RPC INC - Annual Report: 2009 (Form 10-K)

t67253_10k.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

(Mark One)
x	Annual report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
o	Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the fiscal year ended December 31, 2009

Commission File No. 1-8726

RPC, INC.

Delaware

(State of Incorporation)

58-1550825

(I.R.S. Employer Identification No.)

2801 BUFORD HIGHWAY, SUITE 520

ATLANTA, GEORGIA 30329

(404) 321-2140

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

Title of each class

COMMON STOCK, $0.10 PAR VALUE

Name of each exchange on which registered

NEW YORK STOCK EXCHANGE

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

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

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

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

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 o No o

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

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

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

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

The aggregate market value of RPC, Inc. Common Stock held by non-affiliates on June 30, 2009, the last business day of the registrant’s most recently completed second fiscal quarter, was $232,379,112 based on the closing price on the New York Stock Exchange on June 30, 2009 of $8.35 per share.

RPC, Inc. had 98,823,439 shares of Common Stock outstanding as of February 12, 2010.

Documents Incorporated by Reference

Portions of the Proxy Statement for the 2010 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 belief that the long-term prospects for our business are favorable due to growing demand for oil and natural gas and declining production of these commodities; our belief that the gas-directed drilling will represent at least 70 percent of the total drilling rig count in the foreseeable future; our belief that drilling activity and demand for our services began to recover in the fourth quarter of 2009; our expectation to continue to focus on the development of international business opportunities in current and other international markets; our belief that the favorable long-term returns on our purchases of revenue-producing equipment will continue, thus justifying the funding of these expenditures with debt; our ability to obtain other customers in the event of a loss of our largest customers; 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 expectation that our consolidated revenues and financial performance will improve; our expectations regarding capital expenditures in 2010; our ability to maintain sufficient liquidity and a conservative capital structure; our belief that the Company will not make a significant contribution to the defined benefit pension plan in 2010; our ability to reduce the amount drawn on our credit facility over the course of 2010; our ability to fund capital requirements in the future; the adequacy of our liquidity in the future; the estimated amount of our capital expenditures and contractual obligations for future periods; estimates made with respect to our critical accounting policies; and the effect of new accounting standards.

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 Gulf of Mexico, mid-continent, southwest, Rocky Mountain and Appalachian regions, and in selected international markets. The services and equipment provided include, among others, (1) pressure pumping services, (2) coiled tubing services, (3) snubbing services (also referred to as hydraulic workover services), (4) nitrogen services, (5) the rental of drill pipe and other specialized oilfield equipment, (6) downhole tool rental services and (7) firefighting and 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, 2009, RPC had approximately 2,000 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.

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, coiled tubing, snubbing, nitrogen, well control, downhole tools, wireline and fishing. The principal markets for this business segment include the United States, including the Gulf of Mexico, mid-continent, southwest, Rocky Mountain, and Appalachian regions, and contract or project work in selected international locations in the last three years including primarily Africa, Canada, China, Eastern Europe, Latin America, the Middle East and New Zealand. 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 38 percent of 2009 revenues, 41 percent of 2008 revenues and 40 percent of 2007 revenues, are provided to customers throughout the Gulf Coast, mid-continent and Rocky Mountain regions of the United States and are generally utilized to initiate production in new or enhance production in existing customer wells. 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. The fracturing process consists of pumping nitrogen or a fluid gel into a cased well at sufficient pressure to fracture the formation at desired depths. Sand, bauxite or synthetic proppant, which is suspended in the gel, is pumped into the fracture. When the pressure is released at the surface, the fluid gel returns to the well, but the proppant remains in the fracture, thus keeping it open so that oil and natural gas can flow through the fracture into the well. 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.

Coiled Tubing. Coiled tubing services, which accounted for approximately nine percent of 2009, 2008 and 2007 revenues, involve the injection of coiled tubing into wells to perform various applications and functions for use principally in well-servicing operations and more recently 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. 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 eight percent of 2009 revenues, seven percent of 2008 revenues and 10 percent of 2007 revenues, 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 in 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 relatively few operators who have the experience and knowledge required to perform such services safely and efficiently.

Nitrogen. Nitrogen accounted for approximately seven percent of 2009 revenues, eight percent of 2008 revenues and seven percent of 2007 revenues. 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. 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.

Downhole Tools. Thru Tubing Solutions (“TTS”) accounted for approximately 15 percent of 2009 revenues, nine percent of 2008 revenues and seven percent of 2007 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.

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. In the last nine years, the Company has responded to well control situations in several international locations including Algeria, Argentina, Australia, Bolivia, Canada, Colombia, Egypt, Hungary, India, Kuwait, Libya, Mexico, Peru, Qatar, Taiwan, Trinidad, Turkmenistan and Venezuela.

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 well bore, 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 eight percent of 2009 revenues, 11 percent of 2008 revenues and 13 percent of 2007 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 inventories with rental items instead of owning a complete inventory. The Company’s facilities are strategically located to serve the major staging points for oil and gas activities in the Gulf of Mexico, mid-continent region and Rocky Mountains.

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

Blowout Preventors	Diverters
High Pressure Manifolds and Valves	Drill Pipe
Hevi-wate Drill Pipe	Drill Collars
Tubing	Handling Tools
Production Related Rental Tools	Coflexip Hoses
Pumps

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 pipe 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 the 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 several international locations. Well Control School provides this 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 the Gulf of Mexico, the mid-continent, the southwest, the Rocky Mountains and the northeast production fields. 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 74 percent from its peak in 1981. Due to enhanced technology, however, more wells are being drilled and the domestic production of oil and natural gas remains roughly equivalent to prior years. Record low drilling activity levels were experienced 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 most recent cycle peaked at the end of the third quarter of 2008, and began to decline sharply during the fourth quarter. At the beginning of 2009, there were 1,623 domestic working drilling rigs, down 20 percent from the third quarter of 2008. U.S. domestic drilling activity declined by 57 percent from the third quarter of 2008 to the second quarter of 2009, which was the steepest annualized decline rate in the industry’s history.

During 2009 the average price of natural gas decreased by approximately 56 percent, and the average price of oil decreased by approximately 38 percent. The price of natural gas rose sequentially in the fourth quarter compared to the third quarter of 2009, and the price of oil rose during each quarter of 2009. The change in domestic drilling activity during 2008 and 2009 was consistent with the direction and severity of the changes in the prices of oil and natural gas, as well as the overall fluctuations in the general economy. During the first quarter of 2010, the domestic drilling rig count has continued to increase steadily, along with the prices of oil and natural gas. Although our business has repeatedly demonstrated that it is cyclical, we continue to believe that the long-term prospects for our business are favorable due to growing demand for, and declining production of, oil and natural gas.

Gas drilling rigs have represented an increasing percentage of the total drilling rig count, and have represented over 70 percent of the drilling rig count each year since 2001. In 2009, gas drilling rigs represented 74 percent of total drilling activity. The demand trend for natural gas is continuing to rise, although it fluctuates in the short term due to factors such as economic activity and the weather. Also, 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. Based on current demand levels for natural gas as well as the high oil and gas well depletion rates experienced over the past several years, it is anticipated that gas-directed drilling will represent at least 70 percent of the total drilling rig count in the foreseeable future.

In addition, there are certain types of wells, predominately natural gas, 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. Because they are drilled through a narrow formation and the formation is typically a 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 means that there is a great deal of pressure pumping horsepower required 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, although international revenues have never accounted for more than 10 percent of total revenues. Over the past several years, RPC has continued its focus on developing international opportunities, although our equipment investments over the last couple of years have emphasized domestic rather than international expansion. International revenues for 2009 increased due to higher customer activity levels in New Zealand, Mexico and Egypt, among other countries, partially offset by decreases in Saudi Arabia and the elimination of revenue in Venezuela. During 2009, RPC provided snubbing, well control and oilfield training services in Cameroon, Egypt, Gabon, Mexico, New Zealand, Oman and the United Arab Emirates, among other countries. We also provided rental tools in Bolivia and Mexico, and downhole motors and tools in Canada, the Congo, Mexico and South Africa. We continue to focus on the development of international opportunities in these and other markets, although we believe that it will continue to be less than 10 percent of total revenues.

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. Pursuing selective international opportunities for revenue growth continues to be a strong emphasis for RPC. 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, thus yielding strong cash flow and asset appreciation. 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 areas and markets in which we believe there exist opportunities for higher growth, 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 or there exists significant growth potential.

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 attractive acquisition opportunities exist. However, near-term business conditions do not justify sellers’ price expectations, so we believe we generate better returns growing organically in service lines and geographic locations in which we have experience and presence.

RPC has traditionally had a conservative capital structure with minimal debt. During 2006, however, we established a new revolving credit facility to fund the purchase of revenue-producing equipment and other working capital requirements to pursue our growth plan. We pursued this capital source because of the high returns on investment that had 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. We completed purchases of revenue-producing equipment under our growth plan during 2008, and during 2009 we reduced capital expenditures due to the industry downturn and the resulting lower near-term expected returns on investment. In addition, we reduced capital expenditures in order to reduce the balance on our revolving credit facility and enhance our conservative capital structure. At the end of 2009, our level of debt was conservative compared to a number of our peers, and we believe that the favorable long-term returns on investment in our revenue-producing equipment justify financing their purchase using debt.

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 2009, RPC provided oilfield services to several hundred customers. Of these customers, Southwestern Energy Company accounted for approximately 13 percent of revenues and Chesapeake Energy Corporation accounted for approximately 12 percent of revenues. RPC believes that its relationship with these customers is good. Although the Company believes that we would be able to obtain other customers for our services in the event of the loss of either of these major customers, the loss of these customers could have a material adverse effect on Company revenues and operating results in the near term. Sales are generated by RPC’s sales force and through referrals from existing customers. There are long-term written contracts for services and equipment with certain international and domestic customers, although revenues earned under such contracts are a small percentage of total revenues. 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. RPC’s products and services are sold in highly competitive markets, and its revenues and earnings 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. RPC believes that the principal competitive factors in the market areas that it serves are product and service quality and availability, 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, BJ Services Company 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 in Houston, Texas that includes the Company’s operations, engineering, sales and marketing headquarters, and one 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 prices affect demand throughout the oil and natural 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.

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.

The relationship between the prices of oil and natural gas and our customers’ drilling and production activities may not be highly correlated in the future.

Historically, fluctuations in the prices of oil and natural gas have led to corresponding changes in our customers’ drilling and production activities as measured by the domestic rig count. As drilling and production activities increase (or remain active) or decrease (or remain stagnant), our operating results are correspondingly favorably or adversely impacted. If this correlation weakens in the future, then it is possible that increases in the prices of oil and natural gas will not lead to corresponding increases in our customers’ activities, and our future operating results could be negatively impacted.

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 Northeast. 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 may impact our overall exposure to credit risk.

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.

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

During 2009, two of our largest customers accounted for approximately 25 percent of our total revenues. This reliance on large customers for a significant portion of our total revenues exposes us to the risk that the loss or reduction in revenues from any one or more of these customers, which could occur unexpectedly, could have a material and disproportionate adverse impact upon our net revenues and operating results.

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

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

Our operations may be adversely affected if we are unable to comply with regulatory 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.

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, Eastern Europe, Latin America, the Middle East and New Zealand 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 Rule 303A of the New York Stock Exchange (“NYSE”) Company Guide. 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 71 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 $200 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 100 offices and operating facilities. The Company leases approximately 13,400 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 2013. 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

Houma, Louisiana — Administrative office

Houston, Texas — Pipe storage terminal and inspection sheds

Houston, Texas — Operations, sales and administrative office

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

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

Lafayette, Louisiana — Operations, sales and equipment storage yards

Conway, Arkansas — Operations, sales and equipment storage yards

Kilgore, Texas — Pumping services facility

Leased Locations

Seminole, Oklahoma — Pumping services facility

Oklahoma City, Oklahoma — Operations, sales and administrative office

Houston, Texas — Operations, sales and administrative office

Odessa, Texas — Operations, sales and equipment storage yards

Washington, Pennsylvania — 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. Reserved

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.

Name and Office with Registrant	Age	Date First Elected to Present Office
R. Randall Rollins (1)	78	1/24/84

Chairman of the Board

Richard A. Hubbell (2)	65	4/22/03

President and Chief Executive Officer

Linda H. Graham (3)	73	1/27/87

Vice President and Secretary

Ben M. Palmer (4)	49	7/8/96

Vice President, Chief Financial Officer and Treasurer

(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 for 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 for 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. At February 12, 2010, there were 98,523,276 shares of common stock outstanding and approximately 4,300 beneficial holders of 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, 2009 and 2008:

	2009						2008
Quarter	High		Low		Dividends		High		Low		Dividends
First	$	11.45	$	5.17	$	0.07	$	15.32	$	8.52	$	0.06
Second		11.97		6.43		0.07		17.80		12.50		0.06
Third		10.94		7.10		0.04		18.91		13.15		0.06
Fourth		11.35		9.15		0.04		14.10		6.02		0.06

On January 26, 2010, the Board of Directors approved a $0.04 per share cash dividend, payable March 10, 2010 to stockholders of record at the close of business on February 10, 2010. 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 2009 are outlined below.

Period	Total Number of Shares (or Units) Purchased			Average Price Paid Per Share (or Unit)		Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs

October 1, 2009 to October 31, 2009		12,812	(1)	$	9.68		-		2,807,265

November 1, 2009 to November 30, 2009		2,147	(1)		9.60		-		2,807,265

December 1, 2009 to December 31, 2009		-			-		-		2,807,265

Totals		14,959		$	9.67		-		2,807,265

(1)	Consists of shares repurchased by the Company in connection with option exercises and taxes related to vesting of restricted shares.

The Company’s Board of Directors announced a stock buyback program in March 1998 authorizing the repurchase of 11,812,500 shares in the open market. Currently the program does not have a predetermined expiration date.

Performance Graph

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

The Russell 2000 is a stock index representing small capitalization U.S. stocks. The components of the index had an average market capitalization in 2009 of over $1.0 billion, and the Company was a component of the Russell 2000 during 2009. The Russell 2000 was chosen because it represents companies with comparable market capitalizations to the Company. The OSX is a stock index of 15 U.S. 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 it 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., BJ Services Company, 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:

Years Ended December 31,	2009			2008			2007			2006			2005
	(in thousands, except employee and per share amounts)
Revenues	$	587,863		$	876,977		$	690,226		$	596,630		$	427,643
Cost of revenues		393,806			503,631			368,175			287,037			227,492
Selling, general and administrative expenses		97,672			117,140			107,800			91,051			75,478
Depreciation and amortization		130,580			118,403			78,506			46,711			39,129
Gain on disposition of assets, net (a)		(1,143	)		(6,367	)		(6,293	)		(5,969	)		(12,169	)
Operating (loss) profit		(33,052	)		144,170			142,038			177,800			97,713
Interest expense		(2,176	)		(5,282	)		(4,179	)		(356	)		(127	)
Interest income		147			73			70			319			1,077
Other income (expense), net		1,582			(1,176	)		1,905			1,085			2,077
(Loss) income before income taxes		(33,499	)		137,785			139,834			178,848			100,740
Income tax (benefit) provision (b)		(10,754	)		54,382			52,785			68,054			34,256
Net (loss) income (b)	$	(22,745	)	$	83,403		$	87,049		$	110,794		$	66,484
(Loss) earnings per share:

Basic	$	(0.24	)	$	0.86		$	0.90		$	1.16		$	0.70
Diluted	$	(0.24	)	$	0.85		$	0.89		$	1.13		$	0.67
Dividends paid per share	$	0.220		$	0.240		$	0.200		$	0.133		$	0.071
OTHER DATA:
Operating margin percent		(5.6	)%		16.4	%		20.6	%		29.8	%		22.8	%
Net cash provided by operating activities	$	168,740		$	177,320		$	141,872		$	118,228		$	66,362
Net cash used for investing activities		(61,144	)		(158,953	)		(239,624	)		(151,085	)		(62,415	)
Net cash (used for) provided by financing activities		(106,144	)		(21,668	)		101,361			22,777			(20,774	)
Depreciation and amortization		130,580			118,403			78,506			46,711			39,129
Capital expenditures	$	67,830		$	170,318		$	248,758		$	159,831		$	72,808
Employees at end of period		1,980			2,532			2,370			2,000			1,649
BALANCE SHEET DATA AT END OF YEAR:
Accounts receivable, net	$	130,619		$	210,375		$	176,154		$	148,469		$	107,428
Working capital		151,681			200,494			144,338			111,302			95,215
Property, plant and equipment, net		396,222			470,115			433,126			262,797			141,218
Total assets		649,043			793,461			701,015			478,007			311,785
Long-term debt (c)		90,300			174,450			156,400			35,600			—
Total stockholders’ equity	$	409,723		$	449,084		$	409,272		$	335,287		$	232,501

(a)	Gain on disposition of assets, net in 2005 includes a $10.7 million pre-tax gain ($0.07 after tax per diluted share) on the sale of certain operating assets during the third quarter of 2005.

(b)	During the fourth quarter of 2005, the income tax provision and net income reflect the receipt of tax refunds of $3.5 million related to the successful resolution of certain tax matters, which had a positive impact of $0.04 after tax per diluted share.

(c)

Effective September 2006, the Company closed on a revolving credit facility that was reduced to $200 million in the third quarter of 2009. In February 2005, the Company prepaid a $2.8 million promissory note and the remaining balance of long-term debt was paid in full upon maturity of a promissory note in July 2005.

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 Gulf of Mexico, mid-continent, southwest, northeast and Rocky Mountain regions, and selected international locations. 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:

	-	To focus our management resources on and invest our capital in equipment and geographic markets that we believe will earn high returns on capital, and maintain an appropriate capital structure.

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

	-	To deliver equipment and services to our customers safely.

	-	To maintain and increase market share.

	-	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.

	-	To align the interests of our management and stockholders.

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

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, pricing for our services and equipment, profit margins, selling, general and administrative expenses, cash flows and the return on our invested capital. 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 include natural gas prices which stabilized during 2009 following a steep decline in 2008, and during the first quarter of 2010 have increased slightly. Oil prices have increased gradually during 2009 and the first quarter of 2010, following a five-year low of $32 per barrel at the end of 2008. In the beginning of 2010, natural gas prices are approximately 27 percent higher than they were during the first quarter of 2009, and the price of oil is approximately 74 percent higher than it was in the first quarter of 2009. The average U.S. rig count declined by 42 percent in 2009, although it began to increase during the third and fourth quarters of 2009. During the first quarter of 2010, the rig count returned to the same levels experienced in the first quarter of 2009.

In addition to the overall rig count, the Company also 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. The number of horizontal and directional wells drilled in the United States increased in 2009, and was 60 percent of total wells drilled during the year. During the first part of 2010, the percentage of horizontal and directional wells drilled as a percentage of total wells increased to approximately 66 percent. Between 2006 and 2008, the supply of oilfield service equipment in the U.S. domestic market increased tremendously, both from existing service companies and new entrants to the oilfield services business. Although the supply of oilfield equipment did not increase in 2009, the large supply of equipment and service providers coupled with the tremendous decline in domestic oilfield activity has caused pricing for the Company’s services to decrease tremendously during the past few years, which has had a negative impact on the Company’s financial results and returns. The Company responded by reducing its capital expenditures during 2008 and 2009, managing working capital carefully, closely monitoring its competitors’ activities, and scrutinizing planned capital expenditures more closely for acceptable financial returns. In spite of a decline in revenues and an operating loss during 2009, the Company generated sufficient cash from operating activities to decrease the balance on its revolving credit facility by 48 percent.

Loss before income taxes was $33.5 million in 2009 compared to income before taxes of $137.8 million in the prior year. The effective tax rate for 2009 was 32.1 percent compared to 39.5 percent in the prior year. Diluted loss per share was $0.24 in 2009 compared to diluted earnings per share of $0.85 for the prior year. Cash flows from operating activities were $168.7 million in 2008 compared to $177.3 million in the prior year, and cash and cash equivalents were $4.5 million at December 31, 2009, an increase of $1.5 million compared to December 31, 2008. During the third quarter of 2009, we reduced the size of our revolving credit facility to $200 million. As of December 31, 2009, there was $90.3 million in outstanding borrowings under this credit facility.

Cost of revenues as a percentage of revenues increased approximately 9.6 percentage points in 2009 compared to 2008, because of lower pricing for our services and lower revenues.

Selling, general and administrative expenses as a percentage of revenues increased approximately 3.3 percentage points in 2009 compared to 2008, which was due to the fixed nature of many of these expenses and lower revenues.

Consistent with our strategy to selectively grow our capacity and maintain our existing fleet of high demand equipment, capital expenditures were $67.8 million in 2009.

Outlook

Drilling activity in the U.S. domestic oilfields, as measured by the rotary drilling rig count, had been gradually increasing since about 2003 when rig count was just over 800 through the latter half of 2008 when the U.S. rig count peaked at 2,031 during the third quarter. The global recession that began in the fourth quarter of 2007 precipitated the steepest annualized decline in U.S. domestic oilfield history. From the third quarter of 2008 to the second quarter of 2009, the U.S. domestic rig count dropped almost 57 percent, reaching a trough of 876 in June 2009. Since June 2009, the rig count has increased by 42 percent to 1,248 early in the first quarter of 2010. The outlook for U.S. domestic oilfield activity is to increase slowly during the remainder of 2010. The price of oil fell by 77 percent from $147 per barrel in the third quarter of 2008 to $34 early in 2009. Since that time, the price of oil has increased by over 100 percent to approximately $80 per barrel in the first quarter of 2010. The price of natural gas fell by 85 percent from approximately $13 per Mcf in the second quarter of 2008 to slightly below $2 per Mcf in the third quarter of 2009. Since that time, the price of natural gas has increased to almost $6 per Mcf early in the first quarter of 2010.

Unconventional drilling activity, which requires more of RPC’s services, accounted for 65 percent of total U.S. domestic drilling at the end of 2009. Unconventional activity as a percentage of total oilfield activity had grown to 66 percent by the first quarter of 2010.

We continue to monitor the competitive environment in 2010, and are concerned about pricing for our services. The highly competitive pricing levels are due to lower activity levels and the large amount of additional equipment that has been placed in service in the domestic market during the past several years. Our recent response to industry conditions was to reduce capital expenditures, continue cost-reduction plans and enhance our sales and marketing efforts. We understand that factors influencing the industry are unpredictable, and our response to the industry’s potential uncertainty is to maintain sufficient liquidity and a conservative capital structure and monitor our discretionary spending. Although we used our bank credit facility to finance our expansion, we will still maintain a conservative financial structure. We intend to closely manage the amount drawn on this facility over the course of 2010. Based on current industry conditions, we believe that the Company’s consolidated revenues will increase and financial performance will improve.

Results of Operations

Years Ended December 31,	2009			2008			2007
Consolidated revenues	$	587,863		$	876,977		$	690,226
Revenues by business segment:
Technical	$	513,289		$	745,991		$	574,723
Support		74,574			130,986			115,503

Consolidated operating (loss) profit	$	(33,052	)	$	144,170		$	142,038
Operating (loss) profit by business segment:
Technical	$	(20,328	)	$	110,648		$	116,493
Support		(1,636	)		36,515			29,955
Corporate expenses		(12,231	)		(9,360	)		(10,703	)
Gain on disposition of assets, net		1,143			6,367			6,293

Net (loss) income	$	(22,745	)	$	83,403		$	87,049
(Loss) earnings per share — diluted	$	(0.24	)	$	0.85		$	0.89
Percentage of cost of revenues to revenues		67	%		57	%		53	%
Percentage of selling, general and administrative expenses to revenues		17	%		13	%		16	%
Percentage of depreciation and amortization expense to revenues		22	%		14	%		11	%
Effective income tax rate		32.1	%		39.5	%		37.7	%
Average U.S. domestic rig count		1,089			1,879			1,768
Average natural gas price (per thousand cubic feet (mcf))	$	3.90		$	8.81		$	6.93
Average oil price (per barrel)	$	61.90		$	99.96		$	72.78

Year Ended December 31, 2009 Compared To Year Ended December 31, 2008

Revenues. Revenues for 2009 decreased $289.1 million or 33.0 percent compared to 2008. The Technical Services segment revenues for 2009 decreased 31.2 percent from the prior year due primarily to highly competitive pricing coupled with lower equipment utilization. The Support Services segment revenues for 2009 decreased 43.1 percent from the prior year due to decreased customer activity and significantly lower pricing in the rental tool service line, the largest within this segment.

Domestic revenues decreased 36 percent to $543.0 million during 2009 compared to 2008 due to decreased customer activity and competitive pricing in our largest service lines, such as pressure pumping and rental tools. The average price of natural gas decreased by 56 percent and the average price of oil decreased by approximately 38 percent during 2009 compared to the prior year. In conjunction with the decrease in natural gas prices, the average domestic rig count during 2009 was 42 percent lower than in 2008. This decrease in drilling activity had a negative impact on our financial results. We believe that our activity levels are affected more by the price of natural gas than by the price of oil, because the majority of U.S. domestic drilling activity relates to natural gas, and many of our services are more appropriate for gas wells than oil wells. Foreign revenues, which increased from $30.8 million in 2008 to $44.8 million in 2009, were eight percent of consolidated revenues. These revenue increases were due mainly to higher customer activity levels in New Zealand and Mexico 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 2009 was $393.8 million compared to $503.6 million in 2008, a decrease of $109.8 million or 21.8 percent. The decrease in these costs was due to the variable nature of most of these expenses as well as the impact of expense reduction measures taken during 2009, including employment cost reductions. Cost of revenues, as a percent of revenues, increased in 2009 from 2008 due to lower pricing for our services.

Selling, general and administrative expenses. Selling, general and administrative expenses decreased 16.6 percent to $97.7 million in 2009 compared to $117.1 million in 2008. This decrease was primarily due to lower employment costs and other expenses resulting from expense reduction efforts instituted during 2009. As a percentage of revenues, selling, general and administrative expenses increased to 16.6 percent in 2009 compared to 13.4 percent in 2008.

Depreciation and amortization. Depreciation and amortization were $130.6 million in 2009, an increase of $12.2 million or 10.3 percent compared to $118.4 million in 2008. This increase resulted from a higher level of capital expenditures during recent quarters within both Support Services and Technical Services to increase capacity and to maintain our existing equipment.

Gain on disposition of assets, net. Gain on the disposition of assets, net decreased due primarily to reduced gains related to various property and equipment dispositions or sales to customers of lost or damaged rental equipment.

Other income (expense), net. Other income, net was $1.6 million in 2009, an increase of $2.8 million compared to other expense of $1.2 million in 2008. The increase is mainly due to the current year increase in the fair value of trading securities held in the non-qualified Supplemental Retirement Plan. In addition to changes in the fair value of trading securities, other income (expense) includes gains from settlements of various legal and insurance claims and royalty payments.

Interest expense. Interest expense was $2.2 million in 2009 compared to $5.3 million in 2008. The decrease is due to lower interest expense in 2009 incurred on lower outstanding interest bearing advances on our revolving credit facility.

Interest income. Interest income increased to $147 thousand in 2009 compared to $73 thousand in 2008 as a result of a higher average investable cash balance in 2009 compared to 2008.

Income tax (benefit) provision. The income tax benefit was $10.8 million in 2009 compared to a tax provision of $54.4 million in 2008. The change is due to 2009’s loss before income tax, partially offset by a decrease in the effective tax rate to 32.1 percent in 2009 from 39.5 percent in 2008.

Net (loss) income and diluted (loss) earnings per share. Net loss was $22.7 million in 2009, or $0.24 per share, compared to net income of $83.4 million, or $0.85 per diluted share in 2008. This decrease is due to decreased revenues and higher, as a percentage of revenues, costs of revenues, selling, general and administrative expenses and depreciation expense.

Year Ended December 31, 2008 Compared To Year Ended December 31, 2007

Revenues. Revenues for 2008 increased $186.8 million or 27.1 percent compared to 2007. The Technical Services segment revenues for 2008 increased 29.8 percent from the prior year due primarily to a higher drilling rig count and increased capacity driven by higher capital expenditures partially offset by lower pricing for services. The Support Services segment revenues for 2008 increased 13.4 percent from the prior year due to increased capacity driven by higher capital expenditures as well as a more profitable job mix in the rental tool service line, the largest within this segment.

Domestic revenues increased 30 percent to $846.2 million during 2008 compared to 2007 due to increased capacity in our largest service lines, such as pressure pumping and rental tools. The average price of natural gas increased by 27 percent and the average price of oil increased by approximately 37 percent during 2008 compared to the prior year. In conjunction with the increase in natural gas prices, the average domestic rig count during 2008 was seven percent higher than in 2007. This increase in drilling activity had a positive impact on our financial results. We believe that our activity levels are affected more by the price of natural gas than by the price of oil, because the majority of U.S. domestic drilling activity relates to natural gas, and many of our services are more appropriate for gas wells than oil wells. Foreign revenues, which decreased from $41.1 million in 2007 to $30.8 million in 2008, were four percent of consolidated revenues. These revenue decreases were due mainly to lower customer activity levels in Turkmenistan and Hungary compared to the prior year. Our international revenues are impacted by the timing of project initiation and their ultimate duration.

Cost of revenues. Costs of revenues in 2008 was $503.6 million compared to $368.2 million in 2007, an increase of $135.4 million or 36.8 percent. The increase in these costs was due to the variable nature of many of these expenses, including materials and supplies, compensation, and maintenance and repairs. Cost of revenues, as a percent of revenues, increased in 2008 from 2007 due to more competitive pricing, higher costs of proppant used in our pressure pumping service line and increased maintenance and repairs expenses.

Selling, general and administrative expenses. Selling, general and administrative expenses increased 8.7 percent to $117.1 million in 2008 compared to $107.8 million in 2007. This increase was primarily due to higher employment costs consistent with higher activity levels and geographic expansion under RPC’s long-term growth plan. As a percentage of revenues, selling, general and administrative expenses decreased to 13.4 percent in 2008 compared to 15.6 percent in 2007.

Depreciation and amortization. Depreciation and amortization were $118.4 million in 2008, an increase of $39.9 million or 50.8 percent compared to $78.5 million in 2007. This increase resulted from a higher level of capital expenditures during 2008 as compared to 2007 within both Support Services and Technical Services to increase capacity and to maintain our existing equipment.

Gain on disposition of assets, net. Gain on the disposition of assets, net increased due primarily to gains related to various property and equipment dispositions or sales to customers of lost or damaged rental equipment.

Other (expense) income, net. Other (expense), net in 2008 was $(1.2) million, a decrease of $3.1 million compared to other income of $1.9 million in 2007. The decrease is mainly due to the 2008 decline in the fair value of trading securities held in the non-qualified Supplemental Retirement Plan. In addition to changes in the fair value of trading securities, other (expense) income in 2008 includes gains from settlements of various legal and insurance claims and royalty payments.

Interest expense. Interest expense was $5.3 million in 2008 compared to $4.2 million in 2007. The increase is due to higher interest expense in 2008 incurred on larger outstanding interest bearing advances on our revolving line of credit.

Interest income. Interest income increased to $73 thousand in 2008 compared to $70 thousand in 2007 as a result of a higher average investable cash balance in 2008 compared to 2007.

Income tax provision. The income tax provision increased to $54.4 million in 2008 from $52.8 million in 2007. The increase is due to an increase in the effective tax rate to 39.5 percent in 2008 from 37.7 percent in 2007.

Net income and diluted earnings per share. Net income decreased 4.2 percent to $83.4 million, or $0.85 earnings per diluted share in 2008, compared to $87.0 million, or $0.89 earnings per diluted share in 2007. This decrease is due to higher costs of revenues, selling, general and administrative expenses, depreciation expense, other expense, and interest expense partially offset by increased revenues.

Liquidity and Capital Resources

Cash and Cash Flows

The Company’s cash and cash equivalents were $4.5 million as of December 31, 2009, $3.0 million as of December 31, 2008 and $6.3 million as of December 31, 2007.

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

	(in thousands)
	2009			2008			2007
Net cash provided by operating activities	$	168,740		$	177,320		$	141,872
Net cash used for investing activities		(61,144	)		(158,953	)		(239,624	)
Net cash (used for) provided by financing activities		(106,144	)		(21,668	)		101,361

2009

Cash provided by operating activities decreased by $8.6 million in 2009 compared to the prior year. Net loss was $22.7 million in 2009 compared to net income of $83.4 million in 2008, decreasing cash provided by operating activities partially offset by decreases in working capital requirements. Decreased business activity levels and revenues in 2009 resulted in lower accounts receivable and prepaid expenses partially offset by increased inventory and declines in accounts payable and accrued payroll including bonuses, consistent with lower activity levels and profitability.

Cash used for investing activities in 2009 decreased by $97.8 million compared to 2008, primarily as a result of lower capital expenditures.

Cash used for financing activities in 2009 increased by $84.5 million compared to 2008, primarily due to the reduction in notes payable to banks during 2009, partially offset by a decrease in common stock purchased and retired.

2008

Cash provided by operating activities increased by $35.4 million in 2008 compared to the prior year. Although net income decreased $3.6 million in 2008 compared to 2007, cash provided by operating activities increased due primarily to an increase in depreciation due to higher capital expenditures and a higher deferred tax provision due to accelerated tax depreciation. Increased business activity levels and revenues in 2008 resulted in higher accounts receivable, inventories and prepaid expenses partially offset by increased accounts payable and accrued payroll including bonuses.

Cash used for investing activities in 2008 decreased by $80.7 million compared to 2007, primarily as a result of lower capital expenditures.

Cash (used for) provided by financing activities in 2009 increased by $123.0 million compared to 2007, primarily due to lower net borrowings from notes payable to banks during 2008, an increase in common stock purchased and retired, and a 20 percent increase in dividends paid per share to common stockholders.

Financial Condition and Liquidity

The Company’s financial condition as of December 31, 2009, 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. The Company currently has a $200 million revolving credit facility (the “Revolving Credit Agreement”) that matures in September 2011. The Revolving Credit Agreement 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 $91.9 million was available under our facility as of December 31, 2009; approximately $17.8 million of the credit facility supports outstanding letters of credit relating to self-insurance programs or contract bids. For additional information with respect to RPC’s credit 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 credit 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.

Cash Requirements

Capital expenditures were $67.8 million in 2009, and we currently expect capital expenditures to be approximately $70.0 million in 2010. We expect these expenditures to be primarily directed towards revenue-producing equipment in our larger, core service lines including pressure pumping, snubbing, nitrogen, and rental tools. The actual amount of 2010 expenditures will depend primarily on equipment maintenance requirements, expansion opportunities, and equipment delivery schedules.

The Company’s Retirement Income Plan, a multiple employer trusteed defined benefit pension plan, provides monthly benefits upon retirement at age 65 to eligible employees. The Company does not currently expect to make a significant contribution to the defined benefit pension plan in 2010 to meet its funding objectives.

The Company’s Board of Directors announced a stock buyback program on March 9, 1998 authorizing the repurchase of up to 11,812,500 shares of which 2,807,265 additional shares were available to be repurchased as of December 31, 2009. The program does not have a predetermined expiration date.

On January 26, 2010, the Board of Directors approved a $0.04 per share cash dividend, payable March 10, 2010 to stockholders of record at the close of business on February 10, 2010. 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

The Company’s obligations and commitments that require future payments include our credit facility, certain non-cancelable operating leases, purchase obligations and other long-term liabilities. The following table summarizes the Company’s significant contractual obligations as of December 31, 2009:

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	$	90,300	$	-	$	90,300	$	-	$	-
Interest on long-term debt obligations		3,154		1,869		1,285		-		-
Capital lease obligations		-		-		-		-		-
Operating leases (1)		13,023		4,389		5,318		2,504		812
Purchase obligations (2)		-		-		-		-		-
Other long-term liabilities (3)		988		-		988		-		-
Total contractual obligations	$	107,465	$	6,258	$	97,891	$	2,504	$	812

(1)	Operating leases include agreements for various office locations, office equipment, and certain operating equipment.

(2)	Includes agreements to purchase goods or services that have been approved and that specify all significant terms (pricing, quantity, and timing). As part of the normal course of business the Company occasionally enters into purchase commitments to manage its various operating needs.

(3)	Includes expected cash payments for long-term liabilities reflected on the balance sheet where the timing of the payments are known. These amounts include incentive compensation. These amounts exclude pension obligations with uncertain funding requirements and deferred compensation liabilities.

Fair Value Measurements

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

In 2009, the Company transferred trading securities from assets utilizing Level 1 inputs to assets utilizing Level 2 inputs because significant observable inputs in addition to quoted market prices were used to value these trading securities.

Inflation

The Company purchases its equipment and materials from suppliers who provide competitive prices, and employs skilled workers from competitive labor markets. If inflation in the general economy increases, the Company’s costs for equipment, materials and labor could increase as well. Also, increases in activity in the domestic oilfield can cause upward wage pressures in the labor markets from which it hires employees as well as increases in the costs of certain materials used to provide services to the Company’s customers. Both the costs of equipment and labor increased prior to and during 2008. In the third and fourth quarters of 2008 and 2009, however, the prices of commodities such as steel decreased dramatically, as did demand for oilfield equipment and personnel. As a result, the Company’s labor costs declined, and equipment that the Company ordered was not subject to extended lead time for deliveries. The costs of certain materials used to provide services to RPC’s customers have remained high throughout 2009, however, which has resulted in higher costs of revenues. The Company has attempted to mitigate these high costs by securing materials through different sources, although no assurance can be given that these efforts will mitigate these high costs.

Off Balance Sheet Arrangements

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

Related Party Transactions

Marine Products Corporation

Effective February 28, 2001, the Company spun off the business conducted through Chaparral Boats, Inc. (“Chaparral”), RPC’s former powerboat manufacturing segment. RPC accomplished the spin-off by contributing 100 percent of the issued and outstanding stock of Chaparral to Marine Products Corporation (a Delaware corporation) (“Marine Products”), a newly formed wholly owned subsidiary of RPC, and then distributing the common stock of Marine Products to RPC stockholders. In conjunction with the spin-off, RPC and Marine Products entered into various agreements that define the companies’ relationship.

In accordance with a Transition Support Services agreement, which may be terminated by either party, RPC provides certain administrative services, including financial reporting and income tax administration, acquisition assistance, etc., to Marine Products. Charges from the Company (or from corporations that are subsidiaries of the Company) for such services aggregated approximately $713,000 in 2009, $842,000 in 2008 and $957,000 in 2007. The Company’s receivable due from Marine Products for these services as of December 31, 2009 and 2008 was approximately $65,000 and $70,000. The Company’s directors are also directors of Marine Products and all of the executive officers are employees of both the Company and Marine Products.

Other

The Company periodically purchases in the ordinary course of business products or services from suppliers, who are owned by significant officers or stockholders, or affiliated with the directors of RPC. The total amounts paid to these affiliated parties were approximately $409,000 in 2009, $393,000 in 2008 and $1,035,000 in 2007.

RPC receives certain administrative services and rents office space from Rollins, Inc. (a company of which Mr. R. Randall Rollins is also Chairman and which is otherwise affiliated with RPC). The service agreements between Rollins, Inc. and the Company provide for the provision of services on a cost reimbursement basis and are terminable on six months notice. The services covered by these agreements include office space, administration of certain employee benefit programs, and other administrative services. Charges to the Company (or to corporations which are subsidiaries of the Company) for such services and rent totaled $87,000 in 2009, $90,000 in 2008 and $72,000 in 2007.

Critical Accounting Policies

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

Allowance for doubtful accounts — Substantially all of the Company’s receivables are due from oil and gas exploration and production companies in the United States, selected international locations and foreign, nationally owned oil companies. Our allowance for doubtful accounts is determined using a combination of factors to ensure that our receivables are not overstated due to uncollectibility. Our established credit evaluation procedures seek to minimize the amount of business we conduct with higher risk customers. Our customers’ ability to pay is directly related to their ability to generate cash flow on their projects and is significantly affected by the volatility in the price of oil and natural gas. Provisions for doubtful accounts are recorded in selling, general and administrative expenses. Accounts are written-off against the allowance for doubtful accounts when the Company determines that amounts are uncollectible and recoveries of amounts previously written off are recorded when collected. Significant recoveries will generally reduce the required provision in the period of recovery. Therefore, the provision for doubtful accounts can fluctuate significantly from period to period. Recoveries were insignificant in 2009 and 2007. Recoveries in 2008 totaled $1.5 million, causing a reduction in bad debt expense in 2008. We record specific provisions when we become aware of a customer’s inability to meet its financial obligations to us, such as in the case of bankruptcy filings or deterioration in the customer’s operating results or financial position. If circumstances related to customers change, our estimates of the realizability of receivables would be further adjusted, either upward or downward.

The estimated allowance for doubtful accounts is based on our evaluation of the overall trends in the oil and gas industry, financial condition of our customers, our historical write-off experience, current economic conditions, and in the case of international customers, our judgments about the economic and political environment of the related country and region. In addition to reserves established for specific customers, we establish general reserves by using different percentages depending on the age of the receivables. Excluding the effect of the recoveries referred to above, the annual provisions for doubtful accounts have ranged from 0.10 percent to 0.45 percent of revenues over the last three years. Increasing or decreasing the estimated general reserve percentages by 0.50 percentage points as of December 31, 2009 would have resulted in a change of approximately $0.7 million to the allowance for doubtful accounts and a corresponding change to selling, general and administrative expenses.

Income taxes — The effective income tax rates were 32.1 percent in 2009, 39.5 percent in 2008 and 37.7 percent in 2007. Our effective tax rates vary due to changes in estimates of our future taxable income, fluctuations in the tax jurisdictions in which our earnings and deductions are realized, and favorable or unfavorable adjustments to our estimated tax liabilities related to proposed or probable assessments. As a result, our effective tax rate may fluctuate significantly on a quarterly or annual basis.

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

We calculate our current and deferred tax provision based on estimates and assumptions that could differ from the actual results reflected in income tax returns filed during the subsequent year. Adjustments based on filed returns are recorded when identified, which is generally in the third quarter of the subsequent year for U.S. federal and state provisions. Deferred tax liabilities and assets are determined based on the differences between the financial and tax bases of assets and liabilities using enacted tax rates in effect in the year the differences are expected to reverse.

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

Insurance expenses – The Company self insures, up to certain policy-specified limits, certain risks related to general liability, workers’ compensation, vehicle and equipment liability. The cost of claims under these self-insurance programs is estimated and accrued using individual case-based valuations and statistical analysis and is based upon judgment and historical experience; however, the ultimate cost of many of these claims may not be known for several years. These claims are monitored and the cost estimates are revised as developments occur relating to such claims. The Company has retained an independent third party actuary to assist in the calculation of a range of exposure for these claims. As of December 31, 2009, the Company estimates the range of exposure to be from $11.1 million to $14.9 million. The Company has recorded liabilities at December 31, 2009 of approximately $12.9 million which represents management’s best estimate of probable loss.

Depreciable life of assets — RPC’s net property, plant and equipment at December 31, 2009 was $396.2 million representing 61.0 percent of the Company’s consolidated assets. Depreciation and amortization expenses for the year ended December 31, 2009 were $130.6 million. Management judgment is required in the determination of the estimated useful lives used to calculate the annual and accumulated depreciation and amortization expense.

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

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

The Company chooses an expected rate of return on plan assets based on historical results for similar allocations among asset classes, the investments strategy, and the views of our investment adviser. Differences between the expected long-term return on plan assets and the actual return are amortized over future years. Therefore, the net deferral of past asset gains (losses) ultimately affects future pension expense. The Company’s assumption for the expected return on plan assets was seven percent for 2009 and eight percent for 2008 and 2007.

The discount rate reflects the current rate at which the pension liabilities could be effectively settled at the end of the year. In estimating this rate, the Company utilizes a yield curve approach. The approach utilizes an economic model whereby the Company’s expected benefit payments over the life of the plan are forecasted and then compared to a portfolio of investment grade corporate bonds that will mature at the same time that the benefit payments are due in any given year. The economic model then calculates the one discount rate to apply to all benefit payments over the life of the plan which will result in the same total lump sum as the payments from the corporate bonds. A lower discount rate increases the present value of benefit obligations. The discount rate was 6.00 percent as of December 31, 2009 compared to 6.84 percent in 2008 and 6.25 percent in 2007.

As of December 31, 2009, the defined benefit plan was under-funded and the recorded change within accumulated other comprehensive loss increased stockholders’ equity by $0.9 million after tax. Holding all other factors constant, a change in the discount rate used to measure plan liabilities by 0.25 percentage points would not result in a significant pre-tax change to the net loss related to pension reflected in accumulated other comprehensive loss.

The Company recognized pre-tax pension (income) expense of $2.0 million in 2009, $(0.4) million in 2008 and $0.3 million in 2007. Based on the under-funded status of the defined benefit plan as of December 31, 2009, the Company expects to recognize pension expense of $0.6 million in 2010. Holding all other factors constant, a change in the expected long-term rate of return on plan assets by 0.50 percentage points would result in an increase or decrease in pension expense/income of approximately $0.1 million in 2010. Holding all other factors constant, a change in the discount rate used to measure plan liabilities by 0.25 percentage points would result in an increase or decrease in pension expense/income of approximately $0.1 million in 2010.

New Accounting Pronouncements

Recently Adopted Accounting Pronouncements:

During 2009, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update No. 2009-01(ASU 2009-01) titled “Topic 105-Generally Accepted Accounting Principles amendments based on Statement of Financial Accounting Standards No. 168-The FASB Accounting Standards CodificationTM and the Hierarchy of Generally Accepted Accounting Principles.” FASB Accounting Standards CodificationTM (ASC) Topic 105, “Generally Accepted Accounting Principles” has become the single source of authoritative U.S. generally accepted accounting principles (GAAP) recognized by the FASB to be applied by nongovernmental entities, effective for financial statements issued for interim and annual periods ending after September 15, 2009. Rules and interpretive releases of the Securities and Exchange Commission (SEC) under authority of federal securities laws are also sources of authoritative GAAP for SEC registrants. The FASB now issues Accounting Standards Updates that are not considered authoritative in their own right, but will serve to update the Codification, provide background information about the guidance, and provide the bases for conclusions on the change(s) in the Codification. References to accounting literature throughout this document have been updated to reflect the codification.

In September 2009, the FASB issued ASU No. 2009-12, “Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent)” (ASU 2009-12). ASU 2009-12 amends Accounting Standards Codification Topic 820-10, “Fair Value Measurements-Overall.” The amendments in ASU 2009-12 provide a practical expedient to measure investments that are required to be measured at fair value on a recurring or non-recurring basis but do not have a readily determinable fair value. The investments can be valued on the basis of the net asset value per share of the investment. There are additional disclosure requirements by major category of investments and the nature of restrictions on the investor’s ability to redeem its investments. The amendments in this ASU are effective for annual periods ending after December 15, 2009. See Note 10 of the Consolidated Financial Statements for related disclosures regarding pension assets that do not have readily determinable fair value.

In August 2009, the FASB issued Accounting Standards Update No. 2009-5, “Measuring Liabilities at Fair Value” (ASU 2009-05). ASU 2009-05 amends Accounting Standards Codification Topic 820, “Fair Value Measurements.” ASU 2009-05 provides clarification that in circumstances in which a quoted price in an active market for the identical liability is not available, a reporting entity is required to measure fair value using one or more of the following methods: 1) a valuation technique that uses a) the quoted price of the identical liability when traded as an asset or b) quoted prices for similar liabilities or similar liabilities when traded as assets and/or 2) a valuation technique that is consistent with the principles of ASC Topic 820 (e.g. an income approach or market approach). ASU 2009-05 also clarifies that when estimating the fair value of a liability, a reporting entity is not required to adjust to include inputs relating to the existence of transfer restrictions on that liability. The Company adopted these provisions in the fourth quarter of 2009 and the adoption did not have a material impact on the Company’s consolidated financial statements.

In December 2008, the FASB issued certain amendments as codified in ASC 715-20-65, “Compensation – Retirement Benefits, Defined Benefit Plans.” These amendments require additional disclosures regarding how investment decisions are made: the major categories of plan assets; the inputs and valuation techniques used to measure the fair value of plan assets; the effect of fair value measurements using significant unobservable inputs on changes in plan assets for the period; and significant concentrations of risk within plan assets. The disclosures about plan assets are required to be provided for fiscal years ending after December 15, 2009, with no restatement required for earlier periods that are presented for comparative purposes, upon initial application. Earlier application of the provisions is permitted. See Note 10 of the Consolidated Financial Statements for related disclosures.

In May 2009, the FASB issued a new standard, as codified in ASC Topic 855 “Subsequent Events.” ASC Topic 855 establishes general standards of accounting for and disclosure of events that occur after the balance sheet date but before financial statements are issued or are available to be issued. In addition, it provides guidance regarding the period after the balance sheet date during which management of a reporting entity should evaluate events or transactions that may occur for potential recognition or disclosure in the financial statements; the circumstances under which an entity should recognize events or transactions occurring after the balance sheet date in its financial statements; and the disclosures that an entity should make about events or transactions that occurred after the balance sheet date. The Company adopted this standard in the second quarter of 2009 and the adoption did not have a material effect on the Company’s consolidated financial statements.

In April 2009, the FASB issued certain amendments as codified in ASC 820-10-65, “Fair Value Disclosures.” ASC 820-10-65 affirms that the objective of fair value when the market for an asset is not active is the price that would be received to sell the asset in an orderly transaction, and includes additional factors for determining whether there has been a significant decrease in market activity for an asset when the market for that asset is not active. An entity is required to base its conclusion about whether a transaction was not orderly on the weight of the evidence. The Company adopted these provisions in the second quarter of 2009 and the adoption did not have a material impact on the Company’s consolidated financial statements.

In April 2009, the FASB issued certain amendments as codified in ASC Topic 320-10-65, “Investments — Debt and Equity Securities.” These amendments (i) change existing guidance for determining whether an impairment is other than temporary to debt securities and (ii) replace the existing requirement that the entity’s management assert it has both the intent and ability to hold an impaired security until recovery with a requirement that management assert: (a) it does not have the intent to sell the security; and (b) it is more likely than not it will not have to sell the security before recovery of its cost basis. Declines in the fair value of held-to-maturity and available-for-sale securities below their cost that are deemed to be other than temporary are reflected in earnings as realized losses to the extent the impairment is related to credit losses. The amount of the impairment related to other factors is recognized in other comprehensive income. The Company adopted ASC 320 in the second quarter of 2009 and the adoption did not have a material impact on the Company’s consolidated financial statements.

In April 2009, the FASB issued certain amendments as codified in ASC 825-10-65, “Financial Instruments,” that require an entity to provide disclosures about fair value of financial instruments in interim financial information including whenever it issues summarized financial information for interim reporting periods. In addition, entities must disclose, in the body or in the accompanying notes of its summarized financial information for interim reporting periods and in its financial statements for annual reporting periods, the fair value of all financial instruments for which it is practicable to estimate that value, whether recognized or not recognized in the statement of financial position. The Company adopted these amendments in the second quarter of 2009. See Note 8 of the Consolidated Financial Statements for related disclosures.

Recently Issued Accounting Pronouncements Not Yet Adopted:

In November 2009, the FASB issued ASU 2009-17, “Consolidations (Topic 810) – Improvements to Financial Reporting by Enterprises Involved with Variable Interest Entities,” which codifies FASB Statement No. 167, “Amendments to FASB Interpretation No. 46(R).” The ASU changes how a reporting entity determines when an entity that is insufficiently capitalized or is not controlled through voting (or similar rights) should be consolidated. The determination of whether a reporting entity is required to consolidate another entity is based on, among other things, the other entity’s purpose and design and the reporting entity’s ability to direct the activities of the other entity that most significantly impact the other entity’s economic performance. These provisions are effective January 1, 2010, for a calendar year-end entity, with early application not being permitted. Adoption of these provisions is not expected to have a material impact on the Company’s consolidated financial statements.

In November 2009, the FASB issued ASU 2009-16, “Transfers and Servicing (Topic 860) – Accounting for Transfers of Financial Assets,” which formally codifies FASB Statement No. 166, “Accounting for Transfers of Financial Assets.” ASU 2009-16 is a revision to SFAS No. 140, “Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities,” and requires more information about transfers of financial assets, including securitization transactions, and where entities have continuing exposure to the risks related to transferred financial assets. It eliminates the concept of a “qualifying special-purpose entity,” changes the requirements for derecognizing financial assets, and requires additional disclosures. The provisions are effective January 1, 2010, for a calendar year-end entity, with early application not being permitted. Adoption of these provisions is not expected to have a material impact on the Company’s consolidated financial statements.

In September 2009, the FASB issued certain amendments as codified in ASC 605-25, “Revenue Recognition; Multiple-Element Arrangements.” These amendments provide clarification on whether multiple deliverables exist, how the arrangement should be separated, and the consideration allocated. An entity is required to allocate revenue in an arrangement using estimated selling prices of deliverables in the absence of vendor-specific objective evidence or third-party evidence of selling price. These amendments also eliminate the use of the residual method and require an entity to allocate revenue using the relative selling price method. The amendments significantly expand the disclosure requirements for multiple-deliverable revenue arrangements. These provisions are to be applied on a prospective basis for revenue arrangements entered into or materially modified in fiscal years beginning on or after June 15, 2010, with earlier application permitted. The Company is currently evaluating the impact of these amendments to its consolidated financial statements.

Item 7A. Quantitative and Qualitative Disclosures about Market Risk

The Company is subject to interest rate risk exposure through borrowings on its credit facility. As of December 31, 2009, there are outstanding interest-bearing advances of $90.3 million on our credit facility which bear interest at a floating rate. Effective December 2008, we entered into an interest rate swap agreement that effectively converted $50 million of the outstanding variable-rate borrowings under the revolving credit agreement to a fixed-rate basis, thereby hedging against the impact of potential interest rate changes. Under this agreement, the Company and the issuing lender settle each month for the difference between a fixed interest rate of 2.07 percent and a comparable one month variable-rate interest paid to the syndicate of lenders under our Revolving Credit Agreement on the same notional amount, excluding the margin. The swap agreement terminates on September 8, 2011. As of December 31, 2009 the interest rate swap had a negative fair value of $820,000. An increase in interest rates of one percent would result in the interest rate swap having a negative fair value of approximately $18,000 at December 31, 2009. A decrease in interest rates of one percent would result in the interest rate swap having a negative fair value $1,647,000 at December 31, 2009. A change in interest rates will have no impact on the interest expense associated with the $50,000,000 of borrowings under the revolving credit agreement that are subject to the interest rate swap. A change in interest rates of one percent on the balance outstanding on the revolving credit agreement at December 31, 2009 not subject to the interest rate swap would cause a change of $0.9 million in total annual interest costs.

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

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

To the Stockholders of RPC, Inc.:

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

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

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of the design and operations of our internal control over financial reporting as of December 31, 2009 based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management’s assessment is that RPC, Inc. maintained effective internal control over financial reporting as of December 31, 2009.

The independent registered public accounting firm, Grant Thornton LLP, has audited the consolidated financial statements as of and for the year ended December 31, 2009, and has also issued their report on the effectiveness of the Company’s internal control over financial reporting, included in this report on page 30.

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

Atlanta, Georgia

March 3, 2010

Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting

Board of Directors and Stockholders

RPC, Inc.

We have audited RPC, Inc. (a Delaware Corporation) and subsidiaries’ (the “Company”) internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

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

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

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

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control—Integrated Framework issued by COSO.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of the Company as of December 31, 2009 and 2008, and the related consolidated statements of operations, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2009 and our report dated March 3, 2010 expressed an unqualified opinion on those consolidated financial statements.

/s/ Grant Thornton LLP

Atlanta, Georgia

March 3, 2010

Report of Independent Registered Public Accounting Firm on Consolidated Financial Statements

Board of Directors and Stockholders

RPC, Inc.

We have audited the accompanying consolidated balance sheets of RPC, Inc. (a Delaware corporation) and subsidiaries (the “Company”) as of December 31, 2009 and 2008, and the related consolidated statements of operations, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2009. Our audits of the basic consolidated financial statements included the financial statement schedule listed in the index appearing under Item 15. These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits.

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

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2009 and 2008, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2009 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the related financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.

As described in Note 5 to the consolidated financial statements, the Company adopted new accounting guidance related to the accounting for uncertainty in income tax reporting during 2007.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) and our report dated March 3, 2010 expressed an unqualified opinion thereon.

/s/ Grant Thornton LLP

Atlanta, Georgia

March 3, 2010

Item 8. Financial Statements and Supplementary Data

CONSOLIDATED BALANCE SHEETS

RPC, INC. AND SUBSIDIARIES

(in thousands except share information)

December 31,	2009			2008
ASSETS
Cash and cash equivalents	$	4,489		$	3,037
Accounts receivable, net		130,619			210,375
Inventories		55,783			49,779
Deferred income taxes		4,894			6,187
Income taxes receivable		18,184			15,604
Prepaid expenses and other current assets		5,485			7,841
Current assets		219,454			292,823
Property, plant and equipment, net		396,222			470,115
Goodwill		24,093			24,093
Other assets		9,274			6,430
Total assets	$	649,043		$	793,461
LIABILITIES AND STOCKHOLDERS’ EQUITY
LIABILITIES
Accounts payable	$	49,882		$	61,217
Accrued payroll and related expenses		10,708			20,398
Accrued insurance expenses		4,315			4,640
Accrued state, local and other taxes		2,001			2,395
Income taxes payable		647			3,359
Other accrued expenses		220			320
Current liabilities		67,773			92,329
Long-term accrued insurance expenses		8,597			8,398
Notes payable to banks		90,300			174,450
Long-term pension liabilities		14,647			11,177
Other long-term liabilities		1,838			3,628
Deferred income taxes		56,165			54,395
Total liabilities		239,320			344,377
Commitments and contingencies
STOCKHOLDERS’ EQUITY
Preferred stock, $0.10 par value, 1,000,000 shares authorized, none issued		-			-
Common stock, $0.10 par value, 159,000,000 shares authorized, 98,364,669 and 97,705,142 shares issued and outstanding in 2009 and 2008, respectively		9,836			9,770
Capital in excess of par value		7,638			3,990
Retained earnings		401,055			445,356
Accumulated other comprehensive loss		(8,806	)		(10,032	)
Total stockholders’ equity		409,723			449,084
Total liabilities and stockholders’ equity	$	649,043		$	793,461

The accompanying notes are an integral part of these statements.

CONSOLIDATED STATEMENTS OF OPERATIONS

RPC, INC. AND SUBSIDIARIES

(in thousands except per share data)

Years ended December 31,	2009			2008			2007
REVENUES	$	587,863		$	876,977		$	690,226
COSTS AND EXPENSES:
Cost of revenues		393,806			503,631			368,175
Selling, general and administrative expenses		97,672			117,140			107,800
Depreciation and amortization		130,580			118,403			78,506
Gain on disposition of assets, net		(1,143	)		(6,367	)		(6,293	)
Operating (loss) profit		(33,052	)		144,170			142,038
Interest expense		(2,176	)		(5,282	)		(4,179	)
Interest income		147			73			70
Other income (expense), net		1,582			(1,176	)		1,905
(Loss) income before income taxes		(33,499	)		137,785			139,834
Income tax (benefit) provision		(10,754	)		54,382			52,785
Net (loss) income	$	(22,745	)	$	83,403		$	87,049
(LOSS) EARNINGS PER SHARE

Basic	$	(0.24	)	$	0.86		$	0.90
Diluted	$	(0.24	)	$	0.85		$	0.89
Dividends paid per share	$	0.22		$	0.24		$	0.20

The accompanying notes are an integral part of these statements.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

RPC, INC. AND SUBSIDIARIES

(in thousands)

										Capital
										in						Accumulated
										Excess of						Other
Three Years Ended	Comprehensive			Common Stock						Par			Retained			Comprehensive
December 31, 2009	Income (Loss)			Shares			Amount			Value			Earnings			Income (Loss)			Total
Balance, December 31, 2006				97,214		$	9,721		$	13,595		$	317,705		$	(5,734	)	$	335,287
Stock issued for stock incentive plans, net				989			99			4,843			—			—			4,942
Stock purchased and retired				(163	)		(16	)		(2,838	)		—			—			(2,854	)
Net income	$	87,049		—			—			—			87,049			—			87,049
Pension adjustment, net of taxes		2,535		—			—			—			—			2,535			2,535
Unrealized gain on securities, net of taxes		486		—			—			—			—			486			486
Foreign currency translation, net of taxes		172		—			—			—			—			172			172
Comprehensive income	$	90,242
Dividends declared				—			—			—			(19,473	)		—			(19,473	)
Excess tax benefits for share-based payments				—			—			1,128			—			—			1,128
Balance, December 31, 2007				98,040			9,804			16,728			385,281			(2,541	)		409,272
Stock issued for stock incentive plans, net				1,288			128			5,654			—			—			5,782
Stock purchased and retired				(1,623	)		(162	)		(19,238	)		—			—			(19,400	)
Net income	$	83,403		—			—			—			83,403			—			83,403
Pension adjustment, net of taxes		(6,053	)	—			—			—			—			(6,053	)		(6,053	)
Loss on cash flow hedge, net of taxes		(527	)	—			—			—			—			(527	)		(527	)
Unrealized loss on securities, net of taxes		(585	)	—			—			—			—			(585	)		(585	)
Foreign currency translation, net of taxes		(326	)	—			—			—			—			(326	)		(326	)
Comprehensive income	$	75,912
Dividends declared				—			—			—			(23,328	)		—			(23,328	)
Excess tax benefits for share-based payments				—			—			846			—			—			846
Balance, December 31, 2008				97,705			9,770			3,990			445,356			(10,032	)		449,084
Stock issued for stock incentive plans, net				911			91			4,323			—			—			4,414
Stock purchased and retired				(252	)		(25	)		(2,096	)		—			—			(2,121	)
Net loss	$	(22,745	)	—			—			—			(22,745	)		—			(22,745	)
Pension adjustment, net of taxes		897		—			—			—			—			897			897
Gain on cash flow hedge, net of taxes		7		—			—			—			—			7			7
Unrealized gain on securities, net of taxes		91		—			—			—			—			91			91
Foreign currency translation, net of taxes		231		—			—			—			—			231			231
Comprehensive loss	$	(21,519	)
Dividends declared				—			—			—			(21,556	)		—			(21,556	)
Excess tax benefits for share-based payments				—			—			1,421			—			—			1,421
Balance, December 31, 2009				98,364		$	9,836		$	7,638		$	401,055		$	(8,806	)	$	409,723

The accompanying notes are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CASH FLOWS

RPC, Inc. and Subsidiaries

(in thousands)

Years ended December 31,	2009			2008			2007
OPERATING ACTIVITIES
Net (loss) income	$	(22,745	)	$	83,403		$	87,049
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, amortization and other non-cash charges		130,581			118,444			78,493
Stock-based compensation expense		4,440			3,732			3,189
Gain on disposition of assets, net		(1,143	)		(6,367	)		(6,293	)
Deferred income tax provision		1,669			27,199			15,738
Excess tax benefits for share-based payments		(1,421	)		(846	)		(1,128	)
Changes in current assets and liabilities:
Accounts receivable		80,035			(34,508	)		(27,497	)
Income taxes receivable		(1,159	)		(2,462	)		(7,229	)
Inventories		(5,798	)		(20,377	)		(8,316	)
Prepaid expenses and other current assets		2,575			(2,231	)		(568	)
Accounts payable		(5,711	)		9,691			7,826
Income taxes payable		(2,712	)		(981	)		123
Accrued payroll and related expenses		(9,690	)		2,426			4,683
Accrued insurance expenses		(325	)		(113	)		1,426
Accrued state, local and other taxes		(394	)		676			(1,078	)
Other accrued expenses		(167	)		(203	)		46
Changes in working capital		56,654			(48,082	)		(30,584	)
Changes in other assets and liabilities:
Pension liabilities		4,882			(481	)		(3,067	)
Accrued insurance expenses		199			232			1,274
Other non-current assets		(2,597	)		(20	)		(1,173	)
Other non-current liabilities		(1,779	)		106			(1,626	)
Net cash provided by operating activities		168,740			177,320			141,872
INVESTING ACTIVITIES
Capital expenditures		(67,830	)		(170,318	)		(248,758	)
Proceeds from sale of assets		6,686			11,365			9,134
Net cash used for investing activities		(61,144	)		(158,953	)		(239,624	)
FINANCING ACTIVITIES
Payment of dividends		(21,556	)		(23,328	)		(19,473	)
Borrowings from notes payable to banks		276,100			392,300			478,600
Repayments of notes payable to banks		(360,250	)		(374,250	)		(357,800	)
Debt issue costs for notes payable to banks		(234	)		(94	)		—
Excess tax benefits for share-based payments		1,421			846			1,128
Cash paid for common stock purchased and retired		(1,747	)		(17,489	)		(1,730	)
Proceeds received upon exercise of stock options		122			347			636
Net cash (used for) provided by financing activities		(106,144	)		(21,668	)		101,361
Net increase (decrease) in cash and cash equivalents		1,452			(3,301	)		3,609
Cash and cash equivalents at beginning of year		3,037			6,338			2,729
Cash and cash equivalents at end of year	$	4,489		$	3,037		$	6,338

The accompanying notes are an integral part of these statements.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

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, including the Gulf of Mexico, mid-continent, southwest, northeast and Rocky Mountain 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 159,000,000 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, 2009, 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 26, 2010, the Board of Directors approved a $0.04 per share cash dividend payable March 10, 2010 to stockholders of record at the close of business on February 10, 2010.

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 requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

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

Revenues

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

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

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. Two customers individually accounted for 13 percent and 12 percent of the Company’s 2009 revenues. No customers accounted for more than 10 percent of 2008 or 2007 revenues. Additionally, one of these customers accounted for 12 percent of accounts receivable as of December 31, 2009 and no customers accounted for more than 10 percent of accounts receivable as of December 31, 2008.

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 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 on securities during 2009, 2008 or 2007 on its available-for-sale securities. Securities that are held in the non-qualified Supplemental 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 (expense) income 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 are 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 amount owed by 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 our evaluation of industry trends, financial condition of our customers, our historical write-off experience, current economic conditions, and in the case of our international customers, our 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 in RPC’s services provided to customers, (ii) spare parts for equipment used in providing these services and (iii) manufactured components and attachments for equipment used in providing services, are recorded at the lower of weighted average cost or market value. Market value is determined based on replacement cost for material and supplies. The Company regularly reviews inventory quantities on hand and records provisions for excess or obsolete inventory based primarily on its estimated forecast of product demand, market conditions, production requirements and technological developments.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

Derivative Instruments and Hedging Activities

The Company is subject to interest rate risk on the variable component of the interest rate under our revolving credit agreement. Effective December 2008, the Company entered into a $50 million interest rate swap agreement. The agreement terminates on September 8, 2011. The Company has designated the interest rate swap as a cash flow hedge. Changes in the fair value of the effective portion of the interest rate swap are recognized in other comprehensive loss until the hedged item is recognized in earnings.

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 expense is computed using the following useful lives: operating equipment, 3 to 10 years; buildings and leasehold improvements, 15 to 30 years; furniture and fixtures, 5 to 7 years; software, 5 years; and vehicles, 3 to 5 years. The cost of assets retired or otherwise disposed of and the related accumulated depreciation and amortization are eliminated from the accounts in the year of disposal with the resulting gain or loss credited or charged to income from operations. Expenditures for additions, major renewals, and betterments are capitalized. Expenditures for restoring an identifiable asset to working condition or for maintaining the asset in good working order constitute repairs and maintenance and are expensed as incurred.

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.

Goodwill and Other Intangibles

Goodwill represents the excess of the purchase price over the fair value of net assets of businesses acquired. The carrying amount of goodwill was $24,093,000 at December 31, 2009 and 2008. 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. In reviewing goodwill for impairment, potential impairment is measured by comparing the estimated fair value of a reporting unit with its carrying value. Based upon the results of these analyses, the Company has concluded that no impairment of its goodwill has occurred for the years ended December 31, 2009, 2008 and 2007.

Other intangibles primarily represent non-compete agreements related to businesses acquired. Non-compete agreements are amortized on a straight-line basis over the period of the agreement, as this method best estimates the ratio that current revenues bear to the total of current and anticipated revenues. These non-compete agreements are fully amortized as of December 31, 2009 and 2008.

Advertising

Advertising expenses are charged to expense during the period in which they are incurred. Advertising expenses totaled $1,065,000 in 2009, $1,957,000 in 2008 and $1,594,000 in 2007.

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.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

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.

Earnings per Share

FASB ASC Topic 260-10 “Earnings Per Share-Overall,” requires a basic earnings per share and diluted earnings per share presentation. During 2009, the Company adopted certain amendments to ASC 260-10 which requires that all outstanding unvested share-based payment awards that contain non-forfeitable rights to dividends or dividend equivalents, whether paid or unpaid, be considered participating securities and included in the calculation of its basic earnings per share.

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 and 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 (loss) income by the weighted average number of shares outstanding during the respective periods.

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

(In thousands except per share data)	2009			2008			2007
Net (loss) income available for stockholders:	$	(22,745	)	$	83,403		$	87,049
Less: Dividends paid
Common stock		(21,229	)		(22,905	)		(19,159	)
Restricted shares of common stock		(327	)		(423	)		(314	)
Undistributed (loss) earnings	$	(44,301	)	$	60,075		$	67,576

Allocation of undistributed earnings:
Common stock	$	(43,408	)	$	58,992		$	66,494
Restricted shares of common stock		(893	)		1,083			1,082

Basic shares outstanding:
Common stock		94,260			94,750			94,664
Restricted shares of common stock		2,045			1,815			1,604
		96,305			96,565			96,268
Diluted shares outstanding:
Common stock		94,260			94,750			94,664
Dilutive effect of options		-			1,300			2,094
		94,260			96,050			96,758
Restricted shares of common stock		2,045			1,815			1,604
		96,305			97,865			98,362
Basic earnings per share:
Common stock:
Distributed earnings	$	0.22		$	0.24		$	0.20
Undistributed (loss) earnings		(0.46	)		0.62			0.70
	$	(0.24	)	$	0.86		$	0.90
Restricted shares of common stock:
Distributed earnings	$	0.16		$	0.23		$	0.20
Undistributed (loss) earnings		(0.44	)		0.60			0.67
	$	(0.28	)	$	0.83		$	0.87
Diluted earnings per share:
Common Stock:
Distributed earnings	$	0.22		$	0.24		$	0.20
Undistributed (loss) earnings		(0.46	)		0.61			0.69
	$	(0.24	)	$	0.85		$	0.89

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

During the year ended December 31, 2009, the Company incurred a net loss from continuing operations and consequently the common stock equivalents were excluded from the computation of diluted loss per share because the effect would have been anti-dilutive.

Fair Value of Financial Instruments

The Company’s financial instruments consist of cash and cash equivalents, accounts receivable, marketable securities, accounts payable, an interest rate swap, 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 marketable securities classified as available-for-sale and the securities held in the SERP classified as trading are carried at fair value in the accompanying consolidated balance sheets. The interest rate swap is carried at fair value, which is based on quotes from the issuer of the swap and represents the estimated amounts that we would expect to pay to terminate the swap. 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.

Reclassifications

In the current year the Company classified stock-based compensation together with stock issued for stock incentive plans, net in the consolidated statements of stockholders' equity. For comparative purposes, amounts in the prior year have been reclassified to conform to current year presentation.

New Accounting Pronouncements

Recently Adopted Accounting Pronouncements:

In September 2009, the FASB issued ASU No. 2009-12, “Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent)” (ASU 2009-12). ASU 2009-12 amends Accounting Standards Codification Topic 820-10, “Fair Value Measurements-Overall.” The amendments in ASU 2009-12 provide a practical expedient to measure investments that are required to be measured at fair value on a recurring or non-recurring basis but do not have a readily determinable fair value. The investments can be valued on the basis of the net asset value per share of the investment. There are additional disclosure requirements by major category of investments and the nature of restrictions on the investor’s ability to redeem its investments. The amendments in this ASU are effective for annual periods ending after December 15, 2009. See Note 10 for related disclosures regarding pension assets that do not have readily determinable fair value.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

In December 2008, the FASB issued certain amendments as codified in ASC 715-20-65, “Compensation – Retirement Benefits, Defined Benefit Plans.” These amendments require additional disclosures regarding how investment decisions are made: the major categories of plan assets; the inputs and valuation techniques used to measure the fair value of plan assets; the effect of fair value measurements using significant unobservable inputs on changes in plan assets for the period; and significant concentrations of risk within plan assets The disclosures about plan assets are required to be provided for fiscal years ending after December 15, 2009, with no restatement required for earlier periods that are presented for comparative purposes, upon initial application. Earlier application of the provisions is permitted. See Note 10 for related disclosures.

In April 2009, the FASB issued certain amendments as codified in ASC Topic 320-10-65, “Investments — Debt and Equity Securities.” These amendments (i) changes existing guidance for determining whether an impairment is other than temporary to debt securities and (ii) replace the existing requirement that the entity’s management assert it has both the intent and ability to hold an impaired security until recovery with a requirement that management assert: (a) it does not have the intent to sell the security; and (b) it is more likely than not it will not have to sell the security before recovery of its cost basis. Declines in the fair value of held-to-maturity and available-for-sale securities below their cost that are deemed to be other than temporary are reflected in earnings as realized losses to the extent the impairment is related to credit losses. The amount of the impairment related to other factors is recognized in other comprehensive income. The Company adopted ASC 320 in the second quarter of 2009 and the 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, 2009, 2008 and 2007

Recently Issued Accounting Pronouncements Not Yet Adopted:

Note 2: Accounts Receivable

Accounts receivable, net consists of the following:

December 31,	2009			2008
(in thousands)
Trade receivables:
Billed	$	98,275		$	168,989
Unbilled		34,753			47,034
Other receivables		801			551
Total		133,829			216,574
Less: Allowance for doubtful accounts		(3,210	)		(6,199	)
Accounts receivable, net	$	130,619		$	210,375

Trade receivables relate to sale of our services and products, for which credit is extended based on the customer’s credit history. 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.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

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

Years Ended December 31,	2009			2008
(in thousands)
Beginning balance	$	6,199		$	5,217
Bad debt expense (credit)		660			(84	)
Accounts written-off		(3,763	)		(392	)
Recoveries		114			1,458
Ending balance	$	3,210		$	6,199

Note 3: Inventories

Inventories are $55,783,000 at December 31, 2009 and $49,779,000 at December 31, 2008 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:

December 31,	2009			2008
(in thousands)
Land	$	14,980		$	14,927
Buildings and leasehold improvements		80,928			77,867
Operating equipment		631,666			595,217
Capitalized software		15,391			15,700
Furniture and fixtures		4,342			4,398
Vehicles		180,408			181,102
Construction in progress		35			231
Gross property, plant and equipment		927,750			889,442
Less: accumulated depreciation		(531,528	)		(419,327	)
Net property, plant and equipment	$	396,222		$	470,115

Depreciation expense was $130.6 million in 2009, $118.4 million in 2008 and $78.5 million in 2007. There are no capital leases outstanding as of December 31, 2009 and December 31, 2008. The Company had accounts payable for purchases of property and equipment of approximately $3.7 million, $9.4 million and $19.1 million as of December 31, 2009, 2008 and 2007.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

Note 5: Income Taxes

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

Years ended December 31,	2009			2008		2007
(in thousands)
Current (benefit) provision:
Federal	$	( 13,490	)	$	20,793	$	29,589
State		235			5,453		4,857
Foreign		832			937		2,601
Deferred (benefit) provision:
Federal		1,698			25,486		14,531
State		( 29	)		1,713		1,207
Total income tax (benefit) provision	$	(10,754	)	$	54,382	$	52,785

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

Years ended December 31,	2009			2008			2007
Federal statutory rate		35.0	%		35.0	%		35.0	%
State income taxes, net of federal benefit		(2.4	)		3.2			2.8
Tax credits		1.3			(0.8	)		(1.6	)
Federal and state refunds		—			—			0.1
Non-deductible expenses		(2.6	)		0.9			0.7
Other		0.8			1.2			0.7
Effective tax rate		32.1	%		39.5	%		37.7	%

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

December 31,	2009			2008
(in thousands)
Deferred tax assets:
Self-insurance	$	5,445		$	5,404
Pension		5,346			4,054
State net operating loss carryforwards		1,742			1,649
Bad debts		1,361			2,418
Accrued payroll		866			1,579
Stock-based compensation		2,413			2,294
All others		149			501
Valuation allowance		(1,550	)		(1,454	)
Gross deferred tax assets		15,772			16,445
Deferred tax liabilities:
Depreciation		(62,640	)		(60,946	)
Goodwill amortization		(4,403	)		(3,707	)
Gross deferred tax liabilities		(67,043	)		(64,653	)
Net deferred tax liabilities	$	(51,271	)	$	(48,208	)

Historically and currently, undistributed earnings of the Company’s foreign subsidiaries are considered indefinitely reinvested and, accordingly, no provision for U.S. federal income taxes has been recorded. Deferred taxes are provided for earnings outside the United States when those earnings are not considered indefinitely reinvested.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

As of December 31, 2009, the Company has net operating loss carryforwards related to state income taxes of approximately $40.6 million that will expire between 2010 and 2029. As of December 31, 2009 the Company has a valuation allowance of approximately $1.6 million, representing the tax affected amount of loss carryforwards that the Company does not expect to utilize, against the corresponding deferred tax asset.

Total net income tax payments (refunds) were ($8,351,000) in 2009, $29,714,000 in 2008 and $46,328,000 in 2007.

The Company’s policy is to record interest and penalties related to income tax matters as income tax expense. Accrued interest and penalties were immaterial to the financial statements as of December 31, 2009 and 2008.

During 2007 the Company adopted new accounting guidance relating to the accounting for uncertainty in income tax reporting, which provided criteria for the recognition, measurement, presentation and disclosure of uncertain tax positions. As a result of the adoption the Company did not recognize a material adjustment in the liability for unrecognized income tax benefits.

The Company’s liability for unrecognized tax benefits was $30 thousand as of December 31, 2009 and $11 thousand as of December 31, 2008, all of which would affect our effective rate if recognized. A reconciliation of the beginning and ending amount of unrecognized tax benefits for 2009 and 2008 are as follows:

Years Ended December 31,	2009		2008
(in thousands)
Beginning balance	$	11	$	10
Additions based on tax positions related to current year		-		-
Additions for tax positions of prior years		19		1
Reductions for tax positions of prior years		-		-
Ending balance	$	30	$	11

The Company and its subsidiaries are subject to U.S. federal and state income tax 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 2006 through 2009 tax years remain open to examination.

It is reasonably possible that the amount of the unrecognized tax benefits with respect to our unrecognized tax positions will increase or decrease in the next 12 months. These changes may be the result of, among other things, state tax settlements under Voluntary Disclosure Agreements. However, quantification of an estimated range cannot be made at this time.

Note 6: Long-Term Debt

The Company currently has a revolving credit agreement (the “Revolving Credit Agreement”) with SunTrust Capital Markets, Inc, as Joint Lead Arranger and Sole Book Manager, Banc of America Securities LLC as Joint Lead Arranger, and a syndicate of six other lenders. The Revolving Credit Agreement includes a full and unconditional guarantee by RPC’s 100 percent owned domestic subsidiaries whose assets equal substantially all of the consolidated assets of RPC and its subsidiaries. The subsidiaries of the Company that are not guarantors are considered minor.

The Revolving Credit Agreement has a general term of five years and provides for an unsecured line of credit of up to $200 million, which includes a $50 million letter of credit subfacility, and a $20 million swingline subfacility. During the third quarter of 2009, the Company and its banking syndicate lenders entered into an agreement to amend two substantive components of the Revolving Credit Agreement. First, the aggregate revolving commitment amount was reduced from $296.5 million to $200 million. Second, the numerator of the interest coverage ratio, one of two financial covenants contained in the Revolving Credit Agreement, was changed from EBIT to EBITDA. In addition, the amendment revises the definition of the term “Base Rate” to provide that such rate will be not less than the per annum rate determined by increasing the one (1) month LIBOR rate by 1.0%. The maturity date of all revolving loans under the Credit Agreement is September 8, 2011. The Company has incurred loan origination fees and other debt related costs associated with the Revolving Credit Agreement, including amendment costs in the aggregate of approximately $753 thousand. These costs are being amortized over the five year term of the loan, and the net amount is classified as non-current other assets on the consolidated balance sheets.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

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

●

the Base Rate, which is the highest of SunTrust Bank’s “prime rate” for the day of the borrowing, a fluctuating rate per annum equal to the Federal Funds Rate plus .50%, and a rate per annum equal to one (1) month LIBOR rate plus 1.00%; or

●

with respect to any Eurodollar borrowings, Adjusted LIBOR (which equals LIBOR as increased to account for the maximum reserve percentages established by the U.S. Federal Reserve) plus a margin ranging from .40% to .80%, based upon RPC’s then-current consolidated debt-to-EBITDA ratio.

In addition, RPC will pay an annual fee ranging from .10% to .20% of the total credit facility based upon RPC’s then-current consolidated debt-to-EBITDA ratio. The Revolving Credit Agreement contains customary terms and conditions, including certain financial covenants and restrictions on indebtedness, dividend payments, business combinations and other related items. Further, the Revolving Credit Agreement contains financial covenants limiting the ratio of the Company’s consolidated debt-to-EBITDA to no more than 2.5 to 1, and limiting the ratio of the Company’s consolidated EBITDA to interest expense to no less than 2 to 1.

As of December 31, 2009, RPC has outstanding borrowings of $90.3 million under the Revolving Credit Agreement. Interest incurred and recorded as expense on the facility was $2,327,000 in 2009, $5,188,000 in 2008 and $4,083,000 in 2007. The weighted average interest rate was 1.8% in 2009, 3.6% in 2008 and 6.1% for 2007. The Company capitalized interest incurred of $150,000 in 2009, $1,064,000 in 2008 and $2,300,000 in 2007 related to facilities and equipment under construction. Additionally there were letters of credit relating to self-insurance programs and contract bids outstanding for $17.8 million as of December 31, 2009.

Cash interest paid (net of capitalized interest) was approximately $2,192,000 in 2009, $5,232,000 in 2008 and $3,849,000 in 2007.

Effective December 2008 the Company entered into an interest rate swap agreement that effectively converted $50 million of our variable-rate debt to a fixed rate basis, thereby hedging against the impact of potential interest rate changes on future interest expense. The agreement terminates on September 8, 2011. Under this agreement the Company and the issuing lender settle on a monthly basis for the difference between a fixed interest rate of 2.07% and a comparable one month LIBOR rate.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

Note 7: Accumulated Other Comprehensive (Loss) Income

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

	Pension Adjustment			Unrealized Gain (Loss) On Securities			Foreign Currency Translation			Net Gain (Loss) On Cash Flow Hedge			Total
Balance at December 31, 2007	$	(3,427	)	$	714		$	172		$	—		$	(2,541	)
Change during 2008:
Before-tax amount		(9,532	)		(921	)		(513	)		(830	)		(11,796	)
Tax benefit		3,479			336			187			303			4,305
Total activity in 2008		(6,053	)		(585	)		(326	)		(527	)		(7,491	)
Balance at December 31, 2008	$	(9,480	)	$	129		$	(154	)	$	(527	)	$	(10,032	)
Change during 2009:
Before-tax amount		1,413			143			530			11			2,097
Tax expense		(516	)		(52	)		(299	)		(4	)		(871	)
Total activity in 2009		897			91			231			7			1,226
Balance at December 31, 2009	$	(8,583	)	$	220		$	77		$	(520	)	$	(8,806	)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

Note 8: Fair Value Disclosures

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

1.	Level 1 – Quoted market prices in active markets for identical assets or liabilities.

Level 2 – Quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-based valuation techniques for which all significant assumptions are observable in the market or can be corroborated by observable market data for substantially the full term of the assets or liabilities.

3.	Level 3 – Unobservable inputs developed using the Company’s estimates and assumptions, which reflect those that market participants would use.

The following table summarizes the valuation of financial instruments measured at fair value on a recurring basis on the balance sheet as of December 31, 2009 and 2008:

	Fair Value Measurements at December 31, 2009 with:
(in thousands)	Quoted prices in active markets for identical assets		Significant other observable inputs		Significant unobservable inputs
	(Level 1)		(Level 2)		(Level 3)
Assets:
Trading securities	$	-	$	6,905	$	-
Available-for-sale securities		653		-		-
Liabilities:
Interest rate swap	$	-	$	820	$	-

	Fair Value Measurements at December 31, 2008 with:
(in thousands)	Quoted prices in active markets for identical assets		Significant other observable inputs		Significant unobservable inputs
	(Level 1)		(Level 2)		(Level 3)
Assets:
Trading securities	$	4,074	$	-	$	-
Available-for-sale securities		511		-		-
Liabilities:
Interest rate swap	$	-	$	830	$	-

The Company determines the fair value of the marketable securities that are available-for-sale through quoted market prices. The total fair value is the final closing price, as defined by the exchange in which the asset is actively traded, on the last trading day of the period, multiplied by the number of units held without consideration of transaction costs. During fiscal year 2009, significant observable inputs in addition to quoted market prices were used to value trading securities. As a result, the Company classified these investments as using level 2 inputs.

At December 31, 2009 and 2008, there was $90,300,000 and $174,450,000 outstanding under our revolving credit agreement. The fair value of these borrowings was $88,043,000 in 2009 and $174,450,000 in 2008. The fair value of these borrowings was based on quotes from the lender (level 2 inputs). The borrowings under our revolving credit agreement bear interest at the variable rate described in Note 6. We are subject to interest rate risk on the variable component of the interest rate. Our risk management objective is to lock in the interest cash outflows on a portion of our debt. As a result, as described in Note 6, we entered into an interest rate swap agreement effectively converting a portion of the outstanding borrowings under the revolving credit agreement to a fixed-rate, thereby hedging against the impact of potential interest rate changes on future interest expense. At December 31, 2009 the interest rate swap had a negative fair value of $820,000, which is recorded in other long-term liabilities. The fair value of the interest rate swap was based on quotes from the issuer of the swap and represents the estimated amounts that we would expect to pay to terminate the swap.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

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

Note 9: Commitments and Contingencies

Lease Commitments - Minimum annual rentals, principally for noncancelable real estate and equipment leases with terms in excess of one year, in effect at December 31, 2009, are summarized in the following table:

(in thousands)
2010	$	3,671
2011		3,172
2012		2,146
2013		1,554
2014		950
Thereafter		812
Total rental commitments	$	12,305

Total rental expense, including short-term rentals, charged to operations was approximately $10,787,000 in 2009, $9,109,000 in 2008 and $7,116,000 in 2007.

Income Taxes - The amount of income taxes the Company pays is subject to ongoing audits by federal and state tax authorities, which often result in proposed assessments. Other long-term liabilities include $30,000 as of December 31, 2009 and $11,000 as of December 31, 2008, that represents the Company’s estimated statute for the probable assessments payable.

Sales and Use Taxes - The Company has ongoing sales and use tax audits in various jurisdictions and may be subjected to varying interpretations of statute that could result in unfavorable outcomes that cannot be currently estimated.

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

Note 10: Employee Benefit Plans

Defined Benefit Pension Plan

The Company’s Retirement Income Plan, a trusteed defined benefit pension plan, provides monthly benefits upon retirement at age 65 to substantially all employees with at least one year of service prior to 2002. As of February 28, 2001, the plan became a multiple employer plan, with Marine Products Corporation as an adopting employer.

In 2002, the Company’s Board of Directors approved a resolution to cease all future retirement benefit accruals under the Retirement Income Plan. In lieu thereof, the Company began providing enhanced benefits in the form of cash contributions for certain longer serviced employees that had not reached the normal retirement age of 65 as of March 31, 2002. The contributions were discretionary and made annually based on continued employment over a seven year period ending in 2008. These discretionary contributions were made to either the SERP established by the Company or to the 401(k) plan for each employee that was entitled to the enhanced benefit. There was no expense related to the enhanced benefits for 2009. The expense related to enhanced benefits was $295,000 for 2008 and $315,000 for 2007.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

The Company permits selected highly compensated employees to defer a portion of their compensation into the SERP. The SERP assets are marked to market and totaled $6,905,000 as of December 31, 2009 and $4,073,000 as of December 31, 2008. The SERP assets are reported in other assets on the balance sheet and changes related to the fair value of assets are recorded in the consolidated statement of operations as part of other (expense) income, net. Trading gains (losses) related to the SERP assets totaled $1,373,000 for 2009, $(1,661,000) for 2008 and $73,000 for 2007. The SERP deferrals and the contributions are recorded on the balance sheet in pension liabilities with any change in the fair value of the liabilities recorded as compensation cost in the statement of operations.

The Company’s projected benefit obligation exceeds the fair value of the plan assets under its pension plan by $7,258,000 and thus the plan was under-funded as of December 31, 2009.

The following table sets forth the funded status of the Retirement Income Plan and the amounts recognized in RPC’s consolidated balance sheets:

December 31,	2009			2008
(in thousands)
Accumulated Benefit Obligation at end of year	$	32,190		$	29,203

CHANGE IN PROJECTED BENEFIT OBLIGATION:
Benefit obligation at beginning of year	$	29,203		$	30,149
Service cost		—			—
Interest cost		1,938			1,841
Amendments		—			—
Actuarial (gain) loss		2,706			(1,239	)
Benefits paid		(1,657	)		(1,548	)
Projected benefit obligation at end of year	$	32,190		$	29,203
CHANGE IN PLAN ASSETS:
Fair value of plan assets at beginning of year	$	22,488		$	32,548
Actual return on plan assets		4,101			(8,512	)
Employer contribution		—			—
Benefits paid		(1,657	)		(1,548	)
Fair value of plan assets at end of year		24,932			22,488

Funded status at end of year	$	(7,258	)	$	(6,715	)

December 31,	2009			2008
(in thousands)
AMOUNTS RECOGNIZED IN THE CONSOLIDATED BALANCE SHEETS CONSIST OF:
Noncurrent assets	$	—		$	—
Current liabilities		—			—
Noncurrent liabilities		(7,258	)		(6,715	)
	$	(7,258	)	$	(6,715	)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

December 31,	2009		2008
(in thousands)
AMOUNTS (PRE-TAX) RECOGNIZED IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) CONSIST OF:
Net loss (gain)	$	13,517	$	14,928
Prior service cost (credit)		—		—
Net transition obligation (asset)		—		—
	$	13,517	$	14,928

The accumulated benefit obligation for the Retirement Income Plan at December 31, 2009 and 2008 has been disclosed above. The Company uses a December 31 measurement date for this qualified plan.

Amounts recognized in the consolidated balance sheets consist of:

December 31,	2009			2008
(in thousands)
Funded status	$	(7,258	)	$	(6,715	)
SERP employer contributions/deferrals		(7,389	)		(4,462	)
Long-term pension liabilities	$	(14,647	)	$	(11,177	)

RPC’s funding policy is to contribute to the defined benefit pension plan the amount required, if any, under the Employee Retirement Income Security Act of 1974. RPC made no contributions in 2009 or in 2008.

The components of net periodic benefit cost are summarized as follows:

Years ended December 31,	2009			2008			2007
(in thousands)
Service cost for benefits earned during the period	$	—		$	—		$	—
Interest cost on projected benefit obligation		1,938			1,841			1,759
Expected return on plan assets		(1,521	)		(2,543	)		(2,321	)
Amortization of net loss		1,538			285			860
Net periodic benefit plan cost (credit)	$	1,955		$	(417	)	$	298

The Company recognized pre-tax (increases) decreases to the funded status in comprehensive loss of $(1,413,000) in 2009, $9,532,000 in 2008 and $(3,992,000) in 2007. There were no previously unrecognized prior service costs as of December 31, 2009, 2008 and 2007. The pre-tax amounts recognized in comprehensive loss for the years ended December 31, 2009, 2008 and 2007 are summarized as follows:

(in thousands)	2009			2008			2007
Net loss (gain)	$	125		$	9,817		$	(3,132	)
Amortization of net (loss) gain		(1,538	)		(285	)		(860	)
Net transition obligation (asset)		—			—			—
Amount recognized in other comprehensive loss	$	(1,413	)	$	9,532		$	(3,992	)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

The amounts in accumulated other comprehensive loss expected to be recognized as components of net periodic benefit cost in 2010 are as follows:

(in thousands)	2010
Amortization of net loss (gain)	$	388
Prior service cost (credit)		—
Net transition obligation (asset)		—
Estimated net periodic benefit plan cost	$	388

The weighted average assumptions as of December 31 used to determine the projected benefit obligation and net benefit cost were as follows:

December 31,	2009			2008			2007
Projected Benefit Obligation:
Discount rate		6.00	%		6.84	%		6.25	%
Rate of compensation increase		N/A			N/A			N/A
Net Benefit Cost:
Discount rate		6.84	%		6.25	%		5.50	%
Expected return on plan assets		7.00	%		8.00	%		8.00	%
Rate of compensation increase		N/A			N/A			N/A

The Company’s expected return on assets assumption is derived from a detailed periodic assessment conducted by its management and its investment adviser. It includes a review of anticipated future long-term performance of individual asset classes and consideration of the appropriate asset allocation strategy given the anticipated requirements of the plan to determine the average rate of earnings expected on the funds invested to provide for the pension plan benefits. While the study gives appropriate consideration to recent fund performance and historical returns, the rate of return assumption is derived primarily from a long-term, prospective view. Based on its recent assessment, the Company has concluded that its expected long-term return assumption of seven percent is reasonable.

The Plan’s weighted average asset allocation at December 31, 2009 and 2008 by asset category along with the target allocation for 2010 are as follows:

Asset Category	Target Allocation for 2010			Percentage of Plan Assets as of December 31, 2009			Percentage of Plan Assets as of December 31, 2008
Debt Securities – Core Fixed Income		27.0	%		26.2	%		14.0	%
Tactical – Fund of Equity and Debt Securities		5.0	%		5.2	%		4.3	%
Domestic Equity Securities		32.5	%		25.0	%		22.7	%
Global Equity Securities		2.5	%		4.4	%		3.6	%
International Equity Securities		8.0	%		13.8	%		11.2	%
Real Estate		5.0	%		4.2	%		7.7	%
Other		20.0	%		21.2	%		36.5	%
Total		100.0	%		100.0	%		100.0	%

The Company’s overall investment strategy is to achieve a mix of approximately 70 percent of investments for long-term growth and 30 percent for near-term benefit payments, with a wide diversification of asset types, fund strategies and fund managers. Equity securities primarily include investments in large-cap and mid-cap companies. Fixed-income securities include corporate bonds of companies in diversified securities, mortgage-backed securities, and U.S. Treasuries. Other types of investments include hedge funds and private equity funds that follow several different investment strategies. For each of the asset categories in the pension plan, the investment strategy is identical – maximize the long-term rate of return on plan assets with an acceptable level of risk in order to minimize the cost of providing pension benefits. The investment policy establishes a target allocation for each asset class which is rebalanced as required.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

Some of our assets, primarily our private equity, real estate and hedge funds, do not have readily determinable market values given the specific investment structures involved and the nature of the underlying investments. For the December 31, 2009 plan asset reporting, publicly traded asset pricing was used where possible. For assets without readily determinable values, estimates were derived from investment manager discussions focusing on underlying fundamentals and significant events.

The following table presents our plan assets using the fair value hierarchy as of December 31, 2009. The fair value hierarchy has three levels based on the reliability of the inputs used to determine fair value. See Note 8 for a brief description of the three levels under the fair value hierarchy.

Investments (in thousands)		Total		Level 1		Level 2		Level 3
Cash and Cash Equivalents	(1)	$	943	$	943	$	-	$	-
Fixed Income Securities	(2)		6,529		-		6,529		-
Domestic Equity Securities			6,237		6,237		-		-
Global Equity Securities	(3)		1,085		-		1,085		-
International Equity Securities	(3)		3,440		1,475		1,965		-
Real Estate	(4)		1,039		-		-		1,039
Hedge Funds	(5)		5,659		-		1,302		4,357
		$	24,932	$	8,655	$	10,881	$	5,396

(1)

Cash and cash equivalents, which are used to pay benefits and plan administrative expenses, are held in Rule 2a-7 money market funds.

(2)

Fixed income securities are primarily valued using a market approach with inputs that include broker quotes, benchmark yields, base spreads and reported trades.

(3)

Global equity securities and certain international securities are valued using a market approach based on the quoted market prices of similar instruments in their respective markets.

(4)

Real estate fund values are primarily reported by the fund manager and are based on valuation of the underlying investments, which include inputs such as cost, discounted future cash flows, independent appraisals and market based comparable data.

(5)

Hedge funds consist of fund-of-fund LLC or commingled fund structures. The LLCs are primarily valued based on Net Asset Values [NAV] calculated by the fund and are not publicly available. Liquidity for the LLCs is monthly and is subject to liquidity of the underlying funds. The commingled fund NAV is calculated by the manager on a daily basis and has monthly liquidity.

The following table presents a reconciliation of Level 3 assets held during the year ended December 31, 2009:

Investments (in thousands)	Balance at December 31, 2008		Net Realized and Unrealized Gains/(Losses)			Net Purchases, Issuances and Settlements			Net Transfers In to (Out of) Level 3		Balance at December 31, 2009

Real Estate	$	1,723	$	(360	)	$	(324	)	$	-	$	1,039
Hedge Funds		4,114		243			-			-		4,357
	$	5,837	$	(117	)	$	(324	)	$	-	$	5,396

The Company does not currently expect to make a significant contribution to the Retirement Income Plan in 2010 and does not expect to receive a refund in 2010.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

The Company estimates that the future benefits payable for the Retirement Income Plan over the next ten years are as follows:

(in thousands)
2010	$	1,658
2011		1,683
2012		1,771
2013		1,867
2014		1,946
2015-2019		11,060

401(k) Plan

RPC sponsors a defined contribution 401(k) plan that is available to substantially all full-time employees with more than three months of service. This plan allows employees to make tax-deferred contributions from one to 25 percent of their annual compensation, not exceeding the permissible contribution imposed by the Internal Revenue Code. RPC matches 50 percent of each employee’s contributions that do not exceed six percent of the employee’s compensation, as defined by the plan. Employees vest in the RPC contributions after three years of service. The charges to expense for the Company’s contributions to the 401(k) plan were approximately $2,621,000 in 2009, $2,814,000 in 2008 and $2,300,000 in 2007.

Stock Incentive Plans

The Company has issued stock options and restricted stock to employees under two 10 year stock incentive plans that were approved by stockholders in 1994 and 2004. The 1994 plan expired in 2004. The Company reserved 5,062,500 shares of common stock under the 2004 Plan which expires in 2014. This plan provides for the issuance of various forms of stock incentives, including, among others, incentive and non-qualified stock options and restricted stock which are discussed in detail below. As of December 31, 2009, there were approximately 2,200,000 shares available for grants. The Company issues new shares from its authorized but unissued share pool.

The Company recognizes compensation expense for the unvested portion of awards outstanding over the remainder of the service period. The compensation cost recorded for these awards is based on their fair value at grant date less the cost of estimated forfeitures. Forfeitures are estimated at the time of grant and revised, if necessary, in subsequent periods to reflect actual forfeitures. Cash flows related to share-based payment awards to employees that result in tax benefits in excess of recognized cumulative compensation cost (excess tax benefits) are classified as financing activity in the accompanying consolidated statements of cash flows.

Pre-tax stock-based employee compensation expense was $4,440,000 in 2009 ($2,819,000 after tax), $3,732,000 in 2008 ($2,382,000 after tax) and $3,189,000 in 2007 ($2,167,000 after tax).

Stock Options

Stock options are granted at an exercise price equal to the fair market value of the Company’s common stock at the date of grant except for grants of incentive stock options to owners of greater than 10 percent of the Company’s voting securities which must be made at 110 percent of the fair market value of the Company’s common stock. Options generally vest ratably over a period of five years and expire in 10 years, except incentive stock options granted to owners of greater than 10 percent of the Company’s voting securities, which expire in five years.

The Company estimates the fair value of stock options as of the date of grant using the Black-Scholes option pricing model. The Company has not granted stock options to employees since 2003.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

Transactions involving RPC’s stock options for the year ended December 31, 2009 were as follows:

	Shares	Weighted Average Exercise Price		Weighted Average Remaining Contractual Life	Aggregate Intrinsic Value
Outstanding at January 1, 2009	1,108,022		$ 3.12	2.68 years
Granted	-		-	N/A
Exercised	(238,579)		2.89	N/A
Forfeited	(8,715)		3.76	N/A
Expired	-		-	N/A
Outstanding at December 31, 2009	860,728		$ 3.39	2.25 years	$	6,034,000
Exercisable at December 31, 2009	860,728		$ 3.39	2.25 years	$	6,034,000

The total intrinsic value of stock options exercised was approximately $1,519,000 during 2009, $6,214,000 during 2008 and $7,758,000 during 2007. Recognized excess tax benefits associated with the exercise of stock options were approximately $353,000 during 2009 and $344,000 during 2008. There were no recognized excess tax benefits associated with the exercise of stock options during 2007, since all of the stock options exercised in 2007 were incentive stock options which do not generate tax deductions for the Company.

Restricted Stock

The Company has granted employees two forms of restricted stock: time lapse restricted and performance restricted.

Time lapse restricted shares

Time lapse restricted shares vest after a stipulated number of years from the grant date, depending on the terms of the issue. Time lapse restricted shares issued in years 2003 and prior vest after ten years. Time lapse restricted shares issued subsequent to fiscal year 2003 vest in 20 percent increments annually starting with the second anniversary of the grant, over six years from the date of grant. Grantees receive dividends declared and retain voting rights for the granted shares.

Performance restricted shares

The performance restricted shares are granted, but not earned and issued until certain five-year tiered performance criteria are met. The performance criteria are predetermined market prices of RPC’s common stock. On the date the common stock appreciates to each level (determination date), 20 percent of performance shares are earned. Once earned, the performance shares vest five years from the determination date. After the determination date, the grantee will receive dividends declared and voting rights to the shares. The Company has not granted performance restricted shares since 1999.

The agreements under which the restricted stock is issued provide that shares awarded may not be sold or otherwise transferred until restrictions established under the stock plans have lapsed. Upon termination of employment from RPC or, in certain cases, termination of employment from Marine Products Corporation or Chaparral Boats, Inc., shares with restrictions must be returned to RPC.

The following is a summary of the changes in non-vested restricted shares for the year ended December 31, 2009:


	Shares			Weighted Average Grant-Date Fair Value
Non-vested shares at January 1, 2009		1,762,478		$	11.34
Granted		722,000			8.55
Vested		(453,200	)		8.87
Forfeited		(49,162	)		12.03
Non-vested shares at December 31, 2009		1,982,116		$	10.88

The fair value of restricted awards is based on the market price of the Company’s stock on the date of the grant and is amortized to compensation expense on a straight-line basis over the requisite service period. The weighted average grant date fair value of these restricted stock awards was $8.55, $9.81 and $17.61 for the years ended December 31, 2009, 2008 and 2007. The total fair value of shares vested was approximately $3,976,000 during 2009, $3,675,000 during 2008 and $4,903,000 during 2007. The tax benefit for compensation tax deductions in excess of compensation expense was credited to capital in excess of par value aggregating $1,068,000 for 2009, $502,000 for 2008 and $1,128,000 for 2007. The excess tax deductions are classified as financing activity in the accompanying consolidated statements of cash flows.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

Other Information

As of December 31, 2009, total unrecognized compensation cost related to non-vested restricted shares was approximately $18,754,000 which is expected to be recognized over a weighted-average period of 3.7 years. As of December 31, 2009, there was no unrecognized compensation cost related to non-vested stock options.

The Company received cash from options exercised of $122,000 during 2009, $347,000 during 2008 and $636,000 during 2007. These cash receipts are classified as financing activity in the accompanying consolidated statements of cash flows. The fair value of shares tendered to exercise employee stock options totaled approximately $389,000 during 2009, $1,911,000 during 2008 and $1,123,000 during 2007 and have been excluded from the consolidated statements of cash flows.

Note 11: Related Party Transactions

Related Party Transactions

Marine Products Corporation

Effective February 28, 2001, the Company spun-off the business conducted through Chaparral Boats, Inc. (“Chaparral”), RPC’s former powerboat manufacturing segment. RPC accomplished the spin-off by contributing 100 percent of the issued and outstanding stock of Chaparral to Marine Products Corporation (a Delaware corporation) (“Marine Products”), a newly formed wholly-owned subsidiary of RPC, and then distributing the common stock of Marine Products to RPC stockholders. In conjunction with the spin-off, RPC and Marine Products entered into various agreements that define the companies’ relationship.

Other

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.

Note 12: Business Segment Information

RPC’s service lines have been aggregated into two reportable oil and gas services 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. Corporate includes selected administrative costs incurred by the Company.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

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. These services include pressure pumping services, coiled tubing, snubbing, nitrogen pumping, well control consulting and firefighting, downhole tools, wireline, and fluid pumping services. These Technical Services are primarily used in the completion, production and maintenance of oil and gas wells. The principal markets for this segment include the United States, including the Gulf of Mexico, the mid-continent, southwest, Rocky Mountain and Appalachian regions, and international locations including primarily Africa, Canada, China, Latin America, the Middle East and New Zealand. 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, 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, the mid-continent and Appalachian regions, and international locations, including primarily Canada, Latin America, and the Middle East. Customers include domestic operations of major multi-national and independent oil and gas producers, and selected nationally-owned oil companies.

The accounting policies of the reportable segments are the same as those described in Note 1 to these consolidated financial statements. RPC evaluates the performance of its segments based on revenues, operating profits and return on invested capital. Gains or losses on disposition of assets are reviewed by the Company’s chief decision maker on a consolidated basis, and accordingly the Company does not report gains or losses at the segment level. Inter-segment revenues are generally recorded in segment operating results at prices that management believes approximate prices for arm’s length transactions and are not material to operating results.

Summarized financial information concerning RPC’s reportable segments for the years ended December 31, 2009, 2008 and 2007 are shown in the following table.

	Technical Services			Support Services			Corporate			Gain on disposition of assets, net		Total
(in thousands)

2009
Revenues	$	513,289		$	74,574		$	—		$	—	$	587,863
Operating profit (loss)		(20,328	)		(1,636	)		(12,231	)		1,143		(33,052	)
Capital expenditures		48,175			19,220			435			—		67,830
Depreciation and amortization		101,780			28,085			715			—		130,580
Identifiable assets		453,133			144,905			51,005			—		649,043
2008
Revenues	$	745,991		$	130,986		$	—		$	—	$	876,977
Operating profit (loss)		110,648			36,515			(9,360	)		6,367		144,170
Capital expenditures		127,054			42,238			1,026			—		170,318
Depreciation and amortization		92,738			24,798			867			—		118,403
Identifiable assets		564,708			181,991			46,762			—		793,461
2007
Revenues	$	574,723		$	115,503		$	—		$	—	$	690,226
Operating profit (loss)		116,493			29,955			(10,703	)		6,293		142,038
Capital expenditures		211,389			35,138			2,231			—		248,758
Depreciation and amortization		59,436			18,106			964			—		78,506
Identifiable assets		480,840			168,027			52,148			—		701,015

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

RPC, Inc. and Subsidiaries

Years ended December 31, 2009, 2008 and 2007

The following summarizes selected information between the United States and all international locations combined for the years ended December 31, 2009, 2008 and 2007. The revenues are presented based on the location of the use of the product or service. Assets related to international operations are less than 10 percent of RPC’s consolidated assets, and therefore are not presented.

Years ended December 31,	2009		2008		2007
(in thousands)
United States Revenues	$	543,026	$	846,202	$	649,116
International Revenues		44,837		30,775		41,110
	$	587,863	$	876,977	$	690,226

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

None.

Item 9A. Controls and Procedures

Evaluation of disclosure controls and procedures — The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in its Exchange Act reports is recorded, processed, summarized and reported within the time periods specified in the Commission’s rules and forms, and that such information is accumulated and communicated to its management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

As of the end of the period covered by this report, December 31, 2009 (the “Evaluation Date”), the Company carried out an evaluation, under the supervision and with the participation of its management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of its disclosure controls and procedures. Based upon this evaluation, the Chief Executive Officer and the Chief Financial Officer concluded that the Company’s disclosure controls and procedures were effective at a reasonable assurance level as of the Evaluation Date.

Management’s report on internal control over financial reporting — Management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Management’s report on internal control over financial reporting is included on page 29 of this report. Grant Thornton LLP, the Company’s independent registered public accounting firm, has audited the effectiveness of internal control as of December 31, 2009 and issued a report thereon which is included on page 30 of this report.

Changes in internal control over financial reporting — Management’s evaluation of changes in internal control did not identify any changes in the Company’s internal control over financial reporting that occurred during the Company’s most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Item 9B. Other Information

None.

PART III

Item 10. Directors, Executive Officers and Corporate Governance

Information concerning directors and executive officers will be included in the RPC Proxy Statement for its 2010 Annual Meeting of Stockholders, in the section titled “Election of Directors.” This information is incorporated herein by reference. Information about executive officers is contained on page 13 of this document.

Audit Committee and Audit Committee Financial Expert

Information concerning the Audit Committee of the Company and the Audit Committee Financial Expert(s) will be included in the RPC Proxy Statement for its 2010 Annual Meeting of Stockholders, in the section titled “Corporate Governance and Board of Directors, Committees and Meetings – Audit Committee.” This information is incorporated herein by reference.

Code of Ethics

RPC, Inc. has a Code of Business Conduct that applies to all employees. In addition, the Company has a Code of Business Conduct and Ethics for Directors and Executive Officers and Related Party Transaction Policy. Both of these documents are available on the Company’s website at www.rpc.net. Copies are available at no charge by writing to Attention: Human Resources, RPC Inc., 2801 Buford Highway, Suite 520, N.E., Atlanta, GA 30329.

RPC, Inc. intends to satisfy the disclosure requirement under Item 10 of Form 8-K regarding an amendment to, or waiver from, a provision of its code that relates to any elements of the code of ethics definition enumerated in SEC rules by posting such information on its internet website, the address of which is provided above.

Section 16(a) Beneficial Ownership Reporting Compliance

Information regarding compliance with Section 16(a) of the Exchange Act will be included under “Section 16(a) Beneficial Ownership Reporting Compliance” in the Company’s Proxy Statement for its 2010 Annual Meeting of Stockholders, which is incorporated herein by reference.

Item 11. Executive Compensation

Information concerning director and executive compensation will be included in the RPC Proxy Statement for its 2010 Annual Meeting of Stockholders, in the sections titled “Compensation Committee Interlocks and Insider Participation,” “Director Compensation,” “Compensation Discussion and Analysis,” “Compensation Committee Report” and “Executive Compensation.” This information is incorporated herein by reference.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Information concerning security ownership will be included in the RPC Proxy Statement for its 2010 Annual Meeting of Stockholders, in the sections “Capital Stock” and “Election of Directors.” This information is incorporated herein by reference.

Securities Authorized for Issuance Under Equity Compensation Plans

The following table sets forth certain information regarding equity compensation plans as of December 31, 2009.

Plan Category	(A) Number of Securities To Be Issued Upon Exercise of Outstanding Options, Warrants and Rights		(B) Weighted Average Exercise Price of Outstanding Options, Warrants and Rights		(C) Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (Excluding Securities Reflected in Column (A))
Equity compensation plans approved by securityholders		860,728	$	3.39		2,226,824	(1)
Equity compensation plans not approved by securityholders		-		-		-
Total		860,728	$	3.39		2,226,824

(1)	All of the securities can be issued in the form of restricted stock or other stock awards.

See Note 10 to the Consolidated Financial Statements for information regarding the material terms of the equity compensation plans.

Item 13. Certain Relationships and Related Party Transactions and Director Independence

Information concerning certain relationships and related party transactions will be included in the RPC Proxy Statement for its 2010 Annual Meeting of Stockholders, in the sections titled, “Certain Relationships and Related Party Transactions.” Information regarding director independence will be included in the RPC Proxy Statement for its 2010 Annual Meeting of Stockholders in the section titled “Director Independence and NYSE Requirements.” This information is incorporated herein by reference.

Item 14. Principal Accounting Fees and Services

Information regarding principal accountant fees and services will be included in the section titled “Independent Registered Public Accountants” in the RPC Proxy Statement for its 2010 Annual Meeting of Stockholders. This information is incorporated herein by reference.

PART IV

Item 15. Exhibits and Financial Statement Schedules

Consolidated Financial Statements, Financial Statement Schedule and Exhibits

1.	Consolidated financial statements listed in the accompanying Index to Consolidated Financial Statements and Schedule are filed as part of this report.

2.	The financial statement schedule listed in the accompanying Index to Consolidated Financial Statements and Schedule is filed as part of this report.

3.	Exhibits listed in the accompanying Index to Exhibits are filed as part of this report. The following such exhibits are management contracts or compensatory plans or arrangements:

	10.1	2004 Stock Incentive Plan (incorporated herein by reference to Appendix B to the Registrant’s definitive Proxy Statement filed on March 24, 2004).

	10.6	Form of stock option grant agreement (incorporated herein by reference to Exhibit 10.1 to Form 10-Q filed on November 2, 2004).

	10.7	Form of time lapse restricted stock grant agreement (incorporated herein by reference to Exhibit 10.2 to Form 10-Q filed on November 2, 2004).

	10.8	Form of performance restricted stock grant agreement (incorporated herein by reference to Exhibit 10.3 to Form 10-Q filed on November 2, 2004).

	10.9	Supplemental Retirement Plan (incorporated herein by reference to Exhibit 10.11 to the Form 10-K filed on March 16, 2005).

	10.10	First Amendment to 1994 Employee Stock Incentive Plan and 2004 Stock Incentive Plan (incorporated herein by reference to Exhibit 10.14 to the Form 10-K filed on March 2, 2007).

	10.11	Performance-Based Incentive Cash Compensation Plan (incorporated by reference to Exhibit 10.1 to the Form 8-K filed April 28, 2006).

	10.12	Summary of “At-Will” of Compensation Arrangements with Executive Officers as of February 28, 2008 (incorporated by reference to Exhibit 10.16 to the Form 10-K filed on March 4, 2008).

	10.13	Summary of Compensation Arrangements with Non-Employee Directors as of February 28, 2008 (incorporated by reference to Exhibit 10.17 to the Form 10-K filed on March 4, 2008).

	10.16	Summary of “At-Will” of Compensation Arrangements with Executive Officers as of February 28, 2009 (incorporated by reference to Exhibit 10.18 to the Form 10-K filed on March 5, 2009).

	10.17	Summary of Compensation Arrangements with Executive Officers.

Exhibits (inclusive of item 3 above):

Exhibit Number		Description
3.1A		Restated certificate of incorporation of RPC, Inc. (incorporated herein by reference to exhibit 3.1 to the Annual Report on Form 10-K for the fiscal year ended December 31, 1999).
3.1B		Certificate of Amendment of Certificate of Incorporation of RPC, Inc. (incorporated by reference to Exhibit 3.1(B) to the Quarterly Report on Form 10-Q filed May 8, 2006).
3.2		Bylaws of RPC, Inc. (incorporated herein by reference to Exhibit 3.1 to the Form 8-K filed on October 25, 2007).
4		Form of Stock Certificate (incorporated herein by reference to the Annual Report on Form 10-K for the fiscal year ended December 31, 1998).
10.1		2004 Stock Incentive Plan (incorporated herein by reference to Appendix B to the Registrant’s definitive Proxy Statement filed on March 24, 2004).
10.2		Agreement Regarding Distribution and Plan of Reorganization, dated February 12, 2001, by and between RPC, Inc. and Marine Products Corporation (incorporated herein by reference to Exhibit 10.2 to the Form 10-K filed on February 13, 2001).
10.3		Employee Benefits Agreement dated February 12, 2001, by and between RPC, Inc., Chaparral Boats, Inc. and Marine Products Corporation (incorporated herein by reference to Exhibit 10.3 to the Form 10-K filed on February 13, 2001).
10.4		Transition Support Services Agreement dated February 12, 2001 by and between RPC, Inc. and Marine Products Corporation (incorporated herein by reference to Exhibit 10.4 to the Form 10-K filed on February 13, 2001).
10.5		Tax Sharing Agreement dated February 12, 2001, by and between RPC, Inc. and Marine Products Corporation (incorporated herein by reference to Exhibit 10.5 to the Form 10-K filed on February 13, 2001).
10.6		Form of stock option grant agreement (incorporated herein by reference to Exhibit 10.1 to the Form 10-Q filed on November 2, 2004).
10.7		Form of time lapse restricted stock grant agreement (incorporated herein by reference to Exhibit 10.2 to the Form 10-Q filed on November 2, 2004).
10.8		Form of performance restricted stock grant agreement (incorporated herein by reference to Exhibit 10.3 to the Form 10-Q filed on November 2, 2004).
10.9		Supplemental Retirement Plan (incorporated herein by reference to Exhibit 10.11 to the Form 10-K filed on March 16, 2005).
10.10		First Amendment to 1994 Employee Stock Incentive Plan and 2004 Stock Incentive Plan (incorporated herein by reference to Exhibit 10.14 to the Form 10-K filed on March 2, 2007).
10.11		Performance-Based Incentive Cash Compensation Plan (incorporated by reference to Exhibit 10.1 to the Form 8-K filed April 28, 2006).
10.12		Summary of “At-Will” of Compensation Arrangements with Executive Officers as of February 28, 2008 (incorporated by reference to Exhibit 10.16 to the Form 10-K filed on March 4, 2008).
10.13		Summary of Compensation Arrangements with Non-Employee Directors as of February 28, 2008 (incorporated by reference to Exhibit 10.17 to the Form 10-K filed on March 4, 2008).
10.14		Revolving Credit Agreement dated September 8, 2006 between RPC, Banc of America, N.A., SunTrust Bank and certain other Lenders party thereto (incorporated by reference to Exhibit 99.1 to the Form 8-K dated September 8, 2006).
10.15		Commitment Increase Amendment to Revolving Credit Agreement dated as of June 9, 2008, by and among the Company, the several banks and other financial institutions from time to time party thereto and SunTrust Bank, in its capacity as Administrative Agent (incorporated herein by reference to Exhibit 99.1 to the Company’s Current Report on Form 8-K dated June 9, 2008).
10.16		Summary of “At-Will” of Compensation Arrangements with Executive Officers as of February 28, 2009 (incorporated herein by reference to Exhibit 10.18 to the Form 10-K filed on March 5, 2009).
10.17		Summary of Compensation Arrangements with Executive Officers.
10.18		Second Amendment to Revolving Credit Agreement dated as of September 2, 2009 by and among the Company, the several banks and other financial institutions from time to time party thereto and SunTrust Bank, in its capacity as administrative agent (incorporated herein by reference to Exhibit 99.1 to the Company’s Current Report on Form 8-K dated September 2, 2009).
21		Subsidiaries of RPC (incorporated herein by reference to Exhibit 21 to the Form 10-K filed on March 4, 2008)
23		Consent of Grant Thornton LLP
24		Powers of Attorney for Directors
31.1		Section 302 certification for Chief Executive Officer
31.2		Section 302 certification for Chief Financial Officer
32.1		Section 906 certifications for Chief Executive Officer and Chief Financial Officer

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

RPC, Inc.

/s/ Richard A. Hubbell

Richard A. Hubbell

President and Chief Executive Officer

(Principal Executive Officer)

March 3, 2010

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

Name	Title	Date
/s/ Richard A. Hubbell
Richard A. Hubbell	President and Chief Executive Officer (Principal Executive Officer)	March 3, 2010
/s/ Ben M. Palmer
Ben M. Palmer	Chief Financial Officer (Principal Financial and Accounting Officer)	March 3, 2010

The Directors of RPC (listed below) executed a power of attorney, appointing Richard A. Hubbell their attorney-in-fact, empowering him to sign this report on their behalf.

R. Randall Rollins, Director
Wilton Looney, Director
Gary W. Rollins, Director
Henry B. Tippie, Director
James B. Williams, Director
James A. Lane, Jr., Director
Linda H. Graham, Director Bill J. Dismuke, Director Larry L. Prince, Director

/s/ Richard A. Hubbell

Richard A. Hubbell

Director and as Attorney-in-fact

March 3, 2010

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS, REPORTS AND SCHEDULE

The following documents are filed as part of this report.

FINANCIAL STATEMENTS AND REPORTS	PAGE

Management’s Report on Internal Control Over Financial Reporting	29

Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting	30

Report of Independent Registered Public Accounting Firm on Consolidated Financial Statements	31

Consolidated Balance Sheets as of December 31, 2009 and 2008	32

Consolidated Statements of Operations for the three years ended December 31, 2009	33

Consolidated Statements of Stockholders’ Equity for the three years ended December 31, 2009	34

Consolidated Statements of Cash Flows for the three years ended December 31, 2009	35

Notes to Consolidated Financial Statements	36 - 58

SCHEDULE
Schedule II — Valuation and Qualifying Accounts	65

Schedules not listed above have been omitted because they are not applicable or the required information is included in the consolidated financial statements or notes thereto.

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

	For the years ended December 31, 2009, 2008 and 2007
(in thousands)	Balance at Beginning of Period		Charged to Costs and Expenses			Net (Deductions) Recoveries				Balance at End of Period
Year ended December 31, 2009
Allowance for doubtful accounts	$	6,199	$	660		$	(3,649	)	(1)	$	3,210
Deferred tax asset valuation allowance	$	1,454	$	96		$	—		(2)	$	1,550
Year ended December 31, 2008
Allowance for doubtful accounts	$	5,217	$	(84	)	$	1,066		(1)	$	6,199
Deferred tax asset valuation allowance	$	1,503	$	—		$	(49	)	(2)	$	1,454
Year ended December 31, 2007
Allowance for doubtful accounts	$	4,904	$	3,119		$	(2,806	)	(1)	$	5,217
Deferred tax asset valuation allowance	$	1,342	$	161		$	0		(2)	$	1,503

(1)	Deductions in the allowance for doubtful accounts principally reflect the write-off of previously reserved accounts net of recoveries.

(2)

The valuation allowance for deferred tax assets is increased or decreased each year to reflect the state net operating losses that management believes will be utilized before they expire. In 2009, the valuation allowance for deferred tax assets was increased by $96. In 2008, the valuation allowance for deferred tax assets was decreased by $49. In 2007 the valuation allowance for deferred tax assets was increased by $161.

SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)

Quarters ended	March 31		June 30			September 30			December 31
(in thousands except per share data)
2009
Revenues	$	176,271	$	127,018		$	132,159		$	152,415
Net (loss) income	$	4,466	$	(11,624	)	$	(10,385	)	$	(5,202	)
Net (loss) income per share — basic:(a)	$	0.05	$	(0.12	)	$	(0.11	)	$	(0.05	)
Net (loss) income per share — diluted:(a)	$	0.05	$	(0.12	)	$	(0.11	)	$	(0.05	)
2008
Revenues	$	197,227	$	214,689		$	237,217		$	227,844
Net income	$	14,757	$	22,458		$	25,780		$	20,408
Net income per share — basic:(a)	$	0.15	$	0.23		$	0.27		$	0.21
Net income per share — diluted:(a)	$	0.15	$	0.23		$	0.26		$	0.21

(a)	The sum of the (loss) income per share for the four quarters may differ from annual amounts due to the required method of computing the weighted average shares in interim periods.