RPC, Inc. (RES, NYSE)
Industry: Oil & Gas Equipment & Services
Annual report, fiscal year 2016


## POSITIVE TRACTION

VRPC
An Oil & Gas Services Company




RPC, INC. is an oil and gas services company that provides a broad range of specialized oilfield services and equipment to independent and major oilfield companies engaged in the exploration, production and development of oil and gas properties throughout the United States and in selected international markets. RPC is headquartered in Atlanta, Georgia, and its common shares are traded on the New York Stock Exchange under the ticker symbol RES. Visit our corporate website at www.rpc.net.

FINANCIAL HIGHLIGHTS.....01
LETTER TO STOCKHOLDERS.....02
SERVICE LINES.....04
INCREASING SERVICE INTENSITY DRIVES STRATEGY AND RESULTS.....06
FORM 10K.....07
CORPORATE INFORMATION.....Inside Back Cover
ON THE FRONT COVER: RPC's pressure pumping service performs a fracturing job.



## FINANCIAL HIGHLIGHTS

REVENUES
($ in thousands)

(LOSS)
PER SHARE
DILUTED
EARNINGS
PER SHARE

RETURN ON
INVESTED
CAPITAL \( ^{*} \) 







*Net cash provided by operating activities divided by average invested capital (stockholders' equity + notes payable to banks + other long-term liabilities)










## DEAR STOCKHOLDERS,

The oilfield downturn which began late in 2014 continued for the first two quarters of 2016, with the U.S. domestic rig count briefly falling to a historical low. The prices of oil and natural gas also fell to cyclical lows during the year. Our customers reduced their drilling and completion activities as the industry collapsed, and the oversupply of oilfield service capacity further depressed pricing for our services. The operating environment characterized by low pricing and activity, coupled with the higher costs associated with increased service intensity, created unsustainable economic for our industry. In 2016 these unsustainable economic characteristics forced a number of our peers to curtail their operations, sell their businesses or seek bankruptcy protection. During this time RPC focused on maintaining our equipment and service capacity to prepare for the eventual upcycle. During the third and fourth quarters of 2016, oil prices rose, approached $50 per barrel, industry activity increased and our financial results began to improve as well. As 2017 begins, we find ourselves in a healthier operating environment and believe the actions we took during the downturn will benefit us this year.

RPC’s 2016 revenues decreased by 42.3 percent to $729.0 million compared to $1.3 billion in 2015. This significant revenue decrease was caused by continued weakness in customer drilling and completion activities and declines in the pricing we received for our services. These negative conditions were partially offset by continued increases in completion service intensity within RPC’s pressure pumping service line. Cost of revenues was $607.9 million in 2016, a decrease of 38.4 percent compared to $986.1 million in 2015. These costs decreased due to lower activity levels as well as price reductions from our suppliers and lower employment expenses. Cost of revenues as a percentage of revenues increased significantly from 78.0 percent in 2015 to 83.4 percent in 2016 due to lower pricing for our services and cost leverage inefficiencies resulting from lower activity levels, despite significant headcount reductions during the year.

Selling, general and administrative expenses decreased to $150.7 million in 2016, or 20.7 percent of revenues, compared to $156.6 million, or 12.4 percent of revenues, in 2015, and $197.1 million, or 8.4 percent of revenues, in 2014. These expenses decreased by 3.8 percent compared to the prior year due to declines in expenses that vary with activity levels. Depreciation and amortization expenses were $217.3 million in 2016, a decrease of $53.7 million compared to $271.0 million in 2015. Depreciation and amortization decreased principally because of lower capital expenditures during 2015 and 2016 compared to the last several years.

## Our customers, suppliers and peers, as well as the investment community, have recognized RPC’s ability to manage our business through the deepest downturn in history.

As the oilfield industry downturn deepened during the first six months of 2016, RPC incurred an operating loss of $238.9 million, significantly higher than the operating loss of $156.3 million incurred in 2015. Interest expense decreased from $2.0 million in 2015 to $681 thousand in 2016. Interest expense in 2016 consisted principally of fees associated with our credit facility, since we did not draw on the facility during the year. During 2015, we were able to pay down the balance on our credit facility through a combination of working capital management, headcount reduction and other expense control measures.

RPC’s net loss for 2016 was $141.2 million, compared to a net loss of $99.6 million in 2015. RPC’s net loss per share was $0.66 in 2016, compared to a net loss per share of $0.47 in 2015. RPC’s earnings before interest, taxes, depreciation and amortization (EBITDA) were negative $21.9 million in 2016, a significant decrease compared to positive EBITDA of $119.9 million in 2015.

The U.S. domestic drilling rig count, a traditional indicator of our industry’s activity levels, declined for a second year during 2016. The average rig count in 2016 was 509, a 48.2 percent decrease compared to 2015. For several weeks in May 2016, there were only 404 drilling rigs in operation in the U.S. domestic oilfield, the lowest recorded rig count in U.S. oilfield history. The average unconventional rig count decreased by 46.7 percent, from 843 in 2015 to 449 in 2016. Unconventional drilling as a percentage of total drilling has climbed steadily over the past few years, and early in 2017, reached 90 percent of total drilling. In 2016 there were 11,874 oil and gas wells drilled in the U.S. land market, a decrease of 9,307 wells, or 43.9 percent, compared to 2015.

The price of natural gas declined slightly during 2016 to an average price of $2.52 per Mcf, a 2.3 percent decrease compared to the average price of $2.58 per Mcf in 2015. The average price of benchmark natural gas liquids was $0.48 per gallon in 2016, a slight increase of 4.3 percent compared to $0.46 per gallon in 2015. While these commodities stabilized during 2016, their prices remained too low to encourage our customers to conduct drilling and production activities directed toward natural gas and natural gas liquids. Furthermore, the production of natural gas and liquids from oil-directed wells remains high, further discouraging increased drilling for natural gas-directed wells in the U.S. domestic market.



The average price of oil during 2016 was $43.49 per barrel, a decrease of 10.8 percent compared to an average price of $48.77 in 2015. This decline was caused by a number of factors, including the actions of the OPEC cartel in November 2014, continued high global oil production offset by weak global demand growth, the strength of the U.S. dollar and historically high storage levels. Toward the end of 2016, however, overall macroeconomic factors improved, and the price of oil increased during the fourth quarter of 2016 by 9.6 percent compared to the third quarter.

One of our strategic business responses to the severe and protracted decline in our industry was to further curtail capital expenditures. During 2016 we invested only $33.9 million primarily towards capitalized maintenance of our existing equipment fleet, the lowest annual capital expenditure amount in more than 10 years. Cash provided by operating activities in 2016 was $101.7 million, a decrease of $372.1 million compared to 2015. Although sequentially lower than in 2015, RPC recorded a favorable change in working capital of $73.5 million during 2016, resulting from lower business activity levels and augmented by our diligent management of inventories and accounts receivable collection.

As an additional measure to preserve our capital, we continued the suspension of our regular quarterly dividend payments during 2016. However, the Board declared a $0.05 per share dividend in October, which continued a 20-year history of annual dividend payments. We intend to resume quarterly dividend payments, but the timing of future dividend payments will depend on RPC's financial results and market conditions, factors which we continue to monitor.

As the oilfield downturn entered its second year and deepened beyond most industry participants' expectations, many of our competitors closed operational locations and cannibalized their equipment, effectively ceasing to function as going concerns. In contrast to many of our peers, we perceived an opportunity to use our financial strength to preserve our service capabilities, so that we would be prepared to participate in a meaningful way in the eventual industry recovery. We started to benefit from this strategy during the third quarter of 2016, and we believe that we are better prepared for higher industry activity levels, profitability and much improved financial returns as 2017 progresses.

As 2017 begins, we are pleased to see many signs of an improving industry environment. The most recent U.S. domestic rig count was almost 15 percent higher than the rig count at the end of 2016 and significantly higher than the historical low rig count recorded in the second quarter of 2016. The price of oil was approximately 80 percent higher, and the price of natural gas was approximately 77 percent higher, than the low prices recorded for these commodities in 2016. Our customers, suppliers and peers, as well as the investment community, have recognized RPC’s ability to manage our business through the deepest downturn in history. As completion services require more equipment, logistical capability and well-trained personnel, our company is poised to gain traction in an improving market.

We appreciate the support of our employees, suppliers and stockholders during the downturn of the past couple of years and look forward to participating with everyone in the improving industry environment.

Sincerely,



R. Randall Rollins
Chairman of the Board



Richard A. Hubbell
President and Chief Executive Officer






## PRESSURE PUMPING

Visit www.cuddenergyservices.com

RPC’s largest service line is pressure pumping, which accounted for approximately 46 percent of RPC’s 2016 revenues. Pressure pumping is a stimulation service that involves fracturing or acidizing a formation to initiate or stimulate production in new and existing customer wells, either at the completion of drilling or later in the well’s life cycle. It is especially useful in unconventional completion activities, where exposing additional surface area in a formation is critical to enhanced flow of hydrocarbons from the formation. Because of the growth of shale-related production activities, our customers’ need for high-capacity, high-quality pressure pumping services has grown tremendously.

This service line has received the majority of our capital investments and is responsible for a significant amount of our growth. Pressure pumping services involve using complex, truck-mounted equipment, so the mobility of this equipment permits our services to be performed in various geographic areas. RPC provides these services to customers in a number of U.S. domestic oil and gas producing regions focused in unconventional basins.

## COILED TUBING

Visit www.cuddenergyservices.com

Coiled tubing is a continuous reel of steel tubing that is unwound, straightened and inserted into a well to perform a variety of services in diverse environments. Coiled tubing is mobile, and because of its versatility can be tripped in and out of a well more quickly than conventional tubing. In many cases it enables the well to continue producing during well-servicing operations. RPC was a pioneer in coiled tubing, and today we see renewed interest in this market due to the unique requirements of unconventional wells and the enhanced capabilities of larger diameter coiled tubing strings for use in these completion activities. Coiled tubing accounted for approximately 10 percent of 2016 revenues.



ENERGY SERVICES

## DOWNHOLE TOOLS

Visit www.thrutubing.com



RPC’s downhole tools service line is dedicated to the coiled tubing and snubbing industry, specializing in working downhole tools under pressure during various fishing and drilling operations. This service line accounted for approximately 23 percent of RPC’s revenues in 2016. Our downhole tools service line engineering department has developed a complete line of downhole equipment, some proprietary in nature. This service line continues to lead its segment of the industry with the development of several new applications. Downhole situations are unpredictable, so determining the best method for solving downhole problems requires visualization skills and the ability to apply the best engineering solution. Our engineering staff understands the mechanical and fluid parameters of any downhole tool assignment. Because our services are especially suited for unconventional drilling and completion activities, the service line has experienced significant growth over the past several years. In addition to our domestic success, we now have regular opportunities in several international markets.

## RENTAL TOOLS

Visit www.pattersonservices.com



The rental tools service line is the largest part of our support services segment and accounted for approximately 3 percent of RPC revenues in 2016. This service line rents equipment to customers for use in both onshore and offshore oil and gas well drilling, as well as completion and workover activities. Usually, operators and drilling contractors find it more economical to supplement their tool and tubular inventories with rental items instead of owning a complete collection of tools. Our facilities are located to serve major staging points for oil and gas activities throughout the Gulf Coast, Mid-Continent and Rocky Mountain regions for use in both onshore and offshore oil and gas well drilling, completion and workover activities. Our rental tools service line has some of the highest exposure to U.S. domestic oil production of any of our service lines due to the strategic placement of our facilities.






## SNUBBING-HYDRAULIC WORKOVER

Visit www.cuddenergyservices.com

Snubbing-hydraulic workover has been an important service line due to its specialization. This service line accounted for approximately 3 percent of our 2016 revenues. Snubbing-hydraulic workover is a well intervention service that uses a portable, hydraulic workover rig and crew to repair damaged casing, production tubing and downhole production equipment in a high-pressure environment and even to replace downhole equipment while maintaining pressure on the well. Snubbing-hydraulic workover requires significant experience and knowledge to perform this service safely and efficiently; therefore, this service is a small, specialized segment of the oil and gas industry. Hydraulic workover is increasingly used in unconventional completions which have extremely long lateral wellbores that coiled tubing cannot effectively service.

## OILFIELD PIPE
INSPECTION SERVICES,
MANAGEMENT AND STORAGE

Visit www.pattersontubular.com

Our 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 near the Gulf Coast are equipped with large-capacity cranes, specially designed forklifts and a computerized inventory system to serve a variety of storage and handling services for both oilfield and non-oilfield customers. Pipe inspection services accounted for less than 3 percent of 2016 revenues.



ENERGY SERVICES

## NITROGEN

Visit www.cuddenergyservices.com



ENERGY SERVICES

Nitrogen is a safe, noncombustible and noncorrosive substance and has a variety of oilfield uses. It is used to complement several of our other service lines, including coiled tubing and snubbing and pressure pumping. There are a number of uses for nitrogen, an inert, noncombustible 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.

Nitrogen can also be used to create a fire-retardant environment in hazardous blowout situations and as a fracturing medium for our fracturing service line. Specialized equipment is required to deliver nitrogen safely and effectively to the well site. Nitrogen accounted for approximately 5 percent of RPC’s revenues in 2016.

## WELL CONTROL

Visit www.cudwellcontrol.com



Well control specializes in responding to and controlling oil and gas well emergencies, including blowouts and well fires domestically and internationally. It is a service line we are known for in the industry. The Company’s professional firefighting staff has many years of aggregate industry experience in responding to well fires and blowouts, and the successful performance of this service often leads to additional service opportunities. We perform these services all over the world and on short notice. In the past few years we have performed well control work in most oil-producing regions around the world. While well control accounted for less than 1 percent of RPC’s 2016 revenues, it remains an important component of our service offerings.






# INCREASING SERVICE INTENSITY DRIVES STRATEGY AND RESULTS

A prominent feature of the oilfield over the past several years is continuing increases in well completion service intensity. Completion service intensity has increased throughout the recent industry downturn, and the catalysts driving this trend continue. We project that service intensity will continue to increase at an even greater rate in the coming years than it has in the past.

Horizontal and directional drilling, which recently reached 90 percent of total U.S. domestic activity, allow our customers to create a wellbore that has much greater exposure to the hydrocarbon-bearing formation. In areas like the Permian Basin, there are many layers of such formations, which increase the opportunity for high-production completions. The drilling rigs in operation today are able to drill longer well laterals, and more efficiently, than in the past.

A longer wellbore logically requires more fracturing stages. In addition, oil well owners and operators have determined that increased proppant volumes for each fracturing stage yield higher well production, especially when using several new diagnostic technologies which allow a customer to discern the specific locations in a wellbore with the best concentrations of hydrocarbons. Industry analysts estimate that the average number of fracturing stages per well in the United States has increased by 70 percent between the beginning of 2013 and the end of 2016, and that the total average amount of proppant per well has increased by more than 150 percent.

These unprecedented trends benefit RPC’s operational metrics and financial results over the long term, and will continue to impact our operational execution, longer-term strategies and ability to create shareholder value. Three of our service lines which comprised almost 80 percent of our 2016 revenues—pressure pumping, downhole tools and motors, and coiled tubing—directly benefit from these trends. The longer a job takes, the more time a pressure pumping fleet remains on the job site, and during its time on site, pumps an even greater amount of proppant. Our downhole tools and motors service line provides downhole completion products and services that include ultra-long reach milling capabilities. In addition, this service line uses proprietary perforation systems that complete multiple perforations during a single entrance into the wellbore, which saves time and money. Coiled tubing has evolved from a workover service to a completion service, because coiled tubing has the flexibility to enter a directional wellbore but the rigidity to convey tools and motors at the end of a coiled tubing string. We have developed and invested in improved string designs capable of working large-diameter coiled tubing that have proven to be more efficient and effective for customers who are completing unconventional wells.

Of the issues that the increased intensity of unconventional well completions presents to our industry, the extremely high attrition rate of our pressure pumping equipment, with specific components in particular, is the most challenging. Traditional pressure pumping equipment is designed to be intermittent-duty equipment. Because of this characteristic, and the fact that today’s completion activities are often conducted on a 24 hour per day basis, equipment attrition has created a significant challenge for the oilfield service industry. RPC first understood this more than 10 years ago when we began to work in service-intensive natural gas shale plays. Our experience during that time was the beginning of a trend that continues to grow today. We have long believed in routine maintenance programs, careful selection of components, and now more than ever, preventative, event-driven maintenance as well.

We budget for our growing maintenance levels as we manage our pricing strategies in order to generate the returns required to maintain our equipment. When market pricing fell to a level that did not allow us to generate acceptable returns, we chose to stack approximately half of our pressure pumping fleet rather than permit it to be degraded under harsh operating conditions. In this operating environment, we have continued to maintain our equipment, because we have adequate capital



resources to do so, and want to be prepared to optimize our financial returns when industry conditions improve. In a larger context, we have maintained the financial discipline to not over-extend ourselves so that we have the ability to maintain the value of our operating capacity during difficult times and take advantage of improved business fundamentals.

Our operational philosophies and capital strength allowed us to maintain this strategy during the recent downturn. We view this course as the best way to manage the inevitable deep cycles of the oilfield. We followed this strategy instead of the much riskier approach of pursuing acquisitions of financially distressed service companies that own equipment whose condition and maintenance history was uncertain at best.

We recognize the long-term impacts of increasing service intensity on our company and its business. We believe that, when properly managed, this oilfield trend can increase our revenues and profits over the long term. In order to accomplish this goal, we continue to focus on proper, well-managed equipment maintenance and the selection of continuous-duty replacement parts. We will maintain pricing discipline to preserve our ability to generate the returns that we need to re-invest in our business. Finally, we will continue to maintain a conservative capital structure both to thrive during the good times and manage through any potential deep downcycles in the oilfield.



# UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

# FORM 10-K

(Mark One)

☒ Annual report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

☐ Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the fiscal year ended December 31, 2016

Commission File No. 1-8726

RPC, INC.

Delaware
(State of Incorporation)

58-1550825
(I.R.S. Employer Identification No.)

2801 BUFORD HIGHWAY NE, 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. ☒ Yes ☐ No

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

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every interactive data file required to be submitted and posted pursuant to Rule 405 of Regulations S-T ( \( §232.405 \)  of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ☒ No ☐

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

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

Large accelerated filer ☒ Accelerated filer ☐ Non-accelerated filer ☐ Smaller reporting company ☐

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

The aggregate market value of RPC, Inc. Common Stock held by non-affiliates on June 30, 2016, the last business day of the registrant’s most recently completed second fiscal quarter, was $905,616,000 based on the closing price on the New York Stock Exchange on June 30, 2016 of $15.53 per share.

RPC, Inc. had 217,792,539 shares of Common Stock outstanding as of February 17, 2017.

Documents Incorporated by Reference

Portions of the Proxy Statement for the 2017 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 demand outlook for natural gas is favorable and that natural gas-directed drilling will increase over the long-term; our belief that oil-directed drilling will continue to represent the majority of the total drilling rig activity; our continued belief in the long-term growth opportunities for our business; our expectation to continue to focus on the development of international business opportunities in current and other international markets; our expectations regarding acquisition targets in our industry; the adequacy of our insurance coverage; the impact of lawsuits, legal proceedings and claims on our business and financial condition; our expectations regarding payment of cash dividends to common stockholders; our belief that industry factors will continue to depress natural gas directed drilling activity during the near-term; our belief that U.S. oilfield activity will continue to increase during the near term; our belief that recovering commodity prices will have moderately positive implications for our near-term activity levels; our belief that the U.S. domestic rig count will continue to recover moderately during the near term; our belief regarding potential revenue related to uncompleted wells; our expectations regarding competition in our market; our expectations regarding the return of assets to service when markets improve; our statement that we plan minimal increases in our fleet of revenue-producing equipment during 2017; our ability to maintain sufficient liquidity and a conservative capital structure; our expectations about contributions to the defined benefit pension plan in 2017; our ability to fund capital requirements in the future; the estimated amount of our capital expenditures and contractual obligations for future periods; our expectations regarding the costs of skilled labor and many of the raw materials used in providing our services; our belief that it will be difficult to increase prices for our services; estimates made with respect to our critical accounting policies; the effect of new accounting standards; and the effect of the changes in foreign exchange rates on our consolidated results of operations or financial condition.

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

## Item 1. Business

## Organization and Overview

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

RPC provides a broad range of specialized oilfield services and equipment primarily to independent and major oil and gas companies engaged in the exploration, production and development of oil and gas properties throughout the United States, including the southwest, mid-continent, Gulf of Mexico, Rocky Mountain and Appalachian regions, and in selected international markets. RPC acts as a holding company for its operating units: Cudd Energy Services, Thru Tubing Solutions and Patterson Services. Selected overhead including centralized support services and regulatory compliance are classified under Corporate. RPC is further organized into Technical Services and Support Services which are its operating segments. As of December 31, 2016, RPC had approximately 2,500 employees.



## Business Segments

RPC manages its business as either services offered on the well site with equipment and personnel (Technical Services) or services and equipment offered off the well site (Support Services). The businesses under Technical Services generate revenues based on equipment, personnel operating the equipment and the materials utilized to provide the service. They are all managed, analyzed and reported based on the similarities of the operational characteristics and costs associated with providing the service. The businesses under Support Services are primarily able to generate revenues through one source, which is either a hard asset or a personnel resource. During 2016, less than one percent of RPC’s consolidated revenues were generated from offshore operations in the U.S. Gulf of Mexico. We also estimate that 70 percent of our 2016 revenues were related to drilling and production activities for oil, and 30 percent were related to drilling and production activities for natural gas.

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

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

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

## Technical Services

Pressure Pumping. Pressure pumping services, which accounted for approximately 46 percent of 2016 revenues, 54 percent of 2015 revenues and 57 percent of 2014 revenues are provided to customers throughout Texas, and the mid-continent and Rocky Mountain regions of the United States. We primarily provide these services to customers in order to enhance the initial production of hydrocarbons in formations that have low permeability. Pressure pumping services involve using complex, truck or skid-mounted equipment designed and constructed for each specific pumping service offered. The mobility of this equipment permits pressure pumping services to be performed in varying geographic areas. Principal materials utilized in the pressure pumping business include fracturing proppants, acid and bulk chemical additives. Generally, these items are available from several suppliers, and the Company utilizes more than one supplier for each item. Pressure pumping services offered include:

Fracturing — Fracturing services are performed to stimulate production of oil and natural gas by increasing the permeability of a formation. Fracturing is particularly important in shale formations, which have low permeability, and unconventional completion, because the formation containing hydrocarbons is not



concentrated in one area and requires multiple fracturing operations. The fracturing process consists of pumping fluid gel and sometimes nitrogen into a cased well at sufficient pressure to fracture the formation at desired locations and depths. Sand, ceramics, or synthetic materials, which are often coated with a material to increase their resistance to crushing, are pumped into the fracture. When the pressure is released at the surface, the fluid gel returns to the well surface, but the proppant remains in the fracture, thus keeping it open so that oil and natural gas can flow through the fracture into the production tubing and ultimately to the well surface. In some cases, fracturing is performed in formations with a high amount of carbonate rock by an acid solution pumped under pressure without a proppant or with small amounts of proppant.

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

Downhole Tools. Thru Tubing Solutions (“TTS”) accounted for approximately 23 percent of 2016 revenues, 18 percent of 2015 revenues and 15 percent of 2014 revenues. TTS provides services and proprietary downhole motors, fishing tools and other specialized downhole tools and processes to operators and service companies in drilling and production operations, including casing perforation at the completion stage of an oil or gas well. The services that TTS provides are especially suited for unconventional drilling and completion activities. TTS’ experience providing reliable tool services allows it to work in a pressurized environment with virtually any coiled tubing unit or snubbing unit.

Coiled Tubing. Coiled tubing services, which accounted for approximately 10 percent of revenues in 2016 and nine percent in 2015 and 2014, involve the injection of coiled tubing into wells to perform various applications and functions for use principally in well-servicing operations and to facilitate completion of horizontal wells. Coiled tubing is a flexible steel pipe with a diameter of less than four inches manufactured in continuous lengths of thousands of feet and wound or coiled around a large reel. It can be inserted through existing production tubing and used to perform workovers without using a larger, costlier workover rig. Principal advantages of employing coiled tubing in a workover operation include: (i) not having to "shut-in" the well during such operations, (ii) the ability to reel continuous coiled tubing in and out of a well significantly faster than conventional pipe, (iii) the ability to direct fluids into a wellbore with more precision, and (iv) enhanced access to remote or offshore fields due to the smaller size and mobility of a coiled tubing unit compared to a workover rig. Increasingly, coiled tubing units are also used to support completion activities in directional and horizontal wells. Such completion activities usually require multiple entrances in a wellbore in order to complete multiple fractures in a pressure pumping operation. A coiled tubing unit can accomplish this type of operation because its flexibility allows it to be steered in a direction other than vertical, which is necessary in this type of wellbore. At the same time, the strength of the coiled tubing string allows various types of tools or motors to be conveyed into the well effectively. The uses for coiled tubing in directional and horizontal wells have been enhanced by improved fabrication techniques and higher-diameter coiled tubing which allows coiled tubing units to be used effectively over greater distances, thus allowing them to function in more of the completion activities currently taking place in the U.S. domestic market. There are several manufacturers of flexible steel pipe used in coiled tubing services, and the Company believes that its sources of supply are adequate.

Snubbing. Snubbing (also referred to as hydraulic workover services), which accounted for approximately three percent of revenues in 2016, 2015 and 2014, involves using a hydraulic workover rig that permits an operator to repair damaged casing, production tubing and downhole production equipment in a high-pressure environment. A snubbing unit makes it possible to remove and replace downhole equipment while maintaining pressure on the well. Customers benefit because these operations can be performed without removing the pressure from the well, which stops production and can damage the formation, and because a snubbing unit can perform many applications at a lower cost than other alternatives. Because this service involves a very hazardous process that entails high risk, the snubbing segment of the oil and gas services industry is limited to a relative few operators who have the experience and knowledge required to perform such services safely and efficiently. Increasingly, snubbing units are used for unconventional completions at the outer reaches of long wellbores which cannot be serviced by coiled tubing because coiled tubing has a more limited range than drill pipe conveyed by a snubbing unit.



Nitrogen. Nitrogen accounted for approximately five percent of revenues in 2016, four percent of revenues in 2015 and three percent of revenues in 2014. There are a number of uses for nitrogen, an inert, non-combustible element, in providing services to oilfield customers and industrial users outside of the oilfield. For our oilfield customers, nitrogen can be used to clean drilling and production pipe and displace fluids in various drilling applications. Increasingly, it is used as a displacement medium to increase production in older wells in which production has depleted. It also can be used to create a fire-retardant environment in hazardous blowout situations and as a fracturing medium for our fracturing service. In addition, nitrogen can be complementary to our snubbing and coiled tubing services, because it is a non-corrosive medium and is frequently injected into a well using coiled tubing. Nitrogen is complementary to our pressure pumping service as well, because foam-based nitrogen stimulation is appropriate in certain sensitive formations in which the fluids used in fracturing or acidizing would damage a customer's well.

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

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

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

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

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

## Support Services

Rental Tools. Rental tools accounted for approximately three percent of revenues in 2016 and four percent of revenues in 2015 and 2014. The Company rents specialized equipment for use with onshore and offshore oil and gas well drilling, completion and workover activities. The drilling and subsequent operation of oil and gas wells generally require a variety of equipment. The equipment needed is in large part determined by the geological features of the production zone and the size of the well itself. As a result, operators and drilling contractors often find it more economical to supplement their tool and tubular assets with rental items instead of owning a complete set of assets. The Company’s facilities are strategically located to serve the major staging points for oil and gas activities in Texas, the Gulf of Mexico, mid-continent region, Appalachian region and the Rocky Mountains.



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

<table><tr><td>Blowout Preventors</td><td>Diverters</td></tr><tr><td>High Pressure Manifolds and Valves</td><td>Drill Pipe</td></tr><tr><td>Hevi-wate Drill Pipe</td><td>Drill Collars</td></tr><tr><td>Tubing</td><td>Handling Tools</td></tr><tr><td>Production Related Rental Tools</td><td>Coflexip® Hoses</td></tr><tr><td>Pumps</td><td>Wear Knot™ Drill Pipe</td></tr></table>

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

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

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

Refer to Note 12 in the Notes to the Consolidated Financial Statements for additional financial information on our business segments.

## Industry

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

Due to aging oilfields and lower-cost sources of oil internationally, the drilling rig count in the U.S. has declined by approximately 83 percent from its peak in 1981. However, due to continuously enhanced technology, more wells are drilled during periods of strong industry activity, and these wells are increasingly productive. For these reasons, the domestic production of natural gas rose to record levels in the third quarter of 2015, and domestic production of crude oil in the third quarter of 2015 reached its highest level since the third quarter of 1971. Due to the decline in domestic drilling and completion activities, domestic production of both natural gas and oil began to decline during the third and fourth quarters of 2015, although production continues to remain high in comparison to historical levels. Oil and gas industry activity levels have historically been volatile, experiencing multiple cycles, including six down cycle troughs between 1981 and 2016, with May 2016 marking the lowest U.S. domestic rig count in U.S. oilfield history. The rig count during the peak of the most recent cycle occurred at the end of the third quarter of 2014, and began to decline sharply during the fourth quarter of 2014. The rig count continued to decline in 2015 and 2016, until June of 2016 when it stabilized and began to increase. Early in 2017, the rig count had recovered by approximately 87 percent from the historical low set during the second quarter of 2016, but was still approximately 62 percent lower than the most recent cyclical peak in the third quarter of 2014.

The fluctuations in domestic drilling activity since the most recent peak in the third quarter of 2014 are consistent with global supply of and demand for oil, the domestic supply of and demand for natural gas, U.S. domestic storage levels of oil and natural gas, fluctuations in the value of the U.S. dollar on world currency markets, and projected near-term economic growth. During 2015 and into the first quarter of 2016, the price of oil fell by



approximately 78 percent from its most recent cyclical peak in the third quarter of 2014. From its low price in early 2016, the price of oil had risen by approximately 80 percent early in the first quarter of 2017. RPC believes that the decrease in the price of oil during this period was caused by the actions of the Organization of the Petroleum Exporting Countries (OPEC) cartel, increased supply from the domestic U.S. market, weak global demand, the strength of the U.S. dollar on global currency markets and high storage levels of oil. The precipitous decline in the price of oil that took place between the third quarter of 2014 and the second quarter of 2016 caused a significant decrease in oil-directed drilling activity. The price of natural gas fell during this time as well, declining by approximately 42 percent from the beginning of 2015 to the second quarter of 2016. Early in the first quarter of 2017, however, the price of natural gas had risen by approximately 77 percent from the low recorded in the second quarter of 2016, and was approximately 19 percent higher than its price early in 2015. Early in 2017, the price of oil was high enough to encourage increased drilling and production activity, but the price of natural gas had not reached levels that were adequate to encourage natural gas-directed drilling activity in the U.S. domestic oilfield. In addition to oil and natural gas, the price of natural gas liquids is a determinant of our customers' activity levels, since it is produced in many of the shale resource plays which also produce oil, and production of various natural gas liquids has increased to a level comparable to that of natural gas. During 2015 the average price of natural gas liquids decreased by approximately 56 percent compared to 2014, but during 2016 the average price of natural gas liquids increased by approximately six percent compared to 2015. Early in the first quarter of 2017, the price of natural gas liquids had increased by approximately 65 percent compared to the average price in 2016. The fluctuations in the prices of these commodities, and in particular, the extreme volatility in the price of oil, significantly impact RPC's financial results.

From 2001 to 2009, gas drilling rigs represented over 80 percent of the drilling rig count. In 2010, the percentage of drilling rigs drilling for natural gas began to decline, and by early in the first quarter of 2015 had fallen to approximately 18 percent of total drilling activity. In absolute terms, the natural gas drilling rig count in the third quarter of 2016 was the lowest natural gas drilling rig count ever recorded. Early in the first quarter of 2017, the natural gas drilling rig count had risen by approximately 79 percent, although it remains very low by historical standards. Although the demand for natural gas has remained stable, the price of natural gas has fallen in recent years due to increased domestic reserves, productivity of new wells, and high associated natural gas production from oil-directed wells. In spite of these unfavorable near-term dynamics, the long-term demand outlook for natural gas is still favorable because, unlike oil, foreign imports of natural gas do not compete with domestic production to a meaningful degree, and in the fourth quarter of 2015, the United States began to export natural gas for the first time. We anticipate that oil-directed drilling will continue to represent the majority of the total drilling rig count during the near term. Over the long term, we believe that natural gas-directed drilling will increase due to the lack of natural gas production from oil-directed drilling and increased natural gas demand from U.S. exports of natural gas and changes in demand due to increased use of natural gas as a transportation fuel or for other purposes. We continue to believe in the long-term growth opportunities for our business due to the continued high demand for hydrocarbons generally and the growing production of oil in the domestic U.S. market in particular. Furthermore, we note that the techniques used to extract oil and natural gas in the U.S. domestic market increasingly require the types of services that RPC provides to its customers.

Unconventional wells generate a higher demand for RPC’s services because they are difficult and costly to complete. They comprise the majority of U.S. domestic drilling and reached a historical high of approximately 90 percent of total drilling during the first quarter of 2017. Because they are drilled through a typically narrow and relatively impermeable formation such as shale, they require additional stimulation when they are completed. Also, many of these formations require high pumping rates of stimulation fluids under high pressures, which in turn require a great deal of pressure pumping horsepower on location to complete the well. Furthermore, since they are not drilled in a straight vertical direction from the Earth’s surface, they require tools and drilling mechanisms that are flexible, rather than rigid, and can be steered once they are downhole. Specifically, these types of wells require RPC’s pressure pumping and coiled tubing services, as well as our downhole tools and services.

International. RPC has historically operated in several countries outside of the United States, and international revenues accounted for approximately seven percent of RPC’s consolidated revenues in 2016, six percent in 2015 and four percent in 2014. RPC’s allocation of growth capital over the last several years have emphasized domestic rather than international expansion because of higher domestic activity levels and expected financial returns. International revenues decreased 29 percent in 2016 compared to the prior year primarily due to lower customer activity levels in Australia, Gabon, Equatorial Guinea, China and Argentina partially offset by increased activity in Bolivia. During 2016, RPC provided snubbing, well control and oilfield training services in several countries.



including Gabon and Australia. We also provided downhole motors and tools in Argentina, Canada, China and Oman, and rental tools in Equatorial Guinea. We continue to focus on the selected development of international opportunities in these and other markets, although we believe that it will continue to be less than ten percent of total revenues in 2017.

RPC provides services to its international customers through branch locations or wholly owned foreign subsidiaries. The international market is prone to political uncertainties, including the risk of civil unrest and conflicts. However, due to the significant investment requirement and complexity of international projects, customers' drilling decisions relating to such projects tend to be evaluated and monitored with a longer-term perspective with regard to oil and natural gas pricing, and therefore have the potential to be more stable than most U.S. domestic operations. Additionally, the international market is dominated by major oil companies and national oil companies which tend to have different objectives and more operating stability than the typical independent oil and gas producer in the U.S. Predicting the timing and duration of contract work is not possible. Refer to Note 12 in the Notes to Consolidated Financial Statements for further information on our international operations.

## Growth Strategies

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

RPC seeks to expand its service capabilities through a combination of internal growth, acquisitions, joint ventures and strategic alliances. Historically, we have found that we generate higher financial returns from organic growth with our services and geographical locations in which we have experience. Because of the fragmented nature of the oil and gas services industry, RPC believes a number of acquisition opportunities exist, and we frequently consider such opportunities. We have consummated relatively few acquisitions, however, due to high seller valuation expectations and the risk of integrating acquired businesses into our existing operations. As the current industry downturn continues, we believe that many financial investors who have provided capital to smaller oilfield service companies in the past several years are seeking to liquidate their investments. This development, along with continued depressed financial results in our industry, may make valuations for acquisition targets more attractive. We will continue to consider the acquisitions of existing businesses but will also continue to maintain a conservative capital structure, which may limit our ability to consummate large transactions.

RPC has a revolving credit facility which can be used to fund working capital requirements. The borrowing base for this credit facility is the lesser of $125 million or a specified percentage of eligible accounts receivable less the amount of any outstanding letters of credit. There was no outstanding balance on this credit facility as of December 31, 2016. Our capital structure is more conservative than that of many of our peers.

## Customers

Demand for RPC’s services and products depends primarily upon the number of oil and natural gas wells being drilled, the depth and drilling conditions of such wells, the number of well completions and the level of production enhancement activity worldwide. RPC’s principal customers consist of major and independent oil and natural gas producing companies. During 2016, RPC provided oilfield services to several hundred customers. Of these customers, there were no customers in 2016 and only one, Anadarko Petroleum Corporation (Anadarko) at 23 percent of revenues in 2015, that accounted for more than 10 percent of revenues.

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



## Competition

RPC operates in highly competitive areas of the oilfield services industry. We sell our products and services in highly competitive markets, and the revenues and earnings generated are affected by changes in prices for our services, fluctuations in the level of customer activity in major markets, general economic conditions and governmental regulation. RPC competes with many large and small oilfield industry competitors, including the largest integrated oilfield services companies. During the past several years, a number of small oilfield services companies as well as several of our publicly traded peers have become insolvent and either been forced to liquidate or undergo bankruptcy proceedings. During the third and fourth quarters of 2016, however, the availability of capital and high public equity valuations have allowed many insolvent companies to resume operations or continue operations as the result of a business combination. As of the first quarter of 2017, RPC has not experienced increased competition from these entities, but we assume that the financial capabilities of these competitors will increase competitive pressures in the future. Pricing for our services has been extremely competitive over the past several years due to the severe industry downturn and the oversupply of equipment and crews operating in the U.S. domestic oilfield. RPC believes that the principal competitive factors in the market areas that it serves are product availability and quality of our equipment and raw materials used to provide our services, service quality, reputation for safety and technical proficiency, and price.

The oil and gas services industry includes dominant global competitors including, among others, Halliburton Energy Services Group, a division of Halliburton Company, Baker Hughes and Schlumberger Ltd. The industry also includes a number of publicly traded peers whose operations are more similar to RPC, including Patterson-UTI Energy, Inc., Superior Energy Services, Weatherford International, Inc., Mammoth Energy Services, Inc. and Keane Group, Inc., as well as numerous smaller, locally owned competitors.

## Facilities/Equipment

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

RPC both owns and leases regional and district facilities from which its oilfield services are provided to land-based and offshore customers. RPC’s principal executive offices in Atlanta, Georgia are leased. The Company has two primary administrative buildings, one it leases in The Woodlands, Texas that includes the Company’s operations, engineering, sales and marketing headquarters, and one it owns in Houma, Louisiana that includes certain administrative functions. RPC believes that its facilities are adequate for its current operations. For additional information with respect to RPC’s lease commitments, see Note 9 of the Notes to Consolidated Financial Statements.

## Governmental Regulation

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

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

## Intellectual Property

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



## Availability of Filings

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

## Item 1A. Risk Factors

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

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

The price of oil is affected by, among other things, the potential of armed conflict in politically unstable areas such as the Middle East as well as the actions of OPEC, an oil cartel which controls slightly less than 40 percent of global oil production. OPEC’s actions have historically been unpredictable, and can contribute to the volatility of the price of oil on the world market.

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

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

At times our business has had a concentration of one or more major customers. There were no customers that accounted for more than 10 percent of the Company’s revenues in 2016 and 2014. However, one of our customers, Anadarko, accounted for approximately 23 percent of revenues in 2015 with no other customers exceeding 10 percent of revenues in 2015. In addition, there was no customer as of December 31, 2016 that accounted for more than 10 percent of accounts receivable, while Anadarko accounted for approximately 14 percent of accounts receivable as of December 31, 2015. The reliance on a large customer for a significant portion of our total revenues exposes us to the risk that the loss or reduction in revenues from this customer, which could occur unexpectedly, could have a material and disproportionate adverse impact upon our revenues and operating results.

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

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

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

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



## We may be unable to identify or complete acquisitions.

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

## Our operations are affected by adverse weather conditions.

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

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

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

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

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

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

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

Our business is significantly affected by stringent environmental laws and other regulations relating to the oil and gas industry and by changes in such laws and the level of enforcement of such laws. We are unable to predict the level of enforcement of existing laws and regulations, how such laws and regulations may be interpreted by



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

Compliance with federal and state regulations relating to hydraulic fracturing and designation of economic development zones related to natural gas-directed drilling from shale formations could increase our operating costs, cause operational delays, and could reduce or eliminate the demand for our pressure pumping services.

RPC’s pressure pumping services are the subject of continuing federal, state and local regulatory oversight. This scrutiny is prompted in part by public concern regarding the potential impact on drinking and ground water and other environmental issues arising from the growing use of hydraulic fracturing. Among these regulatory entities is the White House Council on Environmental Quality, which coordinated a review of hydraulic fracturing practices. In addition, a committee of the United States House of Representatives investigated hydraulic fracturing practices and publicized information regarding the materials used in hydraulic fracturing. The U.S. Environmental Protection Agency (EPA) has also undertaken a study of the environmental impact of hydraulic fracturing practices. In the second quarter of 2015, the EPA issued a report which concluded that hydraulic fracturing had not caused a measureable impact on drinking water sources in the U.S. While this conclusion and other conclusions from similar efforts are favorable for our industry, we are unable to predict whether future scrutiny of RPC’s pressure pumping business and any resulting regulatory change will impact our business through increased operational costs, operational delays, or a reduction in demand for hydraulic fracturing services.

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

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

## Our common stock price has been volatile.

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

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

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

RPC’s executive officers, directors and their affiliates hold directly or through indirect beneficial ownership, in the aggregate, approximately 73 percent of RPC’s outstanding shares of common stock. As a result, these stockholders effectively control the operations of RPC, including the election of directors and approval of significant corporate transactions such as acquisitions and other matters requiring stockholder approval. This concentration of



ownership could also have the effect of delaying or preventing a third party from acquiring control over the Company at a premium.

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

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

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. While these materials are generally available, supply disruptions can occur due to factors beyond our control. Such disruptions, delayed deliveries, and higher prices may limit our ability to provide services, or increase the costs of providing services, which could reduce our revenues and profits.

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

Our business requires a great deal of capital in order to maintain our equipment and increase our fleet of equipment to expand our operations, and we have access to our credit facility to fund our necessary working capital and equipment requirements. Our credit facility, as amended June 30, 2016, provides a borrowing base at the lesser of (a) $125 million or (b) the difference between (i) a specified percentage (ranging from 70% to 80%) of eligible accounts receivable less (ii) the amount of any outstanding letters of credit, and bears interest at a floating rate, which exposes us to market risks as interest rates rise. If our existing capital resources become unavailable, inadequate or unfavorable for purposes of funding our capital requirements, we would need to raise additional funds through alternative debt or equity financings to maintain our equipment and continue our growth. Such additional financing sources may not be available when we need them, or may not be available on favorable terms. If we fund our growth through the issuance of public equity, the holdings of stockholders will be diluted. If capital generated either by cash provided by operating activities or outside financing is not available or sufficient for our needs, we may be unable to maintain our equipment, expand our fleet of equipment, or take advantage of other potentially profitable business opportunities, which could reduce our future revenues and profits.

## Item 1B. Unresolved Staff Comments

None.



## Item 2. Properties

RPC owns or leases approximately 120 offices and operating facilities. The Company leases approximately 18,600 square feet of office space in Atlanta, Georgia that serves as its headquarters, a portion of which is allocated and charged to Marine Products Corporation. See “Related Party Transactions” contained in Item 7. The lease agreement on the headquarters is effective through October 2020. RPC believes its current operating facilities are suitable and adequate to meet current and reasonably anticipated future needs. Descriptions of the major facilities used in our operations are as follows:

## Owned Locations

Broussard, Louisiana — Operations, sales and equipment storage yards

Vilonia, Arkansas — Maintenance and rebuild facilities

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

Houma, Louisiana — Administrative office

Houston, Texas — Pipe storage terminal and inspection sheds

Kilgore, Texas — Operations, sales and equipment storage yards

Odessa, Texas — Operations, sales and equipment storage yards

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

Vernal, Utah — Operations, sales and equipment storage yards

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

## Leased Locations

Canton, Pennsylvania — Operations, sales and equipment storage yards

Hobbs, New Mexico — Pumping services facility

Oklahoma City, Oklahoma — Operations, sales and administrative office

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

Seminole, Oklahoma — Pumping services facility

The Woodlands, Texas — Operations, sales and administrative office

Washington, Pennsylvania — Operations, sales and equipment storage yards

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

## Item 3. Legal Proceedings

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

## Item 4. Mine Safety Disclosures

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



## Item 4A. Executive Officers of the Registrant

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

<table><tr><td>Name and Office with Registrant</td><td>Age</td><td>Date First Elected to Present Office</td></tr><tr><td>R. Randall Rollins (1)</td><td>85</td><td>1/24/84</td></tr><tr><td>Chairman of the Board</td><td></td><td></td></tr><tr><td>Richard A. Hubbell (2)</td><td>72</td><td>4/22/03</td></tr><tr><td>President and Chief Executive Officer</td><td></td><td></td></tr><tr><td>Linda H. Graham (3)</td><td>80</td><td>1/27/87</td></tr><tr><td>Vice President and Secretary</td><td></td><td></td></tr><tr><td>Ben M. Palmer (4)</td><td>56</td><td>7/8/96</td></tr><tr><td>Vice President, Chief Financial Officer and Treasurer</td><td></td><td></td></tr></table>

(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 2001. Mr. Hubbell serves on the Board of Directors of both of these companies.

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

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



## PART II

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

RPC’s common stock is listed for trading on the New York Stock Exchange under the symbol RES. As of February 17, 2017 there were 217,792,539 shares of common stock outstanding and approximately 16,600 beneficial holders of our common stock. The following table sets forth the high and low prices of RPC’s common stock and dividends paid for each quarter in the years ended December 31, 2016 and 2015:

<table><tr><td rowspan="2">Quarter</td><td colspan="4">2016</td><td colspan="4">2015</td></tr><tr><td>High</td><td>Low</td><td>Dividends</td><td>High</td><td>Low</td><td>Dividends</td><td></td><td></td></tr><tr><td>First</td><td>$ 15.51</td><td>$ 9.73</td><td>$ —</td><td>$ 14.15</td><td>$ 10.58</td><td>$ 0.105</td><td></td><td></td></tr><tr><td>Second</td><td>16.84</td><td>13.12</td><td>—</td><td>16.66</td><td>12.81</td><td>0.050</td><td></td><td></td></tr><tr><td>Third</td><td>16.92</td><td>13.50</td><td>—</td><td>13.85</td><td>8.54</td><td>—</td><td></td><td></td></tr><tr><td>Fourth</td><td>22.28</td><td>16.48</td><td>0.050</td><td>13.69</td><td>8.45</td><td>—</td><td></td><td></td></tr></table>

On July 28, 2015, the Board of Directors voted to temporarily suspend RPC’s regular quarterly cash dividend to common stockholders; however, a special year-end cash dividend of $0.05 per share was paid to common stockholders during the fourth quarter of 2016. Subject to industry conditions and RPC’s earnings, financial condition, and other relevant factors, the Company expects to resume regular quarterly cash dividends to common stockholders sometime in the future.

Issuer Purchases of Equity Securities

Shares repurchased by the Company and affiliated purchases in the fourth quarter of 2016 are outlined below.

<table><tr><td>Period</td><td>Total Number of Shares (or Units) Purchased</td><td>Average Price Paid Per Share (or Unit)</td><td>Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs</td><td>Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs (1)</td></tr><tr><td>October 1, 2016 to October 31, 2016</td><td>—</td><td>$ —</td><td>—</td><td>2,050,154</td></tr><tr><td>November 1, 2016 to November 30, 2016</td><td>1,533(2)</td><td>17.08</td><td>—</td><td>2,050,154</td></tr><tr><td>December 1, 2016 to December 31, 2016</td><td>718(2)</td><td>18.12</td><td>—</td><td>2,050,154</td></tr><tr><td>Totals</td><td>2,251</td><td>$ 17.41</td><td>—</td><td>2,050,154</td></tr></table>



## Performance Graph

The following graph shows a five-year comparison of the cumulative total stockholder return based on the performance of the stock of the Company, assuming dividend reinvestment, as compared with both a broad equity market index and an industry or peer group index. The indices included in the following graph are the Russell 1000 Index ("Russell 1000"), the Philadelphia Stock Exchange's Oil Service Index ("OSX"), and a peer group which includes companies that are considered peers of the Company (the "Peer Group"). The Company has voluntarily chosen to provide both an industry and a peer group index.

The Company was a component of the Russell 1000 during 2016. The Russell 1000 is a stock index representing large capitalization U.S. stocks with high historical growth in revenues and earnings. The components of the index had a weighted average market capitalization in 2016 of $140 billion, and a median market capitalization of $9 billion. The Russell 1000 was chosen because it represents companies with comparable market capitalizations to the Company, and because the Company is a component of the index. The OSX is a stock index of 15 companies that provide oil drilling and production services, oilfield equipment, support services and geophysical/reservoir services. The Company is not a component of the OSX, but this index was chosen because it represents a large group of companies that provide the same or similar products and services as the Company. The companies included in the Peer Group are Weatherford International, Inc., Superior Energy Services, Inc., Patterson-UTI Energy, Inc., and Halliburton Company. Patterson-UTI Energy, Inc. was not previously included in the Peer Group because it conducts exploration and production activities and contract drilling activities as well as providing pressure pumping services. However, during 2016 Patterson-UTI Energy, Inc. eliminated exploration and production activities as an operating segment and announced a significant acquisition in the pressure pumping and rental tools business. Also, Patterson-UTI Energy’s market capitalization was similar to the market capitalization of the Company as of December 31, 2016. For these reasons, the Company added Patterson-UTI Energy to the Peer Group. In addition, the Company eliminated Basic Energy Services, Inc. from the Peer Group because during the third and fourth quarters of 2016, Basic Energy Services announced that it could not fulfill its financial obligations and was entering bankruptcy proceedings. We believe that Basic Energy Services’ stock price performance during 2016 reflected the risk of bankruptcy to its shareholders rather than the financial performance of a peer of the Company. For comparison purposes, the following graph includes the Peer Group as well as a group of companies which includes Weatherford International, Inc., Basic Energy Services, Inc., Superior Energy Services, Inc. and Halliburton Company (the Former Peer Group). The companies included in the Peer Group and the Former 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:

<table><tr><td>Years Ended December 31,</td><td>2016</td><td>2015</td><td>2014</td><td>2013</td><td>2012</td></tr><tr><td colspan="6">(in thousands, except employee and per share amounts)</td></tr><tr><td>Revenues</td><td>$ 728,974</td><td>$ 1,263,840</td><td>$ 2,337,413</td><td>$ 1,861,489</td><td>$ 1,945,023</td></tr><tr><td>Cost of revenues</td><td>607,888</td><td>986,144</td><td>1,493,082</td><td>1,178,412</td><td>1,105,886</td></tr><tr><td>Selling, general and administrative expenses</td><td>150,690</td><td>156,579</td><td>197,117</td><td>183,139</td><td>174,397</td></tr><tr><td>Depreciation and amortization</td><td>217,258</td><td>270,977</td><td>230,813</td><td>213,128</td><td>214,899</td></tr><tr><td>(Gain) loss on disposition of assets, net</td><td>(7,920)</td><td>6,417</td><td>15,472</td><td>9,371</td><td>6,099</td></tr><tr><td>Operating (loss) profit</td><td>(238,942)</td><td>(156,277)</td><td>400,929</td><td>277,439</td><td>443,742</td></tr><tr><td>Interest expense</td><td>(681)</td><td>(2,032)</td><td>(1,431)</td><td>(1,822)</td><td>(1,976)</td></tr><tr><td>Interest income</td><td>467</td><td>83</td><td>19</td><td>408</td><td>28</td></tr><tr><td>Other (expense) income, net</td><td>(204)</td><td>5,185</td><td>(131)</td><td>245</td><td>825</td></tr><tr><td>(Loss) income before income taxes</td><td>(239,360)</td><td>(153,041)</td><td>399,386</td><td>276,270</td><td>442,619</td></tr><tr><td>Income tax (benefit) provision</td><td>(98,114)</td><td>(53,480)</td><td>154,193</td><td>109,375</td><td>168,183</td></tr><tr><td>Net (loss) income</td><td>$ (141,246)</td><td>$ (99,561)</td><td>$ 245,193</td><td>$ 166,895</td><td>$ 274,436</td></tr><tr><td>(Loss) earnings per share :</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Basic</td><td>$ (0.66)</td><td>$ (0.47)</td><td>$ 1.14</td><td>$ 0.77</td><td>$ 1.28</td></tr><tr><td>Diluted</td><td>$ (0.66)</td><td>$ (0.47)</td><td>$ 1.14</td><td>$ 0.77</td><td>$ 1.27</td></tr><tr><td>Dividends paid per share</td><td>$ 0.050</td><td>$ 0.155</td><td>$ 0.420</td><td>$ 0.400</td><td>$ 0.520</td></tr></table>

<table><tr><td>Operating margin percent</td><td>(32.8)%</td><td>(12.4)%</td><td>17.2%</td><td>14.9%</td><td>22.8%</td></tr><tr><td>Net cash provided by operating activities</td><td>$ 101,704</td><td>$ 473,792</td><td>$ 322,757</td><td>$ 365,624</td><td>$ 559,933</td></tr><tr><td>Net cash used for investing activities</td><td>(21,339)</td><td>(157,583)</td><td>(355,349)</td><td>(207,654)</td><td>(315,838)</td></tr><tr><td>Net cash (used for) provided by financing activities</td><td>(13,726)</td><td>(260,785)</td><td>33,664</td><td>(163,433)</td><td>(237,325)</td></tr><tr><td>Capital expenditures</td><td>$ 33,938</td><td>$ 167,426</td><td>$ 371,502</td><td>$ 201,681</td><td>$ 328,936</td></tr><tr><td>Employees at end of period</td><td>2,500</td><td>3,100</td><td>4,500</td><td>3,900</td><td>3,600</td></tr></table>

<table><tr><td colspan="7">BALANCE SHEET DATA AT END OF YEAR:</td></tr><tr><td>Accounts receivable, net</td><td>169,166</td><td>$ 232,187</td><td>$ 634,730</td><td>$ 437,132</td><td>$ 387,530</td><td></td></tr><tr><td>Working capital</td><td>377,589</td><td>384,744</td><td>612,616</td><td>436,873</td><td>403,316</td><td></td></tr><tr><td>Property, plant and equipment, net</td><td>497,986</td><td>688,335</td><td>849,383</td><td>726,307</td><td>756,326</td><td></td></tr><tr><td>Total assets</td><td>1,035,452</td><td>1,237,094</td><td>1,759,358</td><td>1,383,860</td><td>1,367,163</td><td></td></tr><tr><td>Long-term debt</td><td>—</td><td>—</td><td>224,500</td><td>53,300</td><td>107,000</td><td></td></tr><tr><td>Total stockholders&#x27; equity</td><td>$ 806,799</td><td>$ 952,281</td><td>$ 1,078,382</td><td>$ 968,702</td><td>$ 899,232</td><td></td></tr></table>



## 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 8.

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

Our key business and financial strategies are:

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

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

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

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

- To deliver equipment and services to our customers safely.

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

• To maintain and selectively 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.

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

Current industry conditions are characterized by oil prices which have risen from a low of approximately $29 per barrel in the first quarter of 2016 to approximately $53 per barrel in the first quarter of 2017. As a result of this moderate increase in the price of oil, as well as improvements in the prices of natural gas and natural gas liquids, the U.S. domestic rig count has risen from an historic low of 404 in the second quarter of 2016 to 751 early in the first quarter of 2017. We believe that the principal reason for the increase in the price of oil and the improvement in U.S. domestic oilfield activity relates to the announcement by the OPEC cartel during the fourth quarter of 2016 that it would impose production quotas on its member countries in order to support the price of oil on the world market. RPC believes that an important catalyst for an increase in world oil prices is declining production in the United



States. We believe this because the United States grew to be the world’s largest producer of oil during the second quarter of 2015, and the increase in oil production was due to the growth of oil-directed drilling in shale formations. These wells produce a large amount of oil immediately following their completion, but typically experience large production declines within two years. Following its recent peak, U.S. oil production has fallen by approximately nine percent as of the most recent reported statistic during the fourth quarter of 2016. Therefore, the declining production of these wells, and the rapid decline in drilling of new wells of this type are additional catalysts for improving industry conditions. Customer activities directed towards natural gas drilling and production have been weak for several years, with the U.S. domestic natural gas rig count during the first quarter of 2016 falling to the lowest level ever recorded. We believe that customer activities directed towards drilling for natural gas have been weak because of the high production of shale-directed natural gas wells, the high amount of natural gas production associated with oil-directed shale wells in the U.S. domestic market, and relatively constant consumption of natural gas in the United States. While natural gas-directed drilling has increased through early in the first quarter of 2017, we believe that these factors will continue to depress natural gas-directed drilling during the near term. From a low of $1.72 per Mcf during the second quarter of 2016, the price of natural gas had risen to $3.04 per Mcf early in the first quarter of 2017. In spite of this increase, we believe that the price of natural gas remains too low to encourage our customers to conduct exploration and production activities directed exclusively towards natural gas.

In 2016, the Company’s strategy of utilizing equipment in unconventional basins has continued. During 2016, we made capital expenditures totaling $33.9 million primarily for the maintenance of our existing revenue-producing equipment.

Revenues during 2016 totaled $729.0 million, a decrease of 42.3 percent compared to 2015 primarily as a result of lower industry activity levels. Cost of revenues decreased $378.3 million in 2016 compared to the prior year also due to lower activity levels. As a percentage of revenue, cost of revenues also increased due to inefficiencies resulting from lower activity levels coupled with continued low pricing for our services. Selling, general and administrative expenses as a percentage of revenues increased to 20.7 percent of revenues in 2016 compared to 12.4 percent of revenues in 2015 due to increases in bad debt expense and professional fees as well as significantly lower revenues.

Losses before income taxes were $239.4 million for 2016 compared to $153.0 million in 2015. Net loss for 2016 was $141.2 million, or $0.66 loss per share compared to net loss of $99.6 million, or $0.47 loss per share in 2015.

Cash flows from operating activities decreased to $101.7 million in 2016 compared to $473.8 million in 2015 primarily due to unfavorable changes in working capital coupled with lower earnings. As of December 31, 2016, there were no outstanding borrowings under our credit facility.

## Outlook

Drilling activity in the U.S. domestic oilfields, as measured by the rotary drilling rig count, reached a recent cyclical peak of 1,931 during the third quarter of 2014. Between the third quarter of 2014 and the second quarter of 2016, the drilling rig count fell by approximately 79 percent. During the second quarter of 2016, the U.S. domestic drilling rig count reached the lowest level ever recorded. The principal catalyst for this steep rig count decline is the decrease in the price of oil in the world markets, which began in the second quarter of 2014. The price of oil began to fall at that time due to the perceived oversupply of oil, weak global demand growth, and the strength of the U.S. dollar on world currency markets. During the second quarter of 2016, the price of oil and the U.S. domestic rig count began to increase, and increased steadily throughout the remainder of 2016 and into the beginning of the first quarter of 2017. As of the beginning of the first quarter of 2017, RPC believes that U.S. oilfield activity will continue to increase during the near term, although our long-term visibility remains limited.

The current and projected prices of oil, natural gas and natural gas liquids are important catalysts for U.S. domestic drilling activity. During the first two quarters of 2016, the prices of oil and natural gas remained at low levels that discouraged our customers from undertaking most of their potential exploration and production activities. The prices of oil and natural gas have increased during the third and fourth quarters of 2016 and into the first quarter of 2017, and we believe that the price of oil has risen to a level that provides adequate financial returns to our customers and encourages increased drilling and production activities in many domestic oil-producing basins. However, the price of natural gas has not risen to a level that encourages our customers to increase their drilling and production activities, and we remain discouraged that U.S. production of natural gas remains high in spite of historically low drilling activities. The average price of natural gas liquids during 2016 increased by approximately



six percent compared to 2015, and early in the first quarter of 2017 the price of natural gas liquids rose to levels not recorded since the fourth quarter of 2014. These commodity price trends, if they continue, have moderately positive implications for our near-term activity levels. As evidence of the impact of recovering commodity prices on our customers' activity levels, the oil-directed drilling rig count at the beginning of the first quarter of 2017 had increased by approximately 89 percent compared to the lowest oil-directed rig count recorded during the second quarter of 2016, and the natural gas-directed rig count had increased by approximately 79 percent during the same period.

The majority of the U.S. domestic rig count remains directed towards oil. At the beginning of the first quarter of 2017, approximately 80 percent of the U.S. domestic rig count was directed towards oil, consistent with the prior year. We believe that oil-directed drilling will remain the majority of domestic drilling, and that natural gas-directed drilling will remain a low percentage of U.S. domestic drilling in the near term. We believe that this relationship will continue due to relatively low prices for natural gas, high production from existing natural gas wells, and industry projections of limited increases in domestic natural gas demand during the near term.

We continue to monitor the market for our services and the competitive environment in 2017. We believe that the U.S. domestic rig count will continue to recover moderately during the near term. However, we believe that in spite of the large percentage increases in oilfield activity during the past several quarters, the pricing for our services has not yet reached a level that provides financial returns that will allow the industry to maintain its fleet of revenue-producing equipment or hire additional personnel to operate idle equipment. Furthermore, our customers during the first quarter of 2017 have thus far been very reluctant to accept increases in pricing for their services in order to compensate us for our increased costs and to allow us to generate higher financial returns. For this reason, we believe that continued near-term expansion in U.S. domestic oilfield activities will be moderate until commodity prices increase significantly. Over the long term, we believe that the steep decline in oil-directed drilling in the U.S. domestic market will reduce U.S. domestic oil production and serve as a catalyst for oil prices to increase. This belief is due to the fact that oil-directed wells drilled in shale resource plays typically exhibit high initial production soon after being completed followed by a decline in production in later years. We note that U.S. domestic oil production has declined by approximately 10 percent since its most recent peak in the third quarter of 2014. We are encouraged by the fact that drilling and completion activities continue to be highly service-intensive and require a large amount of equipment and raw materials. Furthermore, we note that some wells in the U.S. domestic market have been drilled but not completed. We believe that many of our customers have started to complete these wells, and that they provide potential revenue for RPC's completion-directed services during the near term. Finally, we are encouraged by our belief that many of our competitors have not maintained their equipment to a level that allows them to provide reliable, consistent services to their customers. During 2015 and the first three quarters of 2016, we responded to the significant declines in industry activity levels and pricing for our services by reducing costs and employee headcount and closed selected operational locations. During the fourth quarter of 2016 and the first quarter of 2017, however, we have started recruiting and hiring operational personnel to respond to increased industry activity levels.

We note in the current competitive environment that many of our smaller competitors have high levels of debt, higher cost structures, and less-developed logistical capabilities than RPC. During 2015 and through the first three quarters of 2016, a number of smaller competitors ceased operations and sold their businesses or liquidated their assets. During 2016, several of our peers filed for bankruptcy protection. While these developments place us in a more favorable competitive position, they are offset by the fact that the capital markets have recently provided capital to allow several of our competitors to emerge from bankruptcy and several other private equity-funded companies to complete initial public offerings of their common stock. In the fourth quarter of 2015 we initiated a process whereby we more closely scrutinize the maintenance status of our currently idled revenue-producing assets. Through this process, we are attempting to ensure that our idle equipment is prepared to return to service as soon as market conditions encourage us to do so. We believe that this process will allow RPC to return our idle revenue-producing equipment to service quickly and at minimal cost as market conditions improve. In this environment RPC also monitors the financial stability of our customers, due to the fact that many of them have also financed their operations with a large amount of debt, and this type of financing is less available than in previous years, although we also note that many of our customers have recently raised equity to stabilize their capital structures and expand their operations. RPC plans minimal increases in our fleet of revenue-producing equipment during 2017. Our consistent response to the industry's potential uncertainty is to maintain sufficient liquidity and a conservative capital structure and monitor our discretionary spending. We intend to maintain a financial structure which includes little or no debt during the near term.



## Results of Operations

<table><tr><td>Years Ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>(in thousands except per share amounts and industry data)</td><td></td><td></td><td></td></tr><tr><td>Consolidated revenues</td><td>$ 728,974</td><td>$ 1,263,840</td><td>$ 2,337,413</td></tr><tr><td>Revenues by business segment:</td><td></td><td></td><td></td></tr><tr><td>Technical</td><td>$ 679,654</td><td>$ 1,175,293</td><td>$ 2,180,457</td></tr><tr><td>Support</td><td>49,320</td><td>88,547</td><td>156,956</td></tr><tr><td>Consolidated operating (loss) profit</td><td>$ (238,942)</td><td>$ (156,277)</td><td>$ 400,929</td></tr><tr><td>Operating (loss) profit by business segment:</td><td></td><td></td><td></td></tr><tr><td>Technical</td><td>$ (203,804)</td><td>$ (132,982)</td><td>$ 390,004</td></tr><tr><td>Support</td><td>(26,021)</td><td>(2,363)</td><td>42,510</td></tr><tr><td>Corporate expenses</td><td>(17,037)</td><td>(14,515)</td><td>(16,113)</td></tr><tr><td>Gain (loss) on disposition of assets, net</td><td>7,920</td><td>(6,417)</td><td>(15,472)</td></tr><tr><td>Net (loss) income</td><td>$ (141,246)</td><td>$ (99,561)</td><td>$ 245,193</td></tr><tr><td>(Loss) earnings per share — diluted</td><td>$ (0.66)</td><td>$ (0.47)</td><td>$ 1.14</td></tr><tr><td>Percentage of cost of revenues to revenues</td><td>83%</td><td>78%</td><td>64%</td></tr><tr><td>Percentage of selling, general and administrative expenses to revenues</td><td>21%</td><td>12%</td><td>8%</td></tr><tr><td>Percentage of depreciation and amortization expenses to revenues</td><td>30%</td><td>21%</td><td>10%</td></tr><tr><td>Effective income tax rate</td><td>41.0%</td><td>34.9%</td><td>38.6%</td></tr><tr><td>Average U.S. domestic rig count</td><td>509</td><td>982</td><td>1,862</td></tr><tr><td>Average natural gas price (per thousand cubic feet (mcf))</td><td>$ 2.52</td><td>$ 2.58</td><td>$ 4.25</td></tr><tr><td>Average oil price (per barrel)</td><td>$ 43.49</td><td>$ 48.77</td><td>$ 93.25</td></tr></table>

## Year Ended December 31, 2016 Compared to Year Ended December 31, 2015

Revenues. Revenues in 2016 decreased $534.9 million or 42.3 percent compared to 2015. The Technical Services segment revenues for 2016 decreased $495.6 million or 42.2 percent compared to the prior year due primarily to lower activity levels and pricing as compared to prior year, particularly within our pressure pumping service, which is the largest service within this segment. The Support Services segment revenues in 2016 decreased $39.2 million or 44.3 percent compared to 2015 due primarily to lower pricing and activity levels in the majority of our services within this segment. Both the Technical and Support Services continue to report operating losses due to lower levels of revenues, partially offset by cost control efforts undertaken throughout the Company and lower depreciation and amortization expenses. The average price of oil decreased 10.8 percent while the average price of natural gas decreased 2.4 percent during 2016 compared to the prior year. The average domestic rig count during 2016 was 48.2 percent lower than 2015. International revenues, which decreased from $72.1 million in 2015 to $51.2 million in 2016, were seven percent of consolidated revenues in 2016 and six percent of consolidated revenues in 2015. International revenues decreased primarily due to lower customer activity levels in Australia, Gabon, Equatorial Guinea, China and Argentina in 2016, partially offset by increased activity in Bolivia compared to the prior year. Our international revenues are impacted by the timing of project initiation and their ultimate duration.

Cost of revenues. Cost of revenues in 2016 was $607.9 million compared to $986.1 million in 2015, a decrease of $378.3 million or 38.4 percent, due to lower activity levels coupled with reduced personnel headcount and incentive compensation. As a percentage of revenues, cost of revenues increased in 2016 compared to 2015 due to inefficiencies resulting from lower activity levels coupled with continued low pricing for our services.

Selling, general and administrative expenses. Selling, general and administrative expenses decreased 3.8 percent to $150.7 million in 2016 compared to $156.6 million in 2015. These expenses decreased due to lower total employment costs due to headcount reductions, as well as other expense reduction efforts partially offset by an increase in bad debt expense and professional fees. The Company recorded a contingent professional fee of $2.0 million during the first quarter of 2016 in connection with the resolution of an open income tax matter. As a percentage of revenues, these costs increased during 2016 compared to 2015 due to increases in bad debt expense and professional fees previously noted as well as significantly lower revenues.



Depreciation and amortization. Depreciation and amortization were $217.3 million in 2016, a decrease of $53.7 million, compared to $271.0 million in 2015 due to lower capital expenditures during the last two years. As a percentage of revenues, depreciation and amortization increased in 2016 compared to 2015 due to significantly lower revenues.

Gain (loss) on disposition of assets, net. Gain on disposition of assets, net was $7.9 million in 2016 compared to a loss on disposition of assets, net of $6.4 million in 2015. RPC recorded a gain on disposition of assets of $4.0 million during the fourth quarter of 2016 resulting from the sale of operating equipment related to its oilfield pipe inspection service. The remaining gain (loss) on disposition of assets, net is comprised of gains or losses related to various property and equipment dispositions or sales to customers of lost or damaged rental equipment.

Other (expense) income, net. Other expense, net was $204 thousand in 2016 compared to other income, net of $5.2 million in 2015. Proceeds from a legal settlement totaling $6.3 million was recorded during 2015.

Interest expense and interest income. Interest expense decreased to $0.7 million in 2016 compared to $2.0 million in 2015. Interest expense in 2016 declined in comparison to the prior year because interest expense in the prior year included the accelerated amortization of loan fees totaling $0.6 million associated with RPC’s voluntary reduction of its syndicated credit facility. The current year expense principally consists of facility fees on the unused portion of the credit facility. Interest income increased to $467 thousand in 2016 compared to $83 thousand in 2015.

Income tax benefit. The income tax benefit was $98.1 million in 2016 compared to $53.5 million in 2015. The effective tax rate was 41.0 percent in 2016 compared to 34.9 percent in 2015. The income tax benefit in 2016 includes a discrete tax benefit of $15.7 million recorded in connection with the favorable resolution of an open income tax matter.

Net loss and diluted loss per share. Net loss was $141.2 million in 2016, or $0.66 loss per diluted share, compared to a net loss of $99.6 million in 2015, or $0.47 loss per diluted share. This increase in loss per share was due to lower profitability as average shares outstanding was essentially unchanged.

## Year Ended December 31, 2015 Compared to Year Ended December 31, 2014

Revenues. Revenues in 2015 decreased $1.1 billion or 45.9 percent compared to 2014. The Technical Services segment revenues for 2015 decreased 46.1 percent compared to the prior year due primarily to lower activity levels and pricing as compared to prior year, partially offset by increasing service intensity in our pressure pumping service, which is the largest service within this segment. The Support Services segment revenues for 2015 decreased 43.6 percent compared to 2014 due primarily to lower pricing and activity levels in the rental tool service, which is the largest service within this segment. Both the Technical and Support Services reported operating losses due to lower revenues, partially offset by cost control efforts undertaken throughout the Company. The average price of oil decreased 47.7 percent while the average price of natural gas decreased 39.3 percent during 2015 compared to the prior year. The average domestic rig count during 2015 was 47.3 percent lower than 2014. International revenues, which decreased from $88.2 million in 2014 to $72.1 million in 2015, were as a percentage of consolidated revenues, six percent in 2015 and four percent in 2014. International revenues decreased primarily due to lower customer activity levels in Canada, Australia, Bolivia and Mexico in 2015 partially offset by increased activity in Argentina compared to the prior year. Our international revenues are impacted by the timing of project initiation and their ultimate duration.

Cost of revenues. Cost of revenues in 2015 was $986.1 million compared to $1.5 billion in 2014, a decrease of $506.9 million or 34.0 percent. The decrease in these costs was due to lower costs resulting from lower activity levels, reduced personnel headcount and incentive compensation, and price reductions from suppliers, partially offset by the impact of increasing service intensity. Also during 2015, replacement parts totaling approximately $41.9 million were charged to cost of revenues rather than capitalized as a result of a change in accounting estimate. As a percentage of revenues, cost of revenues increased in 2015 compared to 2014 due to competitive pricing for our services and inefficiencies resulting from lower activity levels.

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



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

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

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

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

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

Net (loss) income and diluted (loss) earnings per share. Net loss was $99.6 million in 2015, or $0.47 loss per diluted share, compared to net income of $245.2 million, or $1.14 earnings per diluted share in 2014.

## Liquidity and Capital Resources

## Cash and Cash Flows

The Company’s cash and cash equivalents were $131.8 million as of December 31, 2016, $65.2 million as of December 31, 2015 and $9.8 million as of December 31, 2014.

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

<table><tr><td rowspan="2"></td><td colspan="4">(in thousands)</td></tr><tr><td>2016</td><td>2015</td><td>2014</td><td></td></tr><tr><td>Net cash provided by operating activities</td><td>$ 101,704</td><td>$ 473,792</td><td>$ 322,757</td><td></td></tr><tr><td>Net cash used for investing activities</td><td>(21,339)</td><td>(157,583)</td><td>(355,349)</td><td></td></tr><tr><td>Net cash (used for) provided by financing activities</td><td>(13,726)</td><td>(260,785)</td><td>33,664</td><td></td></tr></table>

## 2016

Cash provided by operating activities in 2016 decreased by $372.1 million compared to the same period in the prior year. This decrease is due primarily to net unfavorable changes in working capital of $237.0 million coupled with an increase in net losses of $41.7 million, a decrease in depreciation and amortization expenses of $54.4 million, a decrease in (gains) and losses on sale of assets of $14.3 million and a decrease in long-term liabilities of $15.7 million primarily related to the positive resolution of an income tax matter.

The net unfavorable change in working capital is primarily due to unfavorable changes of $337.0 million in accounts receivable due to a less significant decline in business activity levels in 2016 compared to 2015, and $6.4 million decrease in inventory consistent with lower business activity levels. This unfavorable change was partially offset by favorable changes of $56.2 million in accounts payable; $28.6 million in accrued payroll and related expenses; $6.1 million in income taxes payable/ receivable, net; $5.0 million in prepaid expenses and other current assets and $4.2 million in accrued state, local and other taxes consistent with lower business activity levels coupled with the timing of payments.



Cash used for investing activities for 2016 decreased by $136.2 million, compared to 2015, primarily as a result of significantly lower capital expenditures in response to weaker industry conditions.

Cash used for financing activities for 2016 decreased by $247.1 million primarily as a result of lower net loan repayments as there has been no outstanding borrowings since the fourth quarter of 2015 coupled with lower common stock dividends during 2016 compared to the same period in the prior year. The Company reduced its common stock dividend during the first quarter of 2015 and then temporarily suspended its regular quarterly common stock dividend beginning in the second quarter of 2015. The Company paid a special year-end cash dividend of $0.05 per share to common stockholders in the fourth quarter of 2016.

## 2015

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

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

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

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

## Financial Condition and Liquidity

The Company’s financial condition as of December 31, 2016 remains strong. We believe the liquidity provided by our existing cash and cash equivalents and our overall strong capitalization will provide sufficient liquidity to meet our requirements for at least the next twelve months. The Company currently has a $125 million revolving credit facility that matures in January 2019. The facility contains customary terms and conditions, including restrictions on indebtedness, dividend payments, business combinations and other related items. On June 30, 2016, the Company amended the revolving credit facility to (1) establish a borrowing base to be the lesser of $125 million or a specified percentage of eligible accounts receivable less the amount of any outstanding letters of credit. As of December 31, 2016, there were no outstanding borrowings. RPC had letters of credit outstanding relating to self-insurance programs and contract bids totaling $19.1 million as of December 31, 2016. For additional information with respect to RPC’s facility, see Note 6 of the Notes to Consolidated Financial Statements.

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



## Cash Requirements

Capital expenditures were $33.9 million in 2016, and we currently expect capital expenditures to be approximately $70 million in 2017. We expect that a majority of these expenditures in 2017 will be directed towards capitalized equipment maintenance. The remaining capital expenditures will be directed towards the purchase of revenue-producing equipment. The actual amount of capital expenditures will depend primarily on equipment maintenance requirements, expansion opportunities, and equipment delivery schedules.

The Company’s Retirement Income Plan, a multiple employer trusted defined benefit pension plan, provides monthly benefits upon retirement at age 65 to eligible employees. During 2016, the Company contributed $4.3 million to the pension plan and does not expect to make any additional contributions to the plan during 2017.

The Company has a stock buyback program, initially adopted in 1998 and subsequently amended in 2013, that authorizes the repurchase of up to 31,578,125 shares. There were no shares purchased on the open market by the Company during 2016, and 2,050,154 shares remain available to be repurchased under the current authorization as of December 31, 2016. The Company may repurchase outstanding common shares periodically based on market conditions and our capital allocation strategies considering restrictions under our credit facility. The stock buyback program does not have a predetermined expiration date.

On July 28, 2015, the Board of Directors voted to temporarily suspend RPC’s regular quarterly dividend to common stockholders; however, the Board of Directors voted to pay a special year-end cash dividend of $0.05 per share to common stockholders during the fourth quarter of 2016. The Company expects to resume cash dividends to common stockholders sometime in the future, subject to the earnings and financial condition of the Company and other relevant factors.

## Contractual Obligations

The Company’s obligations and commitments that require future payments include our credit facility, certain non-cancelable operating leases, purchase obligations and other long-term liabilities. The following table summarizes the Company’s significant contractual obligations as of December 31, 2016:

<table><tr><td rowspan="2">Contractual Obligations</td><td colspan="6">Payments due by period</td></tr><tr><td>Total</td><td>Less than 1 year</td><td>1-3 years</td><td>3-5 years</td><td>More than 5 years</td><td></td></tr><tr><td>(in thousands)</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Long-term debt obligations</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ —</td></tr><tr><td>Interest on long-term debt obligations</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Capital lease obligations</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><tr><td>Operating leases (1)</td><td>42,994</td><td>12,648</td><td>18,077</td><td>8,074</td><td>4,195</td><td></td></tr><tr><td>Purchase obligations (2)</td><td>21,316</td><td>10,354</td><td>10,962</td><td>—</td><td>—</td><td></td></tr><tr><td>Other long-term liabilities (3)</td><td>1,054</td><td>860</td><td>194</td><td>—</td><td>—</td><td></td></tr><tr><td>Total contractual obligations</td><td>$ 65,364</td><td>$ 23,862</td><td>$ 29,233</td><td>$ 8,074</td><td>$ 4,195</td><td></td></tr></table>

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

(2) Includes agreements to purchase raw materials, 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 is 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 and Supplemental Executive Retirement Plan



(“SERP”) investments measured at net asset value, the values are computed using inputs such as cost, discounted future cash flows, independent appraisals and market based comparable data or on net asset values calculated by the fund or when not publicly available.

## Inflation

The Company purchases its equipment and materials from suppliers who provide competitive prices, and employs skilled workers from competitive labor markets. If inflation in the general economy increases, the Company’s costs for equipment, materials and labor could increase as well. Also, increases in activity in the domestic oilfield can cause upward wage pressures in the labor markets from which it hires employees as well as increases in the costs of certain materials and key equipment components used to provide services to the Company’s customers. In previous periods of strong oilfield activity, we experienced high employment costs due to the demand for skilled labor in our markets as well as high costs for certain raw materials the Company uses to provide its services. During 2015 and 2016, however, supplies of raw materials became more readily available as domestic oilfield activity decreased. In addition, skilled labor became more available, and upward wage pressures subsided. During the third quarter of 2016, however, the Company began to experience upward pressure on the price of labor, due to increased oilfield activity and a shortage of skilled employees caused by the industry’s headcount reductions since the first quarter of 2015. Early in the first quarter of 2017, the Company has also started to experience increases in the prices of certain raw materials used in providing our services. The market for the Company’s services remains competitive, due to relatively low commodity prices, so it may be difficult for the Company to increase the prices charged to our customers to compensate for these cost increases.

## Off Balance Sheet Arrangements

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

## Related Party Transactions

## Marine Products Corporation

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

In accordance with a Transition Support Services agreement, which may be terminated by either party, RPC provides certain administrative services, including financial reporting and income tax administration, acquisition assistance, etc., to Marine Products. Charges from the Company (or from corporations that are subsidiaries of the Company) for such services were $739,000 in 2016, $753,000 in 2015, and $663,000 in 2014. The Company’s receivable (payable) due to (from) Marine Products for these services was $60,000 as of December 31, 2016 and $ (11,000) \)  as of December 31, 2015. 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 $890,000 in 2016, $1,127,000 in 2015 and $1,092,000 in 2014.

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 $111,000 in 2016, $100,000 in 2015 and $84,000 in 2014.



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

RPC and Marine Products own 50 percent each of a limited liability company called 255 RC, LLC that was created for the joint purchase and ownership of a corporate aircraft. The purchase of the aircraft was completed in January 2015, and the purchase was funded primarily by a $2,554,000 contribution by each company to 255 RC, LLC. Each of RPC and Marine Products is a party to an operating lease agreement with 255 RC, LLC for a period of five years. RPC recorded certain net operating costs comprised of rent and an allocable share of fixed costs of approximately $197,000 in 2016 and $186,000 in 2015 for the corporate aircraft. The Company accounts for this investment using the equity method and its proportionate share of income or loss is recorded in selling, general and administrative expenses. As of December 31, 2016, the investment closely approximates the underlying equity in the net assets of 255 RC, LLC.

## Critical Accounting Policies

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

Allowance for doubtful accounts — Substantially all of the Company’s receivables are due from oil and gas exploration and production companies in the United States, selected international locations and foreign, nationally owned oil companies. Our allowance for doubtful accounts is determined using a combination of factors to ensure that our receivables are not overstated due to uncollectibility. Our established credit evaluation procedures seek to minimize the amount of business we conduct with higher risk customers. Our customers’ ability to pay is directly related to their ability to generate cash flow on their projects and is significantly affected by the volatility in the price of oil and natural gas. Provisions for doubtful accounts are recorded in selling, general and administrative expenses. Accounts are written off against the allowance for doubtful accounts when the Company determines that amounts are uncollectible and recoveries of amounts previously written off are recorded when collected. Significant recoveries will generally reduce the required provision in the period of recovery. Therefore, the provision for doubtful accounts can fluctuate significantly from period to period. Recoveries were insignificant in 2016 and 2014 and approximately $1.0 million in 2015. We record specific provisions when we become aware of a customer’s inability to meet its financial obligations to us, such as in the case of bankruptcy filings or deterioration in the customer’s operating results or financial position. If circumstances related to a customer changes, our estimate of the realizability of the receivable would be further adjusted, either upward or downward.

The estimated allowance for doubtful accounts is based on our evaluation of the overall trends in the oil and gas industry, financial condition of our customers, our historical write-off experience, current economic conditions, and in the case of international customers, our judgments about the economic and political environment of the related country and region. In addition to reserves established for specific customers, we establish general reserves by using different percentages depending on the age of the receivables which we adjust periodically based on management judgment and the economic strength of our customers. The net provisions for doubtful accounts as a percentage of revenues have ranged from 0.8 percent to (0.2) percent over the last three years. Increasing or decreasing the estimated general reserve percentages by 0.50 percentage points as of December 31, 2016 would have resulted in a change of approximately $0.9 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 41.0 percent in 2016, 34.9 percent in 2015 and 38.6 percent in 2014. Our effective tax rates vary due to changes in estimates of our future taxable income or losses, fluctuations in the tax jurisdictions in which our earnings and deductions are realized, and favorable or unfavorable adjustments to our estimated tax liabilities related to proposed or probable assessments. As a result, our effective tax rate may fluctuate significantly on a quarterly or annual basis.



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, 2016, the Company estimates the range of exposure to be from $12.1 million to $15.3 million. The Company has recorded liabilities at December 31, 2016 of approximately $13.6 million which represents management’s best estimate of probable loss.

Depreciable life of assets — RPC’s net property, plant and equipment at December 31, 2016 was $498.0 million representing 48.1 percent of the Company’s consolidated assets. Depreciation and amortization expenses for the year ended December 31, 2016 were $217.3 million. Management judgment is required in the determination of the estimated useful lives used to calculate the annual and accumulated depreciation and amortization expense.

Property, plant and equipment are reported at cost less accumulated depreciation and amortization, which is provided on a straight-line basis over the estimated useful lives of the assets. The estimated useful life represents the projected period of time that the asset will be productively employed by the Company and is determined by management based on many factors including historical experience with similar assets. Assets are monitored to ensure changes in asset lives are identified and prospective depreciation and amortization expense is adjusted accordingly. During 2015 the Company reassessed the useful life of a specific component of its pressure pumping equipment that prior to 2015 had an expected useful life of 18 months. As a result of this reassessment, the Company concluded that this component is no longer a long-lived asset, but instead a consumable supply inventory item. Accordingly, effective January 1, 2015, the cost of this component was expensed as repairs and maintenance as part of cost of revenues at the time of installation. Management deemed the change preferable because it more closely reflects the pattern of consumption of this component as a result of continual increases in wear and tear resulting from harsher geological environments. We did not make any changes to the estimated lives of assets resulting in a material impact in 2016 and 2014.

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



The Company chooses an expected rate of return on plan assets based on historical results for similar allocations among asset classes, the investments strategy, and the views of our investment advisor. Differences between the expected long-term return on plan assets and the actual return are amortized over future years. Therefore, the net deferral of past asset gains (losses) ultimately affects future pension expense. The Company’s assumption for the expected return on plan assets was seven percent for 2016, 2015 and 2014.

The discount rate reflects the current rate at which the pension liabilities could be effectively settled at the end of the year. In estimating this rate, the Company utilizes a yield curve approach. The approach utilizes an economic model whereby the Company’s expected benefit payments over the life of the plan are forecasted and then compared to a portfolio of investment grade corporate bonds that will mature at the same time that the benefit payments are due in any given year. The economic model then calculates the one discount rate to apply to all benefit payments over the life of the plan which will result in the same total lump sum as the payments from the corporate bonds. A lower discount rate increases the present value of benefit obligations. The discount rate was 4.45 percent as of December 31, 2016 compared to 4.70 percent as of December 31, 2015 and 4.15 percent in 2014.

As set forth in Note 10 to the Company’s financial statements, included among the asset categories for the Plan’s investments are real estate and alternative/ opportunistic/ special fund investments comprised of real estate funds and private equity funds. These investments are measured at net asset value and are valued using significant non-observable inputs which do not have a readily determinable fair value. These valuations are subject to judgments and assumptions of the funds which may prove to be incorrect, resulting in risks of incorrect valuation of these investments. The Company seeks to mitigate these risks by evaluating the appropriateness of the funds’ judgments and assumptions by reviewing the financial data included in the funds’ financial statements for reasonableness.

As of December 31, 2016, the defined benefit plan was under-funded and the recorded change within accumulated other comprehensive loss decreased stockholders' equity by approximately $1.3 million after tax. Holding all other factors constant, a change in the discount rate used to measure plan liabilities by 0.25 percentage points would result in a pre-tax increase or decrease of approximately $1.2 million to the net loss related to pension reflected in accumulated other comprehensive loss.

The Company recognized pre-tax pension expense of $0.7 million in 2016, $0.4 million in 2015 and $0.2 million in 2014. Based on the under-funded status of the defined benefit plan as of December 31, 2016, the Company expects to recognize pension expense of $0.4 million in 2017. Holding all other factors constant, a change in the expected long-term rate of return on plan assets by 0.50 percentage points would result in an increase or decrease in pension expense of approximately $0.2 million in 2017. Holding all other factors constant, a change in the discount rate used to measure plan liabilities by 0.25 percentage points would result in an increase or decrease in pension expense of an immaterial amount in 2017.

## Recent Accounting Pronouncements

During the year ended December 31, 2016, the Financial Accounting Standards Board (FASB) issued the following applicable Accounting Standards Updates (ASUs):

## Recently Adopted Accounting Pronouncements:

- ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments. The amendments eliminate the requirement to retrospectively account for adjustments made to provisional amounts recognized in a business combination. Adjustments to provisional amounts that are identified during the measurement period are required to be recognized in the reporting period in which the adjustments are determined and calculated as if the accounting had been completed at the acquisition date and either disclosed on the face of the income statement or in the notes by each category. The Company adopted these provisions in the first quarter of 2016 and plans to apply the provisions for all future business combinations. The adoption did not have a material impact on the Company’s consolidated financial statements.

- ASU No. 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent). The amendments remove the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share (or its equivalent) practical expedient. In addition, there is no requirement to make certain



disclosures for such investments. The Company adopted these provisions in the first quarter of 2016 applied retrospectively and has excluded the pension assets that are measured using the net asset value per share from the fair value hierarchy disclosure. The adoption did not have a material impact on the Company’s consolidated financial statements.

- ASU No. 2014-15, Presentation of Financial Statements — Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. Financial statements are generally prepared under the presumption that the reporting organization will continue to operate as a going concern, except in limited circumstances. This ASU provides guidance on management’s responsibility to include footnote disclosures when there is substantial doubt about the organization’s ability to continue as a going concern. The Company adopted these provisions in the first quarter of 2016 and will provide such disclosures as required if there are conditions and events that raise substantial doubt about its ability to continue as a going concern. The adoption did not have a material impact on the Company’s consolidated financial statements.

## Recently Issued Accounting Pronouncements Not Yet Adopted:

## To be adopted in 2017:

- ASU No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. Current requirements are to measure inventory at the lower of cost or market. Market could be replacement cost, net realizable value, or net realizable value less an approximated normal profit margin. These amendments allow inventory to be measured at lower of cost or net realizable value and eliminates the market requirement. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The amendments do not apply to inventory that is measured using last-in, first-out or the retail inventory method. The amendments will be adopted in the first quarter of 2017 and applied prospectively. The Company does not expect the adoption of these provisions to have a material impact on its consolidated financial statements.

- ASU No. 2016-07, Investments — Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting. The amendments eliminate the requirement to adjust the investment, results of operations, and retained earnings retroactively when an investment qualifies for use of the equity method as a result of an increase in the level of ownership interest or degree of influence. The cost of acquiring the additional interest in the investee is to be added to the current basis of the investor’s previously held interest and the equity method is to be adopted as of the date the investment qualifies. In addition, an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting is required to recognize through earnings the unrealized holding gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. The amendments will be adopted in the first quarter of 2017 and applied prospectively. The Company does not expect the adoption of these provisions to have a material impact on its consolidated financial statements.

- ASU No. 2016-09, Compensation — Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The amendments simplify several aspects of the accounting for share-based payment award transactions, requiring excess tax benefits and deficiencies to be recognized as a component of income tax expense rather than equity. This guidance also requires excess tax benefits and deficiencies to be presented as an operating activity on the statement of cash flows and allows an entity to make an accounting policy election to either estimate expected forfeitures or to account for them as they occur. The Company will adopt these provisions in the first quarter of 2017 and adoption of these provisions will result in the inclusion of excess tax benefits and deficiencies as a component of income tax expense which may increase volatility of the provision for income taxes as the amount of excess tax benefits or deficiencies from stock-based compensation awards are dependent on the Company’s stock price as of the date the stock awards vest. Based on the Company’s current stock price and its stock incentive plan awards, this change resulted in a beneficial adjustment of approximately $2.5 million to the provision for income taxes in the first quarter of 2017. The Company will continue to estimate expected forfeitures.

- ASU No. 2016-17, Consolidation (Topic 810): Interests Held through Related Parties That are under Common Control. The amendments affect reporting entities that are required to evaluate whether they should consolidate a variable interest entity in certain situations involving entities under common control. Specifically,



the amendments change the evaluation of whether a reporting entity is the primary beneficiary of a variable interest entity by changing how a reporting entity that is a single decision maker of a variable interest entity treats indirect interests in the entity held through related parties that are under common control with the reporting entity. The amendments will be adopted in the first quarter of 2017 and the Company does not expect the adoption to have a material impact on its consolidated financial statements.

## To be adopted in 2018:

## REVENUE RECOGNITION:

The Financial Accounting Standards Board and International Accounting Standards Board issued their converged standard on revenue recognition in May 2014. The standard provides a comprehensive, industry-neutral revenue recognition model intended to increase financial statement comparability across companies and industries and significantly reduce the complexity inherent in today’s revenue recognition guidance. The various ASUs related to Revenue from Contracts with Customers (Topic 606) have been listed below:

- ASU No. 2014-09. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services using a five step process.

- ASU No. 2015-14. Deferred the effective date of ASU 2014-09 for all entities by one year to the first quarter of 2018 with early application permitted.

- ASU No. 2016-08, Principal versus Agent Considerations (Reporting Revenue Gross versus Net). The amendments provide guidance on whether an entity is a principal or agent when providing services to a customer along with another party.

- ASU No. 2016-10, Identifying Performance Obligations and Licensing. The amendments clarify the earlier guidance on identifying performance obligations and licensing implementation.

- ASU No. 2016-11, Rescission of SEC Guidance Because of ASUs 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting. This ASU rescinds certain SEC guidance related to issues that are currently codified under various topics.

- ASU No. 2016-12, Narrow-Scope Improvements and Practical Expedients. The amendments provide clarifying guidance on certain aspects of the five step process and practical expedients regarding the effect of modifications and status of completed contracts under legacy GAAP and disclosures related to the application of this guidance using the modified retrospective or retrospective transition method.

- ASU No. 2016-20, Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers. The amendments in ASU 2016-20 affect narrow aspects of the guidance issued in ASU 2014-09 and includes among others, loan guarantees, impairment testing of contract costs, performance obligations disclosures and accrual of advertising costs.

## Current Status of Implementation:

The Company is currently analyzing the effect of the standard across all of its revenue streams to evaluate the impact of the new standard on revenue contracts. This includes reviewing current accounting policies and practices to identify potential differences that would result from applying the requirements under the new standard. Most of the Company’s services are primarily short-term in nature, and the assessment at this stage is that the Company does not expect the adoption of the new revenue recognition standard to have a material impact on its financial statements. The Company plans to adopt the standard in the first quarter of 2018 using the modified retrospective method by recognizing the cumulative effect of initially applying the new standard as an adjustment to the opening balance of retained earnings.

- ASU No. 2016-01, Financial Instruments – Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities. The amendments make targeted improvements to existing U.S. GAAP and affects accounting for equity investments and financial instruments and liabilities and related disclosures. The amendments are effective starting in the first quarter of 2018, with early adoption permitted for



certain provisions. The Company is currently evaluating the impact of these provisions on its consolidated financial statements.

- ASU No. 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. The amendments provide guidance in the presentation and classification of certain cash receipts and cash payments in the statement of cash flows including debt prepayment or debt extinguishment costs, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate-owned life insurance policies, and distributions received from equity method investees. The amendments are effective starting in the first quarter of 2018 with early adoption permitted. The amendments should be applied using a retrospective transition method to each period presented. If it is impracticable to apply the amendments retrospectively for some of the issues, the amendments for those issues would be applied prospectively as of the earliest date practicable. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

- ASU No. 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory. The amendments require an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. The amendments eliminate the exception for an intra-entity transfer of an asset other than inventory. Two common examples of assets included in the scope of the amendments are intellectual property and property, plant, and equipment. The amendments do not include new disclosure requirements; however, existing disclosure requirements might be applicable when accounting for the current and deferred income taxes for an intra-entity transfer of an asset other than inventory. The amendments are effective starting in the first quarter of 2018 with early adoption permitted. The amendments are required to be applied on a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

- ASU No. 2016-18, Statement of Cash Flows (230): Restricted Cash. The amendments require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. As a result, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The amendments do not provide a definition of restricted cash or restricted cash equivalents. The amendments are effective starting in the first quarter of 2018 with early adoption permitted. The amendments should be applied using a retrospective transition method to each period presented. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

## To be adopted in 2019 and later:

- ASU No. 2016-02, Leases (Topic 842). Under the new guidance, lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease), at the commencement of the lease term. The liability will be equal to the present value of lease payments. The asset will be based on the liability, subject to adjustment, such as for initial direct costs. The amendments in this standard are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early application is permitted. Lessees (for capital and operating leases) and lessors (for sales-type, direct financing, and operating leases) must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. Lessees and lessors may not apply a full retrospective transition approach. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

- ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments require that credit losses on available-for-sale debt securities and purchased financial assets with credit deterioration should be presented as an allowance rather than a write-down. It also allows recording of credit loss reversals in current period net income. The amendments are effective in the first quarter of 2020 with early application permitted a year earlier. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.



## Item 7A. Quantitative and Qualitative Disclosures about Market Risk

The Company is subject to interest rate risk exposure through borrowings on its credit agreement. As of December 31, 2016, there are no outstanding interest-bearing advances on our credit facility which bear interest at a floating rate.

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



# MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

To the Stockholders of RPC, Inc.:

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

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

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of the design and operations of our internal control over financial reporting as of December 31, 2016 based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on this evaluation, management’s assessment is that RPC, Inc. maintained effective internal control over financial reporting as of December 31, 2016.

The independent registered public accounting firm, Grant Thornton LLP, has audited the consolidated financial statements as of and for the year ended December 31, 2016, and has also issued their report on the effectiveness of the Company’s internal control over financial reporting, included in this report on page 43.



Richard A. Hubbell

President and Chief Executive Officer



Ben M. Palmer

Vice President, Chief Financial Officer and Treasurer

Atlanta, Georgia

February 28, 2017



# Report of Independent Registered Public Accounting Firm

Board of Directors and Stockholders
RPC, Inc.

We have audited the internal control over financial reporting of RPC, Inc. (a Delaware corporation) and subsidiaries (the "Company") as of December 31, 2016, based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit.

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

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

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

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2016, based on criteria established in the 2013 Internal Control—Integrated Framework issued by COSO.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements of the Company as of and for the year ended December 31, 2016, and our report dated February 28, 2017 expressed an unqualified opinion on those financial statements.

## Grant Thornton LLP

Atlanta, Georgia
February 28, 2017



# Report of Independent Registered Public Accounting Firm

Board of Directors and Stockholders
RPC, Inc.

We have audited the accompanying consolidated balance sheets of RPC, Inc. (a Delaware corporation) and subsidiaries (the "Company") as of December 31, 2016 and 2015, and the related consolidated statements of operations, comprehensive income, stockholders' equity, and cash flows for each of the three years in the period ended December 31, 2016. Our audits of the basic consolidated financial statements included the financial statement schedule listed in the index appearing under Item 15(2). These financial statements and financial statement schedule are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits.

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

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of RPC, Inc. and subsidiaries as of December 31, 2016 and 2015, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2016 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the related financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2016, based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 28, 2017 expressed an unqualified opinion thereon.

## Grant Grant

Atlanta, Georgia

February 28, 2017



## Item 8. Financial Statements and Supplementary Data

## CONSOLIDATED BALANCE SHEETS
RPC, INC. AND SUBSIDIARIES

## (in thousands except share information)

<table><tr><td>December 31,</td><td>2016</td><td>2015</td></tr><tr><td>ASSETS</td><td></td><td></td></tr><tr><td>Cash and cash equivalents</td><td>$ 131,835</td><td>$ 65,196</td></tr><tr><td>Accounts receivable, net</td><td>169,166</td><td>232,187</td></tr><tr><td>Inventories</td><td>108,316</td><td>128,441</td></tr><tr><td>Income taxes receivable</td><td>57,174</td><td>51,392</td></tr><tr><td>Prepaid expenses</td><td>6,718</td><td>8,961</td></tr><tr><td>Other current assets</td><td>5,848</td><td>6,031</td></tr><tr><td>Current assets</td><td>479,057</td><td>492,208</td></tr><tr><td>Property, plant and equipment, net</td><td>497,986</td><td>688,335</td></tr><tr><td>Goodwill</td><td>32,150</td><td>32,150</td></tr><tr><td>Other assets</td><td>26,259</td><td>24,401</td></tr><tr><td>Total assets</td><td>$ 1,035,452</td><td>$ 1,237,094</td></tr><tr><td>LIABILITIES AND STOCKHOLDERS&#x27; EQUITY</td><td></td><td></td></tr><tr><td>LIABILITIES</td><td></td><td></td></tr><tr><td>Accounts payable</td><td>$ 70,536</td><td>$ 75,811</td></tr><tr><td>Accrued payroll and related expenses</td><td>12,130</td><td>16,654</td></tr><tr><td>Accrued insurance expenses</td><td>4,099</td><td>4,296</td></tr><tr><td>Accrued state, local and other taxes</td><td>3,094</td><td>2,838</td></tr><tr><td>Income taxes payable</td><td>4,929</td><td>7,639</td></tr><tr><td>Other accrued expenses</td><td>6,680</td><td>226</td></tr><tr><td>Current liabilities</td><td>101,468</td><td>107,464</td></tr><tr><td>Long-term accrued insurance expenses</td><td>9,537</td><td>11,348</td></tr><tr><td>Long-term pension liabilities</td><td>32,864</td><td>33,009</td></tr><tr><td>Deferred income taxes</td><td>81,466</td><td>115,495</td></tr><tr><td>Other long-term liabilities</td><td>3,318</td><td>17,497</td></tr><tr><td>Total liabilities</td><td>228,653</td><td>284,813</td></tr><tr><td>Commitments and contingencies (Note 9)</td><td></td><td></td></tr><tr><td>STOCKHOLDERS&#x27; EQUITY</td><td></td><td></td></tr><tr><td>Preferred stock, $0.10 par value, 1,000,000 shares authorized, none issued</td><td>—</td><td>—</td></tr><tr><td>Common stock, $0.10 par value, 349,000,000 shares authorized, 217,489,402 and 216,991,357 shares issued and outstanding in 2016 and 2015, respectively</td><td>21,749</td><td>21,699</td></tr><tr><td>Capital in excess of par value</td><td>—</td><td>—</td></tr><tr><td>Retained earnings</td><td>803,152</td><td>948,551</td></tr><tr><td>Accumulated other comprehensive loss</td><td>(18,102)</td><td>(17,969)</td></tr><tr><td>Total stockholders&#x27; equity</td><td>806,799</td><td>952,281</td></tr><tr><td>Total liabilities and stockholders&#x27; equity</td><td>$ 1,035,452</td><td>$ 1,237,094</td></tr></table>

The accompanying notes are an integral part of these statements.



## CONSOLIDATED STATEMENTS OF OPERATIONS
RPC, INC. AND SUBSIDIARIES

## (in thousands except per share data)

<table><tr><td>Years ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>REVENUES</td><td>$ 728,974</td><td>$ 1,263,840</td><td>$ 2,337,413</td></tr><tr><td>COSTS AND EXPENSES:</td><td></td><td></td><td></td></tr><tr><td>Cost of revenues (exclusive of items shown separately below)</td><td>607,888</td><td>986,144</td><td>1,493,082</td></tr><tr><td>Selling, general and administrative expenses</td><td>150,690</td><td>156,579</td><td>197,117</td></tr><tr><td>Depreciation and amortization</td><td>217,258</td><td>270,977</td><td>230,813</td></tr><tr><td>(Gain) loss on disposition of assets, net</td><td>(7,920)</td><td>6,417</td><td>15,472</td></tr><tr><td>Operating (loss) profit</td><td>(238,942)</td><td>(156,277)</td><td>400,929</td></tr><tr><td>Interest expense</td><td>(681)</td><td>(2,032)</td><td>(1,431)</td></tr><tr><td>Interest income</td><td>467</td><td>83</td><td>19</td></tr><tr><td>Other (expense) income, net</td><td>(204)</td><td>5,185</td><td>(131)</td></tr><tr><td>(Loss) income before income taxes</td><td>(239,360)</td><td>(153,041)</td><td>399,386</td></tr><tr><td>Income tax (benefit) provision</td><td>(98,114)</td><td>(53,480)</td><td>154,193</td></tr><tr><td>Net (loss) income</td><td>(141,246)</td><td>(99,561)</td><td>245,193</td></tr><tr><td>(LOSS) EARNINGS PER SHARE</td><td></td><td></td><td></td></tr><tr><td>Basic</td><td>(0.66)</td><td>(0.47)</td><td>1.14</td></tr><tr><td>Diluted</td><td>(0.66)</td><td>(0.47)</td><td>1.14</td><tr><td>Dividends paid per share</td><td>0.050</td><td>0.155</td><td>0.420</td></tr></tr></table>

The accompanying notes are an integral part of these statements.



## CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME
RPC, INC. AND SUBSIDIARIES

## (in thousands except per share data)

<table><tr><td>Years ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>NET (LOSS) INCOME</td><td>$ (141,246)</td><td>$ (99,561)</td><td>$ 245,193</td></tr><tr><td>OTHER COMPREHENSIVE (LOSS) INCOME, NET OF TAXES:</td><td></td><td></td><td></td></tr><tr><td>Pension adjustment</td><td>(788)</td><td>1,531</td><td>(6,486)</td></tr><tr><td>Foreign currency translation</td><td>652</td><td>(1,801)</td><td>(1,124)</td></tr><tr><td>Unrealized gain (loss) on securities, net reclassification adjustments</td><td>3</td><td>134</td><td>(108)</td></tr><tr><td>COMPREHENSIVE (LOSS) INCOME</td><td>$ (141,379)</td><td>$ (99,697)</td><td>$ 237,475</td></tr></table>

The accompanying notes are an integral part of these statements.



## CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
RPC, INC. AND SUBSIDIARIES

## (in thousands)

<table><tr><td>Three Years Ended December 31, 2016</td><td>Common Stock Amount</td><td>Capital in Excess of Par Value</td><td>Retained Earnings</td><td>Accumulated Other Comprehensive Income (Loss)</td><td>Total</td></tr><tr><td>Balance, December 31, 2013</td><td>218,986</td><td>$ 21,899</td><td>$ —</td><td>$ 956,918</td><td>$ (10,115)</td></tr><tr><td>Stock issued for stock incentive plans, net</td><td>569</td><td>57</td><td>9,017</td><td>—</td><td>9,074</td></tr><tr><td>Stock purchased and retired</td><td>(3,016)</td><td>(302)</td><td>(13,353)</td><td>(35,942)</td><td>—</td></tr><tr><td>Net income</td><td>—</td><td>—</td><td>—</td><td>245,193</td><td>—</td></tr><tr><td>Pension adjustment, net of taxes</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(6,486)</td></tr><tr><td>Foreign currency translation</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(1,124)</td></tr><tr><td>Unrealized loss on securities, net of taxes</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(108)</td></tr><tr><td>Dividends declared</td><td>—</td><td>—</td><td>—</td><td>(91,608)</td><td>—</td></tr><tr><td>Excess tax benefits for share-based payments</td><td>—</td><td>—</td><td>4,336</td><td>—</td><td>4,336</td></tr><tr><td>Balance, December 31, 2014</td><td>216,539</td><td>21,654</td><td>—</td><td>1,074,561</td><td>(17,833)</td></tr><tr><td>Stock issued for stock incentive plans, net</td><td>791</td><td>79</td><td>9,802</td><td>—</td><td>9,881</td></tr><tr><td>Stock purchased and retired</td><td>(339)</td><td>(34)</td><td>(11,212)</td><td>7,153</td><td>—</td></tr><tr><td>Net loss</td><td>—</td><td>—</td><td>—</td><td>(99,561)</td><td>—</td></tr><tr><td>Pension adjustment, net of taxes</td><td>—</td><td>—</td><td>—</td><td>—</td><td>1,531</td></tr><tr><td>Foreign currency translation</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(1,801)</td></tr><tr><td>Unrealized gain on securities, net of taxes and reclassification adjustment</td><td>—</td><td>—</td><td>—</td><td>—</td><td>134</td></tr><tr><td>Dividends declared</td><td>—</td><td>—</td><td>—</td><td>(33,602)</td><td>—</td></tr><tr><td>Excess tax benefits for share-based payments</td><td>—</td><td>—</td><td>1,410</td><td>—</td><td>1,410</td></tr><tr><td>Balance, December 31, 2015</td><td>216,991</td><td>21,699</td><td>—</td><td>948,551</td><td>(17,969)</td></tr><tr><td>Stock issued for stock incentive plans, net</td><td>796</td><td>80</td><td>9,508</td><td>—</td><td>9,588</td></tr><tr><td>Stock purchased and retired</td><td>(298)</td><td>(30)</td><td>(9,935)</td><td>6,708</td><td>—</td></tr><tr><td>Net loss</td><td>—</td><td>—</td><td>—</td><td>(141,246)</td><td>—</td></tr><tr><td>Pension adjustment, net of taxes</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(788)</td></tr><tr><td>Foreign currency translation</td><td>—</td><td>—</td><td>—</td><td>—</td><td>652</td></tr><tr><td>Unrealized gain on securities, net of taxes and reclassification adjustment</td><td>—</td><td>—</td><td>—</td><td>—</td><td>3</td></tr><tr><td>Dividends declared</td><td>—</td><td>—</td><td>—</td><td>(10,861)</td><td>—</td></tr><tr><td>Excess tax benefits for share-based payments</td><td>—</td><td>—</td><td>427</td><td>—</td><td>427</td></tr><tr><td>Balance, December 31, 2016</td><td>217,489</td><td>$ 21,749</td><td>$ —</td><td>$ 803,152</td><td>$ (18,102)</td></tr></table>

The accompanying notes are an integral part of these statements.



## CONSOLIDATED STATEMENTS OF CASH FLOWS
RPC, Inc. and Subsidiaries

## (in thousands)

<table><tr><td>Years ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>OPERATING ACTIVITIES</td><td></td><td></td><td></td></tr><tr><td>Net (loss) income</td><td>$ (141,246)</td><td>$ (99,561)</td><td>$ 245,193</td></tr><tr><td>Adjustments to reconcile net (loss) income to net cash provided by operating activities:</td><td></td><td></td><td></td></tr><tr><td>Depreciation, amortization and other non-cash charges</td><td>221,038</td><td>275,413</td><td>233,940</td></tr><tr><td>Stock-based compensation expense</td><td>10,218</td><td>9,960</td><td>9,074</td></tr><tr><td>(Gain) loss on disposition of assets, net</td><td>(7,920)</td><td>6,417</td><td>15,472</td></tr><tr><td>Deferred income tax (benefit) provision</td><td>(34,209)</td><td>(33,013)</td><td>12,354</td></tr><tr><td>Excess tax benefits for share-based payments</td><td>(427)</td><td>(1,410)</td><td>(4,336)</td></tr><tr><td>(Increase) decrease in assets:</td><td></td><td></td><td></td></tr><tr><td>Accounts receivable</td><td>64,715</td><td>401,753</td><td>(198,021)</td></tr><tr><td>Income taxes receivable</td><td>(5,355)</td><td>(20,867)</td><td>(19,059)</td></tr><tr><td>Inventories</td><td>20,294</td><td>26,667</td><td>(29,708)</td></tr><tr><td>Prepaid expenses</td><td>2,244</td><td>161</td><td>2</td></tr><tr><td>Other current assets</td><td>2</td><td>(2,881)</td><td>(749)</td></tr><tr><td>Other non-current assets</td><td>(1,851)</td><td>1,768</td><td>(2,238)</td></tr><tr><td>Increase (decrease) in liabilities:</td><td></td><td></td><td></td></tr><tr><td>Accounts payable</td><td>(6,250)</td><td>(62,446)</td><td>36,421</td></tr><tr><td>Income taxes payable</td><td>(2,710)</td><td>6,695</td><td>944</td></tr><tr><td>Accrued payroll and related expenses</td><td>(4,540)</td><td>(33,143)</td><td>13,221</td></tr><tr><td>Accrued insurance expenses</td><td>(197)</td><td>(1,336)</td><td>(440)</td></tr><tr><td>Accrued state, local and other taxes</td><td>256</td><td>(3,983)</td><td>1,819</td></tr><tr><td>Other accrued expenses</td><td>5,017</td><td>(180)</td><td>(775)</td></tr><tr><td>Pension liabilities</td><td>(1,385)</td><td>1,021</td><td>2,219</td></tr><tr><td>Long-term accrued insurance expenses</td><td>(1,811)</td><td>1,249</td><td>(126)</td></tr><tr><td>Other long-term liabilities</td><td>(14,179)</td><td>1,508</td><td>7,550</td></tr><tr><td>Net cash provided by operating activities</td><td>101,704</td><td>473,792</td><td>322,757</td></tr><tr><td>INVESTING ACTIVITIES</td><td></td><td></td><td></td></tr><tr><td>Capital expenditures</td><td>(33,938)</td><td>(167,426)</td><td>(371,502)</td></tr><tr><td>Proceeds from sale of assets</td><td>12,599</td><td>9,843</td><td>18,707</td></tr><tr><td>Investment in joint venture</td><td>—</td><td>—</td><td>(2,554)</td></tr><tr><td>Net cash used for investing activities</td><td>(21,339)</td><td>(157,583)</td><td>(355,349)</td></tr><tr><td>FINANCING ACTIVITIES</td><td></td><td></td><td></td></tr><tr><td>Payment of dividends</td><td>(10,861)</td><td>(33,602)</td><td>(91,608)</td></tr><tr><td>Borrowings from notes payable to banks</td><td>—</td><td>613,300</td><td>1,168,100</td></tr><tr><td>Repayments of notes payable to banks</td><td>—</td><td>(837,800)</td><td>(996,900)</td></tr><tr><td>Debt issue costs for notes payable to banks</td><td>(35)</td><td>—</td><td>(667)</td></tr><tr><td>Excess tax benefits for share-based payments</td><td>427</td><td>1,410</td><td>4,336</td></tr><tr><td>Cash paid for common stock purchased and retired</td><td>(3,257)</td><td>(4,093)</td><td>(49,597)</td></tr><tr><td>Net cash (used for) provided by financing activities</td><td>(13,726)</td><td>(260,785)</td><td>33,664</td></tr><tr><td>Net increase in cash and cash equivalents</td><td>66,639</td><td>55,424</td><td>1,072</td></tr><tr><td>Cash and cash equivalents at beginning of year</td><td>65,196</td><td>9,772</td><td>8,700</td></tr><tr><td>Cash and cash equivalents at end of year</td><td>$ 131,835</td><td>$ 65,196</td><td>$ 9,772</td></tr></table>

The accompanying notes are an integral part of these statements.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

## Note 1: Significant Accounting Policies

## Principles of Consolidation and Basis of Presentation

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

## Nature of Operations

RPC provides a broad range of specialized oilfield services and equipment primarily to independent and major oil and gas companies engaged in the exploration, production and development of oil and gas properties throughout the United States of America, including the southwest, mid-continent, Gulf of Mexico, Rocky Mountain and Appalachian regions, and in selected international markets. The services and equipment provided include Technical Services such as pressure pumping services, coiled tubing services, snubbing services (also referred to as hydraulic worker services), nitrogen services, and firefighting and well control, and Support Services such as the rental of drill pipe and other specialized oilfield equipment and oilfield training and consulting.

## Common Stock

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

## Preferred Stock

RPC is authorized to issue up to 1,000,000 shares of preferred stock, $0.10 par value. As of December 31, 2016, there were no shares of preferred stock issued. The Board of Directors is authorized, subject to any limitations prescribed by law, to provide for the issuance of preferred stock as a class without series or, if so determined from time to time, in one or more series, and by filing a certificate pursuant to the applicable laws of the state of Delaware and to fix the designations, powers, preferences and rights, exchangeability for shares of any other class or classes of stock. Any preferred stock to be issued could rank prior to the common stock with respect to dividend rights and rights on liquidation.

## Dividends

On July 28, 2015, the Board of Directors voted to temporarily suspend RPC’s regular quarterly dividend to common stockholders. However, the Company paid a special year-end cash dividend of $0.05 per share to common stockholders during the fourth quarter of 2016.

## Use of Estimates in the Preparation of Financial Statements

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

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

## Revenues

RPC’s revenues are generated principally from providing services and the related equipment. Revenues are recognized when the services are rendered and collectibility is reasonably assured. Revenues from services and equipment are based on fixed or determinable priced purchase orders or contracts with the customer and do not include the right of return. Rates for services and equipment are priced on a per day, per unit of measure, per man



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

hour or similar basis. Sales tax charged to customers is presented on a net basis within the consolidated statements of operations and excluded from revenues.

## Concentration of Credit Risk

Substantially all of the Company’s customers are engaged in the oil and gas industry. This concentration of customers may impact overall exposure to credit risk, either positively or negatively, in that customers may be similarly affected by changes in economic and industry conditions. The Company provided oilfield services to several hundred customers during each of the last three years. There were no customers that accounted for more than 10 percent of the Company’s revenues in 2016 and 2014; and one customer accounted for approximately 23 percent of revenues in 2015. Additionally, there were no customers that accounted for more than 10 percent of accounts receivable as of December 31, 2016 and one customer accounted for approximately 14 percent of accounts receivable as of December 31, 2015.

## Cash and Cash Equivalents

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

## Investments

Investments classified as available-for-sale securities are stated at their fair values, with the unrealized gains and losses, net of tax, reported as a separate component of stockholders' equity. The cost of securities sold is based on the specific identification method. Realized gains and losses, declines in value judged to be other than temporary, interest, and dividends with respect to available-for-sale securities are included in interest income. The Company realized no gains or losses on its available-for-sale securities during 2016 and 2014, and an immaterial realized loss during 2015. Securities that are held in the non-qualified Supplemental Executive Retirement Plan (“SERP”) are classified as trading. See Note 10 for further information regarding the SERP. The change in fair value of trading securities is presented as compensation cost in selling, general and administrative expenses on the consolidated statements of operations.

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

## Accounts Receivable

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

## Allowance for Doubtful Accounts

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

## Inventories

Inventories, which consist principally of (i) raw materials and supplies that are consumed providing services to the Company’s customers, (ii) spare parts for equipment used in providing these services and (iii) components and attachments for manufactured equipment used in providing services, are recorded at the lower of cost or market value. Cost is determined using first-in, first-out (“FIFO”) method or the weighted average cost method. Market



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

value is determined based on replacement cost for materials and supplies. The Company regularly reviews inventory quantities on hand and records a write-down for excess or obsolete inventory based primarily on its estimated forecast of product demand, market conditions, production requirements and technological developments.

## Property, Plant and Equipment

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

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

## Goodwill

Goodwill represents the excess of the purchase price over the fair value of net assets of businesses acquired. The carrying amount of goodwill was $32,150,000 at December 31, 2016 and 2015. 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 light of the operating losses for the years ended December 31, 2016 and 2015, the Company proceeded to step 1 of the goodwill impairment test at the annual test date in 2016. The Company estimated the fair value of each of its reporting unit using a discounted cash flow analysis based on management’s short-term and long-term forecast of operating results. The discounted cash flow analysis for each reporting unit includes assumptions regarding discount rates, revenue growth rates, expected profitability margins, forecasted capital expenditures, the timing of an anticipated market recovery and the timing of expected future cash flows. Based on the analysis, the Company concluded that the fair value of its reporting units exceeded their carrying amount and therefore no impairment of goodwill occurred for the year ended December 31, 2016. The Company completed on an annual basis a comprehensive qualitative assessment of the various factors that impact goodwill for the years ended December 31, 2015 and 2014, and concluded it is more likely than not that the fair value of its reporting units exceeded their carrying amounts as of the annual test date. Therefore, the Company did not proceed to Step 1 of the goodwill impairment test in 2015 and 2014. Based on the qualitative assessment in 2015 and 2014, the Company concluded that no impairment of its goodwill occurred for the years ended December 31, 2015 and 2014.

## Advertising

Advertising expenses are charged to expense during the period in which they are incurred. Advertising expenses totaled $1,296,000 in 2016, $2,058,000 in 2015, and $3,959,000 in 2014.

## 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.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

## Income Taxes

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

## Defined Benefit Pension Plan

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

## Share Repurchases

The Company records the cost of share repurchases in stockholders' equity as a reduction to common stock to the extent of par value of the shares acquired and the remainder is allocated to capital in excess of par value and retained earnings if capital in excess of par value is depleted. The Company tracks capital in excess of par value on a cumulative basis and at each reporting period, discloses the excess over capital in excess of par value as part of stock purchased and retired in the consolidated statements of stockholders' equity.

## Earnings per Share

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

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

Restricted shares of common stock (participating securities) outstanding and a reconciliation of weighted average shares outstanding is as follows:

<table><tr><td>(In thousands except per share data)</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>Net (loss) income available for stockholders</td><td>$ (141,246)</td><td>$ (99,561)</td><td>$ 245,193</td></tr><tr><td>Less: Adjustments for losses attributable to participating securities</td><td>(147)</td><td>(240)</td><td>(3,913)</td></tr><tr><td>Net loss used in calculating losses per share</td><td>$ (141,393)</td><td>$ (99,801)</td><td>$ 241,280</td></tr><tr><td>Weighted average shares outstanding (including participating securities)</td><td>217,509</td><td>213,632</td><td>214,840</td></tr><tr><td>Adjustment for participating securities</td><td>(3,282)</td><td>(3,359)</td><td>(3,632)</td></tr><tr><td>Shares used in calculating basic losses per share</td><td>214,227</td><td>210,273</td><td>211,208</td></tr><tr><td>Dilutive effect of stock based awards</td><td>—</td><td>—</td><td>1,049</td></tr><tr><td>Shares used in calculating diluted losses per share</td><td>214,227</td><td>210,273</td><td>212,257</td></tr></table>

## Fair Value of Financial Instruments

The Company’s financial instruments consist primarily of cash and cash equivalents, accounts receivable, investments, accounts payable, and debt. The carrying value of cash and cash equivalents, accounts receivable and accounts payable approximate their fair value due to the short-term nature of such instruments. The Company’s investments are classified as available-for-sale securities with the exception of investments held in the non-qualified



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

Supplemental Executive Retirement Plan (“SERP”) which are classified as trading securities. All of these securities are carried at fair value in the accompanying consolidated balance sheets. See Note 8 for additional information.

## Stock-Based Compensation

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

## Recent Accounting Pronouncements

During the year ended December 31, 2016, the Financial Accounting Standards Board (FASB) issued the following applicable Accounting Standards Updates (ASUs):

## Recently Adopted Accounting Pronouncements:

- ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments. The amendments eliminate the requirement to retrospectively account for adjustments made to provisional amounts recognized in a business combination. Adjustments to provisional amounts that are identified during the measurement period are required to be recognized in the reporting period in which the adjustments are determined and calculated as if the accounting had been completed at the acquisition date and either disclosed on the face of the income statement or in the notes by each category. The Company adopted these provisions in the first quarter of 2016 and plans to apply the provisions for all future business combinations. The adoption did not have a material impact on the Company’s consolidated financial statements.

- ASU No. 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent). The amendments remove the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share (or its equivalent) practical expedient. In addition, there is no requirement to make certain disclosures for such investments. The Company adopted these provisions in the first quarter of 2016 applied retrospectively and has excluded the pension assets that are measured using the net asset value per share from the fair value hierarchy disclosure. The adoption did not have a material impact on the Company’s consolidated financial statements.

- ASU No. 2014-15, Presentation of Financial Statements — Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. Financial statements are generally prepared under the presumption that the reporting organization will continue to operate as a going concern, except in limited circumstances. This ASU provides guidance on management’s responsibility to include footnote disclosures when there is substantial doubt about the organization’s ability to continue as a going concern. The Company adopted these provisions in the first quarter of 2016 and will provide such disclosures as required if there are conditions and events that raise substantial doubt about its ability to continue as a going concern. The adoption did not have a material impact on the Company’s consolidated financial statements.

## Recently Issued Accounting Pronouncements Not Yet Adopted:

## To be adopted in 2017:

- ASU No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. Current requirements are to measure inventory at the lower of cost or market. Market could be replacement cost, net realizable value, or net realizable value less an approximated normal profit margin. These amendments allow inventory to be measured at lower of cost or net realizable value and eliminates the market requirement. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The amendments do not apply to inventory that is measured using last-in, first-out or the retail inventory method. The amendments will be adopted in the first quarter of 2017 and applied prospectively. The Company does not expect the adoption of these provisions to have a material impact on its consolidated financial statements.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

- ASU No. 2016-07, Investments — Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting. The amendments eliminate the requirement to adjust the investment, results of operations, and retained earnings retroactively when an investment qualifies for use of the equity method as a result of an increase in the level of ownership interest or degree of influence. The cost of acquiring the additional interest in the investee is to be added to the current basis of the investor's previously held interest and the equity method is to be adopted as of the date the investment qualifies. In addition, an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting is required to recognize through earnings the unrealized holding gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. The amendments will be adopted in the first quarter of 2017 and applied prospectively. The Company does not expect the adoption of these provisions to have a material impact on its consolidated financial statements.

- ASU No. 2016-09, Compensation — Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The amendments simplify several aspects of the accounting for share-based payment award transactions, requiring excess tax benefits and deficiencies to be recognized as a component of income tax expense rather than equity. This guidance also requires excess tax benefits and deficiencies to be presented as an operating activity on the statement of cash flows and allows an entity to make an accounting policy election to either estimate expected forfeitures or to account for them as they occur. The Company will adopt these provisions in the first quarter of 2017 and adoption of these provisions will result in the inclusion of excess tax benefits and deficiencies as a component of income tax expense which may increase volatility of the provision for income taxes as the amount of excess tax benefits or deficiencies from stock-based compensation awards are dependent on the Company’s stock price as of the date the stock awards vest. Based on the Company’s current stock price and its stock incentive plan awards, this change resulted in a beneficial adjustment of approximately $2.5 million to the provision for income taxes in the first quarter of 2017. The Company will continue to estimate expected forfeitures.

- ASU No. 2016-17, Consolidation (Topic 810): Interests Held through Related Parties That are under Common Control. The amendments affect reporting entities that are required to evaluate whether they should consolidate a variable interest entity in certain situations involving entities under common control. Specifically, the amendments change the evaluation of whether a reporting entity is the primary beneficiary of a variable interest entity by changing how a reporting entity that is a single decision maker of a variable interest entity treats indirect interests in the entity held through related parties that are under common control with the reporting entity. The amendments will be adopted in the first quarter of 2017 and the Company does not expect the adoption to have a material impact on its consolidated financial statements.

## To be adopted in 2018:

## REVENUE RECOGNITION:

The Financial Accounting Standards Board and International Accounting Standards Board issued their converged standard on revenue recognition in May 2014. The standard provides a comprehensive, industry-neutral revenue recognition model intended to increase financial statement comparability across companies and industries and significantly reduce the complexity inherent in today’s revenue recognition guidance. The various ASUs related to Revenue from Contracts with Customers (Topic 606) have been listed below:

- ASU No. 2014-09. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services using a five step process.

- ASU No. 2015-14. Deferred the effective date of ASU 2014-09 for all entities by one year to the first quarter of 2018 with early application permitted.

- ASU No. 2016-08, Principal versus Agent Considerations (Reporting Revenue Gross versus Net). The amendments provide guidance on whether an entity is a principal or agent when providing services to a customer along with another party.

- ASU No. 2016-10, Identifying Performance Obligations and Licensing. The amendments clarify the earlier guidance on identifying performance obligations and licensing implementation.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

- ASU No. 2016-11, Rescission of SEC Guidance Because of ASUs 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting. This ASU rescinds certain SEC guidance related to issues that are currently codified under various topics.

- ASU No. 2016-12, Narrow-Scope Improvements and Practical Expedients. The amendments provide clarifying guidance on certain aspects of the five step process and practical expedients regarding the effect of modifications and status of completed contracts under legacy GAAP and disclosures related to the application of this guidance using the modified retrospective or retrospective transition method.

- ASU No. 2016-20, Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers. The amendments in ASU 2016-20 affect narrow aspects of the guidance issued in ASU 2014-09 and includes among others, loan guarantees, impairment testing of contract costs, performance obligations disclosures and accrual of advertising costs.

Current Status of Implementation:

The Company is currently analyzing the effect of the standard across all of its revenue streams to evaluate the impact of the new standard on revenue contracts. This includes reviewing current accounting policies and practices to identify potential differences that would result from applying the requirements under the new standard. Most of the Company’s services are primarily short-term in nature, and the assessment at this stage is that the Company does not expect the adoption of the new revenue recognition standard to have a material impact on its financial statements. The Company plans to adopt the standard in the first quarter of 2018 using the modified retrospective method by recognizing the cumulative effect of initially applying the new standard as an adjustment to the opening balance of retained earnings.

- ASU No. 2016-01, Financial Instruments – Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities. The amendments make targeted improvements to existing U.S. GAAP and affects accounting for equity investments and financial instruments and liabilities and related disclosures. The amendments are effective starting in the first quarter of 2018, with early adoption permitted for certain provisions. The Company is currently evaluating the impact of these provisions on its consolidated financial statements.

- ASU No. 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. The amendments provide guidance in the presentation and classification of certain cash receipts and cash payments in the statement of cash flows including debt prepayment or debt extinguishment costs, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate-owned life insurance policies, and distributions received from equity method investees. The amendments are effective starting in the first quarter of 2018 with early adoption permitted. The amendments should be applied using a retrospective transition method to each period presented. If it is impracticable to apply the amendments retrospectively for some of the issues, the amendments for those issues would be applied prospectively as of the earliest date practicable. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

- ASU No. 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory. The amendments require an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. The amendments eliminate the exception for an intra-entity transfer of an asset other than inventory. Two common examples of assets included in the scope of the amendments are intellectual property and property, plant, and equipment. The amendments do not include new disclosure requirements; however, existing disclosure requirements might be applicable when accounting for the current and deferred income taxes for an intra-entity transfer of an asset other than inventory. The amendments are effective starting in the first quarter of 2018 with early adoption permitted. The amendments are required to be applied on a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

- ASU No. 2016-18, Statement of Cash Flows (230): Restricted Cash. The amendments require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. As a result, amounts generally described as



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The amendments do not provide a definition of restricted cash or restricted cash equivalents. The amendments are effective starting in the first quarter of 2018 with early adoption permitted. The amendments should be applied using a retrospective transition method to each period presented. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

## To be adopted in 2019 and later:

- ASU No. 2016-02, Leases (Topic 842). Under the new guidance, lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease), at the commencement of the lease term. The liability will be equal to the present value of lease payments. The asset will be based on the liability, subject to adjustment, such as for initial direct costs. The amendments in this standard are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early application is permitted. Lessees (for capital and operating leases) and lessors (for sales-type, direct financing, and operating leases) must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. Lessees and lessors may not apply a full retrospective transition approach. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

- ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments require that credit losses on available-for-sale debt securities and purchased financial assets with credit deterioration should be presented as an allowance rather than a write-down. It also allows recording of credit loss reversals in current period net income. The amendments are effective in the first quarter of 2020 with early application permitted a year earlier. The Company is currently evaluating the impact of adopting these provisions on its consolidated financial statements.

## Note 2: Accounts Receivable

Accounts receivable, net consists of the following:

<table><tr><td>December 31,</td><td>2016</td><td>2015</td></tr><tr><td>(in thousands)</td><td></td><td></td></tr><tr><td>Trade receivables:</td><td></td><td></td></tr><tr><td>Billed</td><td>$ 122,216</td><td>$ 190,567</td></tr><tr><td>Unbilled</td><td>39,223</td><td>40,731</td></tr><tr><td>Other receivables</td><td>10,280</td><td>11,494</td></tr><tr><td>Total</td><td>171,719</td><td>242,792</td></tr><tr><td>Less: allowance for doubtful accounts</td><td>(2,553)</td><td>(10,605)</td></tr><tr><td>Accounts receivable, net</td><td>$ 169,166</td><td>$ 232,187</td></tr></table>

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

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

<table><tr><td>Years Ended December 31,</td><td>2016</td><td>2015</td></tr><tr><td>(in thousands)</td><td></td><td></td></tr><tr><td>Beginning balance</td><td>$ 10,605</td><td>$ 15,351</td></tr><tr><td>Bad debt expense (reduction)</td><td>6,021</td><td>(2,958)</td></tr><tr><td>Accounts written-off</td><td>(14,101)</td><td>(2,825)</td></tr><tr><td>Recoveries</td><td>28</td><td>1,037</td></tr><tr><td>Ending balance</td><td>$ 2,553</td><td>$ 10,605</td></tr></table>



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

## Note 3: Inventories

Inventories are $108,316,000 at December 31, 2016 and $128,441,000 at December 31, 2015 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:

<table><tr><td>December 31,</td><td>2016</td><td>2015</td></tr><tr><td>(in thousands)</td><td></td><td></td></tr><tr><td>Land</td><td>$ 19,070</td><td>$ 19,056</td></tr><tr><td>Buildings and leasehold improvements</td><td>142,741</td><td>142,715</td></tr><tr><td>Operating equipment</td><td>1,432,007</td><td>1,440,508</td></tr><tr><td>Computer software</td><td>22,050</td><td>19,650</td></tr><tr><td>Furniture and fixtures</td><td>8,056</td><td>8,043</td></tr><tr><td>Vehicles</td><td>469,570</td><td>480,899</td></tr><tr><td>Construction in progress</td><td>—</td><td>6</td></tr><tr><td>Gross property, plant and equipment</td><td>2,093,494</td><td>2,110,877</td></tr><tr><td>Less: accumulated depreciation</td><td>(1,595,508)</td><td>(1,422,542)</td></tr><tr><td>Net property, plant and equipment</td><td>$ 497,986</td><td>$ 688,335</td></tr></table>

Depreciation expense was $220.6 million in 2016, $274.4 million in 2015, and $233.4 million in 2014, and includes amounts recorded as costs of revenues and inventory. There were no capital leases outstanding as of December 31, 2016 and December 31, 2015. The Company had accounts payable for purchases of property and equipment of $3.4 million as of December 31, 2016, $2.4 million as of December 31, 2015, and $38.5 million as of December 31, 2014.

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

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



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

## Note 5: Income Taxes

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

<table><tr><td>Years ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>(in thousands)</td><td></td><td></td><td></td></tr><tr><td>Current (benefit) provision:</td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>$ (43,993)</td><td>$ (24,727)</td><td>$ 119,074</td></tr><tr><td>State</td><td>(24,479)</td><td>(3,638)</td><td>19,858</td></tr><tr><td>Foreign</td><td>4,567</td><td>7,898</td><td>2,907</td></tr><tr><td>Deferred (benefit) provision:</td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>(31,505)</td><td>(31,178)</td><td>11,514</td></tr><tr><td>State</td><td>(2,704)</td><td>(1,835)</td><td>840</td></tr><tr><td>Total income tax (benefit) provision</td><td>$ (98,114)</td><td>$ (53,480)</td><td>$ 154,193</td></tr></table>

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

<table><tr><td>Years ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>Federal statutory rate</td><td>35.0%</td><td>35.0%</td><td>35.0%</td></tr><tr><td>State income taxes, net of federal benefit</td><td>1.3</td><td>—</td><td>3.3</td></tr><tr><td>Tax credits</td><td>0.1</td><td>0.3</td><td>(0.7)</td></tr><tr><td>Non-deductible expenses</td><td>(0.7)</td><td>(1.3)</td><td>0.4</td></tr><tr><td>Change in contingencies</td><td>6.6</td><td>—</td><td>—</td></tr><tr><td>Other</td><td>(1.3)</td><td>0.9</td><td>0.6</td></tr><tr><td>Effective tax rate</td><td>41.0%</td><td>34.9%</td><td>38.6%</td></tr></table>

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

<table><tr><td>December 31,</td><td>2016</td><td>2015</td></tr><tr><td>(in thousands)</td><td></td><td></td></tr><tr><td>Deferred tax assets:</td><td></td><td></td></tr><tr><td>Self-insurance</td><td>$ 5,907</td><td>$ 7,274</td></tr><tr><td>Pension</td><td>11,995</td><td>12,048</td></tr><tr><td>State net operating loss carryforwards</td><td>1,455</td><td>370</td></tr><tr><td>Bad debt</td><td>991</td><td>4,041</td></tr><tr><td>Accrued payroll</td><td>857</td><td>1,330</td></tr><tr><td>Stock-based compensation</td><td>5,847</td><td>5,885</td></tr><tr><td>All others</td><td>2,483</td><td>4,704</td></tr><tr><td>Valuation allowance</td><td>(356)</td><td>(276)</td></tr><tr><td>Gross deferred tax assets</td><td>29,179</td><td>35,376</td></tr><tr><td>Deferred tax liabilities:</td><td></td><td></td></tr><tr><td>Depreciation</td><td>(95,606)</td><td>(137,606)</td></tr><tr><td>Goodwill amortization</td><td>(9,340)</td><td>(8,887)</td></tr><tr><td>Basis differences in variable interest entities</td><td>(5,281)</td><td>(4,876)</td></tr><tr><td>Basis differences in joint ventures</td><td>(396)</td><td>518</td></tr><tr><td>All others</td><td>(22)</td><td>(20)</td></tr><tr><td>Gross deferred tax liabilities</td><td>(110,645)</td><td>(150,871)</td></tr><tr><td>Net deferred tax liabilities</td><td>$ (81,466)</td><td>$ (115,495)</td></tr></table>

As of December 31, 2016, undistributed earnings of the Company’s foreign subsidiaries totaled $10.2 million. Additional U.S. taxes due upon full repatriation would be negligible. However, those earnings are considered to be indefinitely reinvested and, accordingly, no U.S. federal and state income taxes have been provided thereon. Upon distribution of these earnings in the form of dividends or otherwise, the Company would be subject to both U.S. income taxes and withholding taxes payable to the foreign countries. The Company’s current intention is to permanently reinvest funds held in our foreign subsidiaries outside of the U.S., with the possible exception of repatriation of funds that have been previously subject to U.S. federal and state taxation or when it would be tax effective through the utilization of foreign tax credits, or would otherwise create no additional U.S. tax cost.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

As of December 31, 2016, the Company has net operating loss carryforwards related to state income taxes of approximately $33.5 million that will expire between 2017 and 2035. As of December 31, 2016, the Company has a valuation allowance of approximately $356 thousand, 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 (refunds) payments were $(42.4) million in 2016, $(7.9) million in 2015, and $152.2 million in 2014.

The Company and its subsidiaries are subject to U.S. federal and state income taxes in multiple jurisdictions. In many cases our uncertain tax positions are related to tax years that remain open and subject to examination by the relevant taxing authorities. The Company’s 2013 through 2016 tax years remain open to examination. Additional years may be open to the extent attributes are being carried forward to an open year.

The Company’s subsidiaries are also subject to foreign income taxes in certain jurisdictions. In November 2016, the Canadian Revenue Agency (CRA) initiated an examination of the Company’s Canadian subsidiary for the periods 2013 – 2015. As of December 31, 2016, the CRA has not proposed any adjustments in connection with this examination.

During 2016, the Company recognized a decrease in its liability for unrecognized tax benefits in the current year related primarily due to settlements with state tax authorities. The remaining liability, if recognized, would affect our effective rate. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:

<table><tr><td></td><td>2016</td><td>2015</td></tr><tr><td>Balance at January 1</td><td>$ 26,152,000</td><td>$ 23,267,000</td></tr><tr><td>Additions based on tax positions related to the current year</td><td>0</td><td>2,171,000</td></tr><tr><td>Additions for tax positions of prior years</td><td>0</td><td>714,000</td></tr><tr><td>Reductions for tax positions of prior years</td><td>(23,937,000)</td><td>0</td></tr><tr><td>Balance at December 31</td><td>$ 2,215,000</td><td>$ 26,152,000</td></tr></table>

The Company’s policy is to record interest and penalties related to income tax matters as income tax expense. Accrued interest and penalties as of December 31, 2016 and 2015 were approximately $76 thousand and $411 thousand, respectively.

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

## Note 6: Long-Term Debt

The Company has a revolving credit facility with Bane of America Securities, LLC, SunTrust Robinson Humphrey, Inc., and Regions Capital Markets as Joint Lead Arrangers and Joint Book Managers, and a syndicate of four other lenders. The facility has a general term of five years ending January 17, 2019 and provides for a line of credit of up to $125 million, including a $50 million letter of credit subfacility, and a $35 million swingline subfacility. The revolving credit facility contains customary terms and conditions, including restrictions on indebtedness, dividend payments, business combinations and other related items. The revolving credit facility includes a full and unconditional guarantee by the Company’s 100 percent owned domestic subsidiaries whose assets equal substantially all of the consolidated assets of the Company and its subsidiaries. Certain of the Company’s minor subsidiaries are not guarantors.

On June 30, 2016, the Company amended the revolving credit facility to (1) establish a borrowing base to be the lesser of (a) $125 million or (b) the difference between (i) a specified percentage (ranging from 70% to 80%) of eligible accounts receivable less (ii) the amount of any outstanding letters of credit, (2) secure payment obligations under the credit facility with a security interest in the consolidated accounts receivable, and (3) replace the financial covenants related to minimum leverage and debt service coverage ratios with a covenant to maintain a minimum tangible net worth of not less than $700 million. As of December 31, 2016, the Company was in compliance with this covenant.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

Revolving loans under the amended revolving credit facility bear interest at one of the following two rates at the Company’s election:

- the Base Rate, which is a fluctuating rate per annum equal to the highest of (a) the Federal Funds Rate plus 0.50%, (b) Bank of America’s publicly announced “prime rate,” and (c) the Eurodollar Rate plus 1.00%; in each case plus a margin that ranges from 0.125% to 1.125% based on a quarterly consolidated leverage ratio calculation; or

- the Eurodollar Rate, which is the rate per annum equal to the London Interbank Offering Rate (“LIBOR”); plus, a margin ranging from 1.125% to 2.125%, based upon a quarterly debt covenant calculation.

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

The Company has incurred loan origination fees and other debt related costs associated with the revolving credit facility in the aggregate of approximately $3.0 million. These costs, net of amounts written off as a result of a reduction in the size of the revolving credit facility in 2015, are being amortized to interest expense over the remaining term of the five-year loan, and the remaining net balance of $0.2 million at December 31, 2016 is classified as part of non-current other assets.

On January 4, 2016, the Company entered into a separate one year $35 million uncommitted letter of credit facility with Bank of America, N.A. Under the terms of the letter of credit facility, the Company paid 0.75% per annum on outstanding letters of credit. This letter of credit facility expired on January 3, 2017. All letters of credit are currently issued under RPC’s $125 million credit facility. Letters of credit outstanding totaled $19.1 million as of December 31, 2016 and $29.3 million as of December 31, 2015.

As of December 31, 2016, RPC had no outstanding borrowings under the revolving credit facility. Interest incurred and paid on the credit facility, interest capitalized related to facilities and equipment under construction, and the related weighted average interest rates were as follows for the periods indicated:

<table><tr><td>Years Ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>(in thousands except interest rate data)</td><td></td><td></td><td></td></tr><tr><td>Interest incurred</td><td>$ 449</td><td>$ 1,913</td><td>$ 2,295</td></tr><tr><td>Capitalized interest</td><td>$ —</td><td>$ 534</td><td>$ 563</td></tr><tr><td>Interest paid (net of capitalized interest)</td><td>$ 284</td><td>$ 1,169</td><td>$ 1,314</td></tr><tr><td>Weighted average interest rate</td><td>—%</td><td>2.2%</td><td>2.2%</td></tr></table>



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

## Note 7: Accumulated Other Comprehensive (Loss) Income

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

<table><tr><td></td><td>Pension Adjustment</td><td>Unrealized Gain (Loss) On Securities</td><td>Foreign Currency Translation</td><td>Total</td></tr><tr><td>Balance at December 31, 2014</td><td>$ (16,246)</td><td>$ (98)</td><td>$ (1,489)</td><td>$ (17,833)</td></tr><tr><td>Change during 2015:</td><td></td><td></td><td></td><td></td></tr><tr><td>Before-tax amount</td><td>1,621</td><td>(16)</td><td>(1,801)</td><td>(196)</td></tr><tr><td>Tax (expense) benefit</td><td>(592)</td><td>6</td><td>—</td><td>(586)</td></tr><tr><td>Reclassification adjustment, net of taxes:</td><td></td><td></td><td></td><td></td></tr><tr><td>Realized loss on securities</td><td>—</td><td>144</td><td>—</td><td>144</td></tr><tr><td>Amortization of net loss (1)</td><td>502</td><td>—</td><td>—</td><td>502</td></tr><tr><td>Total activity in 2015</td><td>1,531</td><td>134</td><td>(1,801)</td><td>(136)</td></tr><tr><td>Balance at December 31, 2015</td><td>(14,715)</td><td>36</td><td>(3,290)</td><td>(17,969)</td></tr><tr><td>Change during 2016:</td><td></td><td></td><td></td><td></td></tr><tr><td>Before-tax amount</td><td>(2,039)</td><td>5</td><td>652</td><td>(1,382)</td></tr><tr><td>Tax (expense) benefit</td><td>744</td><td>(2)</td><td>—</td><td>742</td></tr><tr><td>Reclassification adjustment, net of taxes:</td><td></td><td></td><td></td><td></td></tr><tr><td>Realized loss on securities</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Amortization of net loss (1)</td><td>507</td><td>—</td><td>—</td><td>507</td></tr><tr><td>Total activity in 2016</td><td>(788)</td><td>3</td><td>652</td><td>(133)</td></tr><tr><td>Balance at December 31, 2016</td><td>$ (15,503)</td><td>$ 39</td><td>$ (2,638)</td><td>$ (18,102)</td></tr></table>

(1) Reported as part of selling, general and administrative expenses.

## 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.

2. 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, 2016 and 2015:

<table><tr><td rowspan="2"></td><td rowspan="2">Total</td><td colspan="4">Fair Value Measurements at December 31, 2016 with:</td></tr><tr><td>Quoted prices in active markets for identical assets (Level 1)</td><td>Significant other observable inputs (Level 2)</td><td>Significant unobservable inputs (Level 3)</td><td></td></tr><tr><td>(in thousands)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Assets:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Available-for-sale securities - equity securities ...</td><td>$ 264</td><td>$ 264</td><td>$ —</td><td>$ —</td><td></td></tr><tr><td>Investments measured at net asset value - trading securities</td><td>$ 18,367</td><td></td><td></td><td></td><td></td></tr></table>



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

<table><tr><td rowspan="2"></td><td colspan="4">Fair Value Measurements at December 31, 2015 with:</td></tr><tr><td>Quoted prices in active markets for identical assets (Level 1)</td><td>Significant other observable inputs (Level 2)</td><td>Significant unobservable inputs (Level 3)</td><td></td></tr><tr><td>(in thousands)</td><td>Total</td><td></td><td></td><td></td></tr><tr><td>Assets:</td><td></td><td></td><td></td><td></td></tr><tr><td>Available-for-sale securities - equity securities</td><td>$ 259</td><td>$ 259</td><td>$ —</td><td>$ —</td></tr><tr><td>Investments measured at net asset value - trading securities</td><td>$ 16,081</td><td></td><td></td><td></td></tr></table>

The Company determines the fair value of marketable securities classified as available-for-sale through quoted market prices. The total fair value is the final closing price, as defined by the exchange in which the asset is actively traded, on the last trading day of the period, multiplied by the number of units held without consideration of transaction costs. Marketable securities classified as trading are comprised of the SERP assets, as described in Note 10, and are recorded primarily at their net cash surrender values, calculated using their net asset values, which approximates fair value, as provided by the issuing insurance company. Significant observable inputs, in addition to quoted market prices, were used to value the trading securities. The Company’s policy is to recognize transfers between levels at the beginning of quarterly reporting periods. For the year ended December 31, 2016 there were no significant transfers in or out of levels 1, 2 or 3.

Under the Company’s revolving credit facility, there was no balance outstanding at December 31, 2016 and 2015. Outstanding balances based on the quote from the lender (level 2 inputs) is similar to the fair value at the same date. The borrowings under our revolving credit facility bear variable interest rates as described in Note 6. The Company is subject to interest rate risk on the variable component of the interest rate.

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

## Note 9: Commitments and Contingencies

Lease Commitments - Minimum annual rentals, principally for noncancelable real estate and equipment leases with terms in excess of one year, in effect at December 31, 2016, are summarized in the following table:

<table><tr><td>(in thousands)</td><td></td></tr><tr><td>2017</td><td>$ 10,267</td></tr><tr><td>2018</td><td>10,280</td></tr><tr><td>2019</td><td>7,797</td></tr><tr><td>2020</td><td>4,786</td></tr><tr><td>2021</td><td>3,288</td></tr><tr><td>Thereafter</td><td>4,195</td></tr><tr><td>Total rental commitments</td><td>$ 40,613</td></tr></table>

Total rental expense, including short-term rentals, charged to operations was $15,723,000 in 2016, $20,658,000 in 2015, and $22,968,000 in 2014.

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.

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

Litigation - RPC is a party to various routine legal proceedings primarily involving commercial claims, workers’ compensation claims and claims for personal injury. RPC insures against these risks to the extent deemed prudent by its management, but no assurance can be given that the nature and amount of such insurance will, in every case, fully indemnify RPC against liabilities arising out of pending and future legal proceedings related to its



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

business activities. While the outcome of these lawsuits, legal proceedings and claims cannot be predicted with certainty, management, after consultation with legal counsel, believes that it is not reasonably possible that the outcome of all such proceedings, even if determined adversely, would have a material adverse effect on the Company’s business or financial condition.

## Note 10: Employee Benefit Plans

## Defined Benefit Pension Plan

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

The Company’s projected benefit obligation exceeds the fair value of the plan assets under its pension plan by $9.6 million and thus the plan was under-funded as of December 31, 2016. The following table sets forth the funded status of the Retirement Income Plan and the amounts recognized in RPC’s consolidated balance sheets:

<table><tr><td>December 31, (in thousands)</td><td>2016</td><td>2015</td></tr><tr><td>Accumulated benefit obligation at end of year</td><td>$ 44,315</td><td>$ 42,894</td></tr><tr><td>CHANGE IN PROJECTED BENEFIT OBLIGATION:</td><td></td><td></td></tr><tr><td>Benefit obligation at beginning of year</td><td>$ 42,894</td><td>$ 47,410</td></tr><tr><td>Service cost</td><td>—</td><td>—</td></tr><tr><td>Interest cost</td><td>2,006</td><td>1,898</td></tr><tr><td>Amendments</td><td>—</td><td>—</td></tr><tr><td>Actuarial loss (gain)</td><td>1,371</td><td>(4,593)</td></tr><tr><td>Benefits paid</td><td>(1,956)</td><td>(1,821)</td></tr><tr><td>Projected benefit obligation at end of year</td><td>$ 44,315</td><td>$ 42,894</td></tr><tr><td>CHANGE IN PLAN ASSETS:</td><td></td><td></td></tr><tr><td>Fair value of plan assets at beginning of year</td><td>$ 30,937</td><td>$ 32,622</td></tr><tr><td>Actual return on plan assets</td><td>1,464</td><td>(714)</td></tr><tr><td>Employer contribution</td><td>4,300</td><td>850</td></tr><tr><td>Benefits paid</td><td>(1,956)</td><td>(1,821)</td></tr><tr><td>Fair value of plan assets at end of year</td><td>$ 34,745</td><td>$ 30,937</td></tr><tr><td>Funded status at end of year</td><td>$ (9,570)</td><td>$ (11,957)</td></tr><tr><td>December 31, (in thousands)</td><td>2016</td><td>2015</td></tr><tr><td>AMOUNTS (PRE-TAX) RECOGNIZED IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) CONSIST OF:</td><td></td><td></td></tr><tr><td>Net loss (gain)</td><td>$ 24,412</td><td>$ 23,172</td></tr><tr><td>Prior service cost (credit)</td><td>—</td><td>—</td></tr><tr><td>Net transition obligation (asset)</td><td>—</td><td>—</td></tr><tr><td></td><td>$ 24,412</td><td>$ 23,172</td></tr></table>

The accumulated benefit obligation for the Retirement Income Plan at December 31, 2016 and 2015 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:

<table><tr><td>December 31,</td><td>2016</td><td>2015</td></tr><tr><td>(in thousands)</td><td></td><td></td></tr><tr><td>Funded status of the Retirement Income Plan</td><td>$ (9,570)</td><td>$ (11,957)</td></tr><tr><td>SERP liability</td><td>(23,294)</td><td>(21,052)</td></tr><tr><td>Long-term pension liabilities</td><td>$ (32,864)</td><td>$ (33,009)</td></tr></table>



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

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. Amounts contributed to the plan totaled $4,300,000 in 2016 and $850,000 in 2015.

The components of net periodic benefit cost of the Retirement Income Plan are summarized as follows:

<table><tr><td>Years ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>(in thousands)</td><td></td><td></td><td></td></tr><tr><td>Service cost for benefits earned during the period</td><td>$ —</td><td>$ —</td><td>$ —</td></tr><tr><td>Interest cost on projected benefit obligation</td><td>2,006</td><td>1,898</td><td>1,946</td></tr><tr><td>Expected return on plan assets</td><td>(2,131)</td><td>(2,259)</td><td>(2,240)</td></tr><tr><td>Amortization of net loss</td><td>799</td><td>790</td><td>531</td></tr><tr><td>Net periodic benefit plan cost</td><td>$ 674</td><td>$ 429</td><td>$ 237</td></tr></table>

The Company recognized pre-tax (increases) decreases to the funded status in accumulated other comprehensive loss of $1,240,000 in 2016, $2,411,000 in 2015, and $10,214,000 in 2014. There were no previously unrecognized prior service costs as of December 31, 2016, 2015 and 2014. The pre-tax amounts recognized in accumulated other comprehensive loss for the years ended December 31, 2016, 2015 and 2014 are summarized as follows:

<table><tr><td>(in thousands)</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>Net loss (gain)</td><td>$ 2,039</td><td>$ (1,621)</td><td>$ 10,745</td></tr><tr><td>Amortization of net loss</td><td>(799)</td><td>(790)</td><td>(531)</td></tr><tr><td>Net transition obligation (asset)</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Amount recognized in accumulated other comprehensive loss</td><td>$ 1,240</td><td>$ (2,411)</td><td>$ 10,214</td></tr></table>

The amounts in accumulated other comprehensive loss expected to be recognized as components of net periodic benefit cost in 2017 are as follows:

<table><tr><td>(in thousands)</td><td>2017</td></tr><tr><td>Amortization of net loss</td><td>$ 825</td></tr><tr><td>Prior service cost (credit)</td><td>—</td></tr><tr><td>Net transition obligation (asset)</td><td>—</td></tr><tr><td>Estimated net periodic benefit plan cost</td><td>$ 825</td></tr></table>

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

<table><tr><td>December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>Projected Benefit Obligation:</td><td></td><td></td><td></td></tr><tr><td>Discount rate</td><td>4.45%</td><td>4.70%</td><td>4.15%</td></tr><tr><td>Rate of compensation increase</td><td>N/A</td><td>N/A</td><td>N/A</td></tr><tr><td>Net Benefit Cost:</td><td></td><td></td><td></td></tr><tr><td>Discount rate</td><td>4.70%</td><td>4.15%</td><td>5.20%</td></tr><tr><td>Expected return on plan assets</td><td>7.00%</td><td>7.00%</td><td>7.00%</td></tr><tr><td>Rate of compensation increase</td><td>N/A</td><td>N/A</td><td>N/A</td></tr></table>

The Company’s expected return on assets assumption is derived from a detailed periodic assessment conducted by its management and its investment advisor. 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.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

The plan’s weighted average asset allocation at December 31, 2016 and 2015 by asset category along with the target allocation for 2017 are as follows:

<table><tr><td>Asset Category</td><td>Target Allocation for 2017</td><td>Percentage of Plan Assets as of December 31, 2016</td><td>Percentage of Plan Assets as of December 31, 2015</td></tr><tr><td>Cash and cash equivalents</td><td>0% - 5%</td><td>3.3%</td><td>0.7%</td></tr><tr><td>Fixed income securities</td><td>15% - 50%</td><td>25.3%</td><td>25.8%</td></tr><tr><td>Domestic equity securities</td><td>0% - 40%</td><td>25.5%</td><td>27.6%</td></tr><tr><td>International equity securities</td><td>0% - 40%</td><td>20.8%</td><td>19.1%</td></tr><tr><td>Investments measured at net asset value</td><td>0% - 20%</td><td>25.1%</td><td>26.8%</td></tr><tr><td>Total</td><td></td><td>100.0%</td><td>100.0%</td></tr></table>

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 small-cap companies domiciled domestically and internationally. Fixed-income securities include corporate bonds, mortgage-backed securities, sovereign bonds, and U.S. Treasuries. Other types of investments include real estate 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. The plan utilizes a number of investment approaches, including but not limited to individual market securities, equity and fixed income funds in which the underlying securities are marketable, and debt funds to achieve this target allocation. Company management does not expect to make any contribution to the pension plan during fiscal year 2017.

Some of our assets, primarily our private equity and real estate funds, do not have readily determinable market values given the specific investment structures involved and the nature of the underlying investments. For plan asset reporting as of December 31, 2016, publicly traded asset pricing was used where possible. For assets without readily determinable values, estimates were derived from investment manager statements combined with discussions focusing on underlying fundamentals and significant events. Additionally, these investments are valued based on the net asset value per share calculated by the funds in which the plan has invested and the valuation is based on significant non-observable inputs which do not have a readily determinable fair value. These assets have been excluded from the fair value hierarchy applied retrospectively based on the accounting guidance recently adopted. The valuations are subject to judgments and assumptions of the funds which may prove to be incorrect, resulting in risks of incorrect valuation of these investments. The Company seeks to mitigate these risks by evaluating the appropriateness of the funds’ judgments and assumptions by reviewing the financial data included in the funds’ financial statements for reasonableness.

The following tables present our plan assets using the fair value hierarchy as of December 31, 2016 and 2015. 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.

Fair Value Hierarchy as of December 31, 2016:

<table><tr><td>Investments (in thousands)</td><td>Total</td><td>Level 1</td><td>Level 2</td></tr><tr><td>Cash and Cash Equivalents (1)</td><td>$ 1,154</td><td>$ 1,154</td><td>$ —</td></tr><tr><td>Fixed Income Securities (2)</td><td>8,804</td><td>—</td><td>8,804</td></tr><tr><td>Domestic Equity Securities (3)</td><td>8,865</td><td>4,469</td><td>4,396</td></tr><tr><td>International Equity Securities (4)</td><td>7,215</td><td>—</td><td>7,215</td></tr><tr><td>Total Assets in the Fair Value Hierarchy</td><td>$ 26,038</td><td>$ 5,623</td><td>$ 20,415</td></tr><tr><td>Investments measured at Net Asset Value</td><td>8,707</td><td></td><td></td></tr><tr><td>Investments at Fair Value</td><td>$ 34,745</td><td></td><td></td></tr></table>



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

Fair Value Hierarchy as of December 31, 2015:

<table><tr><td>Investments (in thousands)</td><td>Total</td><td>Level 1</td><td>Level 2</td></tr><tr><td>Cash and Cash Equivalents (1)</td><td>$ 210</td><td>$ 210</td><td>$ —</td></tr><tr><td>Fixed Income Securities (2)</td><td>7,987</td><td>—</td><td>7,987</td></tr><tr><td>Domestic Equity Securities (3)</td><td>8,527</td><td>4,285</td><td>4,242</td></tr><tr><td>International Equity Securities (4)</td><td>5,911</td><td>—</td><td>5,911</td></tr><tr><td>Total Assets in the Fair Value Hierarchy</td><td>$ 22,635</td><td>$ 4,495</td><td>$ 18,140</td></tr><tr><td>Investments measured at Net Asset Value</td><td>8,302</td><td></td><td></td></tr><tr><td>Investments at Fair Value</td><td>$ 30,937</td><td></td><td></td></tr></table>

(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) Domestic equity securities are valued using a market approach based on the quoted market prices of identical instruments in their respective markets.

(4) International equity securities are valued using a market approach based on the quoted market prices of identical instruments in their respective markets.

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

<table><tr><td>(in thousands)</td><td></td></tr><tr><td>2017</td><td>$ 2,432</td></tr><tr><td>2018</td><td>2,530</td></tr><tr><td>2019</td><td>2,589</td></tr><tr><td>2020</td><td>2,626</td></tr><tr><td>2021</td><td>2,710</td></tr><tr><td>2022-2026</td><td>14,194</td></tr></table>

## Supplemental Executive Retirement Plan (SERP)

The Company permits selected highly compensated employees to defer a portion of their compensation into the SERP. The SERP assets are invested primarily in company-owned life insurance (“COLI”) policies as a funding source to satisfy the obligations of the SERP. The assets are subject to claims by creditors, and the Company can designate them to another purpose at any time. Investments in COLI policies consisted of $47.7 million in variable life insurance policies as of December 31, 2016 and $46.8 million as of December 31, 2015. In the COLI policies, the Company is able to allocate investment of the assets across a set of choices provided by the insurance company, including fixed income securities and equity funds. The COLI policies are recorded at their net cash surrender values, which approximates fair value, as provided by the issuing insurance company, whose Standard & Poor’s credit rating was A+.

The Company classifies the SERP assets as trading securities as described in Note 1. The fair value of these assets totaled $18,367,000 as of December 31, 2016 and $16,081,000 as of December 31, 2015. The SERP assets are reported in other assets on the balance sheet. The changes in the fair value of these assets, and normal insurance expenses are recorded in the consolidated statement of operations as compensation cost within selling, general and administrative expenses. Trading (losses) gains related to the SERP assets totaled $966,000 in 2016, $(519,000) in 2015, and $959,000 in 2014. The SERP liability is recorded on the balance sheet in long-term pension liabilities with any change in the fair value of the liabilities recorded as compensation cost within selling, general and administrative expenses in the consolidated statements of operations.

## 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



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

charges to expense for the Company’s contributions to the 401(k) plan were $3,250,000 in 2016, $4,796,000 in 2015, and $6,970,000 in 2014.

## Stock Incentive Plans

The Company has issued stock options and restricted stock to employees under three 10-year stock incentive plans that were approved by stockholders in 1994, 2004 and 2014. The 1994 plan expired in 2004 and the 2004 Plan expired in 2014. In April 2015, the Company reserved 8,000,000 shares of common stock under the 2014 Stock Incentive Plan with a term of 10 years expiring in April 2024. This plan provides for the issuance of various forms of stock incentives, including, among others, incentive and non-qualified stock options and restricted shares. As of December 31, 2016, 6,250,634 shares were available for grant.

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 the 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 a financing activity in the accompanying consolidated statements of cash flows.

Pre-tax stock-based employee compensation expense was $10,218,000 in 2016 ($6,488,000 after tax), $9,960,000 in 2015 ($6,325,000 after tax), and $9,074,000 in 2014 ($5,762,000 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 and there are none outstanding. There were no stock options exercised during 2016, 2015 or 2014 and there are no stock options outstanding as of December 31, 2016.

## Restricted Stock

The Company has granted employees time lapse restricted stock which vest after a stipulated number of years from the grant date, depending on the terms of the issue. Time lapse restricted shares issued vest in 20 percent increments annually starting with the second anniversary of the grant. Grantees receive dividends declared and retain voting rights for the granted shares. The agreement under which the restricted stock is issued provides 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 (other than due to death, disability or retirement on or after age 65), shares with restrictions must be returned to the Company.

The following is a summary of the changes in non-vested restricted shares for the year ended December 31, 2016:

<table><tr><td></td><td>Shares</td><td>Weighted Average Grant-Date Fair Value</td></tr><tr><td>Non-vested shares at January 1, 2016</td><td>3,312,175</td><td>$ 13.17</td></tr><tr><td>Granted</td><td>920,100</td><td>10.77</td></tr><tr><td>Vested</td><td>(891,245)</td><td>11.58</td></tr><tr><td>Forfeited</td><td>(123,955)</td><td>13.41</td></tr><tr><td>Non-vested shares at December 31, 2016</td><td>3,217,075</td><td>$ 12.91</td></tr></table>



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

The following is a summary of the changes in non-vested restricted shares for the year ended December 31, 2015:

<table><tr><td></td><td>Shares</td><td>Weighted Average Grant-Date Fair Value</td></tr><tr><td>Non-vested shares at January 1, 2015</td><td>3,575,150</td><td>$ 12.04</td></tr><tr><td>Granted</td><td>895,725</td><td>12.30</td></tr><tr><td>Vested</td><td>(1,054,625)</td><td>8.66</td></tr><tr><td>Forfeited</td><td>(104,075)</td><td>12.78</td></tr><tr><td>Non-vested shares at December 31, 2015</td><td>3,312,175</td><td>$ 13.17</td></tr></table>

The fair value of restricted share awards is based on the market price of the Company’s stock on the date of the grant and is amortized to compensation expense, net of estimated forfeitures, on a straight-line basis over the requisite service period. The weighted average grant date fair value per share of these restricted stock awards was $10.77 for 2016, $12.30 for 2015 and $18.84 for 2014. The total fair value of shares vested was $9,751,000 during 2016, $12,727,000 during 2015 and $20,664,000 during 2014. The tax benefit for compensation tax deductions in excess of compensation expense was credited to capital in excess of par value aggregating $427,000 for 2016, $1,410,000 for 2015 and $4,336,000 for 2014. The excess tax deductions are classified as a financing activity in the accompanying consolidated statements of cash flows.

## Other Information

As of December 31, 2016, total unrecognized compensation cost related to non-vested restricted shares was $38,673,000 which is expected to be recognized over a weighted-average period of 3.4 years.

## Note 11: Related Party Transactions

## Marine Products Corporation

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

In accordance with a Transition Support Services agreement, which may be terminated by either party, RPC provides certain administrative services, including financial reporting and income tax administration, acquisition assistance, etc., to Marine Products. Charges from the Company (or from corporations that are subsidiaries of the Company) for such services were $739,000 in 2016, $753,000 in 2015, and $663,000 in 2014. The Company’s receivable (payable) due to (from) Marine Products for these services was $60,000 as of December 31, 2016 and $ (11,000) \)  as of December 31, 2015. 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 $890,000 in 2016, $1,127,000 in 2015 and $1,092,000 in 2014.

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 $111,000 in 2016, $100,000 in 2015 and $84,000 in 2014.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

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

RPC and Marine Products own 50 percent each of a limited liability company called 255 RC, LLC that was created for the joint purchase and ownership of a corporate aircraft. The purchase of the aircraft was completed in January 2015, and the purchase was funded primarily by a $2,554,000 contribution by each company to 255 RC, LLC. Each of RPC and Marine Products is a party to an operating lease agreement with 255 RC, LLC for a period of five years. RPC recorded certain net operating costs comprised of rent and an allocable share of fixed costs of approximately $197,000 in 2016 and $186,000 in 2015 for the corporate aircraft. The Company accounts for this investment using the equity method and its proportionate share of income or loss is recorded in selling, general and administrative expenses. As of December 31, 2016, the investment closely approximates the underlying equity in the net assets of 255 RC, LLC.

## Note 12: Business Segment Information

RPC’s reportable segments are the same as its operating segments. RPC manages its business as either services offered on the well site with equipment and personnel (Technical Services) or services and equipment offered off the well site (Support Services). The businesses under Technical Services generate revenue based on equipment, personnel operating the equipment and the materials utilized to provide the service. They are all managed, analyzed and reported based on the similarities of the operational characteristics and costs associated with providing the service. The businesses under Support Services are primarily able to generate revenue through one source, which is either a hard asset or a personnel resource. Selected overhead including centralized support services and regulatory compliance are classified under Corporate.

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

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

The Company’s Chief Operating Decision Maker (“CODM”) assesses performance and makes resource allocation decisions regarding, among others, staffing, growth and maintenance capital expenditures and key initiatives based on operating segments outlined above.



# NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
RPC, Inc. and Subsidiaries
Years ended December 31, 2016, 2015 and 2014

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 CODM 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, 2016, 2015 and 2014 are shown in the following table:

<table><tr><td>(in thousands)</td><td>Technical Services</td><td>Support Services</td><td>Corporate</td><td>Loss on disposition of assets, net</td><td>Total</td></tr><tr><td>2016</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues</td><td>$ 679,654</td><td>$ 49,320</td><td>$ —</td><td>$ —</td><td>$ 728,974</td></tr><tr><td>Operating (loss)</td><td>(203,804)</td><td>(26,021)</td><td>(17,037)</td><td>7,920</td><td>(238,942)</td></tr><tr><td>Capital expenditures</td><td>28,380</td><td>2,928</td><td>2,630</td><td>—</td><td>33,938</td></tr><tr><td>Depreciation and amortization</td><td>191,181</td><td>25,606</td><td>471</td><td>—</td><td>217,258</td></tr><tr><td>Identifiable assets</td><td>733,008</td><td>76,876</td><td>225,568</td><td>—</td><td>1,035,452</td></tr><tr><td>2015</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues</td><td>$ 1,175,293</td><td>$ 88,547</td><td>$ —</td><td>$ —</td><td>$ 1,263,840</td></tr><tr><td>Operating (loss)</td><td>(132,982)</td><td>(2,363)</td><td>(14,515)</td><td>(6,417)</td><td>(156,277)</td></tr><tr><td>Capital expenditures</td><td>155,361</td><td>11,055</td><td>1,010</td><td>—</td><td>167,426</td></tr><tr><td>Depreciation and amortization</td><td>237,778</td><td>32,697</td><td>502</td><td>—</td><td>270,977</td></tr><tr><td>Identifiable assets</td><td>976,761</td><td>108,262</td><td>152,071</td><td>—</td><td>1,237,094</td></tr><tr><td>2014</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues</td><td>$ 2,180,457</td><td>$ 156,956</td><td>$ —</td><td>$ —</td><td>$ 2,337,413</td></tr><tr><td>Operating profit (loss)</td><td>390,004</td><td>42,510</td><td>(16,113)</td><td>(15,472)</td><td>400,929</td></tr><tr><td>Capital expenditures</td><td>342,932</td><td>27,148</td><td>1,422</td><td>—</td><td>371,502</td></tr><tr><td>Depreciation and amortization</td><td>198,636</td><td>31,578</td><td>599</td><td>—</td><td>230,813</td></tr><tr><td>Identifiable assets</td><td>1,514,084</td><td>157,688</td><td>87,586</td><td>—</td><td>1,759,358</td></tr></table>

The following summarizes selected information between the United States and all international locations combined for the years ended December 31, 2016, 2015 and 2014. 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.

<table><tr><td>Years ended December 31,</td><td>2016</td><td>2015</td><td>2014</td></tr><tr><td>(in thousands)</td><td></td><td></td><td></td></tr><tr><td>United States Revenues</td><td>$ 677,755</td><td>$ 1,191,704</td><td>$ 2,249,260</td></tr><tr><td>International Revenues</td><td>51,219</td><td>72,136</td><td>88,153</td></tr><tr><td></td><td>$ 728,974</td><td>$ 1,263,840</td><td>$ 2,337,413</td></tr></table>



## 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, 2016 (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 42 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, 2016 and issued a report thereon which is included on page 43 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 2017 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 21 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 2017 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 Web site at www.rpc.net. Copies are available at no charge by writing to Attention: Human Resources, RPC, Inc., 2801 Buford Highway NE, Suite 520, 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 2017 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 2017 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 2017 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, 2016.

<table><tr><td>Plan Category</td><td>(A) Number of Securities To Be Issued Upon Exercise of Outstanding Options, Warrants and Rights</td><td>(B) Weighted Average Exercise Price of Outstanding Options, Warrants and Rights</td><td>(C) Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (Excluding Securities Reflected in Column (A))</td></tr><tr><td>Equity compensation plans approved by securityholders</td><td>—</td><td>$ —</td><td>6,250,634 \( ^{1)} \)</td></tr><tr><td>Equity compensation plans not approved by securityholders</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Total</td><td>—</td><td>$ —</td><td>6,250,634</td></tr></table>

(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 2017 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 2017 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 Accounting Firm” in the RPC Proxy Statement for its 2017 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 Time Lapse Restricted Stock Grant Agreement (incorporated herein by reference to Exhibit 10.2 to Form 10-Q filed on November 2, 2004).

10.7 Form of Performance Restricted Stock Grant Agreement (incorporated herein by reference to Exhibit 10.3 to Form 10-Q filed on November 2, 2004).

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

10.9 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).

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

10.11 Summary of Compensation Arrangements with Executive Officers (incorporated herein by reference to Exhibit 10.17 to the Form 10-K filed on March 3, 2010).

10.14 Form of Time Lapse Restricted Stock Agreement (incorporated herein by reference to Exhibit 10.1 to the Form 10-Q filed on May 2, 2012).

10.15 Summary of Compensation Arrangements with Non-Employee Directors (incorporated herein by reference to Exhibit 10.15 to the Form 10-K filed on February 27, 2015).

10.17 2014 Stock Incentive Plan (incorporated herein by reference to Appendix A to the Registrant’s definitive Proxy Statement filed on March 17, 2014).

10.20 Form of award agreement under Performance-Based Incentive Cash Compensation Plan.



## Exhibits (inclusive of item 3 above):

<table><tr><td>Exhibit Number</td><td>Description</td></tr><tr><td>3.1A</td><td>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).</td></tr><tr><td>3.1B</td><td>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).</td></tr><tr><td>3.1C</td><td>Certificate of Amendment of Certificate of Incorporation of RPC, Inc. (incorporated by reference to Exhibit 3.1(C) to the Quarterly Report on Form 10-Q filed August 2, 2011).</td></tr><tr><td>3.2</td><td>Amended and Restated Bylaws of RPC, Inc. (incorporated herein by reference to Exhibit 3.2 to the Form 10-Q filed on November 3, 2014).</td></tr><tr><td>4</td><td>Form of Stock Certificate (incorporated herein by reference to the Annual Report on Form 10-K for the fiscal year ended December 31, 1998).</td></tr><tr><td>10.1</td><td>2004 Stock Incentive Plan (incorporated herein by reference to Appendix B to the Registrant&#x27;s definitive Proxy Statement filed on March 24, 2004).</td></tr><tr><td>10.2</td><td>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).</td></tr><tr><td>10.3</td><td>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).</td></tr><tr><td>10.4</td><td>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).</td></tr><tr><td>10.5</td><td>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).</td></tr><tr><td>10.6</td><td>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).</td></tr><tr><td>10.7</td><td>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).</td></tr><tr><td>10.8</td><td>Supplemental Retirement Plan (incorporated herein by reference to Exhibit 10.11 to the Form 10-K filed on March 16, 2005).</td></tr><tr><td>10.9</td><td>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).</td></tr><tr><td>10.10</td><td>Performance-Based Incentive Cash Compensation Plan (incorporated by reference to Exhibit 10.1 to the Form 8-K filed April 28, 2006).</td></tr><tr><td>10.11</td><td>Summary of Compensation Arrangements with Executive Officers (incorporated herein by reference to Exhibit 10.17 to the Form 10-K filed on March 3, 2010).</td></tr><tr><td>10.12</td><td>Credit Agreement dated August 31, 2010 between the Company, Banc of America, N.A., SunTrust Bank, Regions Bank and certain other lenders party thereto (incorporated herein by reference to Exhibit 99.1 to the Form 8-K filed on September 7, 2010).</td></tr></table>



10.13 Amendment No. 1 to Credit Agreement dated as of June 16, 2011 between the Company, the Subsidiary Loan Parties party thereto, Bank of America, N.A. and certain other lenders party thereto (incorporated herein by reference to Exhibit 10.16 to the Form 10-K filed on February 29, 2012).

10.14 Form of Time Lapse Restricted Stock Agreement (incorporated herein by reference to Exhibit 10.1 to the Form 10-Q filed on May 2, 2012).

10.15 Summary of Compensation Arrangements with Non-Employee Directors (incorporated herein by reference to Exhibit 10.15 to the Form 10-K filed on February 27, 2015).

10.16 Amendment No. 2 to Credit Agreement and Amendment No. 1 to Subsidiary Guaranty Agreement dated as of January 17, 2014 between RPC, Bank of America, N.A., certain other Lenders party thereto, and the Subsidiary Loan Parties party thereto (incorporated herein by reference to Exhibit 99.1 to the Company’s Form 8-K dated January 17, 2014).

10.17 2014 Stock Incentive Plan (incorporated herein by reference to Appendix A to the Registrant’s definitive Proxy Statement filed on March 17, 2014).

10.18 Reduction of Commitment Notice, dated November 3, 2015 (incorporated herein by reference to Exhibit 99.1 to the Form 8-K filed on November 6, 2015).

10.19 Amendment No. 3 to Credit Agreement dated as of June 30, 2016 among RPC, Bank of America, N.A., certain other lenders party thereto, and the Subsidiary Loan Parties party thereto (incorporated herein by reference to Exhibit 99.1 to the Company’s Form 8-K dated June 30, 2016).

10.20 Form of award agreement under Performance-Based Incentive Cash Compensation Plan.

21 Subsidiaries of RPC

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

95.1 Mine Safety Disclosure

101.INS XBRL Instance Document

101.SCH XBRL Taxonomy Extension Schema Document

101.CAL XBRL Taxonomy Extension Calculation Linkbase Document

101.LAB XBRL Taxonomy Extension Label Linkbase Document

101.PRE XBRL Taxonomy Extension Presentation Linkbase Document

101.DEF XBRL Taxonomy Extension Definition Linkbase Document



## 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.



Richard A. Hubbell
President and Chief Executive Officer
(Principal Executive Officer)
February 28, 2017

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



Richard A. Hubbell

President and Chief Executive Officer
(Principal Executive Officer)

February 28, 2017



Ben M. Palmer

Vice President, Chief Financial Officer and Treasurer February 28, 2017
(Principal Financial and Accounting Officer)

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
Gary W. Rollins, Director
Henry B. Tippie, Director
James B. Williams, Director

Amy Rollins Kreisler, Director
Linda H. Graham, Director
Bill J. Dismuke, Director
Larry L. Prince, Director



Richard A. Hubbell

Director and as Attorney-in-fact

February 28, 2017



## INDEX TO CONSOLIDATED FINANCIAL STATEMENTS, REPORTS AND SCHEDULE

The following documents are filed as part of this report.

## FINANCIAL STATEMENTS AND REPORTS

Management’s Report on Internal Control Over Financial Reporting..... 41
Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting..... 42
Report of Independent Registered Public Accounting Firm on Consolidated Financial Statements..... 43
Consolidated Balance Sheets as of December 31, 2016 and 2015..... 44
Consolidated Statements of Operations for the three years ended December 31, 2016..... 45
Consolidated Statements of Comprehensive (Loss) Income for the three years ended December 31, 2016..... 46
Consolidated Statements of Stockholders’ Equity for the three years ended December 31, 2016..... 47
Consolidated Statements of Cash Flows for the three years ended December 31, 2016..... 48
Notes to Consolidated Financial Statements..... 49-70
SCHEDULE

Schedule II — Valuation and Qualifying Accounts..... 78

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

<table><tr><td rowspan="2"></td><td colspan="5">For the years ended December 31, 2016, 2015 and 2014</td></tr><tr><td>Balance at Beginning of Period</td><td>Charged to Costs and Expenses</td><td>Net (Deductions) Recoveries</td><td>Balance at End of Period</td><td></td></tr><tr><td>(in thousands)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Year ended December 31, 2016</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Allowance for doubtful accounts</td><td>$ 10,605</td><td>$ 6,021</td><td>$ (14,073) \( ^{(1)} \)</td><td>$ 2,553</td><td></td></tr><tr><td>Deferred tax asset valuation allowance</td><td>$ 276</td><td>$ 80</td><td>$ (2) \)</td><td>$ 356</td><td></td></tr><tr><td>Year ended December 31, 2015</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Allowance for doubtful accounts</td><td>$ 15,351</td><td>$ (2,958) \)</td><td>$ (1,788) \)</td><td>$ 10,605</td><td></td></tr><tr><td>Deferred tax asset valuation allowance</td><td>$ 2</td><td>$ 274</td><td>$</td><td>$ 276</td><td></td></tr><tr><td>Year ended December 31, 2014</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Allowance for doubtful accounts</td><td>$ 13,497</td><td>$ 2,280</td><td>$</td><td>$ (426) \)</td><td>$ 15,351</td></tr><tr><td>Deferred tax asset valuation allowance</td><td>$ 83</td><td>$ —</td><td>$</td><td>$ (81) \)</td><td>$ 2</td></tr></table>



## SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)

<table><tr><td>Quarters ended</td><td>March 31</td><td>June 30</td><td>September 30</td><td>December 31</td></tr><tr><td>(in thousands except per share data)</td><td></td><td></td><td></td><td></td></tr><tr><td>2016</td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues</td><td>$ 189,095</td><td>$ 142,998</td><td>$ 175,884</td><td>$ 220,997</td></tr><tr><td>Operating loss</td><td>$ (75,087)</td><td>$ (75,222)</td><td>$ (56,417)</td><td>$ (32,216)</td></tr><tr><td>Net loss</td><td>$ (32,511)</td><td>$ (48,686)</td><td>$ (38,942)</td><td>$ (21,107)</td></tr><tr><td>Net loss per share — basic (a)</td><td>$ (0.15)</td><td>$ (0.23)</td><td>$ (0.18)</td><td>$ (0.10)</td></tr><tr><td>Net loss per share — diluted (a)</td><td>$ (0.15)</td><td>$ (0.23)</td><td>$ (0.18)</td><td>$ (0.10)</td></tr><tr><td>2015</td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues</td><td>$ 406,270</td><td>$ 297,560</td><td>$ 291,924</td><td>$ 268,086</td></tr><tr><td>Operating profit (loss)</td><td>$ 6,374</td><td>$ (52,347)</td><td>$ (52,899)</td><td>$ (57,405)</td></tr><tr><td>Net income (loss)</td><td>$ 7,548</td><td>$ (34,055)</td><td>$ (35,173)</td><td>$ (37,881)</td></tr><tr><td>Net income (loss) per share — basic (a)</td><td>$ 0.04</td><td>$ (0.16)</td><td>$ (0.16)</td><td>$ (0.18)</td></tr><tr><td>Net income (loss) per share — diluted (a)</td><td>$ 0.04</td><td>$ (0.16)</td><td>$ (0.16)</td><td>$ (0.18)</td></tr></table>

(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 for the respective periods.



## CORPORATE INFORMATION

## OFFICERS

R. Randall Rollins
Chairman of the Board of Directors

Richard A. Hubbell
President and Chief Executive Officer

Linda H. Graham
Vice President and Secretary

Ben M. Palmer
Vice President, Chief Financial Officer
and Treasurer

## DIRECTORS

R. Randall Rollins $
Chairman of the Board, Rollins, Inc. (consumer services) and Chairman of the Board, Marine Products Corporation (boat manufacturing)

Henry B. Tippie *
Chairman of the Board and Chief Executive Officer,
Tippie Services, Inc. (management services)

James B. Williams *
Retired Chairman of the Executive Committee,
SunTrust Banks, Inc. (bank holding company)

Gary W. Rollins $
Vice Chairman and Chief Executive Officer,
Rollins, Inc. (consumer services)

Richard A. Hubbell
President and Chief Executive Officer and
President and Chief Executive Officer, Marine Products
Corporation (boat manufacturing)

Linda H. Graham
Vice President and Secretary and Vice President and Secretary, Marine Products Corporation (boat manufacturing)

Bill J. Dismuke
Retired President, Edwards Baking Company (manufacturer of pies and pie parts)

Larry L. Prince *
Retired Chairman of the Board,
Genuine Parts Company
(automotive parts distributor)

Amy Rollins Kreisler
Executive Director, The O. Wayne Rollins
Foundation and The Ma-Ran Foundation
(private charitable entities)

* Member of the Audit Committee, Compensation Committee, Diversity Committee, and Nominating and Governance Committee

† Chairman of the Audit Committee, Compensation Committee, Diversity Committee, and Nominating and Governance Committee

8 Member of the Executive Committee

° Member of the Audit Committee

## STOCKHOLDER INFORMATION

Corporate Offices
RPC, Inc.
2801 Buford Highway NE, Suite 520
Atlanta, Georgia 30329
Telephone: 404.321.2140



Stock Listing
New York Stock Exchange

Ticker Symbol
RES

Investor Relations Website
www.rpc.net

Transfer Agent and Registrar
For inquiries related to stock certificates, including changes of address, please contact:

American Stock Transfer & Trust Company, LLC
Shareholder Services Department

620115th Avenue
Brooklyn, NY 11219
Telephone: 800.937.5449
info@amstock.com
www.amstock.com

Annual Meeting
The annual meeting of RPC, Inc. will be held at 12:15 p.m., April 25, 2017, 2170 Piedmont Road, NE, Atlanta, GA 30324.

## In Memoriam

James Albert "Jim" Lane, Jr.
September 23, 1942 – March 19, 2016
Member of the Board of Directors, RPC, Inc.
Member of the Board of Directors, Marine Products Corporation
Executive Vice President, Marine Products Corporation
President, Chaparral Boats, Inc.

## Caution Concerning Forward-Looking Statements

This Annual Report contains statements that constitute “forward-looking statements” under the Private Securities Litigation Reform Act of 1995, including all statements that look forward in time or express management’s beliefs, expectations or hopes. In particular, such statements include, without limitation, statements regarding our belief that we are better prepared for higher industry activity levels, profitability and much improved financial returns as 2017 progresses; our beliefs regarding an improving industry environment and eventual industry recovery and that our company is poised to gain traction in an improving market; our beliefs regarding the continuation of catalysts driving completion service intensity and that this service intensity will continue to increase at an even greater rate in the coming years than it has in the past; our belief that, properly managed, the oilfield trend of increasing service intensity can increase our revenues and profits over the long term; and our intention to resume quarterly dividend payments. The actual results of the Company could differ materially from those indicated by the forward-looking statements because of various risks and uncertainties, including, without limitation, those identified under the title “Risk Factors” in the Company’s Annual Report on Form 10-K included as a part of this Annual Report. In addition, the timing of future dividend payments will depend on RPC’s financial results and market conditions as well as on competing uses for cash. All of the foregoing risks and the uncertainties are beyond the ability of the Company to control, and in many cases the Company cannot predict the risks and uncertainties that could cause its actual results to differ materially from those indicated in the forward-looking statements.



2801 BUFORD HIGHWAY NE, SUITE 520
ATLANTA, GEORGIA 30329

www.RPC.net

© 2017 RPC, INC. ALL RIGHTS RESERVED.
The names of other companies and products mentioned herein may be the trademarks of their respective owners.