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

For the fiscal year ended December 31, 2017

or

☐TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from           to

Commission File Number: 001‑38390

Cactus, Inc.

(Exact name of registrant as specified in its charter)

(713) 626‑8800

(Registrant’s telephone number, including area code)

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

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

Indicate by check mark if the Registrant is a well‑known seasoned issuer, as defined in Rule 405 of the Securities Act. 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 Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T 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, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b‑2 of the Exchange Act.

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

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

As of June 30, 2017, the last business day of the registrant’s most recently completed second quarter, there was no public market for the registrant’s common stock. The registrant’s common stock began trading on the New York Stock Exchange on February 8, 2018.

As of March 13, 2018, the registrant had 26,450,000 shares of Class A Common Stock, $0.01 par value per share, and 48,439,772 shares of Class B Common Stock, $0.01 par value per share, outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

The Company’s definitive proxy statement relating to the annual meeting of shareholders (to be held June 20, 2018) will be filed with the Securities and Exchange Commission within 120 days after the close of the Company’s fiscal year ended December 31, 2017 and is incorporated by reference in Part III to the extent described herein.

TABLE OF CONTENTS

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

This Annual Report on Form 10‑K (this “Annual Report”) contains “forward-looking statements” within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). When used in this Annual Report, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project” and similar expressions are intended to identify forward‑looking statements, although not all forward‑looking statements contain such identifying words. These forward‑looking statements are based on our current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. When considering forward‑looking statements, you should keep in mind the risk factors and other cautionary statements described under the heading “Item 1A. Risk Factors” included in this Annual Report. These forward‑looking statements are based on management’s current belief, based on currently available information, as to the outcome and timing of future events.

Forward‑looking statements may include statements about:

We caution you that these forward‑looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond our control, incident to the operation of our business. These risks include, but are not limited to the risks described in this Annual Report under “Item 1A. Risk Factors.”

Should one or more of the risks or uncertainties described in this Annual Report occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward‑looking statements.

All forward‑looking statements, expressed or implied, included in this Annual Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward‑looking statements that we or persons acting on our behalf may issue.

Except as otherwise required by applicable law, we disclaim any duty to update any forward‑looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this Annual Report.

EMERGING GROWTH COMPANY STATUS

We are an “emerging growth company” as defined in the Jumpstart Our Business Startups Act (the “JOBS Act”). For as long as we are an emerging growth company, unlike public companies that are not emerging growth companies under the JOBS Act, we will not be required to:

We will cease to be an emerging growth company upon the earliest of the:

In addition, Section 107 of the JOBS Act provides that an emerging growth company can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act of 1933, as amended (the “Securities Act”), for complying with new or revised accounting standards, but we have irrevocably opted out of the extended transition period and, as a result, we will adopt new or revised accounting standards on the relevant dates in which adoption of such standards is required for other public companies.

For a description of the qualifications and other requirements applicable to emerging growth companies and certain elections that we have made due to our status as an emerging growth company, see “Risk Factors—Risks Related to Our Class A Common Stock—For as long as we are an emerging growth company, we will not be required to comply with certain reporting requirements, including those relating to disclosure about our executive compensation, that apply to other public companies.”

PART I

You should read this entire report carefully, including the risks described under Part 1, Item 1A. Risk Factors and our consolidated financial statements and the notes to those consolidated financial statements included elsewhere in this Annual Report on Form 10‑K. Except as otherwise indicated or required by the context, all references in this Annual Report to the “Company,” “Cactus,” “we,” “us” and “our” refer to (i) Cactus Wellhead, LLC (“Cactus LLC”) and its consolidated subsidiaries prior to the completion of our initial public offering and (ii) Cactus, Inc. (“Cactus Inc.”) and its consolidated subsidiaries (including Cactus LLC) following the completion of our initial public offering on February 12, 2018, unless we state otherwise or the context otherwise requires. References in this Annual Report to “Cadent” are to Cadent Energy Partners II, L.P., an affiliate of Cadent Energy Partners. References in this Annual Report to “Cactus WH Enterprises” are to Cactus WH Enterprises, LLC. Cadent, Cactus WH Enterprises and Mr. Lee Boquet are collectively referred to herein as the “Pre-IPO Owners.”

Item 1.     Business

Overview

Cactus Inc. was incorporated as a Delaware corporation on February 17, 2017 for the purpose of completing an initial public offering of equity (our “IPO”) and related transactions. On February 12, 2018, in connection with our IPO, Cactus Inc. became a holding company whose sole material assets are units in Cactus LLC (“CW Units”). Cactus Inc. became the managing member of Cactus LLC and is responsible for all operational, management and administrative decisions relating to Cactus LLC’s business.

On February 12, 2018, we completed our initial public offering of 23,000,000 shares of Class A common stock, par value $0.01 per share (“Class A Common Stock”), at a price to the public of $19.00 per share. We received net proceeds of $405.8 million after deducting underwriting discounts and commissions and estimated offering expenses of our IPO. On February 14, 2018 we completed the sale of an additional 3,450,000 shares of Class A Common Stock pursuant to the exercise in full by the underwriters of their option to purchase additional shares of Class A Common Stock (the “Option”), resulting in $61.6 million of additional net proceeds. We contributed all of the net proceeds of the IPO to Cactus LLC in exchange for CW Units. Cactus LLC used (i) $251.0 million of the net proceeds to repay all of the borrowings outstanding under its term loan facility, including accrued interest and (ii) $216.4 million to redeem CW Units from certain direct and indirect owners of Cactus LLC.

We design, manufacture, sell and rent a range of highly‑engineered wellheads and pressure control equipment. Our products are sold and rented principally for onshore unconventional oil and gas wells and are utilized during the drilling, completion (including fracturing) and production phases of our customers’ wells. In addition, we provide field services for all of our products and rental items to assist with the installation, maintenance and handling of the wellhead and pressure control equipment.

Organizational Structure

In connection with the completion of the IPO, Cactus Inc. became the sole managing member of Cactus LLC and is responsible for all operational, management and administrative decisions relating to Cactus LLC’s business and consolidates the financial results of Cactus LLC and its subsidiaries. The Limited Liability Company Operating Agreement of Cactus LLC was amended and restated as the First Amended and Restated Limited Liability Company Operating Agreement of Cactus LLC (the “Cactus Wellhead LLC Agreement”) to, among other things, admit Cactus Inc. as the sole managing member of Cactus LLC.

In connection with our IPO, we completed a series of reorganization transactions, including the following:

In connection with the IPO, Cactus Inc. granted 0.7 million restricted stock unit awards, which will vest over one to three years, to certain directors, officers and employees of Cactus. 

In this Annual Report, we refer to the owners of CW Units (along with their permitted transferees) as “CW Unit Holders.”  CW Unit Holders also own one share of our Class B Common Stock for each CW Unit such CW Unit Holders own. After giving effect to our IPO and the related transactions, Cactus Inc. owns an approximate 35.3% interest in Cactus LLC, and the CW Unit Holders own an approximate 64.7% interest in Cactus LLC. These ownership percentages are based on 26,450,000 shares of Class A Common Stock and 48,439,772 shares of Class B Common Stock issued and outstanding as of March 13, 2018.

The following diagram indicates our simplified ownership structure.

Our Company

We design, manufacture, sell and rent a range of highly‑engineered wellheads and pressure control equipment. Our products are sold and rented principally for onshore unconventional oil and gas wells and are utilized during the drilling, completions (including fracturing) and production phases of our customers’ wells. In addition, we provide field services for all of our products and rental items to assist with the installation, maintenance and handling of the wellhead and pressure control equipment.

Our principal products include our Cactus SafeDrill™ wellhead systems, frac stacks, zipper manifolds and production trees that we design and manufacture. Every oil and gas well requires a wellhead, which is installed at the onset of the drilling process and which remains with the well through its entire productive life. The Cactus SafeDrill™ wellhead systems employ technology which allows technicians to land and secure casing strings more safely from the rig floor reducing the need to descend into the cellar. We believe we are a market leader in the application of such technology, with thousands of our products sold and installed across the United States since 2011. During the completion phase of a well, we rent frac stacks, zipper manifolds and other high‑pressure equipment that are used for well control and for managing the transmission of frac fluids and proppants during the hydraulic fracturing process. These severe service applications require robust and reliable equipment. For the subsequent production phase of a well, we sell production trees that regulate hydrocarbon production, which are installed on the wellhead after the frac tree has been removed. In addition, we provide mission‑critical field services for all of our products and rental items, including 24‑hour service crews to assist with the installation, maintenance and safe handling of the wellhead and pressure control equipment. Finally, we provide repair services for all of the equipment that we sell or rent.

Our innovative wellhead products and pressure control equipment are developed internally. We believe our close relationship with our customers provides us with insight into the specific issues encountered in the drilling and completions processes, allowing us to provide them with highly tailored product and service solutions. We have achieved significant market share, as measured by the percentage of total active U.S. onshore rigs that we follow (which we define as the number of active U.S. onshore drilling rigs to which we are the primary provider of wellhead products and corresponding services during drilling), and brand name recognition with respect to our engineered products, which we believe is due to our focus on safety, reliability, cost effectiveness and time saving features. We optimize our products for pad drilling (i.e., the process of drilling multiple wellbores from a single surface location) to reduce rig time and provide operators with significant efficiencies that translate to cost savings at the wellsite.

Our manufacturing and production facilities are located in Bossier City, Louisiana and Suzhou, China. While both facilities can produce our full range of products, our Bossier City facility has advanced capabilities and is designed to support time‑sensitive and rapid turnaround orders, while our facility in China is optimized for longer lead time orders and outsources its machining requirements. Both our United States and China facilities are licensed to the latest API 6A specification for both wellheads and valves and API Q1 and ISO9001:2015 quality management systems.

We operate 14 service centers in the United States, which are strategically located in the key oil and gas producing regions, including the Permian, SCOOP/STACK, Marcellus, Utica, Eagle Ford, Bakken and other active oil and gas regions in the United States. We also have one service center in Eastern Australia. These service centers support our field services and provide equipment assembly and repair services.

Our History

We began operating in August 2011, following the formation of Cactus LLC by Scott Bender and Joel Bender, who have owned or operated wellhead manufacturing businesses since the late 1970s, and by Cadent, as its equity sponsor. We acquired our primary manufacturing facility in Bossier City, Louisiana from one of our Pre-IPO Owners in September 2011 and established our other production facility, located in Suzhou, China, in December 2013. Since we began operating, we have grown to 14 U.S. service centers located in Texas, Louisiana, Colorado, Wyoming, New Mexico, Oklahoma, Pennsylvania and North Dakota. In July 2014, we formed Cactus Wellhead Australia Pty, Ltd and established a service center to develop the market for our products in Eastern Australia.

Suppliers and Raw Materials

Forgings, castings and bar stock represent the principal raw materials used in the manufacture of our products and rental equipment. In addition, we require accessory items (such as elastomers, ring gaskets, studs and nuts) and machining services. We purchase these items and services from over 250 vendors, both in the United States and China.

For the years ended December 31, 2017, 2016 and 2015, approximately $33.4 million, $10.8 million and $18.1 million, respectively, of machined component purchases were made from a vendor located in China, representing approximately 22%, 20% and 27%, respectively, of our total third party vendor purchases of raw materials, finished products, equipment, machining and other services. Although we have historically made purchases from this vendor pursuant to a long term contract, such contract expired at the end of 2016. We are currently purchasing from this vendor on terms substantially similar to those contained in the expired agreement. We expect to negotiate a new agreement with such vendor on terms similar to those in the expired agreement. Although our relationships with our existing vendors, including the Chinese vendor referred to above, are important to us, we do not believe that we are substantially dependent on any individual vendor to supply our required materials or services. The materials and services essential to our business are normally readily available and, where we use one or a few vendors as a source of any particular materials or services, we believe that we can, within a reasonable period of time, make satisfactory alternative arrangements in the event of an interruption of supply from any vendor.

We believe that our materials and services vendors have the capacity to meet additional demand should we require it.

Impact of Section 232 of the Trade Expansion Act of 1962 (“Section 232”)

On March 8, 2018, the President of the United States issued two proclamations imposing tariffs on imports of certain steel and aluminum products, effective March 23, 2018. The decision was made in response to the Department of Commerce’s findings and recommendations in its reports of its investigations into the impact of imported steel and aluminum on the national security of the United States pursuant to Section 232. Specifically, the President has imposed a 25% global tariff on certain imported steel mill products and a 10% global tariff on certain imported aluminum products from all countries except Canada and Mexico. The tariffs could cause the cost of raw materials to increase, although the impact to us of Section 232 remains uncertain.

Customers

We serve over 200 customers representing major independent and other oil and gas companies with operations in the key U.S. oil and gas producing basins including the Permian, Marcellus Shale/Utica, the SCOOP/STACK, the Eagle Ford, the Bakken and other active oil and gas basins, as well as in Australia. For the year ended December 31, 2017, Pioneer Natural Resources represented 11% of our total revenue and no other customer represented 10% or more of our total revenue. For each of the years ended December 31, 2016 and 2015, Devon Energy Corporation represented 12% of our total revenue, and no other customer represented 10% or more of our total revenue.

Manufacturing

Our manufacturing and production facilities are located in Bossier City, Louisiana and Suzhou, China. While both facilities can produce our full range of products, our Bossier City facility has advanced capabilities and is designed to support time‑sensitive and rapid turnaround orders, while China is optimized for longer lead time orders and outsources its machining requirements. Both our U.S. and China facilities are API certified to the API 6A specification for both wellheads and valves and API Q1 and ISO9001:2015 quality management systems.

Our Bossier City facility is configured to provide rapid‑response production of made‑to‑order equipment. Where typical manufacturing facilities are designed to run in batches with different machining processes occurring in stages, this facility uses highly‑capable computer numeric control (“CNC”) machines to perform substantially all machining of the product in a single step. We believe eliminating the setup and queue times between machining processes allows us to offer significantly shorter order‑to‑delivery time for equipment than our competitors, albeit at higher costs than China. Responsiveness to urgent needs strengthens our relationship with key customers.

Our Bossier City manufacturing facility also functions as a repair and testing facility with its API 6A PSL3 certification and full QA/QC department. The facility also has the ability to perform hydrostatic testing, phosphate and oiling, copper coating and frac valve remanufacturing.

Our production facility in China is configured to efficiently produce our range of pressure control products and components for less time‑sensitive, higher‑volume orders. All employees in our Suzhou facility are Cactus employees, which we believe is a key factor in ensuring high quality. Our Suzhou facility currently assembles and tests some machined components before shipment to the United States or Australia.

Trademarks and Other Intellectual Property

Trademarks are important to the marketing of our products. We consider the Cactus Wellhead trademark to be important to our business as a whole. Additionally, the SafeDrillTM trademark is complementary to our marketing efforts and brand recognition. These trademarks are registered in the United States.

We also rely on trade secret protection for our confidential and proprietary information. To protect our information, we customarily enter into confidentiality agreements with our employees and suppliers. There can be no assurance, however, that others will not independently obtain similar information or otherwise gain access to our trade secrets.

Cyclicality

We are substantially dependent on conditions in the oil and gas industry, including the level of exploration, development and production activity of, and the corresponding capital spending by, oil and natural gas companies. The level of exploration, development and production activity is directly affected by trends in oil and natural gas prices, which has historically been volatile, and by capital spending discipline imposed by customers.

Declines, as well as anticipated declines, in oil and gas prices could negatively affect the level of these activities and capital spending, which could adversely affect demand for our products and services and, in certain instances, result in the cancellation, modification or rescheduling of existing and expected orders and the ability of our customers to pay us for our products and services. These factors could have an adverse effect on our revenue and profitability.

Seasonality

Our business is not significantly impacted by seasonality, although our fourth quarter has historically been impacted by holidays and our clients’ budget cycles.

Environmental, Health and Safety Regulation

Our operations are subject to domestic (including U.S. federal, state and local) and international regulations with regard to air, land and water quality and other environmental matters. We believe we are in substantial compliance with these regulations. Laws and regulations to minimize and mitigate risks to the environment and to workplace safety continue to be enacted. Changes in standards of enforcement of existing regulations, as well as the enactment and enforcement of new legislation, may require us and our customers to modify, supplement or replace equipment or facilities or to change or discontinue present methods of operation. Our environmental compliance expenditures, our capital costs for environmental control equipment, and the market for our products may change accordingly.

Hazardous Substances and Waste. The Resource Conservation and Recovery Act (“RCRA”) and comparable state statutes, regulate the generation, transportation, treatment, storage, disposal and cleanup of hazardous and non‑hazardous wastes. Under the auspices of the Environmental Protection Agency (“EPA”), the individual states

administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. We are required to manage the transportation, storage and disposal of hazardous and non‑hazardous wastes generated by our operations in compliance with applicable laws, including RCRA.

The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), also known as the Superfund law, imposes joint and several liability, without regard to fault or legality of conduct, on classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. These persons include the current and former owner or operator of the site where the release occurred, and anyone who disposed of or arranged for the disposal of a hazardous substance released at the site. We currently own, lease, or operate numerous properties used for manufacturing and other operations. We also contract with waste removal services and landfills. In the event of a release from these properties, under CERCLA, RCRA and analogous state laws, we could be required to remove substances and wastes, remediate contaminated property, or perform remedial operations to prevent future contamination even if the releases are not from our operations. In addition, neighboring landowners and other third parties may also file claims for personal injury and property damage allegedly caused by releases into the environment. Any obligations to undertake remedial operations in the future may increase our cost of doing business and may have a material adverse effect on our results of operations and financial condition.

Water Discharges. The Federal Water Pollution Control Act (the “Clean Water Act”) and analogous state laws restrict and control the discharge of pollutants into waters of the United States. Discharges to water associated with our operations require appropriate permits from state agencies and may add material costs to our operations. The adoption of more stringent criteria in the future may also increase our costs of operation. The Clean Water Act and analogous state laws provide for administrative, civil and criminal penalties for unauthorized discharges and, together with the Oil Pollution Act of 1990, impose rigorous requirements for spill prevention and response planning, as well as substantial potential liability for the costs of removal, remediation, and damages in connection with any unauthorized discharges. In addition, in 2015 the EPA and U.S. Army Corps of Engineers (“Corps”) finalized a rule that expanded the scope of waters subject to Clean Water Act jurisdiction. If implemented, this rule may have a material adverse effect on the operation costs of customers, thereby potentially reducing demand for our products. The rule was stayed nationwide in late 2015, however, and the EPA and the Corps have proposed to repeal the rule and reinstate the pre‑2015 rule. In a separate rulemaking, the EPA and the Corps have also proposed to delay the implementation of the 2015 rule until 2019. Neither of these proposals has been finalized and the rule remains stayed by the Sixth Circuit.

Employee Health and Safety. We are subject to a number of federal and state laws and regulations, including OSHA and comparable state statutes, establishing requirements to protect the health and safety of workers. In addition, the OSHA hazard communication standard, the EPA community right‑to‑know regulations under Title III of the federal Superfund Amendment and Reauthorization Act and comparable state statutes require that information be maintained concerning hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and the public. Substantial fines and penalties can be imposed and orders or injunctions limiting or prohibiting certain operations may be issued in connection with any failure to comply with laws and regulations relating to worker health and safety.

API Certifications. Our manufacturing facility and our production facility are currently certified by the API as being in compliance with API 6A specification for both wellheads and valves and API Q1 and ISO9001:2015 quality management systems. These standards have also been incorporated into regulations adopted by the Bureau of Safety and Environmental Enforcement (“BSEE”) that apply to the oil and gas industries that operate on the outer continental shelf. API’s standards are subject to revision, however, and there is no guarantee that future amendments or substantive changes to the standards would not require us to modify our operations or manufacturing processes to meet the new standards. Doing so may materially affect our operation costs. We also cannot guarantee that changes to the standards would not lead to the rescission of our licenses should we be unable to make the changes necessary to meet the new standards. Furthermore, these facilities are subjected to annual audits by the API. Loss of our API licenses could materially affect demand for these products.

Climate Change. International, national and state governments and agencies are currently evaluating and/or promulgating legislation and regulations that are focused on restricting emissions commonly referred to as greenhouse gas (“GHG”) emissions. These regulatory measures include, among others, adoption of cap and trade regimes, carbon taxes, increased efficiency standards and incentives or mandates for renewable energy. Consideration of further legislation or regulation may be impacted by the Paris Agreement, which was announced by the Parties to the United Nations Framework Convention on Climate Change in December 2015 and which calls on signatories to set progressive GHG emission reduction goals. Although the United States became a party to the Paris Agreement in April 2016, the Trump administration announced in June 2017 its intention to either withdraw from the Agreement or renegotiate more favorable terms. However, the Paris Agreement stipulates that participating countries must wait four years before withdrawing from the agreement. Despite the planned withdrawal, certain U.S. city and state governments have announced their intention to satisfy their proportionate obligations under the Paris Agreement. These commitments could further reduce demand and prices for fossil fuels produced by our customers. In the United States, the EPA has made findings under the Clean Air Act that GHG emissions endanger public health and the environment, resulting in the EPA’s adoption of regulations requiring construction and operating permit reviews of both existing and new stationary sources with major emissions of GHGs, which reviews require the installation of new GHG emission control technologies. However, in October 2017, the EPA announced a proposal to repeal its regulation of GHG emissions from existing stationary sources. The EPA has also promulgated rules requiring the monitoring and annual reporting of GHG emissions from certain sources, including onshore and offshore oil and natural gas production facilities and onshore oil and natural gas processing, transmission, storage and distribution facilities. In addition, in May 2016, the EPA finalized a rule that set additional emissions limits for volatile organic compounds and established new methane emission standards for certain new, modified or reconstructed equipment and processes in the oil and natural gas source category, including production, processing, transmission and storage activities. In June 2017, the EPA issued an administrative stay of key provisions of the rule, but was promptly ordered by the D.C. Circuit to implement the rule. The EPA also published proposed 60‑day and two‑year stays of certain provisions in June 2017 and published a Notice of Data Availability in November 2017 seeking comment and providing clarification regarding the agency’s legal authority to stay the rule.

It is too early to determine whether, or in what form, further regulatory action regarding greenhouse gas emissions will be adopted or what specific impact a new regulatory action might have on us or our customers. Generally, the anticipated regulatory actions do not appear to affect us in any material respect that is different, or to any materially greater or lesser extent, than other companies that are our competitors. However, to the extent our customers are subject to these or other similar proposed or newly enacted laws and regulations, the additional costs incurred by our customers to comply with such laws and regulations could impact their ability or desire to continue to operate at current or anticipated levels, which would negatively impact their demand for our products and services. In addition, any new laws or regulations establishing cap‑and‑trade or that favor the increased use of non‑fossil fuels may dampen demand for oil and gas production and lead to lower spending by our customers for our products and services. Similarly, to the extent we are or become subject to any of these or other similar proposed or newly enacted laws and regulations, we expect that our efforts to monitor, report and comply with such laws and regulations, and any related taxes imposed on companies by such programs, will increase our cost of doing business and may have a material adverse effect on our financial condition and results of operations. Moreover, any such regulations could ultimately restrict the exploration and production of fossil fuels, which could adversely affect demand for our products.

Hydraulic Fracturing. Many of our customers utilize hydraulic fracturing in their operations. Environmental concerns have been raised regarding the potential impact of hydraulic fracturing on underground water supplies. These concerns have led to several regulatory and governmental initiatives in the United States to restrict the hydraulic fracturing process, which could have an adverse impact on our customers’ completions or production activities. For example, in December 2016, the EPA released its final report on the potential impacts of hydraulic fracturing on drinking water resources, concluding that “water cycle” activities associated with hydraulic fracturing may impact drinking water resources “under some circumstances,” including water withdrawals for fracturing in times or areas of low water availability; surface spills during the management of fracturing fluids, chemicals or produced water; injection of fracturing fluids into wells with inadequate mechanical integrity; injection of fracturing fluids directly into

groundwater resources; discharge of inadequately treated fracturing wastewater to surface waters; and disposal or storage of fracturing wastewater in unlined pits. In other examples, the EPA has issued final regulations under the U.S. Clean Air Act governing performance standards, including standards for the capture of air emissions released during hydraulic fracturing, though the EPA is currently reconsidering these standards, and published in June 2016 a final rule prohibiting the discharge of wastewater from hydraulic fracturing operations to publicly owned wastewater treatment plants. Also, the U.S. Bureau of Land Management finalized rules in March 2015 that imposed new or more stringent standards for performing hydraulic fracturing on federal and American Indian lands. While the agency subsequently published a final rule rescinding the 2015 rule in December 2017, this decision could be subject to legal challenge. In addition, in some instances, states and local governments have enacted more stringent hydraulic fracturing restrictions or bans on hydraulic fracturing activities. These and other similar state and foreign regulatory initiatives, if adopted, would establish additional levels of regulation for our customers that could make it more difficult for our customers to complete natural gas and oil wells and could adversely affect the demand for our equipment and services, which, in turn, could adversely affect our results of operations, financial condition and cash flows.

State and federal regulatory agencies have also recently focused on a possible connection between the operation of injection wells used for oil and gas waste disposal and seismic activity. Similar concerns have been raised that hydraulic fracturing may also contribute to seismic activity. When caused by human activity, such events are called induced seismicity. Developing research suggests that the link between seismic activity and wastewater disposal may vary by region, and that only a very small fraction of the tens of thousands of injection wells have been suspected to be, or have been, the likely cause of induced seismicity. In March 2016, the United States Geological Survey identified six states with the most significant hazards from induced seismicity, including Oklahoma, Kansas, Texas, Colorado, New Mexico, and Arkansas. In light of these concerns, some state regulatory agencies have modified their regulations or issued orders to address induced seismicity. Increased regulation and attention given to induced seismicity could lead to greater opposition to, and litigation concerning, oil and gas activities utilizing hydraulic fracturing or injection wells for waste disposal, which could indirectly impact our business, financial condition and results of operations. In addition, these concerns may give rise to private tort suits from individuals who claim they are adversely impacted by seismic activity they allege was induced. Such claims or actions could result in liability for property damage, exposure to waste and other hazardous materials, nuisance or personal injuries, and require our customers to expend additional resources or incur substantial costs or losses. This could in turn adversely affect the demand for our products.

Although we do not conduct hydraulic fracturing, increased regulation and attention given to the hydraulic fracturing process could lead to greater opposition to oil and gas production activities using hydraulic fracturing techniques. In addition, the adoption of new laws or regulations at the federal, state, local or foreign level imposing reporting obligations on, or otherwise limiting, delaying or banning, the hydraulic fracturing process or other processes on which hydraulic fracturing relies, such as water disposal, could make it more difficult to complete oil and natural gas wells, increase our customers’ costs of compliance and doing business, and otherwise adversely affect the hydraulic fracturing services they perform, which could negatively impact demand for our products.

Offshore Drilling. Various new regulations intended to improve offshore safety systems and environmental protection have been issued since 2010 that have increased the complexity of the drilling permit process and may limit the opportunity for some operators to continue deepwater drilling in the U.S. Gulf of Mexico, which could have an adverse impact on our customers’ activities. For example, in April 2016, BSEE published a final blowout preventer systems and well control rule that focuses on blowout preventer requirements and includes reforms in well design, well control, casing, cementing, real‑time well monitoring and subsea containment. Additionally, in July 2016, the Bureau of Ocean Energy Management issued a notice to lessees (“NTL”), effective September 30, 2016, setting out new financial assurance requirements for offshore leases intended to ensure that leaseholders will be able to cover the costs of decommissioning. In January 2017, the Bureau extended the NTL implementation timeline for certain leases by an additional six months. In May 2017, the Bureau began a review of the NTL to determine whether it should be implemented. If these new financial assurance requirements remain in place, they may increase our customers’ operating costs and impact our customers’ ability to obtain leases, thereby reducing demand for our products. Additional regulation includes a third‑party certification requirement promulgated by the Bureau of Safety and Environmental

Enforcement (“BSEE”) in September 2016 under which offshore operators must certify through an independent third party that their critical safety and pollution prevention equipment is operational and will function as designed in the most extreme conditions. However, the BSEE published a proposed rule in December 2017 to rescind this requirement, allowing equipment to demonstrate its adequacy through various industry standards, such as those established by the API. Third‑party challenges to industry operations in the U.S. Gulf of Mexico may also serve to further delay or restrict activities. Although our operations are predominately onshore, if the new regulations, policies, operating procedures and possibility of increased legal liability are viewed by our current or future customers as a significant impairment to expected profitability on projects or an unjustifiable increase in risk, they could discontinue or curtail their offshore operations, thereby adversely affecting the demand for our equipment and services, which, in turn could adversely affect our results of operations, financial condition and cash flows.

Chinese Environmental Law. As we have manufacturing operations in the People’s Republic of China (“PRC”), we are regulated by various PRC national and local environmental protection laws, regulations and policies. Chinese PRC environmental laws and regulations include national and local standards governing activities that may impact human health and the environment. These laws and regulations set standards for emissions control, discharges to surface and subsurface water, and the generation, handling, storage, transportation, treatment and disposal of waste materials. Although we believe that our operations are in substantial compliance with current environmental laws and regulations, we may not be able to comply with these regulations at all times as the PRC environmental legal regime is evolving and becoming more stringent. Therefore, if the PRC government imposes more stringent regulations in the future, we will have to incur additional and potentially substantial costs and expenses to comply with new regulations, which may negatively affect our results of operations. If we fail to comply with any of the present or future environmental regulations in any material aspects, we may suffer from negative publicity and may be required to pay substantial fines, suspend or even cease operations.

Companies must register or file an environmental impact report with the appropriate environmental bureau before starting construction or any major expansion or renovation of a new production facility. Before commencing operations, the agency must inspect the new or renovated facility and determine that all necessary equipment has been installed as required by applicable environmental protection requirements.

Chinese PRC authorities have the power to issue fines and penalties for non‑compliance and can also require violators to cease operations until compliance has been restored. We cannot currently predict the extent of future capital expenditures, if any, required for compliance with environmental laws and regulations, which may include expenditures for environmental control facilities.

Insurance and Risk Management

We provide products and systems to customers involved in oil and gas exploration, development and production. We also provide parts, repair services and field services associated with installation at all of our facilities and service centers in the United States and at our facility in Australia, as well as at customer sites. Our operations are subject to hazards inherent in the oil and natural gas industry, including accidents, blowouts, explosions, cratering, fires, oil spills and hazardous materials spills. These conditions can cause personal injury or loss of life, damage to or destruction of property, equipment, the environment and wildlife, and interruption or suspension of operations, among other adverse effects. In addition, claims for loss of oil and natural gas production and damage to formations can occur. If a serious accident were to occur at a location where our equipment and services are being used, it could result in our being named as a defendant to lawsuits asserting significant claims.

We have suffered accidents in the past, and we anticipate that we could experience accidents in the future. In addition to the property and personal losses from these accidents, the frequency and severity of these incidents affect our operating costs and insurability, as well as our relationships with customers, employees and regulatory agencies. Any significant increase in the frequency or severity of these incidents, or the general level of compensation awards, could

adversely affect the cost of, or our ability to obtain, workers’ compensation and other forms of insurance and could have other adverse effects on our results of operations and financial condition.

We rely on customer indemnifications and third‑party insurance as part of our risk mitigation strategy. However, our customers may be unable to satisfy indemnification claims against them. In addition, we indemnify our customers against certain claims and liabilities resulting or arising from our provision of goods or services to them. Our insurance may not be sufficient to cover any particular loss or may not cover all losses. We carry a variety of insurance coverages for our operations, and we are partially self‑insured for certain claims, in amounts that we believe to be customary and reasonable. Historically, insurance rates have been subject to various market fluctuations that may result in less coverage, increased premium costs, or higher deductibles or self‑insured retentions.

Our insurance includes coverage for commercial general liability, damage to our real and personal property, damage to our mobile equipment, sudden and accidental pollution liability, workers’ compensation and employer’s liability, auto liability, foreign package policy, excess liability, and directors and officers insurance. Our insurance includes various limits and deductibles or self‑insured retentions, which must be met prior to, or in conjunction with, recovery. To cover potential pollution risks, our commercial general liability policy is endorsed with sudden and accidental coverage and our excess liability policies provide additional limits of liability for covered sudden and accidental pollution losses.

Employees

As of December 31, 2017, we employed over 880 people. Our future success will depend partially on our ability to attract, retain and motivate qualified personnel. We are not a party to any collective bargaining agreements and have not experienced any strikes or work stoppages. We consider our relations with our employees to be satisfactory.

Facilities

Our corporate headquarters is located in Houston, Texas. Please see “Item 2. Properties” for information with respect to our other facilities. We believe that our facilities are adequate for our current operations.

Competition

The markets in which we operate are highly competitive. We believe that we are one of the largest suppliers of wellheads in the United States. We compete with divisions of Schlumberger, Baker Hughes a GE company, Weir and TechnipFMC as well as with a number of smaller companies. We believe that the wellhead market is relatively concentrated, with Cactus, Schlumberger and Baker Hughes representing over 50% of the market. Similar to Cactus, each of Schlumberger, Baker Hughes and TechnipFMC manufacture their own engineered products.

We believe that the rental market for frac stacks and related flow control equipment is more fragmented than the wellhead product market. Cactus does not believe that any individual company represents more than 10% of the market. As is the case in the wellhead market, Cactus, Schlumberger, Baker Hughes and TechnipFMC rent internally engineered and manufactured products. Other competitors generally rent foreign designed and manufactured generic products.

We believe that the principal competitive factors in the markets we serve are technical features, equipment availability, work force competency, efficiency, safety record, reputation, experience and price. Additionally, projects are often awarded on a bid basis, which tends to create a highly competitive environment. While we seek to be competitive in our pricing, we believe many of our customers elect to work with us based on product features, safety, performance and quality of our crews, equipment and services. We seek to differentiate ourselves from our competitors

by delivering the highest‑quality services and equipment possible, coupled with superior execution and operating efficiency in a safe working environment.

Available Information

We are required to file annual, quarterly and current reports, proxy statements and certain other information with the SEC. Any documents filed by us with the SEC may be inspected without charge at the SEC’s Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549. Copies of these materials may be obtained from such office upon payment of a duplicating fee. Please call the SEC at 1‑800‑SEC‑0330 for further information on the operation of the Public Reference Room.

The SEC maintains a website at www.sec.gov that contains reports, proxy and information statements and other information regarding registrants that file electronically with the SEC. Any documents filed by us with the SEC, including this Annual Report, can be downloaded from the SEC’s website.

Our principal executive offices are located at Cobalt Center, 920 Memorial City Way, Suite 300, Houston, TX 77024, and our telephone number at that address is (713) 626‑8800. Our website address is www.CactusWHD.com. Our periodic reports and other information filed with or furnished to the SEC are available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are electronically filed with or furnished to the SEC. Information on our website or any other website is not incorporated by reference into this Annual Report and does not constitute a part of this Annual Report.

Item 1A.   Risk Factors

Investing in our Class A Common Stock involves risks. You should carefully consider the information in this Annual Report, including the matters addressed under “Cautionary Note Regarding Forward‑Looking Statements,” and the following risks before making an investment decision. Our business, financial condition, prospects and results of operations could be materially and adversely affected by any of these risks. Additional risks or uncertainties not currently known to us, or that we deem immaterial, may also have an effect on our business, financial condition, prospects or results of operations. The trading price of our Class A Common Stock could decline due to any of these risks, and you may lose all or part of your investment.

Risks Related to the Oilfield Services Industry and Our Business

Demand for our products and services depends on oil and gas industry activity and expenditure levels, which are directly affected by trends in the demand for and price of crude oil and natural gas.

Demand for our products and services depends primarily upon the general level of activity in the oil and gas industry, including the number of drilling rigs in operation, the number of oil and gas wells being drilled, the depth and drilling conditions of these wells, the volume of production, the number of well completions and the level of well remediation activity, and the corresponding capital spending by oil and natural gas companies. Oil and gas activity is in turn heavily influenced by, among other factors, oil and gas prices worldwide, which have historically been volatile.

Declines, as well as anticipated declines, in oil and gas prices could negatively affect the level of these activities and capital spending, which could adversely affect demand for our products and services and, in certain instances, result in the cancellation, modification or rescheduling of existing and expected orders and the ability of our customers to pay us for our products and services. These factors could have an adverse effect on our revenue and profitability.

Factors affecting the prices of oil and natural gas include, but are not limited to, the following:

The oil and gas industry has historically experienced periodic downturns, which have been characterized by diminished demand for oilfield services and downward pressure on the prices we charge. The last downturn in the oil and gas industry that began in mid‑2014 resulted in a reduction in demand for oilfield services and adversely affected our financial condition, results of operations and cash flows. Any future downturn or expected downturn could again adversely affect our results of operations, financial condition and cash flows.

The cyclicality of the oil and natural gas industry may cause our operating results to fluctuate.

We derive our revenues from companies in the oil and natural gas exploration and production industry, a historically cyclical industry with levels of activity that are significantly affected by the levels and volatility of oil and natural gas prices. We have experienced and may in the future experience significant fluctuations in operating results as a result of the reactions of our customers to changes in oil and natural gas prices. For example, prolonged low commodity prices during 2015 and 2016, combined with adverse changes in the capital and credit markets, caused many exploration and production companies to reduce their capital budgets and drilling activity. This resulted in a significant decline in demand for oilfield services and adversely impacted the prices we could charge, particularly for rentals of frac equipment.

If oil prices or natural gas prices decline, the demand for our products and services could be adversely affected.

The demand for our products and services is primarily determined by current and anticipated oil and natural gas prices and the level of drilling activity and related general production spending in the areas in which we have operations. Volatility or weakness in oil prices or natural gas prices (or the perception that oil prices or natural gas prices will decrease) affects the spending patterns of our customers and may result in the drilling of fewer new wells or lower production spending on existing wells. When this occurs, exploration and production (“E&P”) companies move to significantly cut costs, both by decreasing drilling and completions activity and by demanding price concessions from their service providers. This results in lower demand for our products and services and may cause lower rates and lower utilization of our equipment. If oil prices decline or natural gas prices continue to remain low or decline further, or if there is a reduction in drilling activities, the demand for our products and services and our results of operations could be materially and adversely affected.

Additionally, the commercial development of economically viable alternative energy sources (such as wind, solar, geothermal, tidal, fuel cells and biofuels) could reduce demand for our products and services and create downward pressure on the revenue we are able to derive from such products and services, as they are dependent on oil and natural gas prices.

Anticipated growth in U.S. drilling and completions activity, and our ability to benefit from such anticipated growth, could be adversely affected by any significant constraints in pressure pumping capacity in the industry.

Growth in U.S. drilling and completions activity may be impacted by, among other things, pressure pumping capacity and pricing, which, in turn, is impacted by, among other things, the availability of fracturing equipment, demand for fracturing equipment and fracturing intensity per active rig. Also, longer laterals and higher intensity fracturing result in greater wear and tear to the industry’s fracturing equipment, which has caused and will continue to cause attrition in the supply of fracturing equipment and shortages in the availability of pressure pumping services. In addition, rising fracturing intensity per rig and an overall increase in completions activity has increased the demand for fracturing equipment. During the completion phase of a well, we rent frac stacks, zipper manifolds and other high‑pressure equipment used during the hydraulic fracturing process. For the subsequent production phase of a well, we sell production trees, which are installed on the wellhead after the frac tree has been removed. Any significant additional constraints in the availability of pressure pumping services, fracturing equipment or the ability of fracturing service providers to deliver fracturing services would have an adverse impact on the demand for the products we sell and rent, which could have a material adverse effect on our business, results of operations, financial condition and cash flows.

We design, manufacture, sell, rent and install equipment that is used in oil and gas exploration and production activities, which may subject us to liability, including claims for personal injury, property damage and environmental contamination should such equipment fail to perform to specifications.

We provide products and systems to customers involved in oil and gas exploration, development and production. Some of our equipment is designed to operate in high‑temperature and/or high‑pressure environments, and some equipment is designed for use in hydraulic fracturing operations. We also provide parts, repair services and field services associated with installation at all of our facilities and service centers in the United States and at our facility in Australia, as well as at customer sites. Because of applications to which our products and services are exposed, particularly those involving high pressure environments, a failure of such equipment, or a failure of our customer to maintain or operate the equipment properly, could cause damage to the equipment, damage to the property of customers and others, personal injury and environmental contamination and could lead to a variety of claims against us that could have an adverse effect on our business and results of operations.

We indemnify our customers against certain claims and liabilities resulting or arising from our provision of goods or services to them. In addition, we rely on customer indemnifications, generally, and third‑party insurance as part

of our risk mitigation strategy. However, our insurance may not be adequate to cover our liabilities. In addition, our customers may be unable to satisfy indemnification claims against them. Further, insurance companies may refuse to honor their policies, or insurance may not generally be available in the future, or if available, premiums may not be commercially justifiable. We could incur substantial liabilities and damages that are either not covered by insurance or that are in excess of policy limits, or incur liability at a time when we are not able to obtain liability insurance. Such potential liabilities could have a material adverse effect on our business, results of operations, financial condition and cash flows.

We may be unable to employ a sufficient number of skilled and qualified workers to sustain or expand our current operations.

The delivery of our products and services requires personnel with specialized skills and experience. Our ability to be productive and profitable will depend upon our ability to attract and retain skilled workers. In addition, our ability to expand our operations depends in part on our ability to increase the size of our skilled labor force. The demand for skilled workers is high, the supply is limited, and the cost to attract and retain qualified personnel has increased. During industry downturns, skilled workers may leave the industry, reducing the availability of qualified workers when conditions improve. In addition, a significant increase in the wages paid by competing employers could result in increases in the wage rates that we must pay. If we are not able to employ and retain skilled workers, our ability to respond quickly to customer demands or strong market conditions may inhibit our growth, which could have a material adverse effect on our business, results of operations and financial condition.

Political, regulatory, economic and social disruptions in the countries in which we conduct business could adversely affect our business or results of operations.

In addition to our facilities in the United States, we operate one production facility in China and have a facility in Australia that sells and rents equipment as well as provides parts, repair services and field services associated with installation. Instability and unforeseen changes in any of the markets in which we conduct business could have an adverse effect on the demand for, or supply of, our products and services, our results of operations and our financial condition. These factors include, but are not limited to, the following:

We are dependent on a relatively small number of customers in a single industry. The loss of an important customer could adversely affect our results of operations and financial condition.

Our customers are engaged in the oil and natural gas E&P business primarily in the United States and Australia. Historically, we have been dependent on a relatively small number of customers for our revenues. For the year ended December 31, 2017, Pioneer Natural Resources represented 11% of our total revenue, and no other customer represented more than 10% of our total revenue. For each of the years ended December 31, 2016 and 2015, Devon Energy Corporation represented 12% of our total revenue, and no other customer represented more than 10% of our total revenue.

Our business, financial condition, prospects and results of operations could be materially adversely affected if an important customer ceases to engage us for our services on favorable terms or at all or fails to pay or delays in paying us significant amounts of our outstanding receivables.

Additionally, the E&P industry is characterized by frequent consolidation activity. Changes in ownership of our customers may result in the loss of, or reduction in, business from those customers, which could materially and adversely affect our business, results of operations and financial condition.

Customer credit risks could result in losses.

The concentration of our customers in the energy industry may impact our overall exposure to credit risk as customers may be similarly affected by changes in economic and industry conditions. In addition, laws in some jurisdictions outside of the U.S. in which we operate could make collection difficult or time consuming. We perform ongoing credit evaluations of our customers and do not generally require collateral in support of our trade receivables. While we maintain reserves for potential credit losses, we cannot assure such reserves will be sufficient to meet write‑offs of uncollectible receivables or that our losses from such receivables will be consistent with our expectations.

To the extent one or more of our key customers commences bankruptcy proceedings, our contracts with these customers may be subject to rejection under applicable provisions of the United States Bankruptcy Code, or may be renegotiated. Further, during any such bankruptcy proceeding, prior to assumption, rejection or renegotiation of such contracts, the bankruptcy court may temporarily authorize the payment of value for our services less than contractually required, which could also have a material adverse effect on our business, results of operations, financial condition and cash flows.

Delays in obtaining, or inability to obtain or renew, permits or authorizations by our customers for their operations could impair our business.

In most states, our customers are required to obtain permits or authorizations from one or more governmental agencies or other third parties to perform drilling and completions activities, including hydraulic fracturing. Such permits or approvals are typically required by state agencies but can also be required by federal and local governmental agencies

or other third parties. The requirements for such permits or authorizations vary depending on the location where such drilling and completions activities will be conducted. As with most permitting and authorization processes, there is a degree of uncertainty as to whether a permit will be granted, the time it will take for a permit or approval to be issued and the conditions which may be imposed in connection with the granting of the permit. In some jurisdictions, such as New York State and within the jurisdiction of the Delaware River Basin Commission, certain regulatory authorities have delayed or suspended the issuance of permits or authorizations while the potential environmental impacts associated with issuing such permits can be studied and appropriate mitigation measures evaluated. In Texas, rural water districts have begun to impose restrictions on water use and may require permits for water used in drilling and completions activities. Permitting, authorization or renewal delays, the inability to obtain new permits or the revocation of current permits could cause a loss of revenue and potentially have a materially adverse effect on our business, results of operations and financial condition.

We may lose money on fixed‑price contracts.

From time to time, we agree to provide products and services under relatively short term fixed‑price contracts. Under these contracts, we are typically responsible for cost overruns. Our actual costs and any gross profit realized on these fixed‑price contracts may vary from the estimated amounts on which these contracts were originally based. There is inherent risk in the estimation process, including significant unforeseen technical and logistical challenges or longer than expected deployment times in the case of rentals. Depending on the size of a project, variations from estimated contract performance could have an adverse impact on our results of operations, financial condition and cash flows.

Increased costs, or lack of availability, of raw materials and other components may result in increased operating expenses and adversely affect our results of operations and cash flows.

Our ability to source low cost raw materials and components, such as steel castings and forgings, is critical to our ability to manufacture and sell our products and provide our services competitively. Our results of operations may be adversely affected by our inability to manage the rising costs and availability of raw materials and components used in our wide variety of products and systems. We cannot assure that we will be able to continue to purchase these raw materials on a timely basis or at commercially viable prices, nor can we be certain of the impact of Section 232. Further, unexpected changes in the size of regional and/or product markets, particularly for short lead‑time products, could affect our results of operations and cash flows. Should our current suppliers be unable to provide the necessary raw materials or components or otherwise fail to deliver such materials and components timely and in the quantities required, resulting delays in the provision of products or services to our customers could have a material adverse effect on our business.

In accordance with Section 1502 of the Dodd‑Frank Act, the SEC’s rules regarding mandatory disclosure and reporting requirements by public companies of their use of “conflict minerals” (tantalum, tin, tungsten and gold) originating in the Democratic Republic of Congo and adjoining countries became effective in 2014. While the conflict minerals rule continues in effect as adopted, there remains uncertainty regarding how the conflict minerals rule, and our compliance obligations, will be affected in the future. Additional requirements under the rule could affect sourcing at competitive prices and availability in sufficient quantities of certain of the conflict minerals used in the manufacture of our products or in the provision of our services, which could have a material adverse effect on our ability to purchase these products in the future. The costs of compliance, including those related to supply chain research, the limited number of suppliers and possible changes in the sourcing of these minerals, could have a material adverse effect on our results of operations and cash flows.

Competition within the oilfield services industry may adversely affect our ability to market our services.

The oilfield services industry is highly competitive and fragmented and includes numerous small companies capable of competing effectively in our markets on a local basis, as well as several large companies that possess substantially greater financial and other resources than we do. The amount of equipment available may exceed demand,

which could result in active price competition. Many contracts are awarded on a bid basis, which may further increase competition based primarily on price. In addition, adverse market conditions lower demand for well servicing equipment, which results in excess equipment and lower utilization rates. If market conditions in our oil‑oriented operating areas were to deteriorate or if adverse market conditions in our natural gas‑oriented operating areas persist, utilization rates may decline. The competitive environment has intensified since late 2014 as a result of the industry downturn and oversupply of oilfield equipment and services. Any significant future increase in overall market capacity for the products, rental equipment or services that we offer could adversely affect our business and results of operations.

Our relationship with one of our vendors is important to us.

We obtain certain important materials and machining services from one of our vendors located in China. For the years ended December 31, 2017, 2016 and 2015, approximately $33.4 million, $10.8 million and $18.1 million of purchases of machined components were made from this vendor, representing approximately 22%, 20% and 27%, respectively, of our total third party vendor purchases of raw materials, finished products, equipment, machining and other services. If we are not able to maintain our relationship with such vendor, our results of operations could be adversely impacted until we are able to find an alternative vendor.

Conservation measures and technological advances could reduce demand for oil and natural gas and our services.

Fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to oil and natural gas, technological advances in fuel economy and energy generation devices could reduce demand for oil and natural gas, resulting in reduced demand for oilfield services. The impact of the changing demand for oil and natural gas services and products may have a material adverse effect on our business, results of operations, financial condition and cash flows.

Indebtedness and liquidity needs could restrict our operations and make us more vulnerable to adverse economic conditions.

Indebtedness we may incur in the future, whether incurred in connection with acquisitions, operations or otherwise, may adversely affect our operations and limit our growth, and we may have difficulty making debt service payments on such indebtedness as payments become due. Our level of indebtedness may affect our operations in several ways, including the following:

We are subject to foreign currency fluctuation risk.

We outsource certain of our wellhead equipment to suppliers in China, and our production facility in China assembles and tests these outsourced components, as we do not engage in machining operations in this facility. In addition, we have a service center in Australia that sells products, rents frac equipment and provides field services. To the extent either facility has net U.S. dollar denominated assets, our profitability is eroded when the U.S. dollar weakens against the Chinese Yuan and the Australian dollar. Our production facility in China generally has net U.S. dollar denominated assets, while our service center in Australia generally has net U.S. dollar denominated liabilities. The U.S. dollar translated profits and net assets of our facilities in China and Australia are eroded if the respective local currency value weakens against the U.S. dollar. We have not entered into any derivative arrangements to protect against fluctuations in currency exchange rates.

New technology may cause us to become less competitive.

The oilfield services industry is subject to the introduction of new drilling and completions techniques and services using new technologies, some of which may be subject to patent or other intellectual property protections. Although we believe our equipment and processes currently give us a competitive advantage, as competitors and others use or develop new or comparable technologies in the future, we may lose market share or be placed at a competitive disadvantage. Further, we may face competitive pressure to develop, implement or acquire certain new technologies at a substantial cost. Some of our competitors have greater financial, technical and personnel resources that may allow them to enjoy various competitive advantages in the development and implementation of new technologies. We cannot be certain that we will be able to continue to develop and implement new technologies or products. Limits on our ability to develop, effectively use and implement new and emerging technologies may have a material adverse effect on our business, results of operations and financial condition, including the reduction in the value of assets replaced by new technologies.

A failure of our information technology infrastructure could adversely impact us.

We depend on our information technology (“IT”) systems for the efficient operation of our business. Accordingly, we rely upon the capacity, reliability and security of our IT hardware and software infrastructure and our ability to expand and update this infrastructure in response to our changing needs. Despite our implementation of security measures, our systems are vulnerable to damages from computer viruses, natural disasters, incursions by intruders or hackers, failures in hardware or software, power fluctuations, cyber terrorists and other similar disruptions. Additionally, we rely on third parties to support the operation of our IT hardware and software infrastructure, and in certain instances, utilize web‑based applications. Although no such material incidents have occurred to date, the failure of our IT systems or those of our vendors to perform as anticipated for any reason or any significant breach of security could disrupt our business and result in numerous adverse consequences, including reduced effectiveness and efficiency of operations, inappropriate disclosure of confidential and proprietary information, reputational harm, increased overhead costs and loss of important information, which could have a material adverse effect on our business and results of operations. In addition, we may be required to incur significant costs to protect against damage caused by these disruptions or security breaches in the future.

Our business is dependent on the continuing services of certain of our key managers and employees.

We depend on key personnel. The loss of key personnel could adversely impact our business if we are unable to implement certain strategies or transactions in their absence. The loss of qualified employees or an inability to retain and motivate additional highly‑skilled employees required for the operation and expansion of our business could hinder our ability to successfully maintain and expand our market share.

Equity interests in us are a substantial portion of the net worth of our executive officers and several of our other senior managers. Following the completion of the IPO, those executive officers and other senior managers have increased liquidity with respect to their equity interests in us. As a result, those executive officers and senior managers may have less incentive to remain employed by us. After terminating their employment with us, some of them may become employed by our competitors.

Adverse weather conditions could impact demand for our services or materially impact our costs.

Our business could be materially adversely affected by adverse weather conditions. For example, unusually warm winters could adversely affect the demand for our products and services by decreasing the demand for natural gas or unusually cold winters could adversely affect our ability to perform our services due to delays in the delivery of products that we need to provide our services. Our operations in arid regions can be affected by droughts and limited access to water used in hydraulic fracturing operations. Adverse weather can also directly impede our own operations. Repercussions of adverse weather conditions may include:

Competition among oilfield service and equipment providers is affected by each provider’s reputation for safety and quality.

Our activities are subject to a wide range of national, state and local occupational health and safety laws and regulations. In addition, customers maintain their own compliance and reporting requirements. Failure to comply with these health and safety laws and regulations, or failure to comply with our customers’ compliance or reporting requirements, could tarnish our reputation for safety and quality and have a material adverse effect on our competitive position.

Our operations require us to comply with various domestic and international regulations, violations of which could have a material adverse effect on our results of operations, financial condition and cash flows.

We are exposed to a variety of federal, state, local and international laws and regulations relating to matters such as environmental, workplace, health and safety, labor and employment, customs and tariffs, export and reexport controls, economic sanctions, currency exchange, bribery and corruption and taxation. These laws and regulations are complex, frequently change and have tended to become more stringent over time. They may be adopted, enacted, amended, enforced or interpreted in such a manner that the incremental cost of compliance could adversely impact our results of operations, financial condition and cash flows.

Our operations outside of the United States require us to comply with numerous anti‑bribery and anti‑corruption regulations. The U.S. Foreign Corrupt Practices Act (“FCPA”), among others, applies to us and our operations. Our policies, procedures and programs may not always protect us from reckless or criminal acts committed by our employees or agents, and severe criminal or civil sanctions may be imposed as a result of violations of these laws. We are also subject to the risks that our employees and agents outside of the United States may fail to comply with applicable laws.

In addition, we import raw materials, semi‑finished goods, and finished products into the United States, China and Australia for use in such countries or for manufacturing and/or finishing for re‑export and import into another country for use or further integration into equipment or systems. Most movement of raw materials, semi‑finished or finished products involves imports and exports. As a result, compliance with multiple trade sanctions, embargoes and import/export laws and regulations pose a constant challenge and risk to us since a portion of our business is conducted outside of the United States through our subsidiaries. Our failure to comply with these laws and regulations could materially affect our reputation, results of operations and financial condition.

Compliance with environmental laws and regulations may adversely affect our business and results of operations.

Environmental laws and regulations in the United States and foreign countries affect the equipment, systems and services we design, market and sell, as well as the facilities where we manufacture and produce our equipment and systems in the United States and China, and opportunities our customers pursue that create demand for our products. For example, we may be affected by such laws as the Resource Conservation and Recovery Act (“RCRA”), the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), the Clean Water Act, and the Occupational Safety and Health Act (“OSHA”) of 1970. Further, our customers may be subject to a range of laws and regulations governing hydraulic fracturing, offshore drilling, and greenhouse gas emissions.

We are required to invest financial and managerial resources to comply with environmental laws and regulations and believe that we will continue to be required to do so in the future. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations, or the issuance of orders enjoining operations. These laws and regulations, as well as the adoption of other new laws and regulations affecting exploration and production of crude oil and natural gas by our customers, could adversely affect our business and operating results by increasing our costs, limiting the demand for our products and services or restricting our operations. Increased regulation or a move away from the use of fossil fuels caused by additional regulation could also reduce demand for our products and services. For additional information, please see “Item 1. Business—Environmental, Health and Safety Regulation.” The operations of the energy industry, including those undertaking hydraulic fracturing, are also subject to wildlife‑protection laws and regulations, such as the Migratory Bird Treaty Act (“MBTA”) or the Endangered Species Act, which may impact exploration, development, and production activities through regulations intended to protect certain species. For example, regulations under the MBTA sometimes require companies to cover reserve pits that are open for more than 90 days to prevent the taking of birds.

Concerns over general economic, business or industry conditions may have a material adverse effect on our results of operations, financial condition and liquidity.

Concerns over global economic conditions, energy costs, geopolitical issues, inflation, the availability and cost of credit and the European, Asian and the United States financial markets have contributed to increased economic uncertainty and diminished expectations for the global economy. These factors, combined with volatility in commodity prices, business and consumer confidence and unemployment rates, have precipitated an economic slowdown. Concerns about global economic growth have had a significant adverse impact on global financial markets and commodity prices. If the economic climate in the United States or abroad deteriorates, worldwide demand for petroleum products could diminish further, which could impact the price at which oil, natural gas and natural gas liquids can be sold, which could affect the ability of our customers to continue operations and ultimately adversely impact our results of operations, financial condition and liquidity.

Our operations are subject to hazards inherent in the oil and natural gas industry, which could expose us to substantial liability and cause us to lose customers and substantial revenue.

Risks inherent in our industry include the risks of equipment defects, vehicle accidents, fires, explosions, blowouts, surface cratering, uncontrollable flows of gas or well fluids, pipe or pipeline failures, abnormally pressured formations and various environmental hazards such as oil spills and releases of, and exposure to, hazardous substances. For example, our operations are subject to risks associated with hydraulic fracturing, including any mishandling, surface spillage or potential underground migration of fracturing fluids, including chemical additives. The occurrence of any of these events could result in substantial losses to us due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, clean‑up responsibilities, regulatory investigations and penalties, suspension of operations and repairs required to resume operations. The cost of managing such risks may be significant. The frequency and severity of such incidents will affect operating costs, insurability and relationships with customers, employees and regulators. In particular, our customers may elect not to purchase our products or services if they view our environmental or safety record as unacceptable, which could cause us to lose customers and substantial revenues.

Our insurance may not be adequate to cover all losses or liabilities we may suffer. Also, insurance may no longer be available to us or its availability may be at premium levels that do not justify its purchase. The occurrence of a significant uninsured claim, a claim in excess of the insurance coverage limits maintained by us or a claim at a time when we are not able to obtain liability insurance could have a material adverse effect on our ability to conduct normal business operations and on our results of operations, financial condition and cash flows. In addition, we may not be able to secure additional insurance or bonding that might be required by new governmental regulations. This may cause us to restrict our operations, which might severely impact our financial condition.

A terrorist attack or armed conflict could harm our business.

The occurrence or threat of terrorist attacks in the United States or other countries, anti‑terrorist efforts and other armed conflicts involving the United States or other countries, including continued hostilities in the Middle East, may adversely affect the United States and global economies and could prevent us from meeting our financial and other obligations. If any of these events occur, the resulting political instability and societal disruption could reduce overall demand for oil and natural gas, potentially putting downward pressure on demand for our services and causing a reduction in our revenues. Oil and natural gas related facilities could be direct targets of terrorist attacks, and our operations could be adversely impacted if infrastructure integral to our customers’ operations is destroyed or damaged. Costs for insurance and other security may increase as a result of these threats, and some insurance coverage may become more difficult to obtain, if available at all.

If we are unable to fully protect our intellectual property rights or trade secrets, we may suffer a loss in our competitive advantage or market share.

We do not have patents relating to many of our key processes and technology. If we are not able to maintain the confidentiality of our trade secrets, or if our customers or competitors are able to replicate our technology or services, our competitive advantage would be diminished. We also cannot assure you that any patents we may obtain in the future would provide us with any significant commercial benefit or would allow us to prevent our competitors from employing comparable technologies or processes.

Risks Related to Our Class A Common Stock

We are a holding company. Our only material asset is our equity interest in Cactus LLC, and accordingly, we are dependent upon distributions from Cactus LLC to pay taxes, make payments under the Tax Receivable Agreement and cover our corporate and other overhead expenses.

We are a holding company and have no material assets other than our equity interest in Cactus LLC. We have no independent means of generating revenue. To the extent Cactus LLC has available cash and subject to the terms of any current or future credit agreements or debt instruments, we intend to cause Cactus LLC to make (i) generally pro rata distributions to its unitholders, including us, in an amount at least sufficient to allow us to pay our taxes and to make payments under the Tax Receivable Agreement and (ii) non‑pro rata payments to us to reimburse us for our corporate and other overhead expenses. To the extent that we need funds and Cactus LLC or its subsidiaries are restricted from making such distributions or payments under applicable law or regulation or under the terms of any future financing arrangements, or are otherwise unable to provide such funds, our financial condition and liquidity could be materially adversely affected.

Moreover, because we have no independent means of generating revenue, our ability to make payments under the Tax Receivable Agreement is dependent on the ability of Cactus LLC to make distributions to us in an amount sufficient to cover our obligations under the Tax Receivable Agreement. This ability, in turn, may depend on the ability of Cactus LLC’s subsidiaries to make distributions to it. The ability of Cactus LLC, its subsidiaries and other entities in which it directly or indirectly holds an equity interest to make such distributions will be subject to, among other things, (i) the applicable provisions of Delaware law (or other applicable U.S. and foreign jurisdictions) that may limit the amount of funds available for distribution and (ii) restrictions in relevant debt instruments issued by Cactus LLC or its subsidiaries and other entities in which it directly or indirectly holds an equity interest. To the extent that we are unable to make payments under the Tax Receivable Agreement for any reason, such payments will be deferred and will accrue interest until paid.

The requirements of being a public company, including compliance with the reporting requirements of the Exchange Act, and the requirements of the Sarbanes‑Oxley Act, may strain our resources, increase our costs and distract management, and we may be unable to comply with these requirements in a timely or cost‑effective manner.

As a public company, we need to comply with new laws, regulations and requirements, certain corporate governance provisions of the Sarbanes‑Oxley Act of 2002, related regulations of the SEC, including filing quarterly and annual financial statements, and the requirements of the NYSE, with which we were not required to comply as a private company. Complying with these statutes, regulations and requirements will occupy a significant amount of time of our board of directors and management and will significantly increase our costs and expenses. We need to:

The changes necessitated by becoming a public company require a significant commitment of resources and management oversight that has increased, and may continue to increase, our costs and might place a strain on our systems and resources. Such costs could have a material adverse effect on our business, results of operations and financial condition.

Furthermore, while we generally must comply with Section 404 of the Sarbanes‑Oxley Act of 2002 for our fiscal year ending December 31, 2018, we are not required to have our independent registered public accounting firm attest to the effectiveness of our internal controls until our first annual report subsequent to our ceasing to be an “emerging growth company” within the meaning of Section 2(a)(19) of the Securities Act. Accordingly, we may not be required to have our independent registered public accounting firm attest to the effectiveness of our internal controls until as late as our annual report for the fiscal year ending December 31, 2023, although this could be required earlier. Once it is required to do so, our independent registered public accounting firm may issue a report that is adverse in the event it is not satisfied with the level at which our controls are documented, designed, operated or reviewed. Compliance with these requirements may strain our resources, increase our costs and distract management, and we may be unable to comply with these requirements in a timely or cost‑effective manner.

In addition, we expect that being a public company subject to these rules and regulations may make it more difficult and more expensive for us to obtain director and officer liability insurance, and we may be required to accept reduced policy limits and coverage or incur substantially higher costs to obtain the same or similar coverage. As a result, it may be more difficult for us to attract and retain qualified individuals to serve on our board of directors or as executive officers. We are currently evaluating these rules, and we cannot predict or estimate the amount of additional costs we may incur or the timing of such costs.

In the past, we identified a material weakness in our internal control over financial reporting and may identify additional material weaknesses in the future. Material weaknesses could affect the reliability of our financial statements and may cause to us to fail to meet our reporting obligations or fail to prevent fraud, which would harm our business and could negatively impact the price of our Class A Common Stock.

Effective internal control over financial reporting is necessary for us to provide reliable financial reports and prevent or detect fraud. If we cannot provide reliable financial reports or prevent fraud, our reputation and operating results would be harmed. A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.

In connection with the audit of the consolidated financial statements of Cactus LLC, our predecessor for accounting purposes, for the year ended December 31, 2016, we identified a material weakness in our internal control over financial reporting. We did not effectively operate controls in place over the review of the consolidated financial statements and related disclosures. This resulted in the identification of certain errors in the consolidated statement of cash flows that have been corrected as a revision of that statement. Please read “Item 9A. Remediation of Material Weakness in Internal Control Over Financial Reporting.” The material weakness described above or any newly identified material weakness could result in a material misstatement of our annual or interim consolidated financial statements that would not be prevented or detected.

In addition, neither our management nor an independent registered public accounting firm has performed an evaluation of our internal control over financial reporting in accordance with the provisions of the Sarbanes‑Oxley Act because no such evaluation has been required. Had we or our independent registered public accounting firm performed an evaluation of our internal control over financial reporting in accordance with the provisions of the Sarbanes‑Oxley Act, additional material weaknesses may have been identified.

Material weaknesses could affect the reliability of our financial statements and may cause to us to fail to meet our reporting obligations or fail to prevent fraud, which would harm our business, and could negatively impact investor perceptions. This could negatively impact the price of our Class A Common Stock.

Additionally, our reporting obligations as a public company will place a significant strain on our management, operational and financial resources and systems for the foreseeable future and may cause us to fail to timely achieve and maintain the adequacy of our internal control over financial reporting. Please see “—The requirements of being a public company, including compliance with the reporting requirements of the Exchange Act and the requirements of the Sarbanes‑Oxley Act, may strain our resources, increase our costs and distract management, and we may be unable to comply with these requirements in a timely or cost‑effective manner.”

Our stock price may be volatile.

The market price of our Class A Common Stock could fluctuate significantly as a result of a number of factors, some of which are beyond our control. In the event of a drop in the market price of our Class A Common Stock, you could lose a substantial part or all of your investment in our Class A Common Stock. The following factors could affect our stock price:

The stock markets in general have experienced extreme volatility that has often been unrelated to the operating performance of particular companies. These broad market fluctuations may adversely affect the trading price of our Class A Common Stock. Securities class action litigation has often been instituted against companies following periods of volatility in the overall market and in the market price of a company’s securities. Such litigation, if instituted against us, could result in very substantial costs, divert our management’s attention and resources and harm our business, results of operations and financial condition.

Cadent and Cactus WH Enterprises will have the ability to direct the voting of a majority of the voting power of our common stock, and their interests may conflict with those of our other shareholders.

Holders of Class A Common Stock and Class B Common Stock vote together as a single class on all matters presented to our shareholders for their vote or approval, except as otherwise required by applicable law or our certificate of incorporation. Cadent owns approximately 49.2% of our Class B common stock (representing 31.8% of our voting power) and Cactus WH Enterprises owns approximately 46.6% of our Class B common stock (representing 30.2% of our voting power).

As a result, Cadent and Cactus WH Enterprises will be able to control matters requiring shareholder approval, including the election of directors, changes to our organizational documents and significant corporate transactions. This concentration of ownership makes it unlikely that any holder or group of holders of our Class A Common Stock will be able to affect the way we are managed or the direction of our business. The interests of Cadent and Cactus WH Enterprises with respect to matters potentially or actually involving or affecting us, such as future acquisitions, financings and other corporate opportunities and attempts to acquire us, may conflict with the interests of our other shareholders. Cadent and Cactus WH Enterprises would have to approve any potential acquisition of us. In addition, one of our directors is currently a partner of Cadent Energy Partners. This director’s duties as a partner of Cadent Energy Partners may conflict with his duties as our director, and the resolution of these conflicts may not always be in our or your best interest. Furthermore, in connection with our IPO, we entered into a stockholders’ agreement with Cadent and Cactus WH Enterprises. Among other things, the stockholders’ agreement provides each of Cadent and Cactus WH Enterprises with the right to designate a certain number of nominees to our board of directors so long as they and their respective affiliates collectively beneficially own at least 5% of the outstanding shares of our common stock. The existence of significant shareholders and the stockholders’ agreement may have the effect of deterring hostile takeovers, delaying or preventing changes in control or changes in management or limiting the ability of our other shareholders to approve transactions that they may deem to be in our best interests. Cadent and Cactus WH Enterprises’ concentration of stock ownership may also adversely affect the trading price of our Class A Common Stock to the extent investors perceive a disadvantage in owning stock of a company with significant shareholders.

Certain of our directors have significant duties with, and spend significant time serving, entities that may compete with us in seeking acquisitions and business opportunities and, accordingly, may have conflicts of interest in allocating time or pursuing business opportunities.

Certain of our directors, who are responsible for managing the direction of our operations and acquisition activities, hold positions of responsibility with other entities (including Cadent and its affiliated entities) whose businesses are similar to our business. The existing positions held by these directors may give rise to fiduciary or other duties that are in conflict with the duties they owe to us. These directors may become aware of business opportunities that may be appropriate for presentation to us as well as to the other entities with which they are or may become affiliated. Due to these existing and potential future affiliations, they may present potential business opportunities to other entities prior to presenting them to us, which could cause additional conflicts of interest. They may also decide that certain opportunities are more appropriate for other entities with which they are affiliated, and as a result, they may elect not to present those opportunities to us. These conflicts may not be resolved in our favor.

Cadent and its affiliates are not limited in their ability to compete with us, and the corporate opportunity provisions in our amended and restated certificate of incorporation could enable Cadent to benefit from corporate opportunities that might otherwise be available to us.

Our governing documents provide that Cadent and its affiliates (including portfolio investments of Cadent and its affiliates) are not restricted from owning assets or engaging in businesses that compete directly or indirectly with us. In particular, subject to the limitations of applicable law, our amended and restated certificate of incorporation, among other things:

Cadent and its affiliates, or our non‑employee directors, may become aware, from time to time, of certain business opportunities (such as, among other things, acquisition opportunities) and may direct such opportunities to other businesses in which they have invested, in which case we may not become aware of or otherwise have the ability to pursue such opportunity. Further, such businesses may choose to compete with us for these opportunities, possibly causing these opportunities to not be available to us or causing them to be more expensive for us to pursue. In addition, Cadent and its affiliates, or our non‑employee directors, may dispose of assets owned by them in the future, without any obligation to offer us the opportunity to purchase any of those assets. As a result, our renouncing our interest and expectancy in any business opportunity that may be from time to time presented to Cadent and its affiliates, or our non‑employee directors, could adversely impact our business or prospects if attractive business opportunities are procured by such parties for their own benefit rather than for ours.

Cadent and its affiliates potentially have access to resources greater than ours, which may make it more difficult for us to compete with Cadent and its affiliates with respect to commercial activities as well as for potential acquisitions. We cannot assure you that any conflicts that may arise between us and our shareholders, on the one hand, and Cadent, on the other hand, will be resolved in our favor. As a result, competition from Cadent and its affiliates could adversely impact our results of operations.

Our amended and restated certificate of incorporation and amended and restated bylaws, as well as Delaware law, contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our Class A Common Stock.

Our amended and restated certificate of incorporation authorizes our board of directors to issue preferred stock without shareholder approval. If our board of directors elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our amended and restated certificate of incorporation and amended and restated bylaws could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our shareholders, including:

In addition, certain change of control events have the effect of accelerating the payment due under the Tax Receivable Agreement, which could be substantial and accordingly serve as a disincentive to a potential acquirer of our company. Please see “—In certain cases, payments under the Tax Receivable Agreement may be accelerated and/or significantly exceed the actual benefits, if any, we realize in respect of the tax attributes subject to the Tax Receivable Agreement.”

Our amended and restated certificate of incorporation designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our shareholders, which could limit our shareholders’ ability to obtain a favorable judicial forum for disputes with us or our directors, officers, employees or agents.

Our amended and restated certificate of incorporation provides that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware will, to the fullest extent permitted by applicable law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees or agents to us or our shareholders, (iii) any action asserting a claim arising pursuant to any provision of the Delaware General Corporation Law (the “DGCL”), our amended and restated certificate of incorporation or our bylaws, or (iv) any action asserting a claim against us that is governed by the internal affairs doctrine, in each such case subject to such Court of Chancery having personal jurisdiction over the indispensable parties named as defendants therein. Any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock will be deemed to have notice of, and consented to, the provisions of our amended and restated certificate of incorporation described in the preceding sentence. This choice of forum provision may limit a shareholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our amended and restated certificate of incorporation inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, results of operations and financial condition.

Future sales of our Class A Common Stock in the public market, or the perception that such sales may occur, could reduce our stock price, and any additional capital raised by us through the sale of equity or convertible securities may dilute your ownership in us.

Subject to certain limitations and exceptions, the CW Unit Holders may cause Cactus LLC to redeem their CW Units for shares of Class A Common Stock (on a one‑for‑one basis, subject to conversion rate adjustments for stock splits, stock dividends and reclassification and other similar transactions) and then sell those shares of Class A Common Stock. Additionally, we may issue additional shares of Class A Common Stock or convertible securities in subsequent public offerings. We have 26,450,000 outstanding shares of Class A Common Stock and 48,439,772 outstanding shares of Class B Common Stock. The CW Unit Holders own 48,439,772 shares of Class B Common Stock, representing approximately 64.7% of our total outstanding common stock. All such shares of Class B Common Stock are restricted from immediate resale under the federal securities laws and are subject to the lock‑up agreements between such parties and the underwriters but may be sold into the market in the future. Cadent and Cactus WH Enterprises are party to a registration rights agreement between us and the Pre-IPO Owners, which will require us to effect the registration of their

shares in certain circumstances no earlier than the expiration of the lock‑up period contained in the underwriting agreement entered into in connection with our IPO.

We cannot predict the size of future issuances of our Class A Common Stock or securities convertible into Class A Common Stock or the effect, if any, that future issuances and sales of shares of our Class A Common Stock will have on the market price of our Class A Common Stock. Sales of substantial amounts of our Class A Common Stock (including shares issued in connection with an acquisition), or the perception that such sales could occur, may adversely affect prevailing market prices of our Class A Common Stock.

Under certain circumstances, redemptions of CW Units by CW Unit Holders will result in dilution to the holders of our Class A Common Stock.

Redemptions of CW Units by CW Unit Holders in accordance with the terms of the Cactus Wellhead LLC Agreement will result in a corresponding increase in our membership interest in Cactus LLC, increase in the number of shares of Class A Common Stock outstanding and decrease in the number of shares of Class B Common Stock outstanding. In the event that CW Units are exchanged at a time when Cactus LLC has made cash distributions to CW Unit Holders, including Cactus Inc., and Cactus Inc. has accumulated such distributions and neither reinvests them in Cactus LLC in exchange for additional CW Units nor distributes them as dividends to the holders of Cactus Inc.’s Class A Common Stock, the holders of our Class A Common Stock would experience dilution with respect to such accumulated distributions.

Cactus Inc. will be required to make payments under the Tax Receivable Agreement for certain tax benefits that we may claim, and the amounts of such payments could be significant.

In connection with our IPO, we entered into a Tax Receivable Agreement with the TRA Holders. This agreement will generally provide for the payment by Cactus Inc. to the TRA Holders of 85% of the net cash savings, if any, in U.S. federal, state and local income tax and franchise tax that Cactus Inc. actually realizes or is deemed to realize in certain circumstances as a result of certain increases in tax basis and certain benefits attributable to imputed interest. Cactus Inc. will retain the benefit of the remaining 15% of these net cash savings.

The term of the Tax Receivable Agreement will continue until all tax benefits that are subject to the Tax Receivable Agreement have been utilized or expired, unless we exercise our right to terminate the Tax Receivable Agreement (or the Tax Receivable Agreement is terminated due to other circumstances, including our breach of a material obligation thereunder or certain mergers or other changes of control), and we make the termination payment specified in the Tax Receivable Agreement. In addition, payments we make under the Tax Receivable Agreement will be increased by any interest accrued from the due date (without extensions) of the corresponding tax return. In the event that the Tax Receivable Agreement is not terminated, the payments under the Tax Receivable Agreement are anticipated to commence in 2019 and to continue for 16 years after the date of the last redemption of CW Units.

The payment obligations under the Tax Receivable Agreement are our obligations and not obligations of Cactus LLC, and we expect that the payments we will be required to make under the Tax Receivable Agreement will be substantial. Estimating the amount and timing of payments that may become due under the Tax Receivable Agreement is by its nature imprecise. For purposes of the Tax Receivable Agreement, cash savings in tax generally are calculated by comparing our actual tax liability (determined by using the actual applicable U.S. federal income tax rate and an assumed combined state and local income tax rate) to the amount we would have been required to pay had we not been able to utilize any of the tax benefits subject to the Tax Receivable Agreement. The amounts payable, as well as the timing of any payments under the Tax Receivable Agreement, are dependent upon significant future events and assumptions, including the timing of the redemption of CW Units, the price of our Class A Common Stock at the time of each redemption, the extent to which such redemptions are taxable transactions, the amount of the redeeming unit holder’s tax basis in its CW Units at the time of the relevant redemption, the depreciation and amortization periods that

apply to the increase in tax basis, the amount and timing of taxable income we generate in the future and the U.S. federal income tax rates then applicable, and the portion of our payments under the Tax Receivable Agreement that constitute imputed interest or give rise to depreciable or amortizable tax basis. The payments under the Tax Receivable Agreement will not be conditioned upon a holder of rights under the Tax Receivable Agreement having a continued ownership interest in us.

In certain cases, payments under the Tax Receivable Agreement may be accelerated and/or significantly exceed the actual benefits, if any, we realize in respect of the tax attributes subject to the Tax Receivable Agreement.

If we elect to terminate the Tax Receivable Agreement early or it is terminated early due to Cactus Inc.’s failure to honor a material obligation thereunder or due to certain mergers or other changes of control, our obligations under the Tax Receivable Agreement would accelerate and we would be required to make an immediate payment equal to the present value of the anticipated future payments to be made by us under the Tax Receivable Agreement (determined by applying a discount rate of one‑year LIBOR plus 150 basis points) and such payment is expected to be substantial. The calculation of anticipated future payments will be based upon certain assumptions and deemed events set forth in the Tax Receivable Agreement, including (i) the assumption that we have sufficient taxable income to fully utilize the tax benefits covered by the Tax Receivable Agreement and (ii) the assumption that any CW Units (other than those held by Cactus Inc.) outstanding on the termination date are deemed to be redeemed on the termination date. Any early termination payment may be made significantly in advance of the actual realization, if any, of the future tax benefits to which the termination payment relates.

As a result of either an early termination or a change of control, we could be required to make payments under the Tax Receivable Agreement that exceed our actual cash tax savings under the Tax Receivable Agreement. In these situations, our obligations under the Tax Receivable Agreement could have a substantial negative impact on our liquidity and could have the effect of delaying, deferring or preventing certain mergers, asset sales, or other forms of business combinations or changes of control. There can be no assurance that we will be able to finance our obligations under the Tax Receivable Agreement.

Payments under the Tax Receivable Agreement will be based on the tax reporting positions that we will determine. The TRA Holders will not reimburse us for any payments previously made under the Tax Receivable Agreement if any tax benefits that have given rise to payments under the Tax Receivable Agreement are subsequently disallowed, except that excess payments made to any TRA Holder will be netted against payments that would otherwise be made to such TRA Holder, if any, after our determination of such excess. As a result, in some circumstances, we could make payments that are greater than our actual cash tax savings, if any, and may not be able to recoup those payments, which could adversely affect our liquidity.

If Cactus LLC were to become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes, we and Cactus LLC might be subject to potentially significant tax inefficiencies, and we would not be able to recover payments previously made by us under the Tax Receivable Agreement even if the corresponding tax benefits were subsequently determined to have been unavailable due to such status.

We intend to operate such that Cactus LLC does not become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes. A “publicly traded partnership” is a partnership the interests of which are traded on an established securities market or are readily tradable on a secondary market or the substantial equivalent thereof. Under certain circumstances, redemptions of CW Units pursuant to the Redemption Right (or our Call Right) or other transfers of CW Units could cause Cactus LLC to be treated as a publicly traded partnership. Applicable U.S. Treasury regulations provide for certain safe harbors from treatment as a publicly traded partnership, and we intend to operate such that one or more such safe harbors shall apply. For example, we intend to limit the number of unitholders of Cactus LLC, and the Cactus Wellhead LLC Agreement, which was entered into in connection with the closing of our IPO, provides for limitations on the ability of CW Unit Holders to transfer their CW Units and provides us, as managing

member of Cactus LLC, with the right to impose restrictions (in addition to those already in place) on the ability of unitholders of Cactus LLC to redeem their CW Units pursuant to the Redemption Right to the extent we believe it is necessary to ensure that Cactus LLC will continue to be treated as a partnership for U.S. federal income tax purposes.

If Cactus LLC were to become a publicly traded partnership, significant tax inefficiencies might result for us and for Cactus LLC, including as a result of our inability to file a consolidated U.S. federal income tax return with Cactus LLC. In addition, we would no longer have the benefit of certain increases in tax basis covered under the Tax Receivable Agreement, and we would not be able to recover any payments previously made by us under the Tax Receivable Agreement, even if the corresponding tax benefits (including any claimed increase in the tax basis of Cactus LLC’s assets) were subsequently determined to have been unavailable.

If Cactus Inc. were deemed to be an investment company under the Investment Company Act of 1940, as amended (the “1940 Act”), as a result of its ownership of Cactus LLC, applicable restrictions could make it impractical for Cactus Inc. to continue its business as contemplated and could have a material adverse effect on its business.

Under Sections 3(a)(1)(A) and (C) of the 1940 Act, a company generally will be deemed to be an “investment company” for purposes of the 1940 Act if (i) it is, or holds itself out as being, engaged primarily, or proposes to engage primarily, in the business of investing, reinvesting or trading in securities or (ii) it engages, or proposes to engage, in the business of investing, reinvesting, owning, holding or trading in securities and it owns or proposes to acquire investment securities having a value exceeding 40% of the value of its total assets (exclusive of U.S. government securities and cash items) on an unconsolidated basis. We do not believe that Cactus Inc. is an “investment company,” as such term is defined in either of those sections of the 1940 Act. As the sole managing member of Cactus LLC, Cactus Inc. will control and operate Cactus LLC. On that basis, we believe that Cactus Inc.’s interest in Cactus LLC is not an “investment security” as that term is used in the 1940 Act. However, if Cactus Inc. were to cease participation in the management of Cactus LLC, its interest in Cactus LLC could be deemed an “investment security” for purposes of the 1940 Act. Cactus Inc. and Cactus LLC intend to conduct their operations so that Cactus Inc. will not be deemed an investment company. However, if Cactus Inc. were to be deemed an investment company, restrictions imposed by the 1940 Act, including limitations on Cactus Inc.’s capital structure and its ability to transact with affiliates, could make it impractical for Cactus Inc. to continue its business as contemplated and could have a material adverse effect on its business.

We may issue preferred stock whose terms could adversely affect the voting power or value of our Class A Common Stock.

Our amended and restated certificate of incorporation authorizes us to issue, without the approval of our shareholders, one or more classes or series of preferred stock having such designations, preferences, limitations and relative rights, including preferences over our Class A Common Stock respecting dividends and distributions, as our board of directors may determine. The terms of one or more classes or series of preferred stock could adversely impact the voting power or value of our Class A Common Stock. For example, we might grant holders of preferred stock the right to elect some number of our directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we might assign to holders of preferred stock could affect the residual value of the Class A Common Stock.

We are a “controlled company” within the meaning of the NYSE rules and, as a result, will qualify for and intend to rely on exemptions from certain corporate governance requirements.

Cadent and Cactus WH Enterprises beneficially own a majority of our outstanding voting interests. As a result, we are a “controlled company” within the meaning of the NYSE corporate governance standards. Under the NYSE rules, a company of which more than 50% of the voting power is held by another person or group of persons acting together is

a “controlled company” and may elect not to comply with certain NYSE corporate governance requirements, including the requirements that:

These requirements will not apply to us as long as we remain a controlled company. For at least some period, we intend to utilize these exemptions. Accordingly, you may not have the same protections afforded to shareholders of companies that are subject to all of the corporate governance requirements of the NYSE.

For as long as we are an emerging growth company, we will not be required to comply with certain reporting requirements, including those relating to accounting standards and disclosure about our executive compensation, that apply to other public companies.

We are classified as an “emerging growth company” under the JOBS Act. For as long as we are an emerging growth company, which may be up to five full fiscal years, unlike other public companies, we will not be required to, among other things: (i) provide an auditor’s attestation report on management’s assessment of the effectiveness of our system of internal control over financial reporting pursuant to Section 404(b) of the Sarbanes‑Oxley Act; (ii) comply with any new requirements adopted by the PCAOB requiring mandatory audit firm rotation or a supplement to the auditor’s report in which the auditor would be required to provide additional information about the audit and the financial statements of the issuer; (iii) provide certain disclosure regarding executive compensation required of larger public companies; or (iv) hold nonbinding advisory votes on executive compensation. We will remain an emerging growth company for up to five years, although we will lose that status sooner if we have more than $1.07 billion of revenues in a fiscal year, have more than $700.0 million in market value of our Class A Common Stock held by non‑affiliates, or issue more than $1.0 billion of non‑convertible debt over a three‑year period.

To the extent that we rely on any of the exemptions available to emerging growth companies, you will receive less information about our executive compensation and internal control over financial reporting than issuers that are not emerging growth companies. If some investors find our Class A Common Stock to be less attractive as a result, there may be a less active trading market for our Class A common stock and our stock price may be more volatile.

Item 1B.   Unresolved Staff Comments

None.

Item 2.    Properties

The following tables set forth information with respect to our facilities.

Additional information about our properties is set forth in “Item 1. Business.”

Item 3.    Legal Proceedings

We are party to lawsuits arising in the ordinary course of our business. We cannot predict the outcome of any such lawsuits with certainty, but management believes it is remote that pending or threatened legal matters will have a material adverse impact on our financial condition.

Due to the nature of our business, we are, from time to time, involved in other routine litigation or subject to disputes or claims related to our business activities, including workers’ compensation claims and employment related disputes. In the opinion of our management, none of these other pending litigation, disputes or claims against us, if decided adversely, will have a material adverse effect on our financial condition, cash flows or results of operations.

Item 4.    Mine Safety Disclosures

Not applicable.

PART II

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

Common Stock

Our Class A Common Stock began trading on the NYSE under the symbol “WHD” on February 8, 2018. Prior to that, there was no public market for our Class A Common Stock. As a result, we have not set forth quarterly information with respect to the high and low prices for our common stock for the two most recent fiscal years or provided a performance graph.

On March 13, 2018, the closing price of our Class A Common Stock as reported by the NYSE was $26.68 per share, and we had approximately one holder of record. This number excludes owners for whom Class A Common Stock may be held in “street” name.

Dividend Policy

We do not anticipate declaring or paying any cash dividends to holders of our Class A Common Stock in the foreseeable future. We currently intend to retain future earnings, if any, to finance the growth of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon then-existing conditions, including our results of operations, financial condition, capital requirements, investment opportunities, statutory restrictions on our ability to pay dividends and other factors our board of directors may deem relevant. In addition, our Credit Agreement restricts our ability to pay cash dividends to holders of our Class A Common Stock.

Securities Authorized for Issuance under Equity Compensation Plans

The information relating to our equity compensation plans required by Item 5 is incorporated by reference to such information as set forth in Item 12. “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters” contained herein.

Issuer Purchases of Equity Securities

We did not purchase any of our equity securities during the quarter ended December 31, 2017.

Sales of Unregistered Equity Securities

We did not have any sales of unregistered equity securities during the fiscal year ended December 31, 2017.

Item 6.    Selected Financial Data

The following tables show selected historical consolidated financial data, for the periods and as of the dates indicated, of Cactus LLC, our accounting predecessor. Our historical results are not necessarily indicative of future results. The following selected financial and operating data should be read in conjunction with “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the consolidated financial statements and related notes, each of which is included in this report.

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

Except as otherwise indicated or required by the context, all references in this Annual Report to the “Company,” “Cactus,” “we,” “us” and “our” refer to (i) Cactus Wellhead, LLC (“Cactus LLC”) and its consolidated subsidiaries prior to the completion of our initial public offering on February 12, 2018 and (ii) Cactus, Inc. (“Cactus Inc.”) and its consolidated subsidiaries (including Cactus LLC) following the completion of our initial public offering, unless we state otherwise or the context otherwise requires. The following discussion and analysis of our financial condition and results of operations should be read in conjunction with the accompanying consolidated financial statements and related notes. The following discussion contains “forward-looking statements” that reflect our plans, estimates, beliefs and expected performance. Our actual results may differ materially from those anticipated as discussed in these forward-looking statements as a result of a variety of risks and uncertainties, including those described above in “Cautionary Statement Regarding Forward-Looking Statements” and “Item 1A. Risk Factors” included elsewhere in this Annual Report, all of which are difficult to predict. In light of these risks, uncertainties and assumptions, the forward-looking events discussed may not occur. We assume no obligation to update any of these forward-looking statements except as otherwise required by law.

Executive Summary

We design, manufacture, sell and rent a range of highly‑engineered wellheads and pressure control equipment. Our products are sold and rented principally for onshore unconventional oil and gas wells and are utilized during the drilling, completions (including fracturing) and production phases of our customers’ wells. In addition, we provide field services for all of our products and rental items to assist with the installation, maintenance and handling of the wellhead and pressure control equipment.

Our principal products include our Cactus SafeDrill™ wellhead systems, as well as frac stacks, zipper manifolds and production trees that we design and manufacture. Every oil and gas well requires a wellhead, which is installed at the onset of the drilling process and which remains with the well through its entire productive life. The Cactus SafeDrill™ wellhead systems employ technology which allows technicians to land and secure casing strings safely from the rig floor without the need to descend into the cellar. We believe we are a market leader in the application of such technology, with thousands of our products sold and installed across the United States since 2011. During the completion phase of a well, we rent frac stacks, zipper manifolds and other high‑pressure equipment that are used for well control and for managing the transmission of frac fluids and proppants during the hydraulic fracturing process. These severe service applications require robust and reliable equipment. For the subsequent production phase of a well, we sell production trees that regulate hydrocarbon production, which are installed on the wellhead after the frac tree has been removed. In addition, we provide mission‑critical field services for all of our products and rental items, including 24‑hour service crews to assist with the installation, maintenance and safe handling of the wellhead and pressure control equipment. Finally, we provide repair services for all of the equipment that we sell or rent.

Our primary wellhead products and pressure control equipment are developed internally. We believe our close relationship with our customers provides us with insight into the specific issues encountered in the drilling and completions processes, allowing us to provide them with highly tailored product and service solutions. We have achieved significant market share, as measured by the percentage of total active U.S. onshore rigs that we follow (which we define as the number of active U.S. onshore drilling rigs to which we are the primary provider of wellhead products and corresponding services during drilling), and brand name recognition with respect to our engineered products, which we believe is due to our focus on safety, reliability, cost effectiveness and time saving features. We optimize our products for pad drilling (i.e., the process of drilling multiple wellbores from a single surface location) to reduce rig time and provide operators with significant efficiencies that translate to cost savings at the wellsite.

Our manufacturing and production facilities are located in Bossier City, Louisiana and Suzhou, China. While both facilities can produce our full range of products, our Bossier City facility has advanced capabilities and is designed

to support time‑sensitive and rapid turnaround orders, while our facility in China is optimized for longer lead time orders and outsources its machining requirements. Both our United States and China facilities are licensed to the latest API 6A specification for both wellheads and valves and API Q1 and ISO9001:2015 quality management systems.

We operate 14 service centers in the United States, which are strategically located in the key oil and gas producing regions, including the Permian, SCOOP/STACK, Marcellus, Utica, Eagle Ford, Bakken and other active oil and gas regions in the United States. We also have one service center in Eastern Australia. These service centers support our field services and provide equipment assembly and repair services.

Market Factors and Trends

Demand for our products and services depends primarily upon the general level of activity in the oil and gas industry, including the number of drilling rigs in operation, the number of oil and gas wells being drilled, the depth and drilling conditions of these wells, the volume of production, the number of well completions and the level of well remediation activity, and the corresponding capital spending by oil and natural gas companies. Oil and gas activity is in turn heavily influenced by, among other factors, oil and gas prices worldwide, which have historically been volatile.

The total U.S. onshore rig count for 2017 as reported by Baker Hughes based on a monthly average was 852 rigs, a material increase relative to the 2016 monthly average of 485 rigs. The December 2017, January 2018 and February 2018 monthly average was 909, 920 and 959 rigs, respectively.

Oil and natural gas prices have historically been volatile. Ongoing compliance among OPEC producers on production cuts implemented in early 2017 and the extension of these production cuts through the end of 2018, combined with current geopolitical tension, have supported upward momentum for energy prices. We believe that recent increases in oil and natural gas prices, as well as moderate relief from the global oversupply of oil and domestic oversupply of natural gas, should increase demand for our products and services.

The key market factor of our product sales is the number of wells drilled, as each well requires an individual wellhead assembly, and after completion, the installation of an associated production tree. We measure our product sales activity levels versus our competitors’ by the number of rigs that we are supporting on a monthly basis as a proxy for wells drilled. Each active drilling rig produces different levels of revenue based on the customer’s drilling plan, which includes factors such as the number of wells drilled per pad, the time taken to drill each well, the number and size of casing strings, the working pressure, material selection and the complexity of the wellhead system chosen by the customer. All of these factors are influenced by the oil and gas region in which our customer is operating. While these factors may lead to differing revenues per rig, they allow us to forecast our product needs and anticipated revenue levels based on general trends in a given region and with a specific customer.

Our rental revenues are primarily dependent on the number of wells completed (i.e., hydraulically fractured) and the number of fracture stages per well. Rental revenues and prices are more dependent on overall industry activity levels in the short‑term than product sales. This is due to the more competitive and price‑sensitive nature of the rental market with more participants having access to completions‑focused rental equipment. Pricing had also been impacted with the move from dayrate pricing to stage‑based pricing in the hydraulic fracturing market. This had a follow‑on effect to the rental pricing of completions‑focused pressure control equipment, as problems experienced with rental equipment do not have as significant a cost impact as they did previously to the E&P operator under dayrate pricing. We believe that as the market increases in activity levels and as capacity becomes more constrained due to cannibalization of both rental and hydraulic fracturing service equipment, the pricing of completions‑focused pressure control rental equipment will improve due to a renewed focus on reliability and quality. Furthermore, we believe that the current number of Drilled But Uncompleted wells (“DUCs”) and any increases thereto could ultimately provide additional opportunities.

Service and other revenues are closely correlated to revenues from product sales and rentals, as items sold or rented often have an associated service component. Almost all service sales are offered in connection with a product sale or rental. Therefore, the market factors and trends of product sales and rental revenues similarly impact the associated levels of service and other revenues generated.

How We Generate Our Revenues

Our revenues are derived from three sources: products, rentals, and field service and other. Product revenues are primarily derived from the sale of wellhead systems and production trees. Rental revenues are primarily derived from the rental of equipment used for well control during the completions process as well as the rental of drilling tools. Field service and other revenues are primarily earned when we provide installation and other field services for both product sales and equipment rental. Additionally, other revenues are derived from providing repair and reconditioning services to customers that have previously installed our products on their wellsite. Items sold or rented generally have an associated service component. Therefore, field service and other revenues closely correlate to revenues from product sales and rentals.

In 2017, we derived 55% of our total revenues from the sale of our products, 23% of our total revenues from rental and 22% of our total revenues from field service and other. In 2016, we derived 50% of our total revenues from the sale of our products, 29% of our total revenues from rental and 21% of our total revenues from field service and other. In 2015, we derived 50% of our total revenues from the sale of our products, 30% of our total revenues from rental and 20% of our total revenues from field service and other. We have predominantly domestic operations, with 99% of our total sales in 2017, 98% of our total sales in 2016 and 99% of our total sales in 2015 earned from U.S. operations.

Substantially all of our sales are made on a call‑out basis, wherein our clients issue requests for goods and/or services as their operations require. Such goods and/or services are most often priced in accordance with a preapproved price list.

Generally, we attempt to raise prices as our costs increase or additional features are provided. However, the actual pricing of our products and services is impacted by a number of factors, including competitive pricing pressure, the level of utilized capacity in the oil service sector, maintenance of market share, and general market conditions.

Costs of Conducting Our Business

The principal elements of cost of sales for products are the direct and indirect costs to manufacture and supply the product, including labor, materials, machine time, lease expense related to our facilities and freight. The principal elements of cost of sales for rentals are the direct and indirect costs of supplying rental equipment, including depreciation, repairs specifically performed on such rental equipment, lease expense and freight. The principal elements of cost of sales for field service and other are labor, equipment depreciation and repair, equipment lease expense, fuel and supplies.

Selling, general and administrative expense is comprised of costs such as sales and marketing, engineering expenses, general corporate overhead, business development expenses, compensation expense, IT expenses, safety and environmental expenses, legal and professional expenses and other related administrative functions.

Interest expense, net is comprised primarily of interest expense associated with our term loan facility. A portion of the net proceeds of the IPO was used to repay the borrowings outstanding under our term loan facility.

Factors Affecting the Comparability of Our Financial Condition and Results of Operations

Our historical financial condition and results of operations for the periods presented may not be comparable, either from period to period or going forward, for the following reasons:

We intend to account for any amounts payable under the Tax Receivable Agreement in accordance with Accounting Standard Codification (“ASC”) Topic 450, Contingencies (“ASC 450”). We believe accounting for the Tax Receivable Agreement under the provisions of ASC 450 is appropriate, given the significant uncertainties regarding the amount and timing of payments, if any, to be made under the Tax Receivable Agreement.

The tax benefits covered by the Tax Receivable Agreement include tax benefits expected to arise in connection with the reorganization and the IPO, including (i) certain increases in tax basis that occur as a result of Cactus Inc.’s acquisition (or deemed acquisition for U.S. federal income tax purposes) of CW Units from the Pre-IPO Owners in connection with the IPO, (ii) certain increases in tax basis resulting from the repayment, in connection with the IPO, of borrowings outstanding under Cactus LLC’s term loan facility and (iii) imputed interest deemed to be paid by Cactus Inc. as a result of, and additional tax basis arising from, any payments Cactus Inc. makes under the Tax Receivable Agreement. Payments will generally be made under the Tax Receivable Agreement as we realize actual cash tax savings from such tax benefits (provided that if we experience a change of control or the Tax Receivable Agreement terminates early at our election or as a result of a breach, we could be required to make an immediate lump‑sum payment in advance of any actual cash tax savings).

We will evaluate whether it is more likely than not that actual cash tax savings will be realized by Cactus Inc. from the tax benefits expected to arise in connection with the reorganization and the IPO. If it is determined that it is more likely than not that the tax benefits will be realized through actual cash tax savings, then the Tax Receivable Agreement would be expected to be probable of resulting in future payments and a liability would be recorded. On the other hand, if it is determined that it is more likely than not that the tax benefits will not be realized through actual cash tax savings, then no Tax Receivable

Agreement liability would be recorded, as future payments under the Tax Receivable Agreement would not be probable of occurring.

The accounting for any exchanges of CW Units subsequent to the reorganization transaction will follow the same accounting described above.

We will recognize subsequent changes to the measurement of the Tax Receivable Agreement liability in the income statement. In the case of any changes resulting from changes to any valuation allowance associated with the underlying tax asset, given the inextricable link between the tax savings generated and the recognition of the Tax Receivable Agreement liability (i.e., one is recorded based on 85% of the other), and the explicit guidance in ASC 740‑20‑45‑11(g) which requires that subsequent changes in a valuation allowance established against deferred tax assets that arose due to change in tax basis as a result of a transaction among or with shareholders to be recorded in the income statement as opposed to equity, we believe recording of the corollary adjustment to the Tax Receivable Agreement liability in the income statement would also be appropriate.

To the extent Cactus LLC has available cash and subject to the terms of any current or future credit agreements or debt instruments, we intend to cause Cactus LLC to generally make pro rata distributions to its unitholders, including us, in an amount at least sufficient to allow us to pay our taxes and to make payments under the Tax Receivable Agreement. Except in cases where we elect to terminate the Tax Receivable Agreement early or it is otherwise terminated, we may generally elect to defer payments due under the Tax Receivable Agreement if we do not have available cash to satisfy our payment obligations under the Tax Receivable Agreement. Any such deferred payments under the Tax Receivable Agreement generally will accrue interest from the due date for such payment until the payment date.

Predecessor Consolidated Results of Operations

Year Ended December 31, 2017 Compared to Year Ended December 31, 2016

The following table presents summary consolidated operating results for the periods indicated:

nm = not meaningful

Revenues

Product revenue for the year ended December 31, 2017 was $189.1 million, an increase of $111.4 million, or 143%, from $77.7 million for the year ended December 31, 2016. The increase was primarily attributable to accelerated U.S. land activity in 2017 associated with increased E&P drilling, completions and production, which led to a higher onshore rig count in the United States, resulting in increased demand for our products and greater volume of product sales. Additionally, a change in mix toward higher value advanced wellheads has also contributed to the increase in revenues.

Rental revenue for the year ended December 31, 2017 was $77.5 million, an increase of $33.1 million, or 75%, from $44.4 million for the year ended December 31, 2016. The increase was primarily attributable to increased drilling and completions activities, which led to increased demand for the rental of our equipment in 2017, as well as pricing improvement in our rental fleet compared to 2016.

Field service and other revenue for the year ended December 31, 2017 was $74.6 million, an increase of $41.7 million, or 127%, from $32.9 million for the year ended December 31, 2016. The increase was primarily attributable to higher demand for these services following the increase in our product and rental revenue, as field service is closely correlated with these activities.

Costs and expenses

Cost of product revenue for the year ended December 31, 2017 was $124.0 million, an increase of $61.3 million, or 98%, from $62.8 million for the year ended December 31, 2016. The increase was largely attributable to increased product sales volume as a result of higher demand for our products. Product margins benefited from price increases together with a change in mix toward higher value advanced wellheads.

Cost of rental revenue for the year ended December 31, 2017 was $40.5 million, an increase of $6.5 million, or 19%, from $34.0 million for the year ended December 31, 2016. The increase was primarily due to higher depreciation expense from capital additions and higher operating costs due to an increase in activity. Increased utilization and better pricing contributed to higher margins.

Cost of field service and other revenue for the year ended December 31, 2017 was $60.6 million, an increase of $32.1 million, or 113%, from $28.5 million for the year ended December 31, 2016. The increase was primarily due to higher payroll costs attributable to additional field personnel and higher operating costs due to activity increases.

Selling, general and administrative expense for the year ended December 31, 2017 was $27.2 million, an increase of $8.0 million, or 42%, from $19.2 million for the year ended December 31, 2016. The increase was primarily due to higher payroll and incentive compensation costs associated with the overall growth of Cactus. Also, we expensed $1.0 million of costs during 2017 related to preparing for being a public company.

Interest expense, net. Interest expense, net for the year ended December 31, 2017 was $20.8 million, an increase of $0.5 million, or 3%, from $20.2 million for the year ended December 31, 2016. The increase was primarily due to higher average interest rates on borrowings under our credit facility and increased interest related to amounts on capital lease obligations.

Other income (expense), net. Other income, net for 2016 relates to a gain on debt extinguishment of $2.3 million associated with our redemption of $7.5 million of debt outstanding under our term loan during the second quarter of 2016.

Income tax expense. Although our operations have not been subject to U.S. federal income tax at an entity level, our operations are subject to state taxes within the United States. In addition, Cactus LLC’s operations located in China and Australia are subject to local country income taxes. Income tax expense for the years ended December 31, 2017 and 2016 were $1.5 million and $0.8 million, respectively.

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

The following table presents summary consolidated operating results for the periods presented:

nm = not meaningful

Revenues

Product revenue for the year ended December 31, 2016 was $77.7 million, a decrease of $33.2 million, or 30%, from $110.9 million for the year ended December 31, 2015. The decrease was primarily attributable to the decline in crude oil prices, which led to a lower onshore rig count in the United States, resulting in a lower demand for our products.

Rental revenue for the year ended December 31, 2016 was $44.4 million, a decrease of $21.1 million, or 32%, from $65.4 million for the year ended December 31, 2015. The decrease was primarily attributable to the decline in oil prices, which reduced drilling and completions activities. These factors reduced demand for the rental of our equipment and put downward pressure on rental pricing.

Field service and other revenue for the year ended December 31, 2016 was $32.9 million, a decrease of $12.1 million, or 27%, from $45.0 million for the year ended December 31, 2015. The decrease was primarily attributable to a reduction in demand for our services following the decline in crude oil prices, resulting in lower rig count.

Costs and expenses

Cost of product revenue for the year ended December 31, 2016 was $62.8 million, a decrease of $21.8 million, or 26%, from $84.6 million for the year ended December 31, 2015. The decrease was primarily attributable to reduced product sales volume as a result of lower demand for our products.

Cost of rental revenue for the year ended December 31, 2016 was $34.0 million, a decrease of $5.3 million, or 13%, from $39.3 million for the year ended December 31, 2015. The decrease was primarily due to lower repair costs.

Cost of field service and other revenue for the year ended December 31, 2016 was $28.5 million, a decrease of $4.7 million, or 14%, from $33.2 million for the year ended December 31, 2015. The decrease was primarily due to reduction in payroll costs and branch overhead costs.

Selling, general and administrative expense for the year ended December 31, 2016 was $19.2 million, a decrease of $2.9 million, or 13%, from $22.1 million for the year ended December 31, 2015. The decrease was largely due to lower headcount costs and a reduction in the provision for doubtful accounts.

Interest expense, net. Interest expense, net for the year ended December 31, 2016 was $20.2 million, a decrease of $1.6 million, or 7%, from $21.8 million for the year ended December 31, 2015. The decrease was primarily related to reduced interest expense due to less average debt outstanding under our credit agreement during 2016 from the early redemptions of this debt in 2016 and 2015.

Other income (expense), net. The increase was due to a higher gain arising from the redemption of $7.5 million of the debt outstanding under our credit agreement during 2016 compared to the gain recognized during 2015 from the redemption of $10.0 million of the debt outstanding under our credit agreement.

Income tax expense. Although our operations have not been subject to U.S. federal income tax at an entity level, our operations are subject to state taxes within the United States. In addition, Cactus LLC’s operations located in China and Australia are subject to local country income taxes. Income tax expense for the year ended December 31, 2016 and 2015 remained consistent at $0.8 million.

Liquidity and Capital Resources

In February 2018, we completed our IPO. We received net proceeds of $467.4 million from the sale of 26,450,000 shares of Class A Common Stock in the IPO. We contributed all of the net proceeds of the IPO to Cactus LLC in exchange for CW Units. Cactus LLC used (i) $251.0 million of the net proceeds to repay all of the borrowings outstanding, plus accrued interest, under its term loan facility and (ii) $216.4 million to redeem CW Units from certain direct and indirect owners of Cactus LLC.

We expect that our primary sources of liquidity and capital resources will be cash flows generated by operating activities and borrowings under our revolving credit facility. Depending upon market conditions and other factors, we may also have the ability to issue additional equity and debt if needed.

Historically, our predecessor’s primary sources of liquidity were cash flows from operations, borrowings under Cactus LLC’s credit agreement and equity provided by the Pre-IPO Owners. Our predecessor’s primary use of capital has been for working capital purposes, to make cash distributions to the Pre-IPO Owners and repay indebtedness. Prior to the repayment of the term loan facility in conjunction with the IPO, our predecessor’s borrowings outstanding under Cactus LLC’s credit agreement were $248.5 million and $251.1 million at December 31, 2017 and 2016, respectively. Borrowings were used primarily for working capital purposes, to make cash distributions to the Pre-IPO Owners and repay indebtedness.

Our ability to satisfy our liquidity requirements, including cash distributions to the CW Unit Holders to fund their share of taxes of the partnership, depends on our future operating performance, which is affected by prevailing economic conditions, market conditions in the E&P industry, availability and cost of raw materials, and financial, business and other factors, many of which are beyond our control.

We currently estimate that our capital expenditures for the year ending December 31, 2018 will range from $40 million to $50 million, excluding acquisitions. We have begun expanding our investments in frac equipment in response to increasing opportunities and client demands, and we expect to expand our facilities. We continuously evaluate our capital expenditures, and the amount we ultimately spend will depend on a number of factors, including, among other things, demand for rental assets, prevailing economic conditions, market conditions in the E&P industry, customers’ forecasts, demand volatility and company initiatives. We believe that our existing cash on hand, cash generated from operations and available borrowings under our revolving credit facility will be sufficient to meet working capital requirements, anticipated capital expenditures, expected cash distributions to the CW Unit Holders and anticipated tax liabilities for at least the next 12 months.

At December 31, 2017 and December 31, 2016, we had approximately $7.6 million and $8.7 million, respectively, of cash and cash equivalents and approximately $50 million and $15 million, respectively, of available borrowing capacity under our revolving credit facility. As of December 31, 2017, there were no borrowings outstanding under the revolving credit facility and $50 million in available borrowing capacity thereunder. On January 21, 2018, the board of directors of Cactus LLC declared a cash distribution of $26.0 million, which was paid to the Pre-IPO Owners on January 25, 2018. Such distribution was funded by borrowing under the revolving credit facility. The purpose of the distribution was to provide funds to the Pre-IPO Owners to pay their federal and state tax liabilities associated with taxable income recognized by them as a result of their ownership interests in Cactus LLC prior to the completion of our IPO. As of March 13, 2018, we had $8.0 million outstanding under the revolving credit facility and approximately $11.0 million of cash and cash equivalents.

Cash Flows

Year Ended December 31, 2017 Compared to Year Ended December 31, 2016

The following table summarizes our cash flows for the periods indicated:

Net cash provided by operating activities was $34.7 million and $24.0 million for the years ended December 31, 2017 and 2016, respectively. The primary reason for the change was the $74.7 million increase in net income and $3.2 million increase in non-cash items, offset by a $67.2 million increase in net working capital items due to the significant increase in business activity during the second half of 2017.

Net cash used in investing activities was $30.7 million and $17.4 million for the years ended December 31, 2017 and 2016, respectively. The primary reason for the change was higher capital expenditures during 2017 related to the additional investments in our rental fleet as market activity improved significantly during 2017.

Net cash used in financing activities was $5.3 million and $10.2 million for the years ended December 31, 2017 and 2016, respectively. The primary reason for the change was due to less debt service in 2017 as 2016 included a partial

redemption of principal under our term loan. Also, there were no distributions to members in 2017 compared to $2.1 million in 2016.

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

The following table summarizes our cash flows for the periods indicated:

Net cash provided by operating activities was $24.0 million and $45.9 million for the years ended December 31, 2016 and 2015, respectively. The primary cause of the reduction was the $29.4 million reduction in net income, partially offset by an $8.9 million reduction in net working capital items.

Net cash used in investing activities was $17.4 million and $23.4 million for the years ended December 31, 2016 and 2015, respectively. The primary reason for the change was a $3.6 million reduction in capital expenditures from 2015 to 2016 following a facility expansion and additional purchases of property and equipment in 2015.

Net cash used in financing activities was $10.2 million and $22.8 million for the years ended December 31, 2016 and 2015, respectively. The primary reason for the change was lower distributions to members of $10.2 million in 2016 compared to 2015.

Credit Agreement

On July 31, 2014, we entered into a credit agreement with Credit Suisse AG as administrative agent, collateral agent and issuing bank, and the other lenders party thereto (the “Credit Agreement”). The Credit Agreement provides for a term loan tranche in an aggregate principal amount of $275.0 million, the outstanding balance of which was repaid in full with the net proceeds of the IPO, and a revolving credit facility of up to $50.0 million with a $10.0 million sublimit for letters of credit. The revolving credit facility matures on July 31, 2019.

As of December 31, 2017 and 2016, we had $248.5 million and $251.1 million, respectively, of borrowings outstanding under the term loan, no borrowings outstanding under the revolving credit facility and no outstanding letters of credit. In conjunction with our IPO, we repaid the $248.5 million outstanding under the term loan, plus accrued interest.

On January 21, 2018, the board of directors of Cactus LLC declared a cash distribution of $26.0 million, which was paid to the Pre-IPO Owners on January 25, 2018. Such distribution was funded by a $26.0 million borrowing under the revolving credit facility. As of March 13, 2018, we had $8.0 million outstanding on the revolving credit facility.

The Credit Agreement is secured by liens on substantially all of our properties and guarantees from Cactus LLC and any future subsidiaries of Cactus LLC that may become guarantors under the Credit Agreement. The Credit Agreement contains restrictive covenants that may limit our ability to, among other things: