RPC INC - Annual Report: 2014 (Form 10-K)

WASHINGTON, D.C. 20549

FORM 10-K

 

 

For the fiscal year ended December 31, 2014

 

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 not required to file reports pursuant to Section 13 or Section 15(d) of the Act. ☐ Yes ☒ No

 

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

 

Indicate by check mark whether the registrant has submitted electronically 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 ☒ 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. ☐

 

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 ☒      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 ☒

 

The aggregate market value of RPC, Inc. Common Stock held by non-affiliates on June 30, 2014, the last business day of the registrant’s most recently completed second fiscal quarter, was $1,436,608,678 based on the closing price on the New York Stock Exchange on June 30, 2014 of $23.49 per share.

 

RPC, Inc. had 217,090,722 shares of Common Stock outstanding as of February 13, 2015.

 

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 for the next twelve months; 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; the adequacy of our insurance coverage; the impact of lawsuits, legal proceedings and claims on our business and financial condition; our expectation to continue to pay cash dividends to the common stockholders subject to the earnings and financial condition of the Company and other relevant factors; 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 2015; our statement that most industry analysts believe that the rig count will continue to decline during the remainder of the first quarter and into second quarter 2015; our statement that industry trends have negative implications for our near-term activity levels; our belief that it is likely that our near-term financial results will be negatively impacted by declining prices; our belief that the overall rig count will not increase during 2015 unless the price of oil increases from its current price; our cautious view about the market for our services; our belief that any potential increase in the price of natural gas will not be enough to encourage our customers to increase their natural gas-directed drilling activities; 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 that the majority of our customers have access to adequate capital to finance their own ongoing operations; our statement that we do not plan additional increases in our fleet of revenue-producing equipment during 2015; 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 2015; our ability to fund capital requirements in the future; the estimated amount of our capital expenditures and contractual obligations for future periods; our statement that indications at the end fourth quarter 2014 and early in the first quarter of 2015 are that the prices of both skilled labor and many of the raw materials used in providing our services has started to decline; our belief that declining oilfield activity during 2015 will decrease both wage rates for skilled labor and the prices of raw materials; our belief that it will be difficult to realize higher operating profits from these 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, 2014, RPC had approximately 4,500 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 2014, approximately 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 60 percent of our 2014 revenues were related to drilling and production activities for oil, and 40 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 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 57 percent of 2014 revenues, 55 percent of 2013 revenues and 53 percent of 2012 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 15 percent of 2014 revenues, 16 percent of 2013 revenues and 14 percent of 2012 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 2014 and 2013 revenues and 11 percent of 2012 revenues, 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 2014 and four percent of revenues in 2013 and 2012, 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 three percent of revenues in 2014 and four percent of revenues in 2013 and 2012.  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 2014 and 2013 revenues and five percent of 2012 revenues.  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 66 percent from its peak in 1981.  However, due to recently enhanced technology, more wells are being drilled, and these wells are increasingly productive.  For these reasons, the domestic production of natural gas has risen to record levels, and we estimate that the domestic production of crude oil during 2014 was at its highest level since 1986.  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 and into the first quarter of 2015.  Early in the first quarter of 2015, the U.S. domestic drilling rig count has declined by approximately 30 percent from the peak.

The fluctuations in domestic drilling activity since 2008 are consistent with the changes in the prices of oil and natural gas, the overall economic recovery following the recession in 2008 and 2009, and most recently, the large increase in global oil production that became apparent during the third and fourth quarters of 2014.  During 2014 the average price of natural gas increased by approximately 15 percent, although it began to decline during the end of the first quarter of 2014, and at the end of the year was approximately 35 percent lower than at the same time in 2013.  During the first quarter of 2015, the price of natural gas continued to decline slightly.   The average price of oil decreased by approximately five percent during 2014 compared to 2013.  However, the price of oil decreased significantly during the third and fourth quarters of 2014, falling by approximately 48 percent during that time.  The price of oil has continued to decline during 2015, and in the first quarter to date was approximately five percent lower than at the end of 2014.  RPC believes that the decrease in the price of oil during this period has been caused by increased supply from the domestic U.S. market, weak global demand, the actions of the OPEC cartel, and the strength of the U.S. dollar on global currency markets.  The precipitous decline in the price of oil during the third and fourth quarters of 2014 and the first quarter of 2015 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 21 percent. The price of natural gas liquids has become an increasingly important 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 2014 the average price of natural gas liquids increased by approximately five percent compared to 2013, but early in the first quarter of 2015 had declined by approximately seven percent.  The declines in the prices of oil, natural gas, and natural gas liquids during 2014 and the first quarter of 2015 to date carry significant negative implications for RPC’s customer activity levels for the next twelve months.

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 21 percent of total drilling activity.  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 natural gas production from oil-directed wells.  The price of natural gas has declined following a colder than normal winter in 2014, and by early in the first quarter of 2015 had fallen below $3 per Mcf for the first time since the third quarter of 2012.  Early in the first quarter of 2015, the amount of natural gas in storage in the United States was approximately one percent lower than the five-year average at this time in the year.  We believe 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. This lack of foreign competition tends to keep prices high enough to ensure that domestic drilling and production will continue at certain minimum levels.  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 during the third and fourth quarters of 2014 and the first quarter of 2015 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, and during 2014 equipment and raw materials requirements of the services we perform for our customers continued to increase.

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 requires a great deal of pressure pumping horsepower 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 presently account for approximately four percent of RPC’s consolidated revenues.  RPC’s equipment investments over the last several years have emphasized domestic rather than international expansion because of higher expected financial returns.  International revenues for 2014 increased compared to 2013 due to higher customer activity levels in Australia, Argentina and Gabon partially offset by lower customer activity in Canada.  During 2014, RPC provided snubbing, well control and oilfield training services in several countries including Gabon and Australia.  We also provided downhole motors and tools in Canada, Mexico and Oman, and rental tools in Bolivia and 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 five percent of total revenues in 2015.

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.  Because of the fragmented nature of the oil and gas services industry, RPC believes a number of acquisition opportunities exist.  However, the favorable long-term outlook for our industry and the strong historical profitability of many potential acquisitions has encouraged potential sellers of businesses to expect high valuations for their businesses.  Due to these high valuations and the potential difficulty of integrating acquired businesses into our existing operations, we believe we generate better returns on investments growing organically in service lines and geographic locations in which we have experience and presence.  We will continue to be selective in pursuing growth through acquisitions of existing businesses.

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.  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 began to take delivery of this equipment during the third and fourth quarters of 2014, and anticipate that the remainder of the equipment will be delivered during the first quarter of 2015.  The outstanding balance on our credit facility at the end of 2014 was higher than at the end of the prior year due to an increase in capital expenditures and working capital, and our ratio of debt to total capitalization continues to be conservative compared to a number 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 2014, RPC provided oilfield services to several hundred customers, none of which accounted for more than 10 percent of revenues.

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 2012, 2013 and 2014.  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 will adversely affect the demand for our products and services and our financial condition and results of operations.

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 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.

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.  In 2014, 2013 and 2012, none of our customers exceeded 10 percent of our total revenues.  In addition, no customer accounted for more than ten percent of accounts receivable as of December 31, 2014 and 2013.  Reliance on a large customer for a significant portion of our total revenues could expose 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 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 has also undertaken a study of the environmental impact of hydraulic fracturing practices. As of early in the first quarter of 2015, the issuance of the report disclosing these findings is pending.  One of the results of this scrutiny has been to require disclosure of materials used in hydraulic fracturing on certain public lands.  RPC participates in this disclosure process and has cooperated fully with all governmental requests for information regarding our operations.  In addition, during the first quarter of 2014, the federal government proposed that specific geographic areas in which natural gas-directed drilling and production from shale formations be set aside as economic development zones.  Such designations, if they arise in geographic areas in which RPC conducts its operations, may increase demand for our customers’ natural gas production, thus increasing demand for RPC’s services.  Such designations may also increase our operating costs due to the cost of compliance with increased regulation as well as subsidies paid by firms engaged in natural gas-directed drilling to other industries which establish operations in these economic development zones.  We are unable to predict whether the 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.  Also, we are unable to predict the magnitude and timing of the impact on our operations and operational costs, if any, of the creation of economic development zones in geographic areas in which natural gas-directed drilling and production from shale formations take place.

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

Our operations in various countries including, but not limited to, Africa, Canada, 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 72 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 can limit our ability to provide services, or increase the costs of providing services, thus reducing 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 $350 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 — Pumping services facility

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.

(1) R. Randall Rollins began working for Rollins, Inc. (consumer services) in 1949. Mr. Rollins has served as Chairman of the Board of RPC since the spin-off of RPC from Rollins, Inc. in 1984.  He has served as Chairman of the Board of Marine Products Corporation (boat manufacturing) since it was spun off from RPC in 2001 and Chairman of the Board of Rollins, Inc. since October 1991. He is also a director of Dover Downs Gaming and Entertainment, Inc. and Dover Motorsports, Inc.

(2) Richard A. Hubbell has been the President of RPC since 1987 and Chief Executive Officer since 2003. He has also been the President and Chief Executive Officer of Marine Products Corporation since it was spun off from RPC in February 2001. Mr. Hubbell serves on the Board of Directors of both of these companies.

(3) Linda H. Graham has been the Vice President and Secretary of RPC since 1987.  She has also been the Vice President and Secretary of Marine Products Corporation since it was spun off from RPC in 2001. Ms. Graham serves on the Board of Directors of both of these companies.

(4) Ben M. Palmer has been the Vice President, Chief Financial Officer and Treasurer of RPC since 1996.  He has also been the Vice President, Chief Financial Officer and Treasurer of Marine Products Corporation since it was spun off from RPC in 2001.

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 13, 2015 there were 217,090,722 shares of common stock outstanding and approximately 40,300 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, 2014 and 2013:

 

On January 27, 2015 RPC’s Board of Directors approved a $0.105 per share cash dividend, payable March 10, 2015 to stockholders of record at the close of business on February 10, 2015.  The Company expects to continue to pay cash dividends to the common stockholders, subject to the earnings and financial condition of the Company and other relevant factors.

Issuer Purchases of Equity Securities

Shares repurchased in the fourth quarter of 2014 are outlined below.

 

(1)

The Company has a stock buyback program initially adopted in 1998 and subsequently amended in 2013 that authorizes the repurchase of up to 31,578,125 shares.  There were 2,052,984 shares repurchased as part of this program during the fourth quarter of 2014.  As of December 31, 2014, there are 2,050,154 shares available to be repurchased under the current authorization.  Currently the program does not have a predetermined expiration date.

(2)

Includes shares purchased by “affiliated purchasers” under Rule 10b - 18 of the Securities Exchange Act in open market transactions.  These affiliated purchases were made by RFPS Investment II, L.P. and RFPS Management Co. II, L.P. of which LOR, Inc. is the manager.  Mr. R. Randall Rollins and Mr. Gary W. Rollins have voting control of LOR, Inc.

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 2014.  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 2014 of $122.7 billion, and a median market capitalization of $8.1 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:

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To focus our management resources on and invest our capital in equipment and geographic markets that we believe will earn high returns on capital.

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To maintain a flexible cost structure that can respond quickly to volatile industry conditions and business activity levels.

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To maintain an efficient, low-cost capital structure which includes an appropriate use of debt financing.

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To maintain high asset utilization which leads to increased revenues and leverage of direct and overhead costs, while also ensuring that increased maintenance resulting from high utilization does not interfere with customer performance requirements or jeopardize safety.

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To deliver equipment and services to our customers safely.

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To secure adequate sources of supplies of certain high-demand raw materials used in our operations, both in order to conduct our operations and to enhance our competitive position.

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To maintain and selectively increase market share.

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To maximize stockholder return by optimizing the balance between cash invested in the Company’s productive assets, the payment of dividends to stockholders, and the repurchase of our common stock on the open market.

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To align the interests of our management and stockholders.

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 the level of 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 $50 per barrel early in the first quarter of 2015, a level not observed since the second quarter of 2009.  As a result, the U.S. domestic rig count is declining, and early in the first quarter of 2015 has declined by almost 30 percent since the third quarter of 2014.  The catalysts for the recent steep decline in the price of oil include the perception that global oil supplies are higher than demand, the forecasted decline in oil demand growth, 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 accelerated in the first quarter of 2015 following an announcement by OPEC 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 2014, 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 in 2015 are the most likely initial catalyst 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 remaining at its lowest level since the second quarter of 1995.  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 presently cannot be exported from the United States to other markets in which demand and prices are higher.  The price of natural gas increased during the first quarter of 2014 due to winter weather that was colder than normal, but has declined during the third and fourth quarters of 2014 and the first quarter of 2015.  Early in the first quarter of 2015, the price of natural gas had fallen to its lowest level since the second quarter of 2012, due to the fact that winter in 2015 has thus far not been as cold as the previous winter, and that natural gas in storage in the United States has increased and is now approaching its average long-term storage level.

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 2014, the average number of horizontal and directional wells drilled in the United States increased by approximately 14 percent, and was 81 percent of total wells drilled during the year.  During the first part of 2015, the percentage of horizontal and directional wells drilled as a percentage of total wells rose to approximately 84 percent.  In addition, the percentage of wells drilled for oil increased to 82 percent during 2014 compared to 78 percent during 2013.  During the beginning of the first quarter of 2015, the percentage of wells drilled for oil decreased slightly to 81 percent.  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 2014, the total U.S. domestic well count increased by approximately five percent.  In the markets in which RPC has operational locations, the well count increased by approximately seven percent.  Pricing for our services did not change materially during 2014.  While there was continued downward pricing pressure due to a larger fleet of revenue-producing equipment in the U.S. domestic market, this impact was offset by greater service intensity and moderately higher customer activity levels.  During previous years, a number of our customers entered into contractual relationships with us to provide services to support their completion programs.  Such arrangements were advantageous to our customers because of the repetitive nature of this type of activity and their need to have service providers dedicated exclusively to their drilling programs.  These arrangements also positively impacted the Company’s financial results, because of increased utilization of our revenue-producing equipment and increased efficiency.  All of these arrangements had expired by the third quarter of 2013.  We do not expect to enter into additional contractual arrangements with such terms during 2015.

During 2014 the Company increased our purchases of revenue-producing equipment.  Cash flows from operating activities as well as borrowings under our revolving credit facility have been sufficient to fund the Company’s higher capital expenditures which increased to $371.5 million in 2014 compared to $201.7 million in 2013. 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 2014 totaled $2.3 billion, an increase of 25.6 percent compared to 2013 due primarily to higher activity levels and service intensity in our major services lines and a larger fleet revenue-producing equipment in our pressure pumping service line.  Cost of revenues increased $314.7 million in 2014 compared to the prior year due to higher materials and supplies expense and employment costs associated with higher activity levels and was approximately 64 percent of revenues in 2014 compared to 63 percent of revenues in 2013.  Selling, general and administrative expenses as a percentage of revenues decreased approximately 1.4 percentage points in 2014 compared to 2013.

Income before income taxes increased to $399.4 million in 2014 compared to $276.3 million in the prior year.  Diluted earnings per share were $1.14 in 2014 compared to $0.77 in the prior year.

Cash flows from operating activities decreased slightly to $322.8 million in 2014 compared to $365.6 million in 2013 primarily due to higher working capital requirements partially offset by higher earnings.  As of December 31, 2014, there were $224.5 million in outstanding borrowings under our credit facility, an increase from $53.3 million at December 31, 2013.

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 2015, the drilling rig count has fallen by approximately 30 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 has fallen by approximately 50 percent during this period. The price of oil began to fall at the end of the second quarter of 2014 due to the perceived oversupply of oil, weak global demand, and the strength of the U.S. dollar on world currency markets.  This decline accelerated during the fourth quarter of 2014 when OPEC stated that it would not curtail its production of oil in order to bring stability to oil prices.  As of the first quarter of 2015, most industry analysts believe that the rig count will continue to decline during the remainder of the first quarter and into second quarter of 2015.

The current and projected prices of oil and natural gas are important catalysts for U.S. domestic drilling activity.  As discussed above, the price of oil began to decline during the second quarter of 2014, and early in the first quarter of 2015 had fallen to its lowest recorded level since the second quarter of 2009.  The price of natural gas has also fallen during 2014 and early in 2015, and early in the first quarter of 2015 had reached its lowest recorded level since the second quarter of 2012.  The price of natural gas liquids has become an increasingly important determinant of our customers’ activities, since its sales comprise a component of our customers’ revenues, and it is produced in many of the shale resource plays that also produce oil.  During 2014, the average price of benchmark natural gas liquids increased by approximately five percent compared to the prior year, but early in the first quarter of 2015 decreased by approximately seven percent compared to the end of 2014. These trends have negative implications for our near-term activity levels.  In particular, 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.  RPC has operational locations and revenue-producing equipment in most of these locations, so it is likely that our near-term financial results will be negatively impacted by these declining prices.

The majority of the U.S. domestic rig count remains directed towards oil, although this percentage will decline as oil-directed drilling continues to fall in 2015.  Early in the first quarter of 2015, approximately 79 percent of the U.S. domestic rig count was directed towards oil, a slight 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.  We do not believe that the overall rig count will increase during 2015 unless the price of oil increases from its current price early in the first quarter of 2015.

We continue to monitor the market for our services and the competitive environment in 2015.  We are cautious about the market for our services because of the recent steep decline in the U.S. domestic rig count 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.  We believe that the price of natural gas may increase during the short term because of cold weather during the first quarter of 2015, but we do not believe that any potential increase will be enough to encourage our customers to increase their natural gas-directed drilling activities. 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 are also encouraged by the fact that the drilling activities that are taking place during 2015 continue to be highly service-intensive and require a large amount of equipment and raw materials.

As we monitor the competitive environment during 2015, we also note that many of our competitors are relatively new entrants into the oilfield services market, and may have higher cost structures and less-developed logistical capabilities than RPC.  Also, many of these new entrants have financed their operations with a capital structure that includes a large amount of debt, so they may not have the ability to maintain their equipment in highly service intensive operating environments, and may not be able to operate for long periods of time in which they do not generate positive cash flow from operations.  These characteristics of our competitors encourage us regarding the overall level of competition in our markets.  In this environment RPC also monitors the financial capabilities 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 2015 than in previous years.  At this time RPC believes that the majority of its customers have access to adequate capital to finance their ongoing operations.  RPC initiated an expansion of its pressure pumping fleet in 2014, and during the fourth quarter of 2014 began to take delivery of this equipment.  We continue to take delivery of this revenue-producing equipment during the first quarter of 2015, but we do not plan additional increases in our fleet of revenue-producing equipment during 2015.  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, 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.  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 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 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 7.0 percent to $198.1 million in 2014 compared to $185.2 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 8.5 percent in 2014 compared to 9.9 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, net.  Other income, net was $0.8 million in 2014 compared to $2.3 million in 2013.  Other income, net primarily includes mark to market gains and losses of investments in the non-qualified benefit plan.

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 $419 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.

Year Ended December 31, 2013 Compared To Year Ended December 31, 2012

Revenues. Revenues in 2013 decreased $83.5 million or 4.3 percent compared to 2012.  The Technical Services segment revenues for 2013 decreased 3.6 percent from the prior year due primarily to lower pricing experienced in most of our service lines within this segment partially offset by higher service intensity and activity in our pressure pumping service line.  The Support Services segment revenues for 2013 decreased 12.7 percent compared to 2012 due primarily to lower pricing in the rental tool service line, which is the largest service line within this segment.  Operating profit in the both Technical Services and Support Services segment declined due to lower pricing.  Operating profit in the Technical Services segment also declined due to higher materials and supplies expense consistent with increased service intensity.

Domestic revenues decreased 4.0 percent during 2013 compared to 2012 to $1.8 billion due primarily to competitive pricing for our services in most service lines.  The average price of oil increased by four percent while the average price of natural gas increased by 36 percent during 2013 compared to the prior year.  The average domestic rig count during 2013 was eight percent lower than in 2012.   Increased competitive pricing for our services negatively impacted our operating income, income before income taxes, net income and earnings per share.  International revenues, which decreased from $74.2 million in 2012 to $65.9 million in 2013, were four percent of consolidated revenues in 2013 and 2012.  These international revenue decreases were due mainly to lower customer activity levels in New Zealand and Mexico in 2013 partially offset by an increase in activity in Equatorial Guinea, Gabon, Australia, Argentina and Bolivia, 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 2013 was $1.2 billion compared to $1.1 billion in 2012, an increase of $72.5 million or 6.6 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 in 2013 compared to 2012 due primarily to competitive pricing for our services.

Selling, general and administrative expenses.  Selling, general and administrative expenses increased 5.4 percent to $185.2 million in 2013 compared to $175.7 million in 2012.  This increase was due primarily to increases in total employment costs and bad debt expense.  As a percentage of revenues, selling, general and administrative expenses increased to 9.9 percent in 2013 compared to 9.0 percent in 2012.

Depreciation and amortization.  Depreciation and amortization were $213.1 million in 2013, a decrease of $1.8 million, compared to $214.9 million in 2012. As a percentage of revenues, depreciation and amortization remained relatively unchanged at 11.4 percent in 2013 compared to 11.0 percent in 2012.

Loss on disposition of assets, net. Loss on disposition of assets, net was $9.4 million in 2013 compared to $6.1 million in 2012.   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, net.  Other income, net was $2.3 million in 2013 compared to $2.2 million in 2012.  Other income, net primarily includes mark to market gains and losses of investments in the non-qualified benefit plan.

Interest expense and interest income.   Interest expense was $1.8 million in 2013 compared to $2.0 million in 2012.  The decrease in 2013 is due to a lower average debt balance on our revolving credit facility partially offset by slightly higher interest rates net of interest capitalized on equipment and facilities under construction.  Interest income increased to $419 thousand in 2013 compared to $30 thousand in 2012.

Income tax provision.  The income tax provision was $109.4 million in 2013 compared to $168.2 million in 2012.  This decrease was due to lower income before taxes in 2013 compared to 2012 partially offset by an increase in the effective tax rate to 39.6 percent in 2013 compared to the effective tax rate of 38.0 percent in 2012.

Net income and diluted earnings per share.   Net income was $166.9 million in 2013, or $0.77 per diluted share, compared to net income of $274.4 million, or $1.27 per diluted share in 2012.  This decline was due to lower profitability.

Liquidity and Capital Resources

Cash and Cash Flows

The Company’s cash and cash equivalents were $9.8 million as of December 31, 2014, $8.7 million as of December 31, 2013 and $14.2 million as of December 31, 2012.

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

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

Cash provided by operating activities decreased $194.3 million in 2013 compared to the prior year due primarily to a decrease in net income of $107.5 million, an unfavorable change in deferred taxes of $17.9 million due to a decrease in tax depreciation benefits resulting from lower capital expenditures coupled with an unfavorable change in working capital of $83.2 million.

The unfavorable change in working capital was primarily due to the following: an unfavorable change of $123.8 million in accounts receivable due to slightly higher business activity levels at the end of 2013 compared to declining activity levels at the end of the prior year; an unfavorable change of $25.1 million in other current assets due to lower deposits for raw materials; an unfavorable net change of $9.8 million in net current income taxes receivable/payable; and an unfavorable change of $4.6 million in accrued state, local and other taxes due to the timing of payments.  These unfavorable changes were partially offset by a favorable change of $54.4 million in inventories due to improved sourcing of critical materials and supplies that require longer lead times.

Cash used for investing activities in 2013 decreased by $108.2 million compared to 2012, primarily as a result of lower capital expenditures in response to highly competitive pricing.

Cash used for financing activities in  2013 decreased by $73.9 million primarily as a result of lower net loan repayments coupled with lower open market share repurchases, partially offset by a 25 percent increase in the per share common stock dividend declared during 2013 compared to the prior year.

Financial Condition and Liquidity

The Company’s financial condition as of December 31, 2014, 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.   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 $96.2 million was available under the facility as of December 31, 2014; $29.3 million of the facility supports outstanding letters of credit related to self-insurance programs or contract bids.  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 $371.5 million in 2014, and we currently expect capital expenditures to be approximately $200 million in 2015.  We expect that a majority of these expenditures in 2015 will be directed towards maintenance of our revenue-producing equipment and refurbishment of our existing fleet of pressure pumping equipment.  The remaining capital expenditures will be directed towards the purchase of revenue-producing equipment in several of our core service lines, including pressure pumping, coiled tubing and rental tools.  The actual amount of expenditures will depend primarily on equipment maintenance requirements, customer 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 2014, the Company contributed $0.8 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 2015 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 2,662,080 shares purchased on the open market during 2014 by the Company, and 2,050,154 shares remain available to be repurchased under the current authorization as of December 31, 2014.  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 January 27, 2015, the Board of Directors approved a $0.105 per share cash dividend, payable March 10, 2015 to stockholders of record at the close of business on February 10, 2015.  The Company expects to continue to pay cash dividends to common stockholders, subject to the earnings and financial condition of the Company and other relevant factors.

Contractual obligations		Payments due by period
(in thousands)		Total				Less than 1 year				1-3 years				3-5 years				More than 5 years
Long-term debt obligations		$	224,500			$	—			$	—			$	224,500			$	—
Interest on long-term debt obligations			24,650				4,850				9,698				9,698				404
Capital lease obligations			—				—				—				—				—
Operating leases (1)			41,458				10,938				12,669				8,402				9,449
Purchase obligations (2)			218,577				178,977				39,600				—				—
Other long-term liabilities (3)			2,554				50				2,404				100				—
Total contractual obligations		$	511,739			$	194,815			$	64,371			$	242,700			$	9,853

 

 

 

 

 

 

/s/ Richard A. Hubbell			/s/  Ben M. Palmer
Richard A. Hubbell President and Chief Executive Officer			Ben M. Palmer Chief Financial Officer and Treasurer

 

 

 

December 31,		2014				2013
ASSETS
Cash and cash equivalents		$	9,772			$	8,700
Accounts receivable, net			634,730				437,132
Inventories			155,611				126,604
Deferred income taxes			9,422				14,185
Income taxes receivable			29,115				5,720
Prepaid expenses			9,135				9,143
Other current assets			3,843				3,441
Current assets			851,628				604,925
Property, plant and equipment, net			849,383				726,307
Goodwill			32,150				31,861
Other assets			26,197				20,767
Total assets		$	1,759,358			$	1,383,860
LIABILITIES AND STOCKHOLDERS’ EQUITY
LIABILITIES
Accounts payable		$	175,416			$	119,170
Accrued payroll and related expenses			49,798				36,638
Accrued insurance expenses			5,632				6,072
Accrued state, local and other taxes			6,821				5,002
Income taxes payable			944				—
Other accrued expenses			401				1,170
Current liabilities			239,012				168,052
Long-term accrued insurance expenses			10,099				10,225
Notes payable to banks			224,500				53,300
Long-term pension liabilities			34,399				21,966
Deferred income taxes			156,977				153,176
Other long-term liabilities			15,989				8,439
Total liabilities			680,976				415,158
Commitments and contingencies (Note 9)
STOCKHOLDERS’ EQUITY
Preferred stock, $0.10 par value, 1,000,000 shares authorized, none issued			—				—
Common stock, $0.10 par value, 349,000,000 shares authorized, 216,539,015 and 218,985,816 shares issued and outstanding in 2014 and 2013, respectively			21,654				21,899
Capital in excess of par value			—				—
Retained earnings			1,074,561				956,918
Accumulated other comprehensive loss			(17,833	)			(10,115	)
Total stockholders’ equity			1,078,382				968,702
Total liabilities and stockholders’ equity		$	1,759,358			$	1,383,860

 

Years ended December 31,		2014				2013				2012
REVENUES		$	2,337,413			$	1,861,489			$	1,945,023
COSTS AND EXPENSES:
Cost of revenues (exclusive of items shown separately below)			1,493,082				1,178,412				1,105,886
Selling, general and administrative expenses			198,076				185,165				175,749
Depreciation and amortization			230,813				213,128				214,899
Loss on disposition of assets, net			15,472				9,371				6,099
Operating profit			399,970				275,413				442,390
Interest expense			(1,431	)			(1,822	)			(1,976	)
Interest income			19				419				30
Other income, net			828				2,260				2,175
Income before income taxes			399,386				276,270				442,619
Income tax provision			154,193				109,375				168,183
Net income		$	245,193			$	166,895			$	274,436
EARNINGS PER SHARE
Basic		$	1.14			$	0.77			$	1.28
Diluted		$	1.14			$	0.77			$	1.27
Dividends paid per share		$	0.42			$	0.40			$	0.52

 

Years ended December 31,		2014				2013				2012
NET INCOME		$	245,193			$	166,895			$	274,436
OTHER COMPREHENSIVE INCOME, NET OF TAXES:
Pension adjustment			(6,486	)			4,928				(1,707	)
Foreign currency translation			(1,124	)			(778	)			265
Unrealized loss on securities, net of reclassification adjustments			(108	)			(19	)			(158	)
COMPREHENSIVE INCOME		$	237,475			$	171,026			$	272,836

 

																		Accumulated Other Comprehensive Income (Loss)
Three Years Ended December 31, 2014		Common Stock								Capital in Excess of Par Value				Retained Earnings								Total
		Shares				Amount
Balance, December 31, 2011			221,188			$	22,119			$	—			$	753,119			$	(12,646	)		$	762,592
Stock issued for stock incentive plans and other, net			1,530				152				11,105				—				—				11,257
Stock purchased and retired			(2,011	)			(201	)			(13,885	)			(16,515	)			—				(30,601	)
Increased ownership interest in subsidiary, net of taxes			—				—				—				(5,507	)			—				(5,507	)
Net income			—				—				—				274,436				—				274,436
Pension adjustment, net of taxes			—				—				—				—				(1,707	)			(1,707	)
Foreign currency translation, net of taxes			—				—				—				—				265				265
Unrealized loss on securities, net of taxes			—				—				—				—				(158	)			(158	)
Dividends declared			—				—				—				(114,069	)			—				(114,069	)
Excess tax benefits for share-based payments			—				—				2,724				—				—				2,724
Three-for-two stock split			(563	)			(56	)			56				—				—				—
Balance, December 31, 2012			220,144				22,014				—				891,464				(14,246	)			899,232
Stock issued for stock incentive plans, net			699				70				8,107				—				—				8,177
Stock purchased and retired			(1,857	)			(185	)			(11,285	)			(13,652	)			—				(25,122	)
Net income			—				—				—				166,895				—				166,895
Pension adjustment, net of taxes			—				—				—				—				4,928				4,928
Foreign currency translation			—				—				—				—				(778	)			(778	)
Unrealized loss on securities, net of taxes			—				—				—				—				(19	)			(19	)
Dividends declared			—				—				—				(87,789	)			—				(87,789	)
Excess tax benefits for share-based payments			—				—				3,178				—				—				3,178
Balance, December 31, 2013			218,986				21,899				—				956,918				(10,115	)			968,702
Stock issued for stock incentive plans, net			569				57				9,017				—				—				9,074
Stock purchased and retired			(3,016	)			(302	)			(13,353	)			(35,942	)			—				(49,597	)
Net income			—				—				—				245,193				—				245,193
Pension adjustment, net of taxes			—				—				—				—				(6,486	)			(6,486	)
Foreign currency translation			—				—				—				—				(1,124	)			(1,124	)
Unrealized loss on securities, net of taxes			—				—				—				—				(108	)			(108	)
Dividends declared			—				—				—				(91,608	)			—				(91,608	)
Excess tax benefits for share-based payments			—				—				4,336				—				—				4,336
Balance, December 31, 2014			216,539			$	21,654			$	—			$	1,074,561			$	(17,833	)		$	1,078,382

 

Years ended December 31,		2014				2013				2012
OPERATING ACTIVITIES
Net income		$	245,193			$	166,895			$	274,436
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and other non-cash charges			233,940				215,812				214,153
Stock-based compensation expense			9,074				8,177				7,860
Loss on disposition of assets, net			15,472				9,371				6,099
Deferred income tax provision (benefit)			12,354				(13,060	)			4,821
Excess tax benefits for share-based payments			(4,336	)			(3,178	)			(2,724	)
(Increase) decrease in assets:
Accounts receivable			(198,021	)			(49,959	)			73,809
Income taxes receivable			(19,059	)			1,692				9,295
Inventories			(29,708	)			14,078				(40,354	)
Prepaid expenses			2				1,519				(2,284	)
Other current assets			(749	)			1,114				26,189
Other non-current assets			(2,238	)			(1,881	)			(6,415	)
Increase (decrease) in liabilities:
Accounts payable			36,421				14,062				(4,929	)
Income taxes payable			944				(6,428	)			(4,277	)
Accrued payroll and related expenses			13,221				4,585				(1,627	)
Accrued insurance expenses			(440	)			(80	)			408
Accrued state, local and other taxes			1,819				(2,324	)			2,260
Other accrued expenses			(775	)			(1,548	)			1,412
Pension liabilities			2,219				3,183				(589	)
Long-term accrued insurance expenses			(126	)			(175	)			1,400
Other long-term liabilities			7,550				3,769				990
Net cash provided by operating activities			322,757				365,624				559,933
INVESTING ACTIVITIES
Capital expenditures			(371,502	)			(201,681	)			(328,936	)
Proceeds from sale of assets			18,707				11,071				19,309
Purchase of business			—				(17,044	)			—
Increased ownership interest in subsidiary			—				—				(6,211	)
Investment in joint venture			(2,554	)			—				—
Net cash used for investing activities			(355,349	)			(207,654	)			(315,838	)
FINANCING ACTIVITIES
Payment of dividends			(91,608	)			(87,789	)			(114,069	)
Borrowings from notes payable to banks			1,168,100				686,700				844,050
Repayments of notes payable to banks			(996,900	)			(740,400	)			(940,350	)
Debt issue costs for notes payable to banks			(667	)			—				—
Excess tax benefits for share-based payments			4,336				3,178				2,724
Cash paid for common stock purchased and retired			(49,597	)			(25,122	)			(30,224	)
Proceeds received upon exercise of stock options			—				—				544
Net cash provided by (used for) financing activities			33,664				(163,433	)			(237,325	)
Net increase (decrease) in cash and cash equivalents			1,072				(5,463	)			6,770
Cash and cash equivalents at beginning of year			8,700				14,163				7,393
Cash and cash equivalents at end of year		$	9,772			$	8,700			$	14,163

 

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2014, 2013 and 2012

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.

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, 2014, 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 January 27, 2015, the Board of Directors declared a $0.105 per share cash dividend payable March 10, 2015 to stockholders of record at the close of business on February 10, 2015.

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.

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. There were no customers that accounted for more than 10 percent of the Company’s revenues during 2014, 2013 and 2012. Additionally, no single customer accounted for more than 10 percent of accounts receivable as of December 31, 2014 and 2013.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2014, 2013 and 2012

 

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 did not realize any gains or losses during 2014, 2013 or 2012 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 in other income (expense) 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, 15 to 39 years or the life of the lease; 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.

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.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2014, 2013 and 2012

 

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, 2014 and $31,861,000 at December 31, 2013.  During 2013, the Company completed an acquisition of assets of a business totaling $17,044,000 that included goodwill of $7,768,000.  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 2014, 2013 and 2012.  Based on the qualitative assessment, the Company concluded that no impairment of its goodwill occurred for the years ended December 31, 2014, 2013 and 2012.

Advertising

 Advertising expenses are charged to expense during the period in which they are incurred.  Advertising expenses totaled $3,959,000 in 2014, $3,458,000 in 2013, and $2,965,000 in 2012.

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.

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.

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 earnings per share. Basic and diluted earnings per share are computed by dividing net income by the weighted average number of shares outstanding during the respective periods.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2014, 2013 and 2012

 

A reconciliation of weighted average shares outstanding along with the 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.

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, 2014, the Financial Accounting Standards Board (FASB) issued the following applicable Accounting Standards Updates (ASU):

Recently Adopted Accounting Pronouncements:

Accounting Standards Update 2013-05, Foreign Currency Matters (Topic 830): Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity. The amendments in this ASU require that when a reporting entity (parent) ceases to have a controlling financial interest in a subsidiary or group of assets within a foreign entity, the parent should release the cumulative translation adjustment into net income only if the sale or transfer results in the complete or substantially complete liquidation of the foreign entity in which the subsidiary or group of assets had resided.  Sale of an investment in a foreign entity includes both: (1) events that result in the loss of a controlling financial interest in a foreign entity; and (2) events that result in an acquirer obtaining control of an acquiree in which it held an equity interest immediately before the acquisition date.  The Company adopted these provisions in the first quarter of 2014 and adoption did not have a material impact on the Company’s consolidated financial statements.

 

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2014, 2013 and 2012

 

Accounting Standards Update 2013-11, Income Taxes (Topic 740): Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists.  The amendments in this ASU requires an unrecognized tax benefit, or a portion of thereof, to be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carry-forward, a similar tax loss, or a tax credit carry-forward.  The only exception would be if the deferred taxes related to these items are not available to settle any additional income taxes that would result from the disallowance of a tax position either by statute or at the entity’s choosing.   In such cases, the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets.  The Company adopted these provisions in the first quarter of 2014 and adoption did not have a material impact on the Company’s consolidated financial statements.

Recently Issued Accounting Pronouncements Not Yet Adopted:

Accounting Standards Update No. 2015-01, Income Statement —Extraordinary and Unusual Items (Subtopic 225-20): Simplifying Income Statement Presentation by Eliminating the Concept of Extraordinary Items. This ASU eliminates from U.S. GAAP the concept of extraordinary items. Presently, an event or transaction is presumed to be an ordinary and usual activity unless evidence clearly supports its classification as an extraordinary item. If an event or transaction meets the criteria for extraordinary classification, then the extraordinary item needs to be segregated from the results of ordinary operations and disclosed separately in the income statement, net of tax, after income from continuing operations. Disclosure of all applicable income taxes and presentation or disclosure of earnings-per-share data applicable to the extraordinary item is required. The amendments in this ASU are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The Company plans to adopt the provisions for the year ending December 31, 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 the provisions for the year ending December 31, 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 2017 and is currently evaluating the impact of these provisions on its financial statements. Early adoption is not permitted.

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 amendments in the ASU are effective in the first quarter of 2015 with early adoption permitted.  The Company plans to adopt these provisions in the first quarter of 2015 and does not expect the adoption to have a material impact on the Company’s consolidated financial statements.

 

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 purchasers of Company property and rebates from suppliers.

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

Note 3: Inventories

Inventories are $155,611,000 at December 31, 2014 and $126,604,000 at December 31, 2013 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 $233.4 million in 2014, $215.4 million in 2013, and $214.9 million in 2012, and includes amounts recorded as costs of sales and inventory.  There were no capital leases outstanding as of December 31, 2014 and December 31, 2013.  The Company had accounts payable for purchases of property and equipment of $38.5 million as of December 31, 2014, $19.7 million as of December 31, 2013, and $24.4 million as of December 31, 2012.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2014, 2013 and 2012

 

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:

 

 

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

 

As of December 31, 2014, undistributed earnings of the Company’s foreign subsidiaries totaled $12.9 million. 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.

 

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2014, 2013 and 2012

 

As of December 31, 2014, the Company has net operating loss carry forwards related to state income taxes of approximately $11.3 million that will expire between 2015 and 2034.  As of December 31, 2014, the Company has a negligible valuation allowance against the corresponding deferred tax asset.

 

Total net income tax payments were $152.2 million in 2014, $122.9 million in 2013, and $158.7 million in 2012.

 

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 2011 through 2014 tax years remain open to examination.  Additional years may be open to the extent attributes are being carried forward to an open year.  The Internal Revenue Service (IRS) commenced an examination of the Company’s US federal income tax return for the 2011 tax year during the fourth quarter of 2013 that is anticipated to be completed by the middle of 2015.  As of December 31, 2014, the IRS has not proposed any adjustments in connection with the examination.

 

During 2014 and 2013, 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: