decisions relating to such projects tend to be evaluated and monitored with a longer-term perspective with regard to oil and natural gas pricing, and therefore have the potential to be more stable than most U.S. domestic operations. Additionally, the international market is dominated by major oil companies and national oil companies which tend to have different objectives and more operating stability than the typical independent oil and gas producer in the U.S. Predicting the timing and duration of contract work is not possible. Refer to Note 14 in the Notes to Consolidated Financial Statements for further information on our international operations.

Growth Strategies

RPC’s primary objective is to generate excellent long-term returns on investment through the effective and conservative management of its invested capital to generate strong cash flow. This objective continues to be pursued through strategic investments and opportunities designed to enhance the long-term value of RPC while improving market share, product offerings and the profitability of existing businesses. Growth strategies are focused on selected customers and markets in which we believe there exist opportunities for higher growth, customer and market penetration, or enhanced returns achieved through consolidations or through providing proprietary value-added equipment and services. RPC intends to focus on specific market segments in which it believes that it has a competitive advantage and on potential large customers who have a long-term need for our services in markets in which we operate.

RPC seeks to expand its service capabilities through a combination of internal growth, acquisitions, joint ventures and strategic alliances. Historically, we have found that we generate higher financial returns from organic growth with our services and geographical locations in which we have experience. Because of the fragmented nature of the oil and gas services industry, RPC believes a number of acquisition opportunities exist, and we frequently consider such opportunities. We have consummated relatively few acquisitions, however, due to high seller valuation expectations and the risk of integrating acquired businesses into our existing operations. We will continue to consider the acquisitions of existing businesses but will also continue to maintain a conservative capital structure, which may limit our ability to consummate large transactions.

RPC has a revolving credit facility which can be used to fund working capital requirements. The borrowing base for this credit facility is $125 million less the amount of any outstanding letters of credit. There was no outstanding balance on this credit facility as of December 31, 2019. Our capital structure is more conservative than that of many of our peers.

Customers

Demand for RPC’s services and equipment depends primarily upon the number of oil and natural gas wells being drilled, the depth and drilling conditions of such wells, the number of well completions and the level of production enhancement activity worldwide. RPC’s principal customers consist of major and independent oil and natural gas producing companies. During 2019, RPC provided oilfield services to several hundred customers. Of these customers, there was no customer in 2019 or 2018 that accounted for more than 10 percent of revenues.

Sales are generated by RPC’s sales force and through referrals from existing customers. We monitor closely the financial condition of these customers, their capital expenditure plans, and other indications of their drilling and completion activities. Due to the short lead time between ordering services or equipment and providing services or delivering equipment, there is no significant sales backlog.

Competition

RPC operates in highly competitive areas of the oilfield services industry. We sell our equipment and services in highly competitive markets, and the revenues and earnings generated are affected by changes in prices for our services, fluctuations in the level of customer activity in major markets, general economic conditions and governmental regulation. RPC competes with many large and small oilfield industry competitors, including the largest integrated oilfield services companies. During the oilfield downturn of 2015 and 2016, a number of smaller oilfield services companies as well as several of our publicly traded peers reduced the scope of their operations or became insolvent. During 2017, however, an improving industry environment and the positive outlook on the industry from the financial markets facilitated the formation of new companies and allowed existing companies to expand their operations. RPC believes that these expanded or newly formed companies increased competitive pressures during the near term, since they began to provide services to our existing customers at lower prices, and hired experienced personnel from more established companies such as RPC. Pricing for our services improved significantly during 2017, but began to decline during the fourth quarter of 2017 and throughout 2019. Rising oil and gas production because of completion efficiencies is contributing to competitive pricing. RPC believes that the principal competitive factors in the market areas that it serves are product availability and quality of our equipment and raw materials used to provide our services, service quality, reputation for safety and technical proficiency, and price.

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The oil and gas services industry includes dominant global competitors including, among others, Halliburton Energy Services Group, a division of Halliburton Company, Baker Hughes Company, and Schlumberger Ltd. The industry also includes a number of other publicly traded peers whose operations are more similar to RPC, including Basic Energy Services, Liberty Oilfield Services, Mammoth Energy Services, Inc., NCS Multistage Holdings, Inc., NexTier Oilfield Solutions, Nine Energy Services, Patterson-UTI Energy, Inc., ProPetro Holding Corporation and Superior Energy Services, as well as numerous smaller, locally owned competitors.

Facilities/Equipment

RPC’s equipment consists primarily of oil and gas services equipment used either in servicing customer wells or provided on a rental basis for customer use. Substantially all of this equipment is Company owned. RPC purchases oilfield service equipment from a limited number of manufacturers. These manufacturers may not be able to meet our requests for timely delivery during periods of high demand which may result in delayed deliveries of equipment and higher prices for equipment.

RPC owns and leases regional and district facilities from which its oilfield services are provided to land-based and offshore customers. RPC’s principal executive offices in Atlanta, Georgia are leased. The Company has two primary administrative buildings, one leased facility in The Woodlands, Texas that includes the Company’s operations, engineering, sales and marketing headquarters, and one owned facility in Houma, Louisiana that includes certain administrative functions. RPC believes that its facilities are adequate for its current operations. For additional information with respect to RPC’s lease commitments, see Note 10 of the Notes to Consolidated Financial Statements.

Governmental Regulation

RPC’s business is affected by state, federal and foreign laws and other regulations relating to the oil and gas industry, as well as laws and regulations relating to worker safety and environmental protection. RPC cannot predict the level of enforcement of existing laws and regulations or how such laws and regulations may be interpreted by enforcement agencies or court rulings, whether additional laws and regulations will be adopted, or the effect such changes may have on it, its businesses or financial condition.

In addition, our customers are affected by laws and regulations relating to the exploration and production of natural resources such as oil and natural gas. These regulations are subject to change, and new regulations may curtail or eliminate our customers’ activities. We cannot determine the extent to which new legislation may impact our customers’ activity levels, and ultimately, the demand for our services.

Intellectual Property

RPC uses several patented items in its operations which management believes are important, but are not indispensable, to RPC’s success. Although RPC anticipates seeking patent protection when possible, it relies to a greater extent on the technical expertise and know-how of its personnel to maintain its competitive position.

Availability of Filings

RPC makes available, free of charge, on its website, rpc.net, its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and all amendments to those reports on the same day they are filed with the Securities and Exchange Commission.

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Item 1A. Risk Factors

Demand for our equipment and services is affected by the volatility of oil and natural gas prices.

Oil and natural gas prices affect demand throughout the oil and gas industry, including the demand for our equipment and services. Our business depends in large part on the conditions of the oil and gas industry, and specifically on the capital investments of our customers related to the exploration and production of oil and natural gas. When these capital investments decline, our customers’ demand for our services declines.

The price of oil, a world-wide commodity, is affected by, among other things, the potential of armed conflict in politically unstable areas such as the Middle East as well as the actions of OPEC, an oil cartel which controls approximately 32 percent of global oil production. OPEC’s actions have historically been unpredictable and can contribute to the volatility of the price of oil on the world market.

Although the production sector of the oil and gas industry is less immediately affected by changing prices, and, as a result, less volatile than the exploration sector, producers react to declining oil and gas prices by curtailing capital spending, which would adversely affect our business. A prolonged low level of customer activity in the oil and gas industry adversely affects the demand for our equipment and services and our financial condition and results of operations.

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Reliance upon a large customer may adversely affect our revenues and operating results.

At times our business has had a concentration of one or more major customers. There was no customer that accounted for more than 10 percent of the Company’s revenues in 2019, 2018 or 2017. In addition, there was no customer as of December 31, 2019 or 2018 that accounted for more than 10 percent of accounts receivable. The reliance on a large customer for a significant portion of our total revenues exposes us to the risk that the loss or reduction in revenues from this customer, which could occur unexpectedly, could have a material and disproportionate adverse impact upon our revenues and operating results.

Our concentration of customers in one industry and periodic downturns may impact our overall exposure to credit risk and cause us to experience increased losses for doubtful accounts.

Substantially all of our customers operate in the energy industry. This concentration of customers in one industry may impact our overall exposure to credit risk, either positively or negatively, in that customers may be similarly affected by changes in economic and industry conditions. We perform ongoing credit evaluations of our customers and do not generally require collateral in support of our trade receivables. The periodic downturns that our industry experiences may adversely affect our customers' operations which could cause us to experience increased losses for doubtful accounts.

Our business depends on capital spending by our customers, many of whom rely on outside financing to fund their operations.

Many of our customers rely on their ability to raise equity capital and debt financing from capital markets to fund their operations. Their ability to raise outside capital depends upon, among other things, the availability of capital, near-term operating prospects of oil and gas companies, current and projected prices of oil and natural gas, and relative attractiveness of competing investments for available investment capital. These factors are outside of our control, and in the event our customers cannot continue to raise outside capital to fund their operations, RPC’s financial results would be negatively impacted.

RPC’s success will depend on its key personnel, and the loss of any key personnel may affect its revenues.

RPC’s success will depend to a significant extent on the continued service of key management personnel. The loss or interruption of the services of any senior management personnel or the inability to attract and retain other qualified management, sales, marketing and technical employees could disrupt RPC’s operations and cause a decrease in its revenues and profit margins.

We may be unable to compete in the highly competitive oil and gas industry in the future.

We operate in highly competitive areas of the oilfield services industry. The equipment and services in our industry segments are sold in highly competitive markets, and our revenues and earnings have in the past been affected by changes in competitive prices, fluctuations in the level of activity in major markets and general economic conditions. We compete with the oil and gas industry’s many large and small industry competitors, including the largest integrated oilfield service providers. We believe that the principal competitive factors in the market areas that we serve are product and service quality and availability, reputation for safety, technical proficiency and price. Although we believe that our reputation for safety and quality service is good, we cannot assure you that we will be able to maintain our competitive position.

We may be unable to identify or complete acquisitions.

Acquisitions have been and may continue to be a key element of our business strategy. We cannot assure you that we will be able to identify and acquire acceptable acquisition candidates on terms favorable to us in the future. We may be required to incur substantial indebtedness to finance future acquisitions and also may issue equity securities in connection with such acquisitions. The issuance of additional equity securities could result in significant dilution to our stockholders. We cannot assure you that we will be able to integrate successfully the operations and assets of any acquired business with our own business. Any inability on our part to integrate and manage the growth from acquired businesses could have a material adverse effect on our results of operations and financial condition.

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Our operations are affected by adverse weather conditions.

Our operations are directly affected by the weather conditions in several domestic regions, including the Gulf of Mexico, the Gulf Coast, the mid-continent, the Rocky Mountains and the Appalachian region. Hurricanes and other storms prevalent in the Gulf of Mexico and along the Gulf Coast during certain times of the year may also affect our operations, and severe hurricanes may affect our customers' activities for a period of several years. While the impact of these storms may increase the need for certain of our services over a longer period of time, such storms can also decrease our customers' activities immediately after they occur. Such hurricanes may also affect the prices of oil and natural gas by disrupting supplies in the short term, which may increase demand for our services in geographic areas not damaged by the storms. Prolonged rain, snow or ice in many of our locations may temporarily prevent our crews and equipment from reaching customer work sites. Due to seasonal differences in weather patterns, our crews may operate more days in some periods than others. Accordingly, our operating results may vary from quarter to quarter, depending on the impact of these weather conditions.

Our ability to attract and retain skilled workers may impact growth potential and profitability.

Our ability to be productive and profitable will depend substantially on our ability to attract and retain skilled workers. Our ability to expand our operations is, in part, impacted by our ability to increase our labor force. A significant increase in the wages paid by competing employers could result in a reduction in our skilled labor force, increases in the wage rates paid by us, or both. If either of these events occurred, our capacity and profitability could be diminished, and our growth potential could be impaired.

Our business has potential liability for litigation, personal injury and property damage claims assessments.

Our operations involve the use of heavy equipment and exposure to inherent risks, including blowouts, explosions and fires. If any of these events were to occur, it could result in liability for personal injury and property damage, pollution or other environmental hazards or loss of production. Litigation may arise from a catastrophic occurrence at a location where our equipment and services are used. This litigation could result in large claims for damages. The frequency and severity of such incidents will affect our operating costs, insurability and relationships with customers, employees and regulators. These occurrences could have a material adverse effect on us. We maintain what we believe is prudent insurance protection. We cannot assure you that we will be able to maintain adequate insurance in the future at rates we consider reasonable or that our insurance coverage will be adequate to cover future claims and assessments that may arise.

Our operations may be adversely affected if we are unable to comply with regulations and environmental laws.

Our business is significantly affected by stringent environmental laws and other regulations relating to the oil and gas industry and by changes in such laws and the level of enforcement of such laws. We are unable to predict the level of enforcement of existing laws and regulations, how such laws and regulations may be interpreted by enforcement agencies or court rulings, or whether additional laws and regulations will be adopted. The adoption of laws and regulations curtailing exploration and development of oil and gas fields in our areas of operations for economic, environmental or other policy reasons would adversely affect our operations by limiting demand for our services. We also have potential environmental liabilities with respect to our offshore and onshore operations, and could be liable for cleanup costs, or environmental and natural resource damage due to conduct that was lawful at the time it occurred, but is later ruled to be unlawful. We also may be subject to claims for personal injury and property damage due to the generation of hazardous substances in connection with our operations. We believe that our present operations substantially comply with applicable federal and state pollution control and environmental protection laws and regulations. We also believe that compliance with such laws has had no material adverse effect on our operations to date. However, such environmental laws are changed frequently. We are unable to predict whether environmental laws will, in the future, materially adversely affect our operations and financial condition. Penalties for noncompliance with these laws may include cancellation of permits, fines, and other corrective actions, which would negatively affect our future financial results.

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Compliance with federal and state regulations relating to hydraulic fracturing could increase our operating costs, cause operational delays, and could reduce or eliminate the demand for our pressure pumping services.

RPC’s pressure pumping services are the subject of continuing federal, state and local regulatory oversight. This scrutiny is prompted in part by public concern regarding the potential impact on drinking and ground water and other environmental issues arising from the growing use of hydraulic fracturing. Among these regulatory entities is the White House Council on Environmental Quality, which coordinated a review of hydraulic fracturing practices. In addition, a committee of the United States House of Representatives investigated hydraulic fracturing practices and publicized information regarding the materials used in hydraulic fracturing. The U.S. Environmental Protection Agency (EPA) also conducted a study of the environmental impact of hydraulic fracturing practices, and in 2015, issued a report which concluded that hydraulic fracturing had not caused a measurable impact on drinking water sources in the U.S. This and similar conclusions from similar investigations carry positive implications for our industry. In spite of these favorable empirical data, however, two presidential candidates in one of the major U.S. political parties have stated that they will ban hydraulic fracturing early in their presidential terms, which will begin in the first quarter of 2021. Furthermore, one of those candidates, in his current position as a U.S. senator, introduced a bill during the first quarter of 2020 which, if passed, would commission a study of oil and natural gas wells in the United States and would institute a permanent ban on all hydraulic fracturing by the year 2025. We believe that such a ban, if it occurs, would be less comprehensive than this bill contemplates. One possibility is that the legislation would only impact Federal oil and gas drilling areas, which at the present time represent less than 20 percent of U.S. drilling and completion activities. We are unable to predict the outcome of the 2020 U.S. presidential election, the probability of the passing of the proposed ban on hydraulic fracturing, and the scope of this ban if it is passed. If this or similar legislation is passed, however, we believe that such legislation would reduce the demand for RPC’s hydraulic fracturing services, as well as the other services within RPC’s Technical Segment.

Our international operations could have a material adverse effect on our business.

Our operations in various international markets including, but not limited to, Africa, Canada, Argentina, China, Mexico, Eastern Europe, Latin America and the Middle East are subject to risks. These risks include, but are not limited to, political changes, expropriation, currency restrictions and changes in currency exchange rates, taxes, boycotts and other civil disturbances. The occurrence of any one of these events could have a material adverse effect on our operations.

Our common stock price has been volatile.

Historically, the market price of common stock of companies engaged in the oil and gas services industry has been highly volatile. Likewise, the market price of our common stock has varied significantly in the past.

Our management has a substantial ownership interest, and public stockholders may have no effective voice in the management of the Company.

The Company has elected the “Controlled Corporation” exemption under Section 303A of the New York Stock Exchange (“NYSE”) Listed Company Manual. The Company is a “Controlled Corporation” because a group that includes the Company’s Chairman of the Board, R. Randall Rollins and his brother, Gary W. Rollins, who is also a director of the Company, and certain companies under their control, controls in excess of fifty percent of the Company’s voting power. As a “Controlled Corporation,” the Company need not comply with certain NYSE rules including those requiring a majority of independent directors.

RPC’s executive officers, directors and their affiliates hold directly or through indirect beneficial ownership, in the aggregate, 73 percent of RPC’s outstanding shares of common stock. As a result, these stockholders effectively control the operations of RPC, including the election of directors and approval of significant corporate transactions such as acquisitions and other matters requiring stockholder approval. This concentration of ownership could also have the effect of delaying or preventing a third party from acquiring control over the Company at a premium.

Our management has a substantial ownership interest, and the availability of the Company’s common stock to the investing public may be limited.

The availability of RPC’s common stock to the investing public may be limited to those shares not held by the executive officers, directors and their affiliates, which could negatively impact RPC’s stock trading prices and affect the ability of minority stockholders to sell their shares. Future sales by executive officers, directors and their affiliates of all or a portion of their shares could also negatively affect the trading price of our common stock.

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Provisions in RPC's certificate of incorporation and bylaws may inhibit a takeover of RPC.

RPC’s certificate of incorporation, bylaws and other documents contain provisions including advance notice requirements for stockholder proposals and staggered terms for the Board of Directors. These provisions may make a tender offer, change in control or takeover attempt that is opposed by RPC’s Board of Directors more difficult or expensive.

Some of our equipment and several types of materials used in providing our services are available from a limited number of suppliers.

We purchase equipment provided by a limited number of manufacturers who specialize in oilfield service equipment. During periods of high demand, these manufacturers may not be able to meet our requests for timely delivery, resulting in delayed deliveries of equipment and higher prices for equipment. There are a limited number of suppliers for certain materials used in pressure pumping services, our largest service line. While these materials are generally available, supply disruptions can occur due to factors beyond our control. Such disruptions, delayed deliveries, and higher prices may limit our ability to provide services, or increase the costs of providing services, which could reduce our revenues and profits.

We have used outside financing in prior years to accomplish our growth strategy, and outside financing may become unavailable or may be unfavorable to us.

Our business requires a great deal of capital in order to maintain our equipment and increase our fleet of equipment to expand our operations, and we have access to our credit facility to fund our necessary working capital and equipment requirements. Our credit facility, as amended July 26, 2018, provides a borrowing base of $125 million less the amount of any outstanding letters of credit, and bears interest at a floating rate, which exposes us to market risks as interest rates rise. If our existing capital resources become unavailable, inadequate or unfavorable for purposes of funding our capital requirements, we would need to raise additional funds through alternative debt or equity financings to maintain our equipment and continue our growth. Such additional financing sources may not be available when we need them, or may not be available on favorable terms. If we fund our growth through the issuance of public equity, the holdings of stockholders will be diluted. If capital generated either by cash provided by operating activities or outside financing is not available or sufficient for our needs, we may be unable to maintain our equipment, expand our fleet of equipment, or take advantage of other potentially profitable business opportunities, which could reduce our future revenues and profits.

Our operations are subject to cyber-attacks that could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.

Our operations are increasingly dependent on digital technologies and services. We use these technologies for internal purposes, including data storage, processing and transmissions, as well as in our interactions with customers and suppliers. Digital technologies are subject to the risk of cyber-attacks. If our systems for protecting against cybersecurity risks prove to be insufficient, we could be adversely affected by, among other things, loss of or damage to intellectual property, proprietary or confidential information, or customer, supplier, or employee data, as well as, interruption of our business operations and increased costs required to prevent, respond to, or mitigate cybersecurity attacks. These risks could harm our reputation and our relationships with customers, suppliers, employees and other third parties, and may result in claims against us. These risks could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.

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Item 1B. Unresolved Staff Comments

None.

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Item 2. Properties

RPC owns or leases approximately 100 offices and operating facilities. The Company leases approximately 21,200 square feet of office space in Atlanta, Georgia that serves as its headquarters, a portion of which is allocated and charged to Marine Products Corporation. See “Related Party Transactions” contained in Item 7. As of December 31, 2019, the lease agreement on the headquarters is effective through May 2031. RPC believes its current operating facilities are suitable and adequate to meet current and reasonably anticipated future needs. Descriptions of the major facilities used in our operations are as follows:

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Item 3. Legal Proceedings

RPC is a party to various routine legal proceedings primarily involving commercial claims, workers’ compensation claims and claims for personal injury. RPC insures against these risks to the extent deemed prudent by its management, but no assurance can be given that the nature and amount of such insurance will, in every case, fully indemnify RPC against liabilities arising out of pending and future legal proceedings related to its business activities. While the outcome of these lawsuits, legal proceedings and claims cannot be predicted with certainty, management believes that the outcome of all such proceedings, even if determined adversely, would not have a material adverse effect on RPC’s business or financial condition.

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Item 4. Mine Safety Disclosures

The information required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95.1 to this Form 10-K.

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Item 4A. Information About Our Executive Officers

Each of the executive officers of RPC was elected by the Board of Directors to serve until the Board of Directors’ meeting immediately following the next annual meeting of stockholders or until his earlier removal by the Board of Directors or his resignation. The following table lists the executive officers of RPC and their ages, offices, and terms of office with RPC.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

RPC’s common stock is listed for trading on the New York Stock Exchange under the symbol RES. As of February 14, 2020 there were 214,432,084 shares of common stock outstanding and approximately 13,500 beneficial holders of our common stock.

Issuer Purchases of Equity Securities

Shares repurchased by the Company and affiliated purchases in the fourth quarter of 2019 are outlined below.

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Performance Graph

The following graph shows a five-year comparison of the cumulative total stockholder return based on the performance of the stock of the Company, assuming dividend reinvestment, as compared with both a broad equity market index and an industry or peer group index. The indices included in the following graph are the Russell 2000 Index (“Russell 2000”), the Philadelphia Stock Exchange’s Oil Service Index (“OSX”), and a peer group which includes companies that are considered peers of the Company (the “Peer Group”). The Company has voluntarily chosen to provide both an industry and a peer group index.

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The Company was a component of the Russell 2000 during 2019. The Russell 2000 is a stock index measuring the performance of the small-cap segment of the US equity universe. The components of the index had a weighted average market capitalization in 2019 of $2.5 billion, and a median market capitalization of $821 million. The Russell 2000 was chosen because it represents companies with comparable market capitalizations to the Company, and because the Company is a component of the index. The OSX is a stock index of 15 companies that provide oil drilling and production services, oilfield equipment, support services and geophysical/reservoir services. The Company is not a component of the OSX, but this index was chosen because it represents a large group of companies that provide the same or similar equipment and services as the Company. The companies included in the Peer Group are Weatherford International, Inc., Superior Energy Services, Inc., Patterson-UTI Energy, Inc., and Halliburton Company. The companies included in the Peer Group have been weighted according to each respective issuer's stock market capitalization at the beginning of each year.

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Item 6. Selected Financial Data

The following table summarizes certain selected financial data of the Company. The historical information may not be indicative of the Company’s future results of operations. The information set forth below should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the Consolidated Financial Statements and the notes thereto included elsewhere in this document.

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Statements of Operations Data:

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Overview

The following discussion should be read in conjunction with “Selected Financial Data” and the Consolidated Financial Statements included elsewhere in this document. See also “Forward-Looking Statements” on page 2.

RPC, Inc. (“RPC”) provides a broad range of specialized oilfield services primarily to independent and major oilfield companies engaged in exploration, production and development of oil and gas properties throughout the United States, including the southwest, mid-continent, Gulf of Mexico, Rocky Mountain and Appalachian regions, and in selected international markets. The Company’s revenues and profits are generated by providing equipment and services to customers who operate oil and gas properties and invest capital to drill new wells and enhance production or perform maintenance on existing wells.

Our key business and financial strategies are:

In assessing the outcomes of these strategies and RPC’s financial condition and operating performance, management generally reviews periodic forecast data, monthly actual results, and other similar information. We also consider trends related to certain key financial data, including revenues, utilization of our equipment and personnel, maintenance and repair expenses, pricing for our services and equipment, profit margins, selling, general and administrative expenses, cash flows and the return on our invested capital. Additionally, we compare our trends to those of our peers. We continuously monitor factors that impact current and expected customer activity levels, such as the price of oil and natural gas, changes in pricing for our services and equipment and utilization of our equipment and personnel. Our financial results are affected by geopolitical factors such as political instability in the petroleum-producing regions of the world, overall economic conditions and weather in the United States, the prices of oil and natural gas, and our customers’ drilling and production activities.

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Current industry conditions are characterized by oil prices which have fallen from a cyclical peak of $75 per barrel in the fourth quarter of 2018 to $53 per barrel in the first quarter of 2020. In spite of this significant decrease in the price of oil, the U.S. domestic rig count and well completion counts have not fallen significantly during the fourth quarter of 2019 and into the first quarter of 2020. However, many of our customers indicate that they are curtailing or delaying their drilling and completion plans early in 2020, and we believe that this will have a negative impact on RPC’s revenues and earnings during the near term. One catalyst for the recent decrease in the price of oil relates to global supply and demand for the commodity. Early in 2020, a potential slowdown in economic growth is perceived to be a catalyst for lower oil prices, a factor which is exacerbated by continued growth in oil production, particularly in the United States. RPC believes that oil production in the United States has also become an increasingly important determinant of global oil prices, because the United States grew to be the world’s largest producer of oil during the second quarter of 2016. Following its recent peak, U.S. oil production fell by 25 percent as of the third quarter of 2017. Since that time, however, improving drilling and completion activity have caused U.S. domestic oil production to rise, and as of the most recent monthly reported statistics, current U.S. oil production has increased to a level that is 42 percent higher than the cyclical low production recorded during the third quarter of 2016. During the fourth quarter of 2018, U.S. oil production rose to its highest level on record. We believe that record U.S. oil production is a catalyst for lower oil prices during the near term. Customer activities directed towards natural gas drilling and production have been weak for several years, with the U.S. domestic natural gas rig count during the first quarter of 2017 falling to the lowest level ever recorded. The U.S. domestic natural gas rig count has increased from this historic low but is still low by historical standards. We believe that customer activities directed towards drilling for natural gas has been weak because of the high production of shale-directed natural gas wells, the high amount of natural gas production associated with oil-directed shale wells in the U.S. domestic market, and relatively constant consumption of natural gas in the United States. We believe that these factors will continue to depress natural gas-directed drilling during the near term. From a low of $1.72 per Mcf during the second quarter of 2017, the price of natural gas had risen to $1.95 per Mcf early in the first quarter of 2020. While current natural gas prices are higher than at the recent cyclical trough, we believe that they are still too low to encourage our customers to conduct exploration and production activities directed exclusively towards natural gas.

In 2019, the Company’s strategy of utilizing equipment in unconventional basins has continued. During 2019, we made capital expenditures totaling $250.6 million primarily for new revenue-producing equipment and capitalized maintenance of our existing equipment.

Revenues during 2019 totaled $1.2 billion, a decrease of 29.0 percent compared to 2018 primarily as a result of lower activity levels and lower pricing for certain service lines. Cost of revenues decreased $263.5 million in 2019 compared to the prior year due to lower employment costs, maintenance and repairs expenses, materials and supplies expense and other costs, all of which were driven by lower activity levels. As a percentage of revenues, cost of revenues increased to 75.2 percent in 2019 compared to 68.7 percent in 2018.

Selling, general and administrative expenses as a percentage of revenues increased to 13.8 percent in 2019 compared to 9.8 percent in 2018 due to lower revenues over primarily fixed expenses.

Impairment and other charges were $82.3 million in 2019, primarily due to equipment disposals, closing operating locations and reducing employee staffing.

Loss before income taxes was $113.1 million for 2019 compared to income before income taxes of $221.3 million in 2018. Net loss for 2019 was $87.1 million, or $0.41 loss per share compared to net income of $175.4 million, or $0.82 earnings per share in 2018. Net income in 2019 and 2018 reflect the lower income tax rates as a result of the Tax Cuts and Jobs Act enacted in 2017.

Cash flows from operating activities decreased to $209.1 million in 2019 compared to $389.0 million in 2018 primarily due to lower earnings, partially offset by a favorable changes in working capital. As of December 31, 2019, there were no outstanding borrowings under our credit facility.

Outlook

Drilling activity in the U.S. domestic oilfields, as measured by the rotary drilling rig count, reached a cyclical peak of 1,931 during the third quarter of 2014. Between the third quarter of 2014 and the second quarter of 2016, the drilling rig count fell by 79 percent. During the second quarter of 2016, the U.S. domestic drilling rig count reached the lowest level ever recorded. The principal catalyst for this steep rig count decline was the decrease in the price of oil in the world markets, which began in the third quarter of 2014. The price of oil began to fall at that time due to the perceived oversupply of oil, weak global demand growth, and the strength of the U.S. dollar on world currency markets. During the second quarter of 2016, the price of oil and the U.S. domestic rig count began to increase, and increased steadily throughout the remainder of 2016, 2017 and 2018. At the end of 2019, the U.S. domestic rig count had fallen by approximately 26 percent compared with the end of 2018. RPC monitors rig count efficiencies and well completion trends because the majority of our services are directed toward well completions. Improvements in drilling rig efficiencies have increased the number of potential well completions for a given drilling rig count; therefore, we believe the statistics regarding well completions are more meaningful indicators of the outlook for RPC’s activity levels and revenues. Annual well completions in the U.S. completions

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increased by approximately 30 percent to 14,655 in 2018 compared to 11,277 in 2017, and by approximately seven percent to 15,734 during 2019. However, we believe that U.S. oilfield well completion activity will decline during the near term.

The current and projected prices of oil, natural gas and natural gas liquids are important catalysts for U.S. domestic drilling activity. During the first two quarters of 2016, the prices of oil and natural gas remained at low levels that discouraged our customers from undertaking most of their potential exploration and production activities. The prices of oil and natural gas increased during the third and fourth quarters of 2016, throughout 2017 and continued during 2018. The price of natural gas declined during 2019 and we do not believe that it is at a level that encourages our customers to increase their natural gas directed drilling and production activities. The price of oil began to increase during 2019, and at the end of the fourth quarter of 2019 was approximately 35 percent higher than at the end of the fourth quarter of 2018. The average price of natural gas liquids in 2019 decreased by 19.2 percent compared to the average price for the full year 2018.

The majority of the U.S. domestic rig count remains directed towards oil. At the beginning of 2020, approximately 85 percent of the U.S. domestic rig count was directed towards oil, a slight increase compared to the prior year. We believe that oil-directed drilling will remain the majority of domestic drilling, and that natural gas-directed drilling will remain a low percentage of U.S. domestic drilling in the near term. We believe that this relationship will continue due to relatively low prices for natural gas, high production from existing natural gas wells, and industry projections of limited increases in domestic natural gas demand during the near term.

We continue to monitor the market for our services and the competitive environment. The U.S. domestic rig count had increased sharply since the historical low recorded during the third quarter of 2016 and continuing until the fourth quarter of 2018, though the rig count has declined during 2019. The fact that drilling and completion activities continue to be highly service-intensive and require a large amount of equipment and raw materials carries favorable implications for our activity levels. Furthermore, we note that some wells in the U.S. domestic market have been drilled but not completed. At the end of the fourth quarter of 2019, the number of wells in this category had decreased by approximately ten percent since the beginning of 2019. These moderately positive economic factors are offset by indications from our customers that they intend to reduce drilling and completion activity during 2020 because they are managing their operations to maximize near-term cash flow. Also, during 2018, we began to observe that oilfield completion crews and equipment were providing services with increasing efficiency, and we believe that this higher efficiency has caused the market for several oilfield completion services, including pressure pumping, to become oversupplied. This trend continued during 2019, and we believe that this development carries negative consequences for pricing of our services, utilization of our equipment and our financial results during the near term.

Activity levels and pricing for oilfield services reached a level during 2018 that allowed the industry to maintain its equipment and encouraged oilfield service providers to expand their fleets of revenue-producing equipment and hire additional personnel. The prospect of improved financial returns also provided access to the capital markets and allowed previously insolvent service companies to resume operations and add equipment. As a result, competition increased during 2018. Increased competition and improved service efficiency, coupled with the significant decline in oil prices during the fourth quarter of 2018, became catalysts for lower pricing and activity levels in 2019. RPC expanded the size of its fleet of revenue-producing equipment modestly during 2018 and placed orders in the latter part of 2018 for a small amount of new equipment that was delivered in 2019. The equipment we placed in service in 2018 and 2019 is more powerful and efficient than earlier generations of oilfield service equipment, and we believe that it will produce acceptable financial returns as it is placed in service at high utilization levels. Our consistent response to the near-term potential of lower activity levels and pricing is to undertake moderate fleet expansions which we believe will allow us to maintain a strong balance sheet, even if near-term pricing and activity levels generated by such new equipment are modest.

The negative implications for RPC’s near-term activity levels from low oil prices and increased competition are partially offset by improved availability and lower cost for some of the critical raw materials used in providing RPC’s services. In addition, lower activity levels reduce the cost, and increase the availability of, skilled labor. These factors may reduce the cost of providing RPC’s services and reduce logistical constraints.

The Company recorded impairment and other charges in 2019 of $82.3 million primarily related to equipment disposals, closing operating locations and reducing employee staffing. We made operational decisions resulting in these impairments and other charges because the U.S. oilfield has undergone fundamental changes in the past few years. These changes require equipment which is capable of operating continuously, over long periods of time, and much of our older equipment is not able to fulfill this requirement, no matter how well maintained. We believe that the oilfield will require less pressure pumping equipment in the foreseeable future based on the fact that U.S. oil production has reached record levels while not fully utilizing the pressure pumping capacity that has been available during the period. In addition, we are aware that our customers have been forced to conduct their operations with little or no access to outside capital for the first time in many years, and we assume that this aspect of exploration and production financing will remain in place for the foreseeable future, thereby reducing the volume of future drilling and completion of new wells.

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Results of Operations

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Year Ended December 31, 2019 Compared to Year Ended December 31, 2018

Revenues. Revenues in 2019 decreased $498.6 million or 29.0 percent compared to 2018. The Technical Services segment revenues in 2019 decreased $501.7 million or 30.5 percent compared to the prior year. The decrease is due primarily to lower activity levels and lower pricing in several of our service lines as compared to the prior year. The Support Services segment revenues in 2019 increased $3.1 million or 4.2 percent compared to 2018 due primarily to improved activity levels and pricing in the rental tools service line, which is the largest service line within this segment. Technical Services reported an operating loss of $33.0 million during 2019 compared to a profit of $216.7 million in the prior year, while Support Services reported an operating income of $10.0 million in 2019 compared to $4.6 million in the prior year. The average price of oil decreased 12.5 percent and the average price of natural gas decreased 19.2 percent during 2019 compared to the prior year. The average domestic rig count during 2019 was 8.6 percent lower than 2018. International revenues, which decreased from $90.4 million in 2018 to $64.6 million in 2019, were five percent of consolidated revenues in both 2019 and 2018. International revenues decreased in 2019 primarily due to lower customer activity levels in Argentina and to a lesser extent, Canada and Gabon, partially offset by higher activity in Algeria compared to the prior year. Our international revenues are impacted by the timing of project initiation and their ultimate duration.

Cost of revenues. Cost of revenues in 2019 was $919.6 million compared to $1.2 billion in 2018, a decrease of $22.3 percent due to lower employment costs, maintenance and repair expenses, materials and supplies expense and other costs, all of which were driven by lower activity levels. As a percentage of revenues, cost of revenues increased to 75.2 percent in 2019 compared to 68.7 percent in 2018 primarily due to lower activity levels and more competitive pricing.

Selling, general and administrative expenses. Selling, general and administrative expenses decreased slightly to $168.1 million in 2019 compared to $168.2 million in 2018. Selling, general and administrative expenses as a percentage of revenues increased to 13.8 percent of revenues in 2019 compared to 9.8 percent of revenues in 2018 due to the negative leverage of lower revenues over primarily fixed expenses.

Depreciation and amortization. Depreciation and amortization were $170.4 million in 2019, an increase of $7.3 million, compared to $163.1 million in 2018 due to capital expenditures made during 2019. As a percentage of revenues, depreciation and amortization increased in 2019 compared to 2018 primarily due to lower revenues.

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Impairment and other charges. Impairment and other charges were $82.3 million in 2019, primarily due to equipment disposals, closing operating locations and reducing employee staffing.

Gain on disposition of assets, net. Gain on disposition of assets, net was $3.7 million in 2019 compared to $3.3 million in 2018. The gain on disposition of assets, net is generally comprised of gains or losses related to various property and equipment dispositions or sales to customers of lost or damaged rental equipment.

Other (expense) income, net. Other expense, net was $0.4 million in 2019 compared to other income, net of $9.3 million in 2018. Other income recorded in 2018 includes property insurance proceeds totaling $9.6 million.

Interest expense and interest income. Interest expense was $0.3 million in 2019 compared to $0.5 million in 2018. Interest expense in 2019 and 2018 principally consists of fees on the unused portion of the credit facility. Interest income decreased to $1.9 million in 2019 compared to $2.4 million in 2018 due to lower investable cash balances.

Income tax (benefit) provision. The income tax benefit was $26.0 million in 2019 compared to a provision of $45.9 million in 2018. The effective tax rate was 23.0 percent in 2019 compared to 20.7 percent in 2018. The increase in the effective tax rate in 2019 is due primarily to certain state taxes based on revenues rather than taxable income or losses and unfavorable discrete adjustments in 2019 compared to 2018.

Net (loss) income and diluted (loss) earnings per share. Net loss was $87.1 million in 2019, or $0.41 loss per diluted share, compared to net income of $175.4 million in 2018, or $0.82 earnings per diluted share. This decrease in earnings per share was due to lower profitability as average shares outstanding was essentially unchanged.

Year Ended December 31, 2018 Compared to Year Ended December 31, 2017

Revenues. Revenues in 2018 increased $125.8 million or 7.9 percent compared to 2017. The Technical Services segment revenues in 2018 increased $108.9 million or 7.1 percent compared to the prior year. The increase is due primarily to higher activity levels and improved pricing in a few of our services lines as compared to the prior year. The Support Services segment revenues in 2018 increased $16.9 million or 29.7 percent compared to 2017 due primarily to improved activity levels and pricing in the rental tool service line, which is the largest service line within this segment. Technical Services reported an operating profit of $216.7 million during 2018 compared to $251.5 million in the prior year, while Support Services reported an operating income of $4.6 million in 2018 compared to an operating loss of $12.2 million in the prior year. The average price of oil increased 27.9 percent while the average price of natural gas increased 6.4 percent during 2018 compared to the prior year. The average domestic rig count during 2018 was 17.7 percent higher than 2017. International revenues, which increased from $55.9 million in 2017 to $90.4 million in 2018, were five percent of consolidated revenues in 2018 compared to four percent of consolidated revenues in 2017. International revenues increased primarily due to higher customer activity levels in Argentina and to a lesser extent, Mexico and Pakistan in 2018, partially offset by lower activity in Gabon compared to the prior year. Our international revenues are impacted by the timing of project initiation and their ultimate duration.

Cost of revenues. Cost of revenues in 2018 was $1.2 billion compared to $1.1 billion in 2017, an increase of $132.2 million or 12.6 percent due to higher employment costs, maintenance and repair expenses and other costs, all of which were driven by higher activity levels. As a percentage of revenues, cost of revenues increased to 68.7 percent in 2018 compared to 65.9 percent in 2017.

Selling, general and administrative expenses. Selling, general and administrative expenses increased 5.6 percent to $168.2 million in 2018 compared to $159.2 million in 2017. These expenses increased due to higher salaries and wages expense consistent with higher activity levels as well as an increase in information technology costs. Selling, general and administrative expenses as a percentage of revenues decreased slightly to 9.8 percent of revenues in 2018 compared to 10.0 percent of revenues in 2017 due to the leverage of higher revenues over primarily fixed expenses.

Depreciation and amortization. Depreciation and amortization were $163.1 million in 2018, a decrease of $0.4 million, compared to $163.5 million in 2017 due to lower capital expenditures in the prior year. As a percentage of revenues, depreciation and amortization decreased in 2018 compared to 2017 primarily due to higher revenues.

Gain on disposition of assets, net. Gain on disposition of assets, net was $3.3 million in 2018 compared to $4.5 million in 2017. The decrease is due to the sale of operating equipment related to its oilfield pipe inspection service line during the second quarter of 2017 that did not recur in the current period. The gain on disposition of assets, net is generally comprised of gains or losses related to various property and equipment dispositions or sales to customers of lost or damaged rental equipment.

Other income (expense), net. Other income, net was $9.3 million in 2018 compared to of $5.5 million in 2017. Other income recorded in 2018 includes property insurance proceeds totaling $9.6 million. Income recorded in 2017 included a favorable settlement of $2.0 million associated with the resolution of a sales tax matter, as well as a property insurance proceeds of $1.9 million.

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Interest expense and interest income. Interest expense increased to $0.5 million in 2018 compared to $0.4 million in 2017. Interest expense in 2018 and 2017 principally consists of fees on the unused portion of the credit facility. Interest income increased to $2.4 million in 2018 compared to $1.5 million in 2017 due to higher investable cash balances.

Income tax provision (benefit). The income tax provision was $45.9 million in 2018 compared to $70.3 million in 2017. The effective tax rate was 20.7 percent in 2018 compared to 30.2 percent in 2017. The decrease in the income tax provision for 2018 primarily reflects the decrease in Federal income tax rates from 35 percent to 21 percent as enacted by the 2017 Tax Cuts and Jobs Act.

Net income and diluted earnings per share. Net income was $175.4 million in 2018, or $0.82 earnings per diluted share, compared to $162.5 million in 2017, or $0.75 earnings per diluted share. This improvement in earnings per share was due to higher net income as average shares outstanding was essentially unchanged.

Liquidity and Capital Resources

Cash and Cash Flows

The Company’s cash and cash equivalents were $50.0 million as of December 31, 2019, $116.3 million as of December 31, 2018 and $91.1 million as of December 31, 2017.

The following table sets forth the historical cash flows for the years ended December 31:

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2019

Cash provided by operating activities in 2019 decreased by $179.9 million compared to the prior year. This decrease is due primarily to a decrease in net income (loss) of $262.5 million, the deferred income tax benefit of $22.2 million and gains due to benefit plan financing arrangement in 2018. These decreases were partially offset by a net favorable change in working capital of $24.9 million. The net favorable change in working capital is primarily due to favorable changes of $27.1 million in accounts receivable due to lower activity levels and revenues in the third and fourth quarters of 2019 and $36.6 million in inventories due to lower activity levels. These favorable changes were partially offset by unfavorable working capital changes of $34.5 million in accounts payable and $8.3 million in accrued payroll and related expenses.

Cash used for investing activities in 2019 increased by $16.1 million compared to 2018 primarily because of higher capital expenditures in 2019 and property insurance proceeds in 2018.

Cash used for financing activities in 2019 decreased by $104.5 million primarily as a result of a reduction in cash dividends to common stockholders, partially offset by the lower cost of repurchases of the Company’s shares on both the open market and for taxes related to the vesting of restricted shares.

2018

Cash provided by operating activities in 2018 increased by $255.3 million compared to the prior year. This increase is due primarily to an increase in net income of $12.9 million, net favorable changes in working capital of $196.7 million and the deferred income tax provision of $64.0 million partially offset by gains due to an insurance recovery and a benefit plan financing arrangement. The net favorable change in working capital is primarily due to favorable changes of $262.6 million in accounts receivable due to lower activity levels and revenues in the third and fourth quarters 2018, $4.3 million in accrued expenses and $6.1 million in prepaid expenses/ other current assets. These favorable changes were partially offset by unfavorable working capital changes of $9.3 million in net income taxes receivable/ payable, $9.4 million in inventories, $36.9 million in accounts payable, $11.1 million in accrued state and local taxes and $9.2 million in accrued payroll and related expenses.

Cash used for investing activities in 2018 increased by $115.3 million, compared to 2017, primarily because of higher capital expenditures partially offset by property insurance proceeds.

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Cash used for financing activities in 2018 increased by $74.0 million primarily as a result of increased cash dividends to common stockholders coupled with the higher cost of repurchases of the Company’s shares on the open market and for taxes related to the vesting of restricted shares.

Financial Condition and Liquidity

The Company’s financial condition as of December 31, 2019 remains strong. We believe the liquidity provided by our existing cash and cash equivalents and our overall strong capitalization will provide sufficient liquidity to meet our requirements for at least the next twelve months. The Company currently has a $125 million revolving credit facility that matures in July 2023. The facility contains customary terms and conditions, including restrictions on indebtedness, dividend payments, business combinations and other related items. On July 26, 2018, the Company amended the revolving credit facility to, among other matters, (1) replace the existing minimum tangible net worth covenant, as well as, (2) extend the maturity date of the revolving credit facility to July 26, 2023, (3) eliminate any borrowing base limitations on revolving loans when certain criteria exist, (4) reduce the commitment fees payable by RPC and (5) reduce the letter of credit sublimit from $50 million to $35 million. As of December 31, 2019, RPC had no outstanding borrowings under the revolving credit facility, and letters of credit outstanding relating to self-insurance programs and contract bids totaled $19.5 million; therefore, a total of $105.5 million of the facility was available. For additional information with respect to RPC’s facility, see Note 8 of the Notes to Consolidated Financial Statements included in this report.

The Company’s decisions about the amount of cash to be used for investing and financing purposes are influenced by its capital position, including the expected amount of cash to be provided by operations and access to borrowings under our facility. We believe our liquidity will continue to provide the opportunity to grow our asset base and revenues during periods with positive business conditions and strong customer activity levels. In addition, the Company's decisions about the amount of cash to be used for investing and financing activities may also be influenced by the financial covenants in our credit facility but we do not expect the covenants to restrict our planned activities. The Company is in compliance with these financial covenants.

Cash Requirements

Capital expenditures were $250.6 million in 2019, and we currently expect capital expenditures to be approximately $80 million in 2020. We expect that a majority of these expenditures in 2020 will be directed towards capitalized maintenance of our existing equipment. The actual amount of capital expenditures will depend primarily on equipment maintenance requirements, expansion opportunities, and equipment delivery schedules.

The Company’s Retirement Income Plan, a multiple employer trusteed defined benefit pension plan, provides monthly benefits upon retirement at age 65 to eligible employees. During 2019, the Company did not make any contributions to the plan and does not expect to make any contributions to the plan during 2020.

The Company has a stock buyback program, initially adopted in 1998 and subsequently amended in 2013 and 2018, that authorizes the repurchase of up to 41,578,125 shares. On February 12, 2018, the Board of Directors increased the number of shares authorized for repurchase by 10 million shares. There were 595,585 shares repurchased on the open market by the Company during 2019, and 8,248,184 shares remain available to be repurchased under the current authorization as of December 31, 2019. The Company may repurchase outstanding common shares periodically based on market conditions and our capital allocation strategies considering restrictions under our credit facility. The stock buyback program does not have a predetermined expiration date.

The Company recorded impairment and other charges of $82.3 million during 2019, of which $8.7 million is expected to have a cash impact during 2020.

On July 22, 2019, the Board of Directors voted to suspend RPC’s dividend to common stockholders. The Company expects to resume cash dividends to common stockholders, subject to the earnings and financial condition of the Company and other relevant factors. The Company has no timetable for the resumption of dividends.

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Contractual Obligations

The Company’s obligations and commitments that require future payments include our credit facility, certain non-cancelable operating leases, purchase obligations and other long-term liabilities. The following table summarizes the Company’s significant contractual obligations as of December 31, 2019:

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Fair Value Measurements

The Company’s assets and liabilities measured at fair value are classified in the fair value hierarchy (Level 1, 2 or 3) based on the inputs used for valuation. Assets and liabilities that are traded on an exchange with a quoted price are classified as Level 1. Assets and liabilities that are valued using significant observable inputs in addition to quoted market prices are classified as Level 2. The Company currently has no assets or liabilities measured on a recurring basis that are valued using unobservable inputs and therefore no assets or liabilities measured on a recurring basis are classified as Level 3. For defined benefit plan and Supplemental Executive Retirement Plan (“SERP”) investments measured at net asset value, the values are computed using inputs such as cost, discounted future cash flows, independent appraisals and market based comparable data or on net asset values calculated by the fund when not publicly available.

Inflation

The Company purchases its equipment and materials from suppliers who provide competitive prices, and employs skilled workers from competitive labor markets. If inflation in the general economy increases, the Company’s costs for equipment, materials and labor could increase as well. In addition, increases in activity in the domestic oilfield can cause upward wage pressures in the labor markets from which it hires employees, especially if employment in the general economy increases. Also, activity increases can cause increases in the costs of certain materials and key equipment components used to provide services to the Company’s customers. When oilfield activity began to increase in the third quarter of 2016, the Company experienced upward pressure on the price of labor due to the shortage of skilled employees as well as occasional increases in the prices of certain raw materials used in providing our services. During 2018, however, prices for the raw material comprising the Company’s single largest raw material purchase began to decline due to increased sources of supply of the material, particularly in geographic markets located close to the largest U.S. oil and gas basin. In addition, labor cost pressures during the fourth quarter of 2018 began to abate due to lower oilfield activity. These cost pressures continued to decline during 2019.

Off Balance Sheet Arrangements

The Company does not have any material off balance sheet arrangements.

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Related Party Transactions

Marine Products Corporation

Effective in 2001, the Company spun off the business conducted through Chaparral Boats, Inc. (“Chaparral”), RPC’s former powerboat manufacturing segment. RPC accomplished the spin-off by contributing 100 percent of the issued and outstanding stock of Chaparral to Marine Products Corporation (a Delaware corporation) (“Marine Products”), a newly formed wholly owned subsidiary of RPC, and then distributing the common stock of Marine Products to RPC stockholders. In conjunction with the spin-off, RPC and Marine Products entered into various agreements that define the companies’ relationship.

In accordance with a Transition Support Services agreement, which may be terminated by either party, RPC provides certain administrative services, including financial reporting and income tax administration, acquisition assistance, etc., to Marine Products. Charges from the Company (or from corporations that are subsidiaries of the Company) for such services were $865,000 in 2019, $873,000 in 2018, and $849,000 in 2017. The Company’s receivable due from Marine Products for these services was $55,000 as of December 31, 2019 and $28,000 as of December 31, 2018. Many of the Company’s directors are also directors of Marine Products and all of the executive officers are employees of both the Company and Marine Products.

Other

The Company periodically purchases in the ordinary course of business equipment or services from suppliers, who are owned by significant officers or stockholders, or affiliated with the directors of RPC. The total amounts paid to these affiliated parties were $1,625,000 in 2019, $1,467,000 in 2018 and $1,372,000 in 2017.

RPC receives certain administrative services and rents office space from Rollins, Inc. (a company of which Mr. R. Randall Rollins is also Chairman and which is otherwise affiliated with RPC). The service agreements between Rollins, Inc. and the Company provide for the provision of services on a cost reimbursement basis and are terminable on six months’ notice. The services covered by these agreements include office space, administration of certain employee benefit programs, and other administrative services. Charges to the Company (or to corporations which are subsidiaries of the Company) for such services and rent totaled $104,000 in 2019, $101,000 in 2018 and $104,000 in 2017.

A group that includes the Company’s Chairman of the Board, R. Randall Rollins and his brother Gary W. Rollins, who is also a director of the Company, and certain companies under their control, controls in excess of fifty percent of the Company’s voting power.

RPC and Marine Products own 50 percent each of a limited liability company called 255 RC, LLC that was created for the joint purchase and ownership of a corporate aircraft. The purchase of the aircraft was completed in January 2015, and the purchase was funded primarily by a $2,554,000 contribution by each company to 255 RC, LLC. Each of RPC and Marine Products is currently a party to an operating lease agreement with 255 RC, LLC for a period of five years. RPC recorded certain net operating costs comprised of rent and an allocable share of fixed costs of $199,000 in 2019 and 2018 and $197,000 in 2017 for the corporate aircraft. The Company has a payable to 255 RC, LLC of $1.0 million as of December 31, 2019 and $0.8 million as of December 31, 2018. The Company accounts for this investment using the equity method and its proportionate share of income or loss is recorded in selling, general and administrative expenses. As of December 31, 2019, the investment closely approximates the underlying equity in the net assets of 255 RC, LLC.

Critical Accounting Policies

The consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States, which require significant judgment by management in selecting the appropriate assumptions for calculating accounting estimates. These judgments are based on our historical experience, terms of existing contracts, trends in the industry, and information available from other outside sources, as appropriate. Senior management has discussed the development, selection and disclosure of its critical accounting estimates with the Audit Committee of our Board of Directors. The Company believes the following critical accounting policies involve estimates that require a higher degree of judgment and complexity:

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Allowance for doubtful accounts — Substantially all of the Company’s receivables are due from oil and gas exploration and production companies in the United States, selected international locations and foreign, nationally owned oil companies. Our allowance for doubtful accounts is determined using a combination of factors to ensure that our receivables are not overstated due to uncollectibility. Our established credit evaluation procedures seek to minimize the amount of business we conduct with higher risk customers. Our customers’ ability to pay is directly related to their ability to generate cash flow on their projects and is significantly affected by the volatility in the price of oil and natural gas. Provisions for doubtful accounts are recorded in selling, general and administrative expenses. Accounts are written off against the allowance for doubtful accounts when the Company determines that amounts are uncollectible and recoveries of amounts previously written off are recorded when collected. Significant recoveries will generally reduce the required provision in the period of recovery. Therefore, the provision for doubtful accounts can fluctuate significantly from period to period. Recoveries were insignificant in 2019, 2018 and 2017. We record specific provisions when we become aware of a customer's inability to meet its financial obligations to us, such as in the case of bankruptcy filings or deterioration in the customer's operating results or financial position. If circumstances related to a customer changes, our estimate of the realizability of the receivable would be further adjusted, either upward or downward.

The estimated allowance for doubtful accounts is based on our evaluation of the overall trends in the oil and gas industry, financial condition of our customers, our historical write-off experience, current economic conditions, and in the case of international customers, our judgments about the economic and political environment of the related country and region. In addition to reserves established for specific customers, we establish general reserves by using different percentages depending on the age of the receivables which we adjust periodically based on management judgment and the economic strength of our customers. The net provisions for doubtful accounts as a percentage of revenues ranged from 0.03 percent to 0.8 percent over the last three years. Increasing or decreasing the estimated general reserve percentages by 0.50 percentage points as of December 31, 2019 would have resulted in a change of $1.1 million to the allowance for doubtful accounts and a corresponding change to selling, general and administrative expenses.

Income taxes — The effective income tax benefits were 23.0 percent in 2019, compared to an income tax provision of 20.7 percent in 2018 and 30.2 percent in 2017. Our effective tax rates vary due to changes in estimates of our future taxable income or losses, fluctuations in the tax jurisdictions in which our earnings and deductions are realized, and favorable or unfavorable adjustments to our estimated tax liabilities related to proposed or probable assessments. As a result, our effective tax rate may fluctuate significantly on a quarterly or annual basis. The effective tax rate for 2019 reflects the decrease in favorable discrete adjustments, along with a higher percentage of permanent adjustments compared to income (loss).

The Company establishes a valuation allowance against the carrying value of deferred tax assets when it is determined that it is more likely than not that the asset will not be realized through future taxable income. Such amounts are charged to earnings in the period the determination is made. Likewise, if we later determine that it is more likely than not that the net deferred tax assets would be realized, the applicable portion of the previously provided valuation allowance is reversed. The Company considers future market growth, forecasted earnings, future taxable income, the mix of earnings in the jurisdictions in which the Company operates, and prudent and feasible tax planning strategies in determining the need for a valuation allowance.

The Company calculates the current and deferred tax provision based on estimates and assumptions that could differ from the actual results reflected in income tax returns filed during the subsequent year. Adjustments based on filed returns are recorded when identified, which is generally in the third quarter of the subsequent year for U.S. federal and state provisions. Deferred tax liabilities and assets are determined based on the differences between the financial and tax bases of assets and liabilities using enacted tax rates in effect in the year the differences are expected to reverse. In 2017, the Company revalued its deferred tax assets and liabilities to reflect the change in Federal income tax rates, as required by the TCJA. All deferred tax assets and liabilities from December 31, 2017 forward reflect the changed rate.

The amount of income taxes we pay is subject to ongoing audits by federal, state and foreign tax authorities, which may result in proposed assessments. Our estimate for the potential outcome for any uncertain tax issue is highly judgmental. The Company believes it has adequately provided for any reasonably foreseeable outcome related to these matters. However, our future results may include favorable or unfavorable adjustments to estimated tax liabilities in the period the assessments are made or resolved or when statutes of limitation on potential assessments expire. Additionally, the jurisdictions in which our earnings or deductions are realized may differ from our current estimates.

Insurance expenses —The Company self-insures, up to certain policy-specified limits, certain risks related to general liability, workers’ compensation, vehicle and equipment liability. The cost of claims under these self-insurance programs is estimated and accrued using individual case-based valuations and statistical analysis and is based upon judgment and historical experience; however, the ultimate cost of many of these claims may not be known for several years. These claims are monitored and the cost estimates are revised as developments occur relating to such claims. The Company has retained an independent third party actuary to assist in the calculation of a range of exposure for these claims. As of December 31, 2019, the Company estimates the range of exposure to be from $19.0 million to $24.2 million. The Company has recorded liabilities at December 31, 2019 of $21.6 million which represents management’s best estimate of probable loss.

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Depreciable life of assets — RPC’s net property, plant and equipment at December 31, 2019 was $516.7 million representing 49.1 percent of the Company’s consolidated assets. Depreciation and amortization expense for the year ended December 31, 2019 was $170.4 million. Management judgment is required in the determination of the estimated useful lives used to calculate the annual and accumulated depreciation and amortization expense.

Property, plant and equipment are reported at cost less accumulated depreciation and amortization, which is provided on a straight-line basis over the estimated useful lives of the assets. The estimated useful life represents the projected period of time that the asset will be productively employed by the Company and is determined by management based on many factors including historical experience with similar assets. Assets are monitored to ensure changes in asset lives are identified and prospective depreciation and amortization expense is adjusted accordingly. We did not make any changes to the estimated lives of assets resulting in a material impact in 2019 or 2018.

Long-lived assets including goodwill — RPC carries a variety of long-lived assets on our balance sheet including property, plant and equipment and goodwill. Impairment is the condition that exists when the carrying amount of a long-lived asset exceeds its fair value. Goodwill is the excess of the cost of an acquired entity over the net of the amounts assigned to assets acquired and liabilities assumed. The Company conducts impairment tests on goodwill annually, during the fourth quarter, or more frequently if events or changes in circumstances indicate an impairment may exist. In addition, the Company conducts impairment tests on long-lived assets, other than goodwill, whenever events or changes in circumstances indicate that the carrying value may not be recoverable.

For the impairment testing on long-lived assets, other than goodwill, a long-lived asset is grouped at the lowest level for which identifiable cash flows are largely independent of the cash flows of other assets and liabilities. Estimated future undiscounted cash flows expected to result from the use and eventual disposition of the asset group are compared to its carrying amount. If the undiscounted cash flows are less than the asset group's carrying amount, then the Company is required to determine the asset group's fair value by using a discounted cash flow analysis. This analysis is based on estimates such as management's short-term and long-term forecast of operating performance, including revenue growth rates and expected profitability margins, estimates of the remaining useful life and service potential of the assets within the asset group, and a discount rate based on weighted average cost of capital. An impairment loss is measured and recorded as the amount by which the asset group's carrying amount exceeds its fair value. Assessment of goodwill impairment is conducted at the level of each reporting unit, which is the same as our reportable segments, Technical Services and Support Services, comparing the estimated fair value of each reporting unit to the reporting unit's carrying value, including goodwill. The fair value of each reporting unit is estimated using an income approach and a market approach. The income approach uses discounted cash flow analysis based on management's short-term and long-term forecast of operating performance. This analysis includes significant assumptions regarding discount rates, revenue growth rates, expected profitability margins, forecasted capital expenditures and the timing of expected future cash flows based on market conditions. If the estimated fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered impaired. If the carrying amount of a reporting unit exceeds its estimated fair value, an impairment loss is measured and recorded.

The impairment assessments discussed above incorporate inherent uncertainties, including projected commodity pricing, supply and demand for the Company's services and future market conditions, which are difficult to predict in volatile economic environments and could result in impairment charges in future periods if actual results materially differ from the estimated assumptions utilized in our forecasts. If market conditions further deteriorate, including crude oil prices significantly declining and remaining at low levels for a sustained period of time, we could be required to record additional impairments of the carrying value of our long-lived assets in the future which could have a material adverse impact on our operating results.

Defined benefit pension plan – In 2002, the Company ceased all future benefit accruals under the defined benefit plan, although the Company remains obligated to provide employees benefits earned through March 2002. The Company accounts for the defined benefit plan in accordance with the provisions of Financial Accounting Standards Board (FASB) ASC 715, “Compensation – Retirement Benefits” and engages an outside actuary to calculate its obligations and costs. With the assistance of the actuary, the Company evaluates the significant assumptions used on a periodic basis including the estimated future return on plan assets, the discount rate, and other factors, and makes adjustments to these liabilities as necessary.

The Company chooses an expected rate of return on plan assets based on historical results for similar allocations among asset classes, the investments strategy, and the views of our investment advisor. Differences between the expected long-term return on plan assets and the actual return are amortized over future years. Therefore, the net deferral of past asset gains (losses) ultimately affects future pension expense. The Company’s assumption for the expected return on plan assets was seven percent for 2019, 2018 and 2017.

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The discount rate reflects the current rate at which the pension liabilities could be effectively settled at the end of the year. In estimating this rate, the Company utilizes a yield curve approach. The approach utilizes an economic model whereby the Company’s expected benefit payments over the life of the plan are forecasted and then compared to a portfolio of investment grade corporate bonds that will mature at the same time that the benefit payments are due in any given year. The economic model then calculates the one discount rate to apply to all benefit payments over the life of the plan which will result in the same total lump sum as the payments from the corporate bonds. A lower discount rate increases the present value of benefit obligations. The discount rate was 3.60 percent as of December 31, 2019 compared to 4.65 percent as of December 31, 2018 and 4.00 percent in 2017.

As set forth in Note 12 to the Company’s financial statements, included among the asset categories for the Plan’s investments are real estate and alternative/ opportunistic/ special fund investments comprised of real estate funds and private equity funds. These investments are measured at net asset value and are valued using significant non-observable inputs which do not have a readily determinable fair value. These valuations are subject to judgments and assumptions of the funds which may prove to be incorrect, resulting in risks of incorrect valuation of these investments. The Company seeks to mitigate these risks by evaluating the appropriateness of the funds’ judgments and assumptions by reviewing the financial data included in the funds’ financial statements for reasonableness.

As of December 31, 2019, the defined benefit plan was under-funded and the recorded change within accumulated other comprehensive loss decreased stockholders’ equity by $3.0 million after tax. Holding all other factors constant, a change in the discount rate used to measure plan liabilities by 0.25 percentage points would result in a pre-tax increase or decrease of $1.3 million to the net loss related to pension reflected in accumulated other comprehensive loss.

The Company recognized pre-tax pension expense (income) of $0.3 million in 2019, $(0.2) million in 2018 and $0.4 million in 2017. Based on the under-funded status of the defined benefit plan as of December 31, 2019, the Company expects to recognize pension income of $15 thousand in 2020. Holding all other factors constant, a change in the expected long-term rate of return on plan assets by 0.50 percentage points would result in an increase or decrease in pension expense of $194 thousand in 2020. Holding all other factors constant, a change in the discount rate used to measure plan liabilities by 0.25 percentage points would result in an increase or decrease in pension expense of $19 thousand in 2020.

Recent Accounting Pronouncements

The Financial Accounting Standards Board (FASB) issued the following applicable Accounting Standards Updates (ASU):

Recently Adopted Accounting Standards:

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Recently Issued Accounting Standards Not Yet Adopted:

To be adopted in 2020 and later:

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Item 7A. Quantitative and Qualitative Disclosures about Market Risk

The Company is subject to interest rate risk exposure through borrowings on its revolving credit facility. As of December 31, 2019, there are no outstanding interest-bearing advances on our credit facility which bear interest at a floating rate.

Additionally, the Company is exposed to market risk resulting from changes in foreign exchange rates. However, since the majority of the Company’s transactions occur in U.S. currency, this risk is not expected to have a material effect on its consolidated results of operations or financial condition.

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MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

To the Stockholders of RPC, Inc.:

The management of RPC, Inc. is responsible for establishing and maintaining adequate internal control over financial reporting for the Company. RPC, Inc. maintains a system of internal accounting controls designed to provide reasonable assurance, at a reasonable cost, that assets are safeguarded against loss or unauthorized use and that the financial records are adequate and can be relied upon to produce financial statements in accordance with accounting principles generally accepted in the United States of America. The internal control system is augmented by written policies and procedures, an internal audit program and the selection and training of qualified personnel. This system includes policies that require adherence to ethical business standards and compliance with all applicable laws and regulations.

There are inherent limitations to the effectiveness of any controls system. A controls system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the objectives of the controls system are met. Also, no evaluation of controls can provide absolute assurance that all control issues and any instances of fraud, if any, within the Company will be detected. Further, the design of a controls system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. The Company intends to continually improve and refine its internal controls.

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of the design and operations of our internal control over financial reporting as of December 31, 2019 based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on this evaluation, management’s assessment is that RPC, Inc. maintained effective internal control over financial reporting as of December 31, 2019.

The independent registered public accounting firm, Grant Thornton LLP, has audited the consolidated financial statements as of and for the year ended December 31, 2019, and has also issued their report on the effectiveness of the Company’s internal control over financial reporting, included in this report on page 33.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

Board of Directors and Stockholders

RPC, Inc.

Opinion on internal control over financial reporting

We have audited the internal control over financial reporting of RPC, Inc. (a Delaware corporation) and subsidiaries (the “Company”) as of December 31, 2019, based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019, based on criteria established in the 2013 Internal Control—Integrated Framework issued by COSO.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the consolidated financial statements of the Company as of and for the year ended December 31, 2019, and our report dated February 28, 2020 expressed an unqualified opinion on those financial statements.

Basis for opinion

The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

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

Definition and limitations of internal control over financial reporting

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

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

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

Board of Directors and Stockholders

RPC, Inc.

Opinion on the financial statements

We have audited the accompanying consolidated balance sheets of RPC, Inc. (a Delaware corporation) and subsidiaries (the “Company”) as of December 31, 2019 and 2018, the related consolidated statements of operations, comprehensive income (loss), stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2019, and the related notes and financial statement schedule included under Item 15(2) (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the Company’s internal control over financial reporting as of December 31, 2019, based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”), and our report dated February 28, 2020 expressed an unqualified opinion.

Change in accounting principle

As discussed in Note 1 to the consolidated financial statements, the Company has changed its method of accounting for leases as of January 1, 2019, due to the adoption of Accounting Standards Codification Topic 842, Leases.

Basis for opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

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Item 8. Financial Statements and Supplementary Data

CONSOLIDATED BALANCE SHEETS

RPC, INC. AND SUBSIDIARIES

(in thousands except share information)

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The accompanying notes are an integral part of these statements.

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CONSOLIDATED STATEMENTS OF OPERATIONS

RPC, INC. AND SUBSIDIARIES

(in thousands except per share data)

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The accompanying notes are an integral part of these statements.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

RPC, INC. AND SUBSIDIARIES

(in thousands except per share data)

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The accompanying notes are an integral part of these statements.

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CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

RPC, INC. AND SUBSIDIARIES

(in thousands)

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