RPC INC - Annual Report: 2015 (Form 10-K)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

(Mark One)

For the fiscal year ended December 31, 2015

Commission File No. 1-8726

RPC, INC.

2801 BUFORD HIGHWAY NE, SUITE 520

ATLANTA, GEORGIA 30329

(404) 321-2140

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

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.

x 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 x 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 x No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every interactive data file required to be submitted and posted pursuant to Rule 405 of 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 and post such files). Yes x No ¨

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

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):

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ¨ No x

The aggregate market value of RPC, Inc. Common Stock held by non-affiliates on June 30, 2015, the last business day of the registrant’s most recently completed second fiscal quarter, was $793,711,327 based on the closing price on the New York Stock Exchange on June 30, 2015 of $13.83 per share.

RPC, Inc. had 217,616,291 shares of Common Stock outstanding as of February 18, 2016.

Documents Incorporated by Reference

Portions of the Proxy Statement for the 2015 Annual Meeting of Stockholders of RPC, Inc. are incorporated by reference into Part III, Items 10 through 14 of this report.

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 products 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 our beliefs regarding natural gas prices, production levels and drilling activities; our belief that petroleum prices carry significant negative implications for RPC’s customer activity levels over the near term; our belief that oil-directed drilling will continue to represent the majority of the total drilling rig activity; 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 and our ability to consummate certain transactions; the adequacy of our insurance coverage; the impact of lawsuits, legal proceedings and claims on our business and financial condition; our expectations regarding payment of cash dividends to common stockholders; our belief that the domestic rig count will continue to decline; our belief that we will not enter into additional long-term contractual arrangements with customers during 2016; our statement that most industry analysts believe that the U.S. domestic rig count will continue to decline during the first half of 2016 before stabilizing in the second half of the year; our statement that industry trends have negative implications for our near-term activity levels; our belief that low commodity prices will continue to depress our financial results in the near term; our cautious view about the market for our services; our belief that the steep decline in oil-directed drilling in the U.S. domestic market will reduce U.S. domestic oil production and over the long term serve as a catalyst for oil prices to increase; our belief regarding potential revenue related to uncompleted wells; our expectations regarding competition in our market; our expectations regarding the return of assets to service when markets improve; our statement that we do not plan additional increases in our fleet of revenue-producing equipment during 2016; our ability to maintain sufficient liquidity and a conservative capital structure; our belief about the amount of the contribution to the defined benefit pension plan in 2016; our ability to fund capital requirements in the future; the estimated amount of our capital expenditures and contractual obligations for future periods; our expectations regarding the prices of skilled labor and many of the raw materials used in providing our services; our belief that it will be difficult to realize higher operating profits from anticipated cost decreases; 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 operation 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. The services and equipment provided include, among others, (1) pressure pumping services, (2) downhole tool services, (3) coiled tubing services, (4) snubbing services (also referred to as hydraulic workover services), (5) nitrogen services, (6) the rental of drill pipe and other specialized oilfield equipment, and (7) well control. RPC acts as a holding company for its operating units, Cudd Energy Services, Patterson Rental and Fishing Tools, Bronco Oilfield Services, Thru Tubing Solutions, Well Control School, and others. As of December 31, 2015, RPC had approximately 3,100 employees.

Business Segments

RPC’s service lines have been aggregated into two reportable oil and gas services business segments, Technical Services and Support Services, because of the similarities between the financial performance and approach to managing the service lines within each of the segments, as well as the economic and business conditions impacting their business activity levels.

During 2015, less than one percent of RPC’s consolidated revenues were generated from offshore operations in the U.S. Gulf of Mexico and in the Gulf of Alaska.  We also estimate that 70 percent of our 2015 revenues were related to drilling and production activities for oil, and 30 percent were related to drilling and production activities for natural gas.

Technical Services include RPC’s oil and gas service lines 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 business segment consists primarily of pressure pumping, downhole tools, coiled tubing, snubbing, nitrogen, well control, wireline and fishing. 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 in selected international markets. Customers include major multi-national and independent oil and gas producers, and selected nationally owned oil companies.

Support Services include RPC’s oil and gas service lines that primarily provide equipment for customer use or services to assist customer operations. The equipment and services include 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 major multi-national and independent oil and gas producers, and selected nationally owned oil companies.

Technical Services

The following is a description of the primary service lines conducted within the Technical Services business segment:

Pressure Pumping. Pressure pumping services, which accounted for approximately 54 percent of 2015 revenues, 57 percent of 2014 revenues and 55 percent of 2013 revenues are provided to customers throughout Texas, and the Appalachian, 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 the pressure pumping business 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, bauxite or synthetic proppant, which is often suspended in gel, is 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 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.

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.

Downhole Tools. Thru Tubing Solutions (“TTS”) accounted for approximately 18 percent of 2015 revenues, 15 percent of 2014 revenues and 16 percent of 2013 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 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 approximately nine percent of revenues in 2015, 2014 and 2013, 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, more costly 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. Increasingly, 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 in 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 services, and the Company believes that its sources of supply are adequate.

Snubbing. Snubbing (also referred to as hydraulic workover services), which accounted for approximately three percent of revenues in 2015 and 2014 and four percent of revenues in 2013, 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 rig 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 approximately four percent of revenues in 2015, three percent of revenues in 2014 and four percent of revenues in 2013. 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 line. In addition, nitrogen can be complementary to our snubbing and coiled tubing service lines, 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 line 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.

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.

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

The following is a description of the primary service lines conducted within the Support Services business segment:

Rental Tools. Rental tools accounted for approximately four percent of revenues in 2015, 2014 and 2013. 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.

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

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 12 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 Gulf of Mexico, the mid-continent, the southwest, 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 89 percent from its peak in 1981. However, due to continuously enhanced technology, more wells are drilled during periods of strong industry activity, and these wells are increasingly productive. For these reasons, the domestic production of natural gas rose to record levels in the third quarter of 2015, and domestic production of crude oil in the third quarter of 2015 reached its highest level since the third quarter of 1971. Domestic production of both natural gas and oil began to decline during the third and fourth quarters of 2015, however, due to the decline in domestic drilling and completion activities. Oil and gas industry activity levels have historically been volatile, experiencing multiple cycles, including down cycle troughs in 1986, 1992, 1999 (with April 1999 recording the lowest U.S. drilling rig count in the industry’s history), 2002 and again in 2009. The rig count during the peak of the most recent cycle occurred at the end of the third quarter of 2014, and began to decline sharply during the fourth quarter of 2014. The rig count continued to decline in 2015 and 2016. Early in 2016, the U.S. domestic drilling rig count had declined by approximately 73 percent from its most recent peak in 2014 and was only five percent higher than the April 1999 record low drilling rig count.

The fluctuations in domestic drilling activity since the most recent peak in the third quarter of 2014 are consistent with global supply of and demand for oil, the domestic supply of and demand for natural gas, U.S. domestic storage levels of oil and natural gas, fluctuations in the value of the U.S. dollar on world currency markets, and projected near-term economic growth. During 2015 the average price of natural gas decreased by approximately 39 percent compared to the prior year, but during the first quarter of 2016 stabilized at a price approximately equal to the average price in the fourth quarter of 2015. The average price of oil decreased by approximately 48 percent during 2015 compared to 2014. Early in the first quarter of 2016, the price of oil decreased by approximately 26 percent compared to the fourth quarter of 2015. RPC believes that the decrease in the price of oil during this period has been caused by the actions of the OPEC cartel, increased supply from the domestic U.S. market, weak global demand, the strength of the U.S. dollar on global currency markets and high storage levels of oil. The precipitous decline in the price of oil that has taken place since the third quarter of 2014 has caused a significant decrease in oil-directed drilling activity. During this period the U.S. domestic oil-directed drilling rig count has fallen by approximately 70 percent. In addition to oil and natural gas, the price of natural gas liquids has become a determinant of 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 2015 the average price of natural gas liquids decreased by approximately 56 percent compared to 2014, and early in the first quarter of 2016 had declined by approximately 26 percent compared to the average price in 2015. The declines in the prices of oil, natural gas, and natural gas liquids during 2015 and the first quarter of 2016 to date carry significant negative implications for RPC’s customer activity levels over the near term.

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 early in the first quarter of 2016 was the lowest natural gas drilling rig count ever recorded. Although the demand for natural gas has remained stable, 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. The price of natural gas has declined in 2015 and early in the first quarter of 2016, and has fallen to a level not observed since the fourth quarter of 1998. We have observed that these natural gas market dynamics discourage our customers from conducting natural gas-directed drilling activities. 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, and in the fourth quarter of 2015, the United States began to export natural gas for the first time. We anticipate that oil-directed drilling will continue to represent the majority of the total drilling rig count, in spite of the fact that the price of oil has declined tremendously from the third quarter of 2014 through the first quarter of 2016 to date. Over the long term, we believe that natural gas-directed drilling will increase due to the lack of natural gas production from oil-directed drilling and increased natural gas demand from U.S. exports of natural gas and changes in demand due to increased use of natural gas as a transportation fuel or for other purposes. 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. Furthermore, we note that the techniques used to extract oil and natural gas in the U.S. domestic market increasingly require the types of services that RPC provides to its customers.

There are certain types of wells being drilled in the U.S. domestic market for which there is a higher demand for RPC’s services. Known as either directional or horizontal wells, these wells are more difficult and costly to complete. They have become an increasingly large percentage of the U.S. domestic market, and since the third quarter of 2008, have consistently comprised the majority of U.S. domestic 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 approximately six percent of RPC’s consolidated revenues in 2015 and four percent in 2014 and 2013. RPC’s equipment investments over the last several years have emphasized domestic rather than international expansion because of higher domestic activity levels and expected financial returns. International revenues decreased primarily due to lower customer activity levels in Canada, Australia, Bolivia and Mexico in 2015 partially offset by increased activity in Argentina compared to the prior year. During 2015, RPC provided snubbing, well control and oilfield training services in several countries including Gabon and Australia. We also provided downhole motors and tools in Argentina, Canada, China and Oman, and rental tools in Equatorial Guinea. 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 2016.

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 12 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 products 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 in service lines 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. As the current industry downturn continues, we believe that many financial investors who have provided capital to smaller oilfield service companies in the past several years are seeking to liquidate their investments. This development, along with continued depressed financial results in our industry, may make valuations for acquisition targets more attractive. 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 to fund the purchase of revenue-producing equipment and other working capital requirements. In January 2014, this facility was extended for five years, and in November of 2015, RPC voluntarily reduced the borrowing capacity of the facility. We have pursued this capital source because of the high returns on investment that have been generated by many of our service lines during the previous several years, and because of the low cost and ready availability of debt capital. During 2014, we purchased additional revenue-producing equipment to support high industry activity levels. We took delivery of this equipment during the third and fourth quarters of 2014 and the first and second quarters of 2015. We had no outstanding balance on our credit facility at the end of 2015 due to a decrease in capital expenditures and working capital. Our capital structure is more conservative than that of many of our peers.

Customers

Demand for RPC’s services and products 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 2015, RPC provided oilfield services to several hundred customers. Of these customers, only one, Anadarko Petroleum Corporation (Anadarko) at approximately 23 percent of revenues, accounted for more than 10 percent of revenues. RPC believes that the relationship with this customer is good, but the loss of this customer could have a material adverse effect on Company revenues in the near term.

Sales are generated by RPC’s sales force and through referrals from existing customers. Over the past three years we have from time to time entered into agreements, with terms beyond one year, to provide services to certain domestic 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 in most of our service lines.

Competition

RPC operates in highly competitive areas of the oilfield services industry. Our products and services are sold 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. Strong oilfield activity during the past several years and the availability of capital have encouraged several new, smaller companies to seek debt and equity capital and accelerate their growth rates. The presence of these new competitors has increased competitive pricing pressures as domestic oilfield activity moderated during 2013, 2014 and 2015. Although the growth in the overall domestic fleet of revenue-producing equipment has moderated, pricing for our services remains competitive. 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.

The oil and gas services industry includes a small number of dominant global competitors including, among others, Halliburton Energy Services Group, a division of Halliburton Company, Baker Hughes and Schlumberger Ltd., and a significant number of locally oriented businesses.

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 of our oilfield service equipment 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 both 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 it leases in The Woodlands, Texas that includes the Company’s operations, engineering, sales and marketing headquarters, and one it owns 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 9 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 for 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 in certain areas where we currently operate. 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, www.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 as they are filed with the Securities and Exchange Commission.

Item 1A. Risk Factors

Demand for our products 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 products 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 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 the Organization of the Petroleum Exporting Countries (OPEC), an oil cartel which controls slightly less than 40 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 has adversely affected the demand for our products and services and our financial condition and results of operations.

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. One of our largest customers, Anadarko, accounted for approximately 23 percent of revenues in 2015, and there were no other customers during 2015 and no customers in 2014 and 2013 that accounted for more than 10 percent of the Company’s revenues. In addition, Anadarko accounted for approximately 14 percent of accounts receivable as of December 31, 2015, and there were no other customers as of December 31, 2015 and no customers as of December 31, 2014 that accounted for more than 10 percent of accounts receivable. This 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 decreased demand for petroleum 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. Recent decreased demand for petroleum adversely affecting our customers may cause us to experience increased losses for doubtful accounts.

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 products 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.

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.

RPC’s subsidiaries have a number of agreements of various types in place with our customers. In general, these agreements indemnify RPC and its subsidiaries against damage or liabilities that arise from the actions of our employees or the operation of our equipment. The provisions in these agreements do not make a distinction among the types of services that RPC provides or the location of the work. These agreements also require that RPC maintain a certain level and type of insurance coverage against any claims that are determined to be our responsibility. RPC has insurance coverage in place with several well-capitalized insurance companies for accidental environmental claims.

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.

Compliance with federal and state regulations relating to hydraulic fracturing and designation of economic development zones related to natural gas-directed drilling from shale formations 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 is coordinating a review of hydraulic fracturing practices. In addition, a committee of the United States House of Representatives has investigated hydraulic fracturing practices and publicized information regarding the materials used in hydraulic fracturing. The U.S. Environmental Protection Agency (EPA) has also undertaken a study of the environmental impact of hydraulic fracturing practices. In the second quarter of 2015, the EPA issued a report which concluded that hydraulic fracturing had not caused a measureable impact on drinking water sources in the U.S. While this conclusion and other conclusions from similar efforts are favorable for our industry, we are unable to predict whether future scrutiny of RPC’s pressure pumping business and any resulting regulatory change will impact our business through increased operational costs, operational delays, or a reduction in demand for hydraulic fracturing services.

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

Our operations in various countries 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, approximately 74 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.

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 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 $125 million credit facility to fund our necessary working capital and equipment requirements. Most of our existing credit facility 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.

Item 1B. Unresolved Staff Comments

None.

Item 2. Properties

RPC owns or leases approximately 120 offices and operating facilities. The Company leases approximately 18,600 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. The lease agreement on the headquarters is effective through October 2020. 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:

Owned Locations

Broussard, Louisiana — Operations, sales and equipment storage yards

Vilonia, Arkansas — Maintenance and rebuild facilities

Elk City, Oklahoma — Operations, sales and equipment storage yards

Houma, Louisiana — Administrative office

Houston, Texas — Pipe storage terminal and inspection sheds

Kilgore, Texas — Operations, sales and equipment storage yards

Odessa, Texas — Operations, sales and equipment storage yards

Rock Springs, Wyoming — Operations, sales and equipment storage yards

Vernal, Utah — Operations, sales and equipment storage yards

Williston, North Dakota — Operations, sales and equipment storage yards

Leased Locations

Canton, Pennsylvania — Operations, sales and equipment storage yards

Hobbs, New Mexico — Pumping services facility

Oklahoma City, Oklahoma — Operations, sales and administrative office

San Antonio, Texas — Operations, sales and equipment storage yards

Seminole, Oklahoma — Pumping services facility

The Woodlands, Texas — Operations, sales and administrative office

Washington, Pennsylvania — Operations, sales and equipment storage yards

Williston, North Dakota — Operations, sales and equipment storage yards

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.

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.

Item 4A. Executive Officers of the Registrant

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 or her earlier removal by the Board of Directors or his or her resignation. The following table lists the executive officers of RPC and their ages, offices, and terms of office with RPC.

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 18, 2016 there were 217,616,291 shares of common stock outstanding and approximately 19,400 beneficial holders of our common stock. The following table sets forth the high and low prices of RPC’s common stock and dividends paid for each quarter in the years ended December 31, 2015 and 2014:

On July 28, 2015, RPC’s Board of Directors voted to temporarily suspend RPC’s quarterly dividend to common stockholders. The Company expects to resume cash dividends to common stockholders in the future, subject to the earnings and financial condition of the Company and other relevant factors.

Issuer Purchases of Equity Securities

The Company has a stock buyback program initially adopted in 1998 and subsequently amended in 2014 that authorizes the repurchase of up to 31,578,125 shares. There were no shares repurchased as part of this program during 2015. As of December 31, 2015, there are 2,050,154 shares available to be repurchased under the current authorization. Currently the program does not have a predetermined expiration date.

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 1000 Index (“Russell 1000”), 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.

The Company was a component of the Russell 1000 during 2015. The Russell 1000 is a stock index representing large capitalization U.S. stocks with high historical growth in revenues and earnings. The components of the index had a weighted average market capitalization in 2015 of $125 billion, and a median market capitalization of $7.7 billion. The Russell 1000 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 products and services as the Company. The companies included in the Peer Group are Weatherford International, Inc., Basic Energy Services, Inc., Superior Energy Services, 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.

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.

STATEMENT OF OPERATIONS DATA:

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.

Current industry conditions are characterized by oil prices which have declined rapidly from more than $100 per barrel in the third quarter of 2014 to approximately $30 per barrel early in the first quarter of 2016, a level not observed since the fourth quarter of 2008. As a result, the U.S. domestic rig count has declined, and early in the first quarter of 2016 had declined by approximately 73 percent since the third quarter of 2014. The catalysts for the recent steep decline in the price of oil include the industry estimates that global oil supplies are higher than demand, the forecasted decline in oil demand growth rates, and the strength of the U.S. dollar on global currency markets. The decline in both the price of oil and our customers’ drilling and completion activities began during the third quarter of 2014 and accelerated following an announcement by OPEC during the fourth quarter of 2014 that the oil cartel would not limit its production in response to falling prices and excess supply. We anticipate that the U.S. domestic rig count will continue to decline until world oil prices increase due to a combination of increased global demand, declining production, or an increase in political instability in the world’s oil-producing regions outside of the United States. RPC believes that the most predictable catalyst for an increase in world oil prices is declining production in the United States. We believe this because the United States grew to be the world’s largest producer of oil during the second quarter of 2015, and the increase in oil production was due to the growth of oil-directed drilling in shale formations. These wells produce a large amount of oil immediately following their completion, but typically experience large production declines within two years. Therefore, the declining production of these wells, and the rapid decline in drilling of new wells of this type beginning in 2015 are the most likely initial catalysts for improving industry conditions. 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 2016 falling to the lowest level ever recorded. We believe that customer activities directed towards drilling for natural gas have 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, relatively constant consumption of natural gas in the United States, and the fact that natural gas has not historically been exported from the United States to other markets in which demand and prices are higher. The price of natural gas continued its decline during 2015 and the first quarter of 2016. Early in the first quarter of 2016, the price of natural gas had fallen to approximately $2.00 per Mcf, its lowest level since the second quarter of 1998.

RPC monitors the number of horizontal and directional wells drilled in the U.S. domestic market, because this type of well is more service-intensive than a vertical oil or gas well, thus requiring more of the Company’s services provided for a longer period of time. During 2015, the average number of horizontal and directional wells drilled in the United States decreased by approximately 43 percent, and was 86 percent of total wells drilled during the year. During the first part of 2016, the percentage of horizontal and directional wells drilled as a percentage of total wells rose to approximately 88 percent. While the increase in horizontal and directional drilling as a percentage of total drilling is favorable, the absolute declines in drilling directed towards all types of wells makes this trend significantly less meaningful. We also monitor the U.S. domestic well count, which is a measure of wells drilled by the existing drilling rig fleet. We believe that the well count is an important measure of our potential activity levels because it reflects changes in rig efficiencies. During 2015, the total U.S. domestic well count decreased by approximately 50 percent. In the markets in which RPC has operational locations, the well count decreased by approximately 47 percent. Pricing for our services declined significantly during 2015, as drilling and completion activities declined, creating a significant oversupply of service capacity. This impact was partially offset by greater service intensity within many of the services provided by RPC’s pressure pumping and downhole motors and tools service lines, among others. During previous years, a number of our customers entered into contractual relationships with us to provide services to support their completion programs. All of these arrangements expired during 2014. We did not enter into any new contractual arrangements during 2015, nor do we expect to enter into any such contractual arrangements in 2016.

During 2015 the Company decreased our purchases of revenue-producing equipment and temporarily suspended the quarterly dividend to common stockholders. Cash flows from operating activities as well as borrowings under our revolving credit facility have been sufficient to fund the Company’s lower capital expenditures which decreased to $167.4 million in 2015 compared to $371.5 million in 2014. The Company has a syndicated revolving credit facility in order to maintain sufficient liquidity to fund its capital expenditure and other funding requirements.

Revenues during 2015 totaled $1.3 billion, a decrease of 45.9 percent compared to 2014 due primarily to lower activity levels and pricing for our services. Cost of revenues decreased $506.9 million in 2015 compared to the prior year due to lower costs resulting from lower activity levels, reduced personnel headcount and incentive compensation, and price reductions from suppliers, partially offset by the impact of increasing service intensity. As a percentage of revenue, cost of revenues increased due to competitive pricing for our services and inefficiencies resulting from lower activity levels. Selling, general and administrative expenses as a percentage of revenues increased to 12.4 percent of revenues in 2015 compared to 8.4 percent of revenues in 2014.

(Loss) income before income taxes decreased to a loss of $153.0 million in 2015 compared to income of $399.4 million in the prior year. Diluted (loss) earnings per share were $(0.47) in 2015 compared to $1.14 in the prior year.

Cash flows from operating activities increased to $473.8 million in 2015 compared to $322.8 million in 2014 primarily due to reductions in working capital requirements coupled with lower earnings. As of December 31, 2015, there were no outstanding borrowings under our credit facility, a decrease from $224.5 million at December 31, 2014.

Outlook

Drilling activity in the U.S. domestic oilfields, as measured by the rotary drilling rig count, reached a recent cyclical peak of 1,931 during the third quarter of 2014. Between the third quarter of 2014 and early in the first quarter of 2016, the drilling rig count has fallen by approximately 73 percent. The principal catalyst for this steep rig count decline is the decline in the price of oil in the world markets, which began in the second quarter of 2014. The price of oil began to fall at this time due to the perceived oversupply of oil, weak global demand growth, and the strength of the U.S. dollar on world currency markets. The price of oil fell by approximately 73 percent from its peak during the second quarter of 2014 until early in the first quarter of 2016. Early in the first quarter of 2016, most industry analysts believe that the U.S. domestic rig count will decrease further during the first two quarters of 2016 before stabilizing in the last two quarters of the year.

The current and projected prices of oil, natural gas and natural gas liquids are important catalysts for U.S. domestic drilling activity. As of the first quarter of 2016, the price of oil has fallen to levels that discourage our customers from undertaking most of their potential exploration and production activities. The price of natural gas also fell during 2015. Although the price of natural gas has stabilized during the first quarter of 2016, it remains at levels that discourage exploration and production activities directed towards natural gas. Early in the first quarter of 2016 the natural gas-directed rig count fell to its lowest level during the time that this statistic has been recorded. The average price of natural gas liquids during 2015 declined by approximately 56 percent compared to the prior year, and by an additional approximately 25 percent early in the first quarter of 2016 compared to the average price in 2015. These trends have negative implications for our near-term activity levels. The low price of oil should continue to have a negative impact on our customers’ activity levels and our financial results, since the majority of the U.S. domestic drilling rig count is directed towards oil. It is likely that these low commodity prices will continue to depress our financial results during the near term.

The majority of the U.S. domestic rig count remains directed towards oil. At the end of 2015, approximately 77 percent of the U.S. domestic rig count was directed towards oil, a decrease compared to approximately 82 percent at the end of 2014. 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. During the first quarter of 2016, the rig count continued to decline, and approached the historic low for U.S. domestic drilling activity set in the second quarter of 1999.

We continue to monitor the market for our services and the competitive environment in 2016. We are cautious about the market for our services because of the decline in the U.S. domestic rig count and the prices of oil and natural gas during 2016, and the highly competitive nature of pricing for our services in the current environment. The current low prices of oil and natural gas discourage us from believing that the U.S. domestic rig count will recover during the near term. Over the long term, we believe that the steep decline in oil-directed drilling in the U.S. domestic market will reduce U.S. domestic oil production and serve as a catalyst for oil prices to increase. This belief is due to the fact that oil-directed wells drilled in shale resource plays typically exhibit high initial production soon after being completed followed by a decline in production in later years. We note that both U.S. domestic oil and natural gas production peaked in the third quarter of 2015, and have declined through the first quarter of 2016. We are also encouraged by the fact that the drilling and completion activities that took place during 2015 and continue in 2016 are highly service-intensive and require a large amount of equipment and raw materials. Furthermore, we note that a large number of wells in the U.S. domestic market have been drilled but not completed. These uncompleted wells represent potential revenue for RPC’s completion-directed service lines, which comprise the majority of RPC’s revenues. Finally, we are encouraged by our belief that our competitors are not increasing the size of their revenue-producing fleets of equipment during this period, and furthermore, that some of our competitors are not maintaining their equipment to a level that allows them to provide services to their customers. During the first three quarters of 2015, we responded to the significant declines in industry activity levels and pricing for our services by reducing costs by seeking price concessions from our suppliers. In addition, we have reduced employee headcount, closed selected operational locations and revised our variable compensation programs.

As we monitor the competitive environment during 2016, we note that many of our smaller competitors have high levels of debt, higher cost structures, and less-developed logistical capabilities than RPC. These characteristics have forced these competitors to cease operations because current pricing and activity levels do not allow them to generate enough cash to service their debt and fund their working capital and capital expenditure requirements. During 2015 several smaller competitors ceased operations and initiated the process of selling their equipment, and this trend has accelerated early in the first quarter of 2016. These observations encourage us to believe that our markets will eventually become less competitive. In the fourth quarter of 2015 we initiated a process whereby we more closely scrutinize the maintenance status of our currently idled revenue-producing assets. Through this process, we are attempting to ensure that our idle equipment is prepared to return to service as soon as market conditions encourage us to do so. We believe that this process will provide an advantage to RPC, in contrast to many competitors who do not have the liquidity to maintain their fleets, and thus will not be able to return their assets to service in a timely manner when market conditions improve. In this environment RPC also monitors the financial stability of our customers, due to the fact that many of them have also financed their operations with a large amount of debt, and this type of financing is less available in 2016 than in previous years. RPC expanded its pressure pumping fleet during 2014 and the first two quarters of 2015, but we do not plan additional increases in our fleet of revenue-producing equipment during 2016. Our consistent response to the industry's potential uncertainty is to maintain sufficient liquidity and a conservative capital structure and monitor our discretionary spending. Although we have used our bank credit facility to finance our current expansion, we will continue to maintain a conservative financial and capital structure by industry standards.

Results of Operations

Year Ended December 31, 2015 Compared To Year Ended December 31, 2014

Revenues. Revenues in 2015 decreased $1.1 billion or 45.9 percent compared to 2014. The Technical Services segment revenues for 2015 decreased 46.1 percent compared to the prior year due primarily to lower activity levels and pricing as compared to prior year, partially offset by increasing service intensity in our pressure pumping service line, which is the largest service line within this segment. The Support Services segment revenues for 2015 decreased 43.6 percent compared to 2014 due principally to lower pricing and activity levels in the rental tool service line, which is the largest service line within this segment. Both the Technical and Support Services reported operating losses due to lower revenues, partially offset by cost control efforts undertaken throughout the Company. The average price of oil decreased 47.7 percent while the average price of natural gas decreased 39.3 percent during 2015 compared to the prior year. The average domestic rig count during 2015 was 47.3 percent lower than 2014. We believe that our activity levels are affected primarily by the price of oil, since oil-directed activity has become the majority of total U.S. drilling activity. The prices of natural gas and natural gas liquids also impact our activity levels because of the service-intensive nature of this type of drilling and completion. We also believe that the total number of directional and horizontal wells more directly affect our activity levels, regardless of whether the wells are directed towards oil or natural gas. This belief is based on the fact that directional and horizontal wells require more of the services within our technical services segment. International revenues, which decreased from $88.2 million in 2014 to $72.1 million in 2015, were as a percentage of consolidated revenues, six percent in 2015 and four percent in 2014. International revenues decreased primarily due to lower customer activity levels in Canada, Australia, Bolivia and Mexico in 2015 partially offset by increased activity in Argentina 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 2015 was $1.0 billion compared to $1.5 billion in 2014, a decrease of $506.9 million or 34.0 percent. The decrease in these costs was due to lower costs resulting from lower activity levels, reduced personnel headcount and incentive compensation, and price reductions from suppliers, partially offset by the impact of increasing service intensity. Also during 2015, replacement parts totaling approximately $41.9 million were charged to cost of revenues rather than capitalized as a result of a change in accounting estimate. As a percentage of revenues, cost of revenues increased in 2015 compared to 2014 due to competitive pricing for our services and inefficiencies resulting from lower activity levels.

Selling, general and administrative expenses.  Selling, general and administrative expenses decreased 20.6 percent to $156.6 million in 2015 compared to $197.1 million in 2014.  This decrease was due to lower total employment costs and other cost reduction efforts as well as decreases in expenses which vary with activity and profitability.  As a percentage of revenues, selling, general and administrative expenses increased to 12.4 percent in 2015 compared to 8.4 percent in 2014 due to the relatively fixed nature of some of these costs during the short term.

Depreciation and amortization. Depreciation and amortization were $271.0 million in 2015, an increase of $40.2 million, compared to $230.8 million in 2014 due to assets placed in service during late 2014 and the first six months of 2015. As a percentage of revenues, depreciation and amortization increased to 21.4 percent in 2015 compared to 9.9 percent in 2014.

Loss on disposition of assets, net. Loss on disposition of assets, net was $6.4 million in 2015 compared to $15.5 million in 2014. The loss on disposition of assets, net is comprised of gains or losses related to various property and equipment dispositions or sales to customers of lost or damaged rental equipment. The decrease in losses compared to the prior year resulted from a change in accounting estimate beginning in 2015 whereby the cost of replacing certain pressure pumping unit components was recorded as cost of revenues upon installation rather than being capitalized. During 2014, the remaining net book value of these components damaged beyond repair was recorded as a loss on disposition.

Other income (expense), net. Other income, net was $5.2 million in 2015 compared to other expense, net of $131 thousand in 2014. Proceeds from a legal settlement totaling $6.3 million was recorded during 2015.

Interest expense and interest income. Interest expense was $2.0 million in 2015 compared to $1.4 million in 2014. Interest expense in 2015 included the accelerated amortization of loan fees totaling $0.6 million associated with RPC’s voluntary reduction of the borrowing capacity under its syndicated credit facility from $350 million to $125 million. This cost was partially offset by lower interest expense due to a lower average debt balance on our revolving credit facility. Interest income increased to $83 thousand in 2015 compared to $19 thousand in 2014.

Income tax (benefit) provision. The income tax benefit was $53.5 million in 2015 compared to an income tax provision of $154.2 million in 2014. The benefit in 2015 resulted from the pretax loss. The effective rate was 34.9 percent in 2015 compared to 38.6 percent in 2014; the decrease is due primarily to state tax calculations based on revenues.

Net (loss) income and diluted (loss) earnings per share. Net loss was $99.6 million in 2015, or $(0.47) per diluted share, compared to net income of $245.2 million, or $1.14 per diluted share in 2014. This decrease was due to lower profitability as average shares outstanding was essentially unchanged.

Year Ended December 31, 2014 Compared To Year Ended December 31, 2013

Revenues. Revenues in 2014 increased $475.9 million or 25.6 percent compared to 2013. The Technical Services segment revenues for 2014 increased 26.1 percent compared to the prior year due primarily to increased service intensity in the service lines within this segment and a larger fleet of pressure pumping equipment. The Support Services segment revenues for 2014 increased 19.1 percent compared to 2013 due principally to an improved job mix and higher activity levels in the rental tool service line, which is the largest service line within this segment, as well as higher activity levels in the other service lines which comprise this segment. Operating profit in both the Technical and Support Services segments increased due to higher revenues and greater utilization of personnel and equipment.

The average price of oil decreased 4.9 percent while the average price of natural gas increased 14.6 percent during 2014 compared to the prior year. The average domestic rig count during 2014 was 5.7 percent higher than 2013. International revenues, which increased from $65.9 million in 2013 to $88.2 million in 2014, were as a percentage of consolidated revenues, four percent in 2014 and 2013. International revenues in 2014 increased due primarily to higher customer activity levels in Australia, Gabon and Singapore in 2014 partially offset by decreased activity in Mexico, Congo and Tunisia, 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 2014 was $1.5 billion compared to $1.2 billion in 2013, an increase of $314.7 million or 26.7 percent. The increase in these costs was due to the variable nature of these expenses especially materials and supplies expenses and employment costs associated with higher activity levels. Cost of revenues, as a percent of revenues, increased slightly in 2014 compared to 2013 due primarily to competitive pricing for our services.

Selling, general and administrative expenses.  Selling, general and administrative expenses increased 7.6 percent to $197.1 million in 2014 compared to $183.1 million in 2013. This increase was due primarily to increases in total employment costs partially offset by a decrease in bad debt expense.  As a percentage of revenues, selling, general and administrative expenses decreased to 8.4 percent in 2014 compared to 9.8 percent in 2013 due to cost leverage achieved with higher revenues.

Depreciation and amortization. Depreciation and amortization were $230.8 million in 2014, an increase of $17.7 million, compared to $213.1 million in 2013. As a percentage of revenues, depreciation and amortization decreased to 9.9 percent in 2014 compared to 11.4 percent in 2013.

Loss on disposition of assets, net. Loss on disposition of assets, net was $15.5 million in 2014 compared to $9.4 million in 2013. The loss on disposition of assets, net includes gains or losses related to various property and equipment dispositions including certain equipment components experiencing increased wear and tear which requires early dispositions, or sales to customers of lost or damaged rental equipment.

Other income (expense), net. Other (expense), net was $131 thousand in 2014 compared to other income, net of $245 thousand in 2013.

Interest expense and interest income. Interest expense was $1.4 million in 2014 compared to $1.8 million in 2013. The decrease in 2014 is due to lower interest rates net of interest capitalized on equipment and facilities under construction partially offset by a higher average debt balance on our revolving credit facility. Interest income decreased to $19 thousand in 2014 compared to $408 thousand in 2013.

Income tax provision. The income tax provision was $154.2 million in 2014 compared to $109.4 million in 2013. This increase was due to higher income before taxes partially offset by a decrease in the effective tax rate to 38.6 percent in 2014 compared to 39.6 percent in 2013.

Net income and diluted earnings per share. Net income was $245.2 million in 2014, or $1.14 per diluted share, compared to net income of $166.9 million, or $0.77 per diluted share in 2013. This increase was due to higher profitability as average shares outstanding was essentially unchanged.

Liquidity and Capital Resources

Cash and Cash Flows

The Company’s cash and cash equivalents were $65.2 million as of December 31, 2015, $9.8 million as of December 31, 2014 and $8.7 million as of December 31, 2013.

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

2015

Cash provided by operating activities increased $151.0 million in 2015 compared to the prior year due primarily to a favorable change in working capital of $506.8 million partially offset by a decrease in net income (loss) of $344.8 million, an increase in depreciation and amortization of $41.3 million, and an unfavorable change in deferred taxes of $45.4 million due to a decrease in tax benefits resulting from lower capital expenditures.

The favorable change in working capital was primarily due to favorable changes of $599.8 million in accounts receivable and $56.4 million in inventory as a result of lower business activity levels in 2015 compared to the prior year. Also, there was a favorable change in income taxes receivable/payable of $3.9 million due to the timing of payments. These favorable changes were partially offset by unfavorable changes in accounts payable of $98.9 million, accrued payroll of $46.4 million and accrued state, local and other taxes of $5.8 million due to lower business activity levels coupled with the timing of payments.

Cash used for investing activities in 2015 decreased by $197.8 million compared to 2014, primarily as a result of lower capital expenditures in response to weaker industry conditions.

Cash provided by financing activities in 2015 increased by $294.4 million primarily as a result of higher net loan payments funded primarily by the favorable changes in working capital, partially offset by lower open market share repurchases and common stock dividends during 2015 compared to the prior year. The Company reduced and then suspended its common stock dividend during 2015.

2014

Cash provided by operating activities decreased $42.9 million in 2014 compared to the prior year due primarily to an unfavorable change in working capital of $173.0 million partially offset by an increase in net income of $78.3 million, an increase in depreciation and amortization of $18.1 million, and a favorable change in deferred taxes of $25.4 million due to tax benefits resulting from higher capital expenditures.

The unfavorable change in working capital was primarily due to unfavorable changes of $148.1 million in accounts receivable due to higher business activity levels in 2014 compared to prior year, $43.8 million in inventories due to an increase in materials and supplies that require longer lead times, and $3.4 million in other current assets due to lower deposits for raw materials. Also, there was an unfavorable net change of $13.4 million in net current income taxes receivable/payable due to the timing of payments. These unfavorable changes were partially offset by favorable changes in accounts payable of $22.4 million, accrued payroll of $8.6 million and accrued state, local and other taxes of $4.1 million due to higher business activity levels coupled with the timing of payments.

Cash used for investing activities in 2014 increased by $147.7 million compared to 2013, primarily as a result of higher capital expenditures primarily directed to expand or maintain our revenue-producing equipment.

Cash provided by financing activities in 2014 increased by $197.1 million primarily as a result of higher net loan borrowings coupled with lower open market share repurchases, partially offset by a 5 percent increase in the per share common stock dividend declared during 2014 compared to the prior year.

Financial Condition and Liquidity

The Company’s financial condition as of December 31, 2015, remains strong. We believe the liquidity provided by our existing cash and cash equivalents, our overall strong capitalization which includes a revolving credit facility and cash expected to be generated from operations will provide sufficient capital to meet our requirements for at least the next twelve months. On January 17, 2014, the Company amended the $350 million revolving credit facility which extended the maturity of the loan to January 2019. On November 3, 2015, RPC reduced the revolving credit facility by $225 million to $125 million. The facility contains customary terms and conditions, including certain financial covenants including covenants restricting RPC's ability to incur liens, merge or consolidate with another entity. A total of $95.7 million was available under the revolving credit facility as of December 31, 2015; $29.3 million of the facility supports outstanding letters of credit related to self-insurance programs or contract bids. Subsequent to year end, the Company obtained a separate letter of credit facility totaling $35 million; accordingly, $125 million is now available under the revolving credit facility. For additional information with respect to RPC’s facility, see Note 6 of the Notes to Consolidated Financial Statements.

The Company’s decisions about the amount of cash to be used for investing and financing purposes are influenced by its capital position, including access to borrowings under our facility, and the expected amount of cash to be provided by operations. 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. The Company's decisions about the amount of cash to be used for investing and financing activities could 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 $167.4 million in 2015, and we currently expect capital expenditures to be approximately $60 million in 2016. We expect that a majority of these expenditures in 2016 will be directed towards capitalized equipment maintenance.  The remaining capital expenditures will be directed towards the purchase of revenue-producing equipment. The actual amount of 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 2015, the Company contributed $0.9 million to the pension plan. The Company expects that additional contributions to the defined benefit pension plan of approximately $0.9 million will be required in 2016 to achieve the Company’s funding objective.

The Company has a stock buyback program initially adopted in 1998 that authorizes the repurchase of up to 26,578,125 shares. On June 5, 2013, the Board of Directors authorized an additional 5,000,000 shares for repurchase under this program. There were no shares purchased on the open market by the Company during 2015, and 2,050,154 shares remain available to be repurchased under the current authorization as of December 31, 2015. 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.

On July 28, 2015, the Board of Directors voted to temporarily suspend RPC’s quarterly dividend to common stockholders. The Company expects to resume cash dividends to common stockholders in the future, subject to the earnings and financial condition of the Company and other relevant factors.

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, 2015:

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 assets classified as Level 3, 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 or 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. Also, increases in activity in the domestic oilfield can cause upward wage pressures in the labor markets from which it hires employees as well as increases in the costs of certain materials and key equipment components used to provide services to the Company’s customers. During 2014, we experienced high employment costs due to the demand for skilled labor in our markets. In addition, we experienced continued high cost for certain raw materials the Company uses to provide its services, in spite of our efforts to secure raw materials from alternative sources. During 2015, however, supplies of raw materials became more readily available as domestic oilfield activity decreased. In addition, skilled labor became more available, and the upward wage pressures that the Company experienced in 2014 subsided. By way of illustration, during this time the price index of one of the most critical raw materials the Company uses to provide its services declined by more than 20 percent. The Company also uses a large amount of diesel fuel to operate its fleet of revenue-producing equipment, and the cost of diesel fuel has declined significantly in 2015 and early in 2016. In fact, during this period, the overall retail price of diesel fuel in the U.S. declined by approximately 36 percent. At the end of the fourth quarter of 2015 and early in the first quarter of 2016, there were many indications that the prices of both skilled labor and many of the raw materials used in providing our services would continue to decline during the near term. Because customers are pressuring the prices we charge for our services, we have not gained any benefit from these declining prices. On the contrary, because competitive market pressures have forced us to decrease our prices to customers, the Company expects that it will be difficult to realize higher operating profit from these anticipated cost decreases.

Off Balance Sheet Arrangements

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

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 $753,000 in 2015, $663,000 in 2014, and $670,000 in 2013. The Company’s (payable) receivable due (to) from Marine Products for these services was $(11,000) as of December 31, 2015 and $47,000 as of December 31, 2014. 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 products 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 $1,127,000 in 2015, $1,092,000 in 2014 and $1,039,000 in 2013.

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 $100,000 in 2015, $84,000 in 2014 and $83,000 in 2013.

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 a party to an operating lease agreement with 255 RC, LLC for a period of five years. During 2015, RPC recorded certain net operating costs comprised of rent and an allocable share of fixed costs of approximately $186,000 for the corporate aircraft. 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, 2015, 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:

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 $1.0 million in 2015 and insignificant in 2014 and 2013. 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 customers change, our estimates of the realizability of receivables 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 have ranged from (0.2) percent to 0.5 percent over the last three years. Increasing or decreasing the estimated general reserve percentages by 0.50 percentage points as of December 31, 2015 would have resulted in a change of approximately $1.2 million to the allowance for doubtful accounts and a corresponding change to selling, general and administrative expenses.

Income taxes — The effective income tax rates were 34.9 percent in 2015, 38.6 percent in 2014 and 39.6 percent in 2013. Our effective tax rates vary due to changes in estimates of our future taxable income, 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.

We establish a valuation allowance against the carrying value of deferred tax assets when we determine 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 in which we make such determination. Likewise, if we later determine that it is more likely than not that the net deferred tax assets would be realized, we would reverse the applicable portion of the previously provided valuation allowance. We have considered future market growth, forecasted earnings, future taxable income, the mix of earnings in the jurisdictions in which we operate, and prudent and feasible tax planning strategies in determining the need for a valuation allowance.

We calculate our 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.

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. We believe we have adequately provided for any reasonably foreseeable outcome related to these matters. However, our future results may include favorable or unfavorable adjustments to our 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, 2015, the Company estimates the range of exposure to be from $13.8 million to $17.6 million. The Company has recorded liabilities at December 31, 2015 of approximately $15.6 million which represents management’s best estimate of probable loss.

Depreciable life of assets — RPC’s net property, plant and equipment at December 31, 2015 was $688.3 million representing 55.6 percent of the Company’s consolidated assets. Depreciation and amortization expenses for the year ended December 31, 2015 were $271.0 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. During 2015 the Company reassessed the useful life of a specific component of its pressure pumping equipment that prior to 2015 had an expected useful life of 18 months. As a result of this reassessment, the Company concluded that this component is no longer a long-lived asset, but instead a consumable supply inventory item. Accordingly, effective January 1, 2015, the cost of this component is being expensed as repairs and maintenance as part of cost of revenues at the time of installation. Management deemed the change preferable because it more closely reflects the pattern of consumption of this component as a result of continual increases in wear and tear resulting from harsher geological environments. We did not make any changes to the estimated lives of assets resulting in a material impact in 2014 and 2013.

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 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 2015, 2014 and 2013.

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 4.70 percent as of December 31, 2015 compared to 4.15 percent as of December 31, 2014 and 5.20 percent in 2013.

As set forth in Note 10 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 categorized as Level 3 investments and are valued using significant non-observable inputs which do not have a readily determinable fair value. In accordance with ASU No. 2009-12 “Investments In Certain Entities That Calculate Net Asset Value per Share (Or Its Equivalent),” these investments are valued based on the net asset value per share calculated by the funds in which the plan has invested. 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, 2015, the defined benefit plan was under-funded and the recorded change within accumulated other comprehensive loss increased stockholders’ equity by approximately $1.0 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 approximately $1.2 million to the net loss related to pension reflected in accumulated other comprehensive loss.

The Company recognized pre-tax pension expense of $0.4 million in 2015, $0.2 million in 2014 and $0.5 million in 2013. Based on the under-funded status of the defined benefit plan as of December 31, 2015, the Company expects to recognize pension expense of $0.6 million in 2016. 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 approximately $0.2 million in 2016. 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 an immaterial amount in 2016.

Recent Accounting Pronouncements

During the year ended December 31, 2015, the Financial Accounting Standards Board (FASB) issued the following applicable Accounting Standards Updates (ASU):

Recently Adopted Accounting Pronouncements:

Accounting Standards Update 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The amendments in the ASU require that only disposals representing a strategic shift in operations should be presented as discontinued operations. Those strategic shifts should have a major effect on the organization’s operations and financial results. Examples include a disposal of a major geographic area, a major line of business, or a major equity method investment. In addition, the new guidance requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income, and expenses of discontinued operations. The new guidance also requires disclosure of the pre-tax income attributable to a disposal of a significant part of an organization that does not qualify for discontinued operations reporting. The Company adopted these provisions in the first quarter of 2015 and the adoption did not have a material impact on the Company’s consolidated financial statements.

Accounting Standards Update No. 2015-15, Interest—Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements. In April 2015, the FASB issued ASU No. 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, which requires the presentation of debt issuance costs related to a recognized debt liability as a direct deduction from the carrying amount of that debt liability. ASU 2015-03 does not address presentation or subsequent measurement of debt issuance costs related to line-of-credit arrangements. Given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements, the SEC staff has approved deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Company currently reports its debt issuance costs as part of non-current other assets and therefore is in compliance with this guidance.

Accounting Standards Updates No. 2015-17, Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes. The amendments in this ASU eliminates the current requirement to present deferred tax liabilities and assets as current and noncurrent in a classified balance sheet and now requires that all deferred tax assets and liabilities be classified as noncurrent. The amendments are effective for financial statements issued for annual periods beginning after December 15, 2016, with early application permitted. The Company elected to early adopt the provisions of this ASU and classified its deferred tax balances as a non-current liability as of December 31, 2015. Deferred tax balances for prior periods have not been retrospectively adjusted.

Recently Issued Accounting Pronouncements Not Yet Adopted:

Accounting Standards Update No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments. To simplify the accounting for adjustments made to provisional amounts recognized in a business combination, the amendments in this ASU eliminate the requirement to retrospectively account for those adjustments. Instead, an acquirer is required to recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. All of the changes are to be recorded in the reporting period and calculated as if the accounting had been completed at the acquisition date and either disclosed on the face of the income statement or in the notes by each category. These amendments are effective for fiscal years beginning after December 15, 2015, including interim periods within those fiscal years. The amendments are to be applied prospectively to adjustments to provisional amounts that occur after the effective date with earlier application permitted for financial statements that have not been issued. The Company plans to adopt the provisions in the first quarter of 2016 for all business combinations completed thereafter and currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. Current guidance requires an entity to measure inventory at the lower of cost or market. Market could be replacement cost, net realizable value, or net realizable value less an approximately normal profit margin. The amendments in this ASU simplify the measurement process and allows inventory to be measured at lower of cost or net realizable value and eliminates the market requirement. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The amendments do not apply to inventory that is measured using last-in, first-out or the retail inventory method. The amendments are effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The amendments are to be applied prospectively with earlier application permitted. The Company plans to adopt the provisions in the first quarter of 2017 and currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update No. 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent). The amendments apply to the fair value of an investment that is measured using the net asset value per share (or its equivalent) practical expedient. The amendments remove the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendments also remove the requirement to make certain disclosures for all investments that are eligible to be measured at fair value using the net asset value per share practical expedient. The amendments are effective for public business entities for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years and are required to be applied retrospectively to all periods presented, with earlier application permitted. The Company plans to adopt the provisions in the first quarter of 2016 and currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update No. 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The amendments in this ASU require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this ASU. The amendments should be applied on a retrospective basis, wherein the balance sheet of each individual period presented should be adjusted to reflect the period-specific effects of applying the new guidance. Upon transition, an entity is required to comply with the applicable disclosures for a change in an accounting principle. These disclosures include the nature of and reason for the change in accounting principle, the transition method, a description of the prior-period information that has been retrospectively adjusted, and the effect of the change on the financial statement line items (i.e., debt issuance cost asset and the debt liability). The amendments in this ASU are effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption of the amendments is permitted for financial statements that have not been previously issued. The Company plans to adopt the provisions in the first quarter of 2016 and currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update No. 2014-15, Presentation of Financial Statements —Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The provisions in this ASU are intended to define management’s responsibility to evaluate whether there is substantial doubt about an organization’s ability to continue as a going concern and to provide related footnote disclosures. Currently, financial statements are prepared under the presumption that the reporting organization will continue to operate as a going concern, except in limited circumstances. This going concern basis of accounting is critical to financial reporting because it establishes the fundamental basis for measuring and classifying assets and liabilities. This ASU provides guidance regarding management’s responsibility to evaluate whether there is substantial doubt about the organization’s ability to continue as a going concern and the related footnote disclosures. The amendments are effective for the year ending December 31, 2016, and for interim periods beginning the first quarter of 2017, with early application permitted. The Company plans to adopt these provisions in the first quarter of 2016 and will provide such disclosures as required if there are conditions and events that raise substantial doubt about its ability to continue as a going concern. The Company currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU affects any entity using U.S. GAAP that either enters into contracts with customers to transfer goods or services or enters into contracts for the transfer of nonfinancial assets unless those contracts are within the scope of other standards (e.g., insurance contracts or lease contracts). The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. To achieve that core principle, an entity should apply a five step process – (i) identifying the contract(s) with a customer, (ii) identifying the performance obligations in the contract, (iii) determining the transaction price, (iv) allocating the transaction price to the performance obligations in the contract and (v) recognizing revenue when (or as) the entity satisfies a performance obligation. The Company plans to adopt these provisions in the first quarter of 2018 in accordance with ASU 2015-14 that deferred the effective date of ASU 2014-09 for all entities by one year. The Company is currently evaluating the impact of these provisions on its consolidated financial statements.

Item 7A. Quantitative and Qualitative Disclosures about Market Risk

The Company is subject to interest rate risk exposure through borrowings on its credit agreement. As of December 31, 2015, 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.

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, 2015 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, 2015.

The independent registered public accounting firm, Grant Thornton LLP, has audited the consolidated financial statements as of and for the year ended December 31, 2015, and has also issued their report on the effectiveness of the Company’s internal control over financial reporting, included in this report on page 31.

Atlanta, Georgia

February 29, 2016

Report of Independent Registered Public Accounting Firm

Board of Directors and Stockholders

RPC, Inc.

We have audited the internal control over financial reporting of RPC, Inc. (a Delaware corporation) and subsidiaries (the “Company”) as of December 31, 2015, based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). 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 conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, 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.

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

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

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2015, 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), the consolidated financial statements of the Company as of and for the year ended December 31, 2015, and our report dated February 29, 2016 expressed an unqualified opinion on those financial statements.

/s/ GRANT THORNTON LLP

Atlanta, Georgia

February 29, 2016

Report of Independent Registered Public Accounting Firm

Board of Directors and Stockholders

RPC, Inc.

We have audited the accompanying consolidated balance sheets of RPC, Inc. (a Delaware corporation) and subsidiaries (the “Company”) as of December 31, 2015 and 2014, and the related consolidated statements of operations, comprehensive income, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2015. Our audits of the basic consolidated financial statements included the financial statement schedule listed in the index appearing under Item 15(2). These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits.

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

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

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2015, 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 29, 2016 expressed an unqualified opinion thereon.

/s/ GRANT THORNTON LLP

Atlanta, Georgia

February 29, 2016

Item 8. Financial Statements and Supplementary Data

CONSOLIDATED BALANCE SHEETS

RPC, INC. AND SUBSIDIARIES

(in thousands except share information)

The accompanying notes are an integral part of these statements.

CONSOLIDATED STATEMENTS OF OPERATIONS

RPC, INC. AND SUBSIDIARIES

(in thousands except per share data)

The accompanying notes are an integral part of these statements.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

RPC, INC. AND SUBSIDIARIES

(in thousands except per share data)

The accompanying notes are an integral part of these statements.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

RPC, INC. AND SUBSIDIARIES

(in thousands)

The accompanying notes are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CASH FLOWS

RPC, Inc. and Subsidiaries

(in thousands)

The accompanying notes are an integral part of these statements.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Note 1: Significant Accounting Policies

Principles of Consolidation and Basis of Presentation

The consolidated financial statements include the accounts of RPC, Inc. and its wholly-owned subsidiaries (“RPC” or the “Company”). All significant intercompany accounts and transactions have been eliminated.

Nature of Operations

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 of America, including the southwest, mid-continent, Gulf of Mexico, Rocky Mountain and Appalachian regions, and in selected international markets. The services and equipment provided include Technical Services such as pressure pumping services, coiled tubing services, snubbing services (also referred to as hydraulic workover services), nitrogen services, and firefighting and well control, and Support Services such as the rental of drill pipe and other specialized oilfield equipment and oilfield training and consulting.

Reclassifications

Certain prior year amounts have been reclassified to conform to the presentation in the current year.

Common Stock

RPC is authorized to issue 349,000,000 shares of common stock, $0.10 par value. Holders of common stock are entitled to receive dividends when, as, and if declared by the Board of Directors out of legally available funds. Each share of common stock is entitled to one vote on all matters submitted to a vote of stockholders. Holders of common stock do not have cumulative voting rights. In the event of any liquidation, dissolution or winding up of the Company, holders of common stock are entitled to ratable distribution of the remaining assets available for distribution to stockholders.

Preferred Stock

RPC is authorized to issue up to 1,000,000 shares of preferred stock, $0.10 par value. As of December 31, 2015, there were no shares of preferred stock issued. The Board of Directors is authorized, subject to any limitations prescribed by law, to provide for the issuance of preferred stock as a class without series or, if so determined from time to time, in one or more series, and by filing a certificate pursuant to the applicable laws of the state of Delaware and to fix the designations, powers, preferences and rights, exchangeability for shares of any other class or classes of stock. Any preferred stock to be issued could rank prior to the common stock with respect to dividend rights and rights on liquidation.

Dividends

On July 28, 2015, the Board of Directors voted to temporarily suspend RPC’s quarterly dividend to common stockholders.

Use of Estimates in the Preparation of Financial Statements

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Significant estimates are used in the determination of the allowance for doubtful accounts, income taxes, accrued insurance expenses, depreciable lives of assets, and pension liabilities.

Revenues

RPC’s revenues are generated principally from providing services and the related equipment. Revenues are recognized when the services are rendered and collectibility is reasonably assured. Revenues from services and equipment are based on fixed or determinable priced purchase orders or contracts with the customer and do not include the right of return. Rates for services and equipment are priced on a per day, per unit of measure, per man hour or similar basis. Sales tax charged to customers is presented on a net basis within the consolidated statement of operations and excluded from revenues.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Concentration of Credit Risk

Substantially all of the Company’s customers are engaged in the oil and gas industry. This concentration of customers may impact overall exposure to credit risk, either positively or negatively, in that customers may be similarly affected by changes in economic and industry conditions. The Company provided oilfield services to several hundred customers during each of the last three years. One customer accounted for approximately 23 percent of revenues in 2015, and there were no customers that accounted for more than 10 percent of the Company’s revenues in 2014 and 2013. Additionally, one customer accounted for approximately 14 percent of accounts receivable as of December 31, 2015, and there were no customers that accounted for more than 10 percent of accounts receivable as of December 31, 2014.

Cash and Cash Equivalents

Highly liquid investments with original maturities of three months or less when acquired are considered to be cash equivalents. The Company maintains its cash in bank accounts which, at times, may exceed federally insured limits. RPC maintains cash equivalents and investments in one or more large financial institutions, and RPC’s policy restricts investment in any securities rated less than “investment grade” by national rating services.

Investments

Investments classified as available-for-sale securities are stated at their fair values, with the unrealized gains and losses, net of tax, reported as a separate component of stockholders’ equity. The cost of securities sold is based on the specific identification method. Realized gains and losses, declines in value judged to be other than temporary, interest, and dividends with respect to available-for-sale securities are included in interest income. The Company realized an immaterial realized loss during 2015 and no gains or losses during 2014 or 2013 on its available-for-sale securities. Securities that are held in the non-qualified Supplemental Executive Retirement Plan (“SERP”) are classified as trading. See Note 10 for further information regarding the SERP. The change in fair value of trading securities is presented as compensation cost in selling, general and administrative expenses on the consolidated statements of operations.

Management determines the appropriate classification of investments at the time of purchase and re-evaluates such designations as of each balance sheet date.

Accounts Receivable

The majority of the Company’s accounts receivable is due principally from major and independent oil and natural gas exploration and production companies. Credit is extended based on evaluation of a customer’s financial condition and, generally, collateral is not required. Accounts receivable are considered past due after 60 days and are stated at amounts due from customers, net of an allowance for doubtful accounts.

Allowance for Doubtful Accounts

Accounts receivable are carried at the amounts due from customers, reduced by an allowance for estimated amounts that may not be collectible in the future. The estimated allowance for doubtful accounts is based on an evaluation of industry trends, financial condition of customers, historical write-off experience, current economic conditions, and in the case of international customers, judgments about the economic and political environment of the related country and region. Accounts are written off against the allowance for doubtful accounts when the Company determines that amounts are uncollectible and recoveries of previously written-off accounts are recorded when collected.

Inventories

Inventories, which consist principally of (i) raw materials and supplies that are consumed providing services to the Company’s customers, (ii) spare parts for equipment used in providing these services and (iii) components and attachments for manufactured equipment used in providing services, are recorded at the lower of cost or market value. Cost is determined using first-in, first-out (“FIFO”) method or the weighted average cost method. Market value is determined based on replacement cost for materials and supplies. The Company regularly reviews inventory quantities on hand and records a write-down for excess or obsolete inventory based primarily on its estimated forecast of product demand, market conditions, production requirements and technological developments.

Property, Plant and Equipment

Property, plant and equipment, including software costs, 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. Annual depreciation and amortization expenses are computed using the following useful lives: operating equipment, 3 to 20 years; buildings and leasehold improvements or the life of the lease, 15 to 39 years; furniture and fixtures, 5 to 7 years; software, 5 years; and vehicles, 3 to 5 years. The cost of assets retired or otherwise disposed of and the related accumulated depreciation and amortization are eliminated from the accounts in the year of disposal with the resulting gain or loss credited or charged to income from operations. Expenditures for additions, major renewals, and betterments are capitalized. Expenditures for restoring an identifiable asset to working condition or for maintaining the asset in good working order constitute repairs and maintenance and are expensed as incurred.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

RPC records impairment losses on long-lived assets used in operations when events and circumstances indicate that the assets might be impaired and the undiscounted cash flows estimated to be generated by those assets are less than the carrying amount of those assets. The Company periodically reviews the values assigned to long-lived assets, such as property, plant and equipment and other assets, to determine if any impairments should be recognized. Management believes that the long-lived assets in the accompanying balance sheets have not been impaired. During 2015, RPC recorded immaterial write-downs on certain equipment to comply with the Company’s policy to store and maintain key equipment in an efficient manner.

Goodwill

Goodwill represents the excess of the purchase price over the fair value of net assets of businesses acquired. The carrying amount of goodwill was $32,150,000 at December 31, 2015 and 2014. Goodwill is reviewed annually, or more frequently if events occur or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount, for impairment. The Company completes on an annual basis a comprehensive qualitative assessment of the various factors that impact goodwill, and concluded it is more likely than not that the fair value of its reporting units exceeds their carrying amounts as of the annual test date.  Therefore the Company did not proceed to Step 1 of the goodwill impairment test in 2015, 2014 and 2013.  Based on the qualitative assessment, the Company concluded that no impairment of its goodwill occurred for the years ended December 31, 2015, 2014 and 2013.

Advertising

Advertising expenses are charged to expense during the period in which they are incurred. Advertising expenses totaled $2,058,000 in 2015, $3,959,000 in 2014, and $3,458,000 in 2013.

Insurance Expenses

RPC self insures, up to certain policy-specified limits, certain risks related to general liability, workers’ compensation, vehicle and equipment liability, and employee health insurance plan costs. The estimated cost of claims under these self-insurance programs is estimated and accrued as the claims are incurred (although actual settlement of the claims may not be made until future periods) and may subsequently be revised based on developments relating to such claims. The portion of these estimated outstanding claims expected to be paid more than one year in the future is classified as long-term accrued insurance expenses.

Income Taxes

Deferred tax liabilities and assets are determined based on the difference between the financial and tax bases of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. The Company establishes a valuation allowance against the carrying value of deferred tax assets when the Company determines that it is more likely than not that the asset will not be realized through future taxable income.

The Company elected to early adopt the provisions of Accounting Standards Update 2015-17 that requires all deferred tax balances to be classified as non-current. Accordingly, net deferred tax balances have been reflected as a non-current liability in the accompanying balance sheet as of December 31, 2015. Deferred tax balances for prior periods have not been retrospectively adjusted.

Defined Benefit Pension Plan

The Company has a defined benefit pension plan that provides monthly benefits upon retirement at age 65 to eligible employees with at least one year of service prior to 2002. In 2002, the Company’s Board of Directors approved a resolution to cease all future retirement benefit accruals under the defined benefit pension plan. See Note 10 for a full description of this plan and the related accounting and funding policies.

Share Repurchases

The Company records the cost of share repurchases in stockholders’ equity as a reduction to common stock to the extent of par value of the shares acquired and the remainder is allocated to capital in excess of par value and retained earnings if capital in excess of par value is depleted.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Earnings per Share

FASB ASC Topic 260-10 “Earnings Per Share-Overall,” requires a basic earnings per share and diluted earnings per share presentation. The Company considers all outstanding unvested share-based payment awards that contain non-forfeitable rights to dividends or dividend equivalents, whether paid or unpaid, to be participating securities. The Company has periodically issued share-based payment awards that contain non-forfeitable rights to dividends, and therefore are considered participating securities. See Note 10 for further information on restricted stock granted to employees.

The basic and diluted calculations differ as a result of the dilutive effect of stock options, time lapse restricted shares and performance restricted shares included in diluted earnings per share, but excluded from basic (loss) earnings per share. Basic and diluted (loss) earnings per share are computed by dividing net (loss) income by the weighted average number of shares outstanding during the respective periods.

A reconciliation of weighted average shares outstanding along with the (losses) earnings per share attributable to restricted shares of common stock (participating securities) is as follows:

Fair Value of Financial Instruments

The Company’s financial instruments consist primarily of cash and cash equivalents, accounts receivable, investments, accounts payable, and debt. The carrying value of cash and cash equivalents, accounts receivable and accounts payable approximate their fair value due to the short-term nature of such instruments. The Company’s investments are classified as available-for-sale securities with the exception of investments held in the non-qualified Supplemental Executive Retirement Plan (“SERP”) which are classified as trading securities. All of these securities are carried at fair value in the accompanying consolidated balance sheets. See Note 8 for additional information.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Stock-Based Compensation

Stock-based compensation expense is recognized for all share-based payment awards, net of an estimated forfeiture rate. Thus, compensation cost is amortized for those shares expected to vest on a straight-line basis over the requisite service period of the award. See Note 10 for additional information.

Recent Accounting Pronouncements

During the year ended December 31, 2015, the Financial Accounting Standards Board (FASB) issued the following applicable Accounting Standards Updates (ASU):

Recently Adopted Accounting Pronouncements:

Accounting Standards Update 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The amendments in the ASU require that only disposals representing a strategic shift in operations should be presented as discontinued operations. Those strategic shifts should have a major effect on the organization’s operations and financial results. Examples include a disposal of a major geographic area, a major line of business, or a major equity method investment. In addition, the new guidance requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income, and expenses of discontinued operations. The new guidance also requires disclosure of the pre-tax income attributable to a disposal of a significant part of an organization that does not qualify for discontinued operations reporting. The Company adopted these provisions in the first quarter of 2015 and the adoption did not have a material impact on the Company’s consolidated financial statements.

Accounting Standards Update No. 2015-15, Interest—Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements. In April 2015, the FASB issued ASU No. 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, which requires the presentation of debt issuance costs related to a recognized debt liability as a direct deduction from the carrying amount of that debt liability. ASU 2015-03 does not address presentation or subsequent measurement of debt issuance costs related to line-of-credit arrangements. Given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements, the SEC staff has approved deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Company currently reports its debt issuance costs as part of non-current other assets and therefore is in compliance with this guidance.

Accounting Standards Updates No. 2015-17, Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes. The amendments in this ASU eliminates the current requirement to present deferred tax liabilities and assets as current and noncurrent in a classified balance sheet and now requires that all deferred tax assets and liabilities be classified as noncurrent. The amendments are effective for financial statements issued for annual periods beginning after December 15, 2016, with early application permitted. The Company elected to early adopt the provisions of this ASU and classified its deferred tax balances as a non-current liability as of December 31, 2015. Deferred tax balances for prior periods have not been retrospectively adjusted.

Recently Issued Accounting Pronouncements Not Yet Adopted:

Accounting Standards Update No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments. To simplify the accounting for adjustments made to provisional amounts recognized in a business combination, the amendments in this ASU eliminate the requirement to retrospectively account for those adjustments. Instead, an acquirer is required to recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. All of the changes are to be recorded in the reporting period and calculated as if the accounting had been completed at the acquisition date and either disclosed on the face of the income statement or in the notes by each category. These amendments are effective for fiscal years beginning after December 15, 2015, including interim periods within those fiscal years. The amendments are to be applied prospectively to adjustments to provisional amounts that occur after the effective date with earlier application permitted for financial statements that have not been issued. The Company plans to adopt the provisions in the first quarter of 2016 for all business combinations completed thereafter and currently does not expect the adoption to have a material impact on its consolidated financial statements.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Accounting Standards Update No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. Current guidance requires an entity to measure inventory at the lower of cost or market. Market could be replacement cost, net realizable value, or net realizable value less an approximately normal profit margin. The amendments in this ASU simplify the measurement process and allows inventory to be measured at lower of cost or net realizable value and eliminates the market requirement. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The amendments do not apply to inventory that is measured using last-in, first-out or the retail inventory method. The amendments are effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The amendments are to be applied prospectively with earlier application permitted. The Company plans to adopt the provisions in the first quarter of 2017 and currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update No. 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent). The amendments apply to the fair value of an investment that is measured using the net asset value per share (or its equivalent) practical expedient. The amendments remove the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendments also remove the requirement to make certain disclosures for all investments that are eligible to be measured at fair value using the net asset value per share practical expedient. The amendments are effective for public business entities for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years and are required to be applied retrospectively to all periods presented, with earlier application permitted. The Company plans to adopt the provisions in the first quarter of 2016 and currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update No. 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The amendments in this ASU require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this ASU. The amendments should be applied on a retrospective basis, wherein the balance sheet of each individual period presented should be adjusted to reflect the period-specific effects of applying the new guidance. Upon transition, an entity is required to comply with the applicable disclosures for a change in an accounting principle. These disclosures include the nature of and reason for the change in accounting principle, the transition method, a description of the prior-period information that has been retrospectively adjusted, and the effect of the change on the financial statement line items (i.e., debt issuance cost asset and the debt liability). The amendments in this ASU are effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption of the amendments is permitted for financial statements that have not been previously issued. The Company plans to adopt the provisions in the first quarter of 2016 and currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update No. 2014-15, Presentation of Financial Statements —Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The provisions in this ASU are intended to define management’s responsibility to evaluate whether there is substantial doubt about an organization’s ability to continue as a going concern and to provide related footnote disclosures. Currently, financial statements are prepared under the presumption that the reporting organization will continue to operate as a going concern, except in limited circumstances. This going concern basis of accounting is critical to financial reporting because it establishes the fundamental basis for measuring and classifying assets and liabilities. This ASU provides guidance regarding management’s responsibility to evaluate whether there is substantial doubt about the organization’s ability to continue as a going concern and the related footnote disclosures. The amendments are effective for the year ending December 31, 2016, and for interim periods beginning the first quarter of 2017, with early application permitted. The Company plans to adopt these provisions in the first quarter of 2016 and will provide such disclosures as required if there are conditions and events that raise substantial doubt about its ability to continue as a going concern. The Company currently does not expect the adoption to have a material impact on its consolidated financial statements.

Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU affects any entity using U.S. GAAP that either enters into contracts with customers to transfer goods or services or enters into contracts for the transfer of nonfinancial assets unless those contracts are within the scope of other standards (e.g., insurance contracts or lease contracts). The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. To achieve that core principle, an entity should apply a five step process – (i) identifying the contract(s) with a customer, (ii) identifying the performance obligations in the contract, (iii) determining the transaction price, (iv) allocating the transaction price to the performance obligations in the contract and (v) recognizing revenue when (or as) the entity satisfies a performance obligation. The Company plans to adopt these provisions in the first quarter of 2018 in accordance with ASU 2015-14 that deferred the effective date of ASU 2014-09 for all entities by one year. The Company is currently evaluating the impact of these provisions on its consolidated financial statements.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Note 2: Accounts Receivable

Accounts receivable, net consists of the following:

Trade receivables relate to sale of our services and products, for which credit is extended based on our evaluation of the customer’s credit worthiness. Unbilled receivables represent revenues earned but not billed to the customer until future dates, usually within one month. Other receivables consist primarily of amounts due from purchases of Company property and rebates from suppliers.

Changes in the Company’s allowance for doubtful accounts are as follows:

Note 3: Inventories

Inventories are $128,441,000 at December 31, 2015 and $155,611,000 at December 31, 2014 and consist of raw materials, parts and supplies.

Note 4: Property, Plant and Equipment

Property, plant and equipment are presented at cost net of accumulated depreciation and consist of the following:

Depreciation expense was $274.4 million in 2015, $233.4 million in 2014, and $215.4 million in 2013, and includes amounts recorded as costs of sales and inventory. There were no capital leases outstanding as of December 31, 2015 and December 31, 2014. The Company had accounts payable for purchases of property and equipment of $2.4 million as of December 31, 2015, $38.5 million as of December 31, 2014, and $19.7 million as of December 31, 2013.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Effective January 1, 2015, the Company reassessed the useful life of a specific component of its pressure pumping equipment. Prior to January 1, 2015, this component was recorded as property, plant and equipment and depreciated over an expected useful life of 18 months. As a result of this reassessment, the Company has concluded that this component is no longer a long-lived asset, but instead a consumable supply inventory item. Accordingly, effective January 1, 2015, the cost of this component is being expensed as repairs and maintenance as part of cost of revenues at the time of installation. Management deemed the change preferable because it more closely reflects the pattern of consumption of this component as a result of continual increases in wear and tear resulting from harsher geological environments.

This change was accounted for as a change in accounting estimate effected by a change in accounting principle. The net impact of this change in accounting estimate effected by a change in accounting principle on operating income and net income is not material. The change has resulted in an increase in the cost of revenues of $41,919,000 during 2015, while loss on dispositions and depreciation expense relating to this component decreased by a comparable amount during the period. Additionally, due to the change in accounting estimate effected by a change in accounting principle, purchases and deployment of this component will no longer be reflected as a capital expenditure under the investing activities section in the consolidated statement of cash flows, but instead will be reflected within cash flows from operating activities. The remaining net book value of these components at December 31, 2014 was $16,406,000 and was depreciated over an estimated weighted average remaining useful life of approximately 12 months. Loss on disposition related to this component totaled $21,408,000 in 2014.

Note 5: Income Taxes

The following table lists the components of the provision for income taxes:

Reconciliation between the federal statutory rate and RPC’s effective tax rate is as follows:

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Significant components of the Company’s deferred tax assets and liabilities are as follows:

As of December 31, 2015, undistributed earnings of the Company's foreign subsidiaries totaled $12.6 million. Additional U.S. taxes due upon full repatriation would be approximately $500 thousand. However, those earnings are considered to be indefinitely reinvested and, accordingly, no U.S. federal and state income taxes have been provided thereon. Upon distribution of these earnings in the form of dividends or otherwise, the Company would be subject to both U.S. income taxes and withholding taxes payable to the foreign countries. The Company's current intention is to permanently reinvest funds held in our foreign subsidiaries outside of the U.S., with the possible exception of repatriation of funds that have been previously subject to U.S. federal and state taxation or when it would be tax effective through the utilization of foreign tax credits, or would otherwise create no additional U.S. tax cost.

As of December 31, 2015, the Company has net operating loss carry forwards related to state income taxes of approximately $9.6 million that will expire between 2016 and 2034. As of December 31, 2015, the Company has a valuation allowance of approximately $280 thousand, representing the tax affected amount of loss carry forwards that the Company does not expect to utilize, against the corresponding deferred tax asset.

Total net income tax (refunds) payments were $(7.9) million in 2015, $152.2 million in 2014, and $122.9 million in 2013.

The Company and its subsidiaries are subject to U.S. federal and state income taxes in multiple jurisdictions. In many cases our uncertain tax positions are related to tax years that remain open and subject to examination by the relevant taxing authorities. The Company’s 2012 through 2015 tax years remain open to examination. Additional years may be open to the extent attributes are being carried forward to an open year. In 2015, the Internal Revenue Service (IRS) completed an examination of the Company’s U.S. federal income tax return and related matters for the 2011 tax year that yielded no adjustments.

During 2015 and 2014, the Company recognized an increase in its liability for unrecognized tax benefits in the current year related primarily to refund claims filed for state income taxes. If recognized, the liability would affect our effective rate. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:

The Company’s policy is to record interest and penalties related to income tax matters as income tax expense. Accrued interest and penalties as of December 31, 2015 and 2014 were approximately $411 thousand and $146 thousand, respectively.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

It is reasonably possible that the amount of the unrecognized tax benefits with respect to our unrecognized tax positions will significantly decrease in the next 12 months. These changes may result from, among other things, state tax settlements under or conclusions of ongoing examinations or reviews, however, quantification of an estimated range cannot be made at this time.

The Protecting Americans from Tax Hikes Act of 2015 (“PATH”) was signed into law on December 18, 2015 and retroactively reinstated the bonus depreciation deduction for 2015 and future years. The acceleration of deductions on 2015 qualifying capital expenditures resulting from the bonus depreciation provision had no impact on our 2015 effective tax rate.

In September 2013, the U.S. Department of the Treasury issued final regulations under Internal Revenue Code Sections 162(a), 263(a), and 168 that provide guidance on the deduction and capitalization of expenditures related to tangible property. Adoption of these regulations required certain mandatory and elective accounting methods with respect to property and equipment, inventory and supplies. RPC adopted these regulations as of January 1, 2014 and filed all required method changes. The adoption resulted in accelerated deductions totaling approximately $21.8 million (gross) for assets placed in service before December 31, 2013, approximately $16.2 million (gross) for assets placed in service during 2014, and approximately $13.5 million (gross) for assets placed in service in 2015.

Note 6: Long-Term Debt

The Company has a revolving credit facility with Banc of America Securities, LLC, SunTrust Robinson Humphrey, Inc., and Regions Capital Markets as Joint Lead Arrangers and Joint Book Managers, and a syndicate of other lenders. The facility has a general term of five years and provides for an unsecured line of credit of up to $125 million, including a $50 million letter of credit subfacility, and a $35 million swingline subfacility. The revolving credit facility includes a full and unconditional guarantee by the Company's 100 percent owned domestic subsidiaries whose assets equal substantially all of the consolidated assets of RPC and its subsidiaries. The Company’s subsidiaries that are not guarantors are considered minor.

On November 30, 2015, the Company gave notice to the syndicate it was reducing the size of the facility, which was previously $350 million, to $125 million. No other terms were changed.

On January 17, 2014, the Company amended the revolving credit facility extending the maturity date of all the revolving loans from August 31, 2015 to January 17, 2019.  Interest rates on the amended loans were reduced by 0.125% at all pricing levels under the amended revolving credit facility.  The amount of the swing line sub-facility as a result of the amendment was increased from $25 million to $35 million. RPC incurred commitment fees and other debt related costs associated with the amendment of approximately $0.7 million. 

The Company has incurred loan origination fees and other debt related costs associated with the revolving credit facility in the aggregate of approximately $3.0 million.  These costs, net of amounts written off as a result of the reduction in the revolving credit facility in 2015, are being amortized to interest expense over the remaining term of the five year loan, and the net amount of $0.3 million at December 31, 2015 is classified as non-current other assets.

Revolving loans under the Revolving Credit Agreement bear interest at one of the following two rates, at the Company's election:

In addition, the Company pays an annual fee ranging from 0.225% to 0.325%, based on a quarterly debt covenant calculation, on the unused portion of the credit facility.

The revolving credit facility contains customary terms and conditions, including certain financial covenants and restrictions on indebtedness, dividend payments, business combinations and other related items. Further, the revolving credit facility contains financial covenants limiting the ratio of the Company's consolidated debt-to-EBITDA to no more than 2.5 to 1, and limiting the ratio of the Company's consolidated EBITDA to debt service coverage to no less than 2 to 1. The Company was in compliance with these covenants for the year ended December 31, 2015.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

As of December 31, 2015, RPC had no outstanding borrowings under the revolving credit facility and letters of credit outstanding relating to self-insurance programs and contract bids totaling $29.3 million; therefore, a total of $95.7 million was available under the revolving credit facility. Interest incurred and paid on the credit facility, interest capitalized related to facilities and equipment under construction, and the related weighted average interest rates were as follows for the periods indicated:

On January 4, 2016, the Company entered into a one year $35 million uncommitted letter of credit facility with Bank of America, N.A; accordingly, $125 million is now available under the revolving credit facility. Under the terms of the letter of credit facility, the Company will pay 0.75% per annum on outstanding letters of credit. No origination fees were incurred in connection with this facility.

Note 7: Accumulated Other Comprehensive (Loss) Income

Accumulated other comprehensive (loss) income consists of the following (in thousands):

Note 8: Fair Value Disclosures

The various inputs used to measure assets at fair value establish a hierarchy that distinguishes between assumptions based on market data (observable inputs) and the Company’s assumptions (unobservable inputs). The hierarchy consists of three broad levels as follows:

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

The following table summarizes the valuation of financial instruments measured at fair value on a recurring basis on the balance sheet as of December 31, 2015 and 2014:

The Company determines the fair value of marketable securities classified as available-for-sale through quoted market prices. The total fair value is the final closing price, as defined by the exchange in which the asset is actively traded, on the last trading day of the period, multiplied by the number of units held without consideration of transaction costs. Marketable securities classified as trading are comprised of the SERP assets, as described in Note 10, and are recorded primarily at their net cash surrender values, which approximates fair value, as provided by the issuing insurance company. Significant observable inputs, in addition to quoted market prices, were used to value the trading securities. As a result, the Company measured the fair value of these investments using level 2 inputs. The Company’s policy is to recognize transfers between levels at the beginning of quarterly reporting periods. For the year ended December 31, 2015 there were no significant transfers in or out of levels 1, 2 or 3.

Under the Company’s revolving credit facility, there was no balance outstanding at December 31, 2015. The balance outstanding at December 31, 2014 was $224,500,000, and based on the quote from the lender (level 2 inputs) is similar to the fair value at the same date. The borrowings under our revolving credit facility bear variable interest rates as described in Note 6. The Company is subject to interest rate risk on the variable component of the interest rate.

The carrying amounts of other financial instruments reported in the balance sheet for current assets and current liabilities approximate their fair values because of the short maturity of these instruments. The Company currently does not use the fair value option to measure any of its existing financial instruments and has not determined whether or not it will elect this option for financial instruments it may acquire in the future.

Note 9: Commitments and Contingencies

Lease Commitments - Minimum annual rentals, principally for noncancelable real estate and equipment leases with terms in excess of one year, in effect at December 31, 2015, are summarized in the following table:

Total rental expense, including short-term rentals, charged to operations was $20,658,000 in 2015, $22,968,000 in 2014, and $20,582,000 in 2013.

Income Taxes - The amount of income taxes the Company pays is subject to ongoing audits by federal and state tax authorities, which often result in proposed assessments.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31 2015, 2014 and 2013

Sales and Use Taxes - The Company has ongoing sales and use tax audits in various jurisdictions and may be subjected to varying interpretations of statute that could result in unfavorable outcomes. Any probable and estimable assessment costs are included in accrued state, local and other taxes.

Litigation - 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, after consultation with legal counsel, believes that it is not reasonably possible that the outcome of all such proceedings, even if determined adversely, would have a material adverse effect on the Company’s business or financial condition.

Note 10: Employee Benefit Plans

Defined Benefit Pension Plan

The Company’s Retirement Income Plan, a trusteed defined benefit pension plan, provides monthly benefits upon retirement at age 65 to substantially all employees with at least one year of service prior to 2002. During 2001, the plan became a multiple employer plan, with Marine Products Corporation as an adopting employer.

The Company’s projected benefit obligation exceeds the fair value of the plan assets under its pension plan by $12.0 million and thus the plan was under-funded as of December 31, 2015. The following table sets forth the funded status of the Retirement Income Plan and the amounts recognized in RPC’s consolidated balance sheets: