SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year ended December 31, 2017
[ ] 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: 001-36909
|ECO-STIM ENERGY SOLUTIONS, INC.|
|(Exact name of registrant as specified in its charter)|
|(State or other jurisdiction of||(IRS Employer|
|incorporation or organization)||Identification Number)|
|2930 W. Sam Houston Pkwy N., Suite 275, Houston TX||77043|
|(Address of principal executive offices)||(Zip Code)|
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
|Title of each class||Name of each exchange on which registered|
|Common Stock, par value $0.001 per share||The NASDAQ Stock Market LLC|
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 [X]
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 [X]
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes [X] No [ ]
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes [X] No [ ]
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) 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, a smaller reporting company or 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. (Check one):
|Large accelerated filer||[ ]||Accelerated filer [ ]|
|Non-accelerated filer||[ ] (Do not check if a smaller reporting company)||Smaller reporting company [X]|
|Emerging growth company [ ]|
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 Act). Yes [ ] No [X]
As of June 30, 2017, the aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant, computed by reference to the closing price of that date, was $15,489,917.
The registrant had 74,577,899 shares of common stock outstanding at March 16, 2018.
Documents Incorporated by Reference: None
CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS
This Annual Report on Form 10-K (this “Form 10-K”) contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical facts, included in this Form 10-K that address activities, events or developments that we expect, project, believe or anticipate will or may occur in the future are forward-looking statements. When used in this Form 10-K, the words “could,” “would,” “should,” “believe,” “anticipate,” “plan,” “intend,” “estimate,” “expect,” “project” and other similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Our forward-looking statements are based on our current expectations and assumptions and currently available information. Forward-looking statements may include statements that relate to, among other things:
|●||our future financial and operating performance and results, including estimated revenue, margins, earnings or losses, or growth rates;|
|●||our business strategy and budgets;|
|●||our prospects and the plans and objectives of our management;|
|●||future pricing and other conditions in the markets we serve;|
|●||our efforts and ability to obtain future contracts and customers;|
|●||our efforts and ability to renegotiate the terms of our existing contract in Argentina and enter into a new modified definitive agreement, or to otherwise exit our existing contract in Argentina, or to bid for new contracts in Argentina;|
|●||our financial strategy;|
|●||the amount, nature and timing of capital expenditures;|
|●||competition and government regulations;|
|●||future operating costs and other expenses;|
|●||our cash flow and anticipated liquidity;|
|●||our property and equipment acquisitions and sales; and|
|●||our plans, forecasts, objectives, expectations and intentions.|
Forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause our actual results, performance or achievements to be materially different from the anticipated future results or financial condition expressed or implied by the forward-looking statements. These risks, uncertainties and other factors include but are not limited to:
|●||the cyclical nature of the oil and natural gas industry;|
|●||the potential for our customers to backward-integrate by starting their own well service operations or otherwise reduce the use of our services;|
|●||the potential for excess capacity in the oil and natural gas service industry;|
|●||dependence on the spending and drilling activity by the onshore oil and natural gas industry;|
|●||competition within the oil and natural gas service industry;|
|●||concentration of our customer base and fulfillment of existing customer contracts;|
|●||our ability to maintain pricing and obtain contracts;|
|●||deterioration of the credit markets;|
|●||our ability to raise additional capital to fund future and committed capital expenditures;|
|●||increased vulnerability to adverse economic conditions due to our incurrence of indebtedness;|
|●||our limited operating history;|
|●||our ability to obtain raw materials and specialized equipment;|
|●||technological developments or enhancements;|
|●||asset impairment and other charges;|
|●||our ability to identify, make and integrate acquisitions;|
|●||Fir Tree Partners (together with its affiliated funds, “Fir Tree”) control over stockholder voting;|
|●||loss of key executives;|
|●||the ability to employ and retain skilled and qualified workers;|
|●||work stoppages and other labor matters;|
|●||hazards inherent to the oil and natural gas industry;|
|●||inadequacy of insurance coverage for certain losses or liabilities;|
|●||delays in obtaining required permits;|
|●||ability to import equipment or spare parts into Argentina on a timely basis;|
|●||legislation and regulations affecting the oil and natural gas industry or aspects of our business, including future legislative and regulatory developments;|
|●||legislation and regulatory initiatives relating to well stimulation;|
|●||foreign currency exchange rate fluctuations;|
|●||effects of climate change;|
|●||volatility of economic conditions in Argentina;|
|●||market acceptance of turbine pressure pumping technology;|
|●||the profitability for our customers of shale oil and gas as commodity prices decrease;|
|●||risks of doing business in Argentina and the United States;|
|●||risks associated with the start-up of new business operations in new markets, such as the inability to hire sufficient qualified employees, obtain necessary machinery and equipment needed to conduct our operations and meet the needs of our customers, and our ability to obtain operating permits in time; and|
|●||costs and liabilities associated with labor, employment, environmental, health and safety laws, including any changes in the interpretation or enforcement thereof.|
For additional information regarding known material factors that could affect our operating results and performance, please read (1) “Part I—Item 1A—Risk Factors” in this Annual Report on Form 10-K and (2) “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II—Item 7 of this Annual Report on Form 10-K. Should one or more of these known material risks occur, or should the underlying assumptions prove incorrect, our actual results, performance, achievements or other events could differ materially from those expressed or implied in any forward-looking statement. There also may be risks of which we are currently unaware.
We believe that it is important to communicate our expectations of future performance to our investors. However, events may occur in the future that we are unable to accurately predict, or over which we have no control. When considering our forward-looking statements, you should keep in mind the cautionary statements in this Form 10-K, which provide examples of risks, uncertainties and events that may cause our actual results to differ materially from those contained in any forward-looking statement.
All subsequent written and oral forward-looking statements attributable to us or any person acting on our behalf are expressly qualified in their entirety by the cautionary statements contained or referred to in this section and any other cautionary statements that may accompany such forward-looking statements. Except as otherwise required by applicable law, we disclaim any duty to revise or 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 Form 10-K.
You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only of our expectations based on known factors as of the date of the particular statement.
TABLE OF CONTENTS
|Item 1A.||Risk Factors||8|
|Item 1B.||Unresolved Staff Comments||27|
|Item 3.||Legal Proceedings||28|
|Item 4.||Mine Safety Disclosures||28|
|Item 5.||Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities||29|
|Item 6.||Selected Financial Data||30|
|Item 7.||Management’s Discussion and Analysis of Financial Condition and Results of Operations||31|
|Item 7A.||Quantitative and Qualitative Disclosures About Market Risk||41|
|Item 8.||Financial Statements and Supplementary Data||42|
|Item 9.||Changes in and Disagreements with Accountants on Accounting and Financial Disclosure||67|
|Item 9A.||Controls and Procedures||67|
|Item 9B.||Other Information||68|
|Item 10.||Directors, Executive Officers and Corporate Governance||69|
|Item 11.||Executive Compensation||75|
|Item 12.||Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters||82|
|Item 13.||Certain Relationships and Related Transactions, and Director Independence||84|
|Item 14.||Principal Accounting Fees and Services||86|
|Item 15.||Exhibits, Financial Statement Schedules||87|
|Item 16.||Form 10-K Summary||90|
Except when the context otherwise requires or where otherwise indicated, throughout this Annual Report on Form 10-K, we use the terms “Eco-Stim,” “EcoStim,” “Company,” “we,” “us” and “our” to refer to Eco-Stim Energy Solutions, Inc.
ITEM 1. BUSINESS
Eco-Stim Energy Solutions, Inc. is a growth-oriented, technology-driven independent oilfield services company providing well stimulation, coiled tubing and field management services to the upstream oil and gas industry. We are focused on reducing the ecological impact and improving the economic performance of the well stimulation process in “unconventional” drilling formations. We currently offer our services to oil and natural gas exploration and production (“E&P”) companies in the United States and Argentina. Our focus is to bring our service offerings, technologies and processes to the most active shale resource basins both domestically and outside of North America using our technology to differentiate our service offerings.
For information about our operating segments and financial information by operating segment and geographic area, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in Part II, Item 7 of this Annual Report on Form 10-K, and Note 19 to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.
We offer a variety of specialized oilfield services and equipment generally categorized by their typical use during the economic life of a well. A description of the various services we offer is provided below.
Our customers utilize our pressure pumping services to enhance the production of oil and natural gas from formations with low permeability, which restricts the natural flow of hydrocarbons. The technique of well stimulation consists of pumping a fluid into a cased well at sufficient pressure to create new channels in the rock, which can increase the extraction rates and the ultimate recovery of the hydrocarbons. Our equipment that is contracted by E&P companies to provide pressure-pumping services is referred to as a “well stimulation fleet” or “spread.”
We currently operate three well stimulation fleets, two in the United States based out of our operations facility in Fairview, Oklahoma, and one in Argentina based out of our operations facility in Neuquén, Argentina. In the United States, we currently provide pressure pumping services to customers in the Anadarko Basin in Oklahoma. Our operations base in Fairview, Oklahoma is well situated to provide services to E&P companies in the mid-continent region, including in the Scoop, Stack, Cana-Woodford, Mississippian Lime and Springer plays.
Our well stimulation fleets generally include high pressure well-stimulation pumps and other supporting equipment, in both trailer-mounted and skid-mounted configurations. We have the capability of providing a variety of pressure-pumping services, including work-over pumping and well injection. As of March 1, 2018, we (i) owned 47 high-pressure pumps with an aggregate capacity of approximately 110,250 horsepower (“HHP”); (ii) leased six high-pressure pumps with an aggregate capacity of approximately 13,500 HHP; and (iii) owned an additional 20 high-pressure pumps with an aggregate capacity of approximately 45,000 HHP that require refurbishment and upgrade prior to activation for service.
A portion of our equipment consists of turbine powered pressure pumping equipment (referred to as “TPUs”), which are powered by remanufactured turbine engines previously used in military applications. Each turbine engine generates approximately 4,000 HHP and therefore when operating at 2,000 HHP, the engine is running at approximately 50% of its capacity, which benefits their reliability and durability. They also weigh less than 10% of the typical reciprocating engine of comparable horsepower. The weight differential allows for better use of space on a trailer and more efficient operations. We believe the TPUs are more cost effective to operate and maintain than conventional diesel-powered equipment when run on natural gas. Prior field operations with our current TPUs have demonstrated compliance with emission standards for nitrogen oxides (“NOx”) and carbon monoxide under the EPA’s Tier 4 standards that regulate emissions from certain off-road diesel engines. Turbine engines also have significantly lower methane leakage compared to reciprocating engines.
We currently offer coiled tubing services to customers in Argentina. Our coiled tubing services are used to perform various functions associated with well-servicing operations and to facilitate completion of horizontal wells. Coiled tubing services involve the insertion of steel tubing into a well to convey materials and/or equipment to perform various applications as part of a new completion or the servicing of existing wells, including wellbore maintenance, nitrogen services, thru-tubing services, and formation stimulation using acid and other chemicals. Coiled tubing has become a preferred method of well completion, workover and maintenance projects due to speed, ability to handle heavy-duty jobs across a wide spectrum of pressure environments, safety and ability to perform services without having to shut-in a well. The capabilities of our coiled tubing unit in Argentina cover a wide range of applications for horizontal completion, work-over and well-maintenance projects.
In May 2017, our first U.S. spread commenced operations in Oklahoma for an independent E&P company. In October 2017, our second U.S. spread commenced operations in Oklahoma for another independent E&P company. In November 2017, we negotiated an early release of our first U.S. spread from our contract with our first U.S. customer and have now deployed that spread to serve other customers consisting primarily of independent E&P companies. For the year ended December 31, 2017, our first two U.S. customers accounted for approximately 99% of our total U.S. revenue.
In Argentina, our customers have consisted primarily of international oil and gas E&P companies including national oil companies, local privately-held exploration and production companies and, on occasion, other service companies that have contractual obligations to provide well stimulation and completion services. For the year ended December 31, 2017, our largest customer in Argentina accounted for approximately 44% of our total revenue and 99% of the revenue generated from our operations in Argentina.
Customer demand for our services depends primarily upon the capital and operating spending of oil and gas exploration and production companies and the level of drilling activity in the regions we serve. We expect to continue to derive a significant portion of our revenue from a relatively small number of customers in the future. If one or more of our customers decided not to continue to use our services, our revenue could decline significantly and our operating results, financial condition and cash flows could be adversely impacted.
We provide services in the U.S. and Argentina, both highly competitive markets, with competitors comprised of both small and large companies. Our revenues and earnings can be affected by numerous factors, including changes in competition, fluctuations in drilling and completion activity, perceptions of future prices of oil and gas, government regulation, disruptions caused by weather and general economic conditions. We believe the principal competitive factors are price, performance, service quality, safety, response time and breadth of services. We believe our primary competitors in Argentina include Schlumberger, Halliburton, Weatherford, Baker Hughes, Calfrac Well Services and San Antonio International and other oilfield service companies. In the United States, we compete against many of the same competitors as in Argentina but in addition, we also face strong competition from many independent pressure pumping companies. We also compete with various other regional and local providers within each of our geographic markets for products and services.
In May 2017, our first U.S. spread commenced operations in Oklahoma. In October 2017, our second U.S. spread commenced operations in Oklahoma. The market in this region is concentrated around wells being drilled in the Scoop, Stack, Cana-Woodford, Mississippian Lime and Springer plays. Activity in this region has accelerated in late 2016 and 2017, and on into the first quarter of 2018. According to Baker Hughes’ North America Rotary Rig Count data, in early March 2018 there were 124 rigs operating in Oklahoma as compared to 98 rigs operating in early March 2017, and 70 rigs operating in early March 2016. We have established a base of operations in Fairview, Oklahoma, which we believe is well situated to provide services to E&P companies in the mid-continent region, including in the Scoop, Stack, Cana-Woodford, Mississippian Lime and Springer plays.
We have been operating an oilfield services business in Argentina since December 2014. Our first full year of operations was 2015. The market for our services in Argentina can be broken into three service offerings, (1) pressure pumping, (2) coiled tubing and (3) field management. The majority of our revenue comes from the pressure pumping market which can be broken into three sub-markets, (1) conventional wells, (2) tight gas wells and (3) unconventional wells. Generally, the conventional wells can be serviced with 3-5 pumping units whereas the tight gas wells require 8-10 pumping units. The unconventional wells in Argentina require anywhere from 16 to 24 pumping units. In 2015, we had sufficient pumping capacity to participate in the conventional well market. In 2016, we expanded our capacity and now have the capacity to serve customers in the tight gas market. In the second quarter of 2017, we entered into a two-year contract with the largest operator in Argentina to provide services for their tight gas completions program. We anticipate that as the market in Argentina recovers and activity increases, there may be opportunities to secure other long-term agreements and add additional pumping capacity to service all three markets.
Our coiled tubing services support our pressure pumping business, including the drill out of frac plugs, wash-downs, chemical treatments and workover activity. We provide these services to the conventional, tight gas and unconventional well markets in Argentina.
Our field management business consists of various degrees of subsurface analysis derived from the data received from clients or otherwise acquired. The different forms of data include geophysical, geo-mechanical, core samples and other information provided by our customers and data acquired, processed and interpreted by our team including real time fiber optic information data gathered from pressure gauges installed in the wells. This market is driven by exploration and step-out development in new regions or in mature areas where our customers are looking to better understand the production associated with older wells. The market for these services is limited but complements our primary business lines and we believe these services bring expertise and value to our customers.
The Baker Hughes rig counts noted drilling rig count in Argentina peaked at 113 in 2014, bottomed at 52 in January 2017 and was 68 in January 2018. The rig count is an indicator of activity in Argentina that we expect will continue to drive the utilization and pricing of our services. Additionally, as wells become more complex and drilling activity moves from traditional to tight gas and then horizontals, we believe demand for pressure pumping services will grow.
Potential Liabilities and Insurance
Our operations involve a high degree of operational risk and expose us to significant liabilities. An accident involving our services or equipment, or the failure of a product sold by us, could result in personal injury, loss of life, and damage to property, equipment or the environment. Litigation arising from a catastrophic occurrence, such as fire, explosion, or well blowout, may result in substantial claims for damages.
We maintain insurance coverage of types and amounts that we believe to be customary and reasonable for companies of our size and with similar operations. In accordance with industry practice, however, we do not maintain insurance coverage against all the operating risks to which our business is exposed. Therefore, there is a risk our insurance program may not be sufficient to cover any particular loss or all losses. Currently, our insurance program includes, among other things, general liability, excess liability, sudden and accidental pollution, contractors’ pollution, equipment floater, commercial property, vehicle, workers’ compensation, directors and officers liability, employment practices liability, and employer’s liability coverage. Our insurance includes various limits and deductibles or retentions, which must be met prior to or in conjunction with recovery.
Our business is significantly affected by federal, state, provincial and local laws and other regulations. These laws and regulations relate to, among other things:
|●||worker safety standards;|
|●||the protection of the environment;|
|●||the handling and transportation of hazardous materials;|
|●||the protection of natural and cultural resources; and|
|●||the mobilization of our equipment to, and operations conducted at, our work sites.|
Numerous permits are required for the conduct of our business and operation of our various facilities and equipment, including our trucks and other heavy equipment. These permits can be revoked, modified or renewed by issuing authorities based on factors both within and outside our control.
We cannot predict changes in the interpretation of, or changes to the policies adopted by governmental agencies in connection with the enforcement of, existing laws and regulations or how such laws, regulations and policies may be interpreted by enforcement agencies or court rulings in the future. We also cannot predict whether additional laws and regulations will be adopted, including changes in regulatory oversight, increase of federal, state or local taxes, increase of inspection costs, or the effect such changes may have on us, our businesses or our financial condition.
Our operations, and those of our customers, are subject to extensive laws, regulations and treaties relating to air and water quality, generation, storage and handling of hazardous materials, and emission and discharge of materials into the environment, and the protection of natural resources. Compliance with these environmental laws and regulations may expose us to significant costs and liabilities and cause us to incur significant capital expenditures in our operations. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of investigatory and remedial obligations, and the issuance of injunctions delaying or prohibiting operations. Historically, our expenditures in furtherance of our compliance with these laws, regulations and treaties have not been material, and we do not expect the cost of compliance to be material in the future; however, we can provide no guarantee that this will not change.
The primary U.S. federal environmental laws to which our operations are subject include the federal Clean Air Act (“CAA”) and regulations thereunder, which regulate air emissions; the Clean Water Act (“CWA”) and regulations thereunder, which regulate the discharge of pollutants in industrial wastewater and storm water runoff; the Resource Conservation and Recovery Act and regulations thereunder, which regulate the management and disposal of hazardous and non-hazardous solid wastes; and the Comprehensive Environmental Response, Compensation, and Liability Act and regulations thereunder, known more commonly as “Superfund,” which imposes liability for the remediation of releases of hazardous substances in the environment. We are also subject to regulation under the U.S. federal Occupational Safety and Health Act and regulations thereunder, which regulate the protection of the safety and health of workers. Analogous state and local laws and regulations may also apply. Similar laws and regulations exist at the national and provincial level in Argentina.
In the last several years, there has been domestic and international scrutiny of hydraulic fracturing activities, resulting in additional regulation. Domestically, the U.S. Environmental Protection Agency (“EPA”) and other federal agencies, including the Bureau of Land Management (“BLM”) have finalized rules or made proposals that would subject hydraulic fracturing to further regulation and could restrict the practice of hydraulic fracturing. For example, in 2016 the EPA issued final regulations under the CAA establishing performance standards for oil and gas activities, including standards for the capture of air emissions released during hydraulic fracturing and finalized CWA regulations that prohibit the discharge of wastewater from hydraulic fracturing operations to publicly owned wastewater treatment plants. In addition, some states and municipalities have significantly limited drilling activities and/or hydraulic fracturing, or are considering doing so. The BLM and several states have already adopted and more states are considering adopting laws and/or regulations that require disclosure of chemicals used in hydraulic fracturing and impose more stringent permitting, disclosure and well-construction requirements on hydraulic fracturing operations. The BLM published a final rule in March 2015 that established new or more stringent standards relating to hydraulic fracturing on federal and American Indian lands. This BLM rule was challenged in litigation, and, in December 2017, the BLM published a final rule rescinding the March 2015 rule. In January 2018, litigation challenging the BLM’s rescission of the 2015 rule was brought in federal court. If such litigation is successful or if the March 2015 rule is otherwise restored in whole or in part, our hydraulic fracturing activities may be subject to increased regulatory burden. Also in Oklahoma, where we operate in the U.S., the Oklahoma Corporation Commission has taken steps to address the potential link between hydraulic fracturing activities and underground injection disposal well operations and induced seismic events. In Argentina, Neuquén Province has promulgated rules and procedures for the exploration and development of unconventional reservoirs, while other provinces have banned hydraulic fracturing altogether. Although it is not possible at this time to predict the final outcome of these proposals, any new federal, state or local restrictions on hydraulic fracturing that may be imposed in areas in which we conduct business could potentially result in increased compliance costs for us or our customers, or delays in development or restrictions on our operations or the operations of our customers, which in turn could have an adverse effect on our business and results of operations.
In addition, from time to time regulators in both the U.S. and Argentina have taken steps to restrict emissions of carbon dioxide, methane, and other greenhouse gases based on determinations by the scientific community that such emissions are contributing to climate change. Initiatives to date have generally focused on the development of cap-and-trade and/or carbon tax programs. A cap-and-trade program generally would cap overall greenhouse gas emissions on an economy-wide basis and require major sources of greenhouse gas emissions or major fuel producers to acquire and surrender emission allowances. Carbon taxes could likewise affect us by being based on emissions from our equipment and could indirectly affect us by increasing operating costs for our customers. Although it is not possible at this time to predict how legislation or new regulations that may be adopted to address greenhouse gas emissions would impact our business, any such future laws and regulations imposing reporting obligations on, or limiting emissions of greenhouse gases from, our equipment and operations could require us to incur costs to reduce emissions of greenhouse gases associated with our operations. Severe limitations on greenhouse gas emissions could also adversely affect demand for oil and natural gas, which could decrease demand for our services and have a material adverse effect on our profitability, financial condition and liquidity.
We purchase various raw materials and component parts in connection with delivering our services. These materials are generally, but not always, available from multiple sources and may be subject to price volatility. While we generally do not experience significant long-term shortages of these materials, we have from time to time experienced temporary shortages of particular raw materials. We are always seeking ways to ensure the availability of resources, as well as manage costs of raw materials.
Cyclical Nature of Our Industry
We operate in a highly cyclical industry. The key factor driving demand for our services is the level of drilling activity by E&P companies, which in turn depends largely on the current and anticipated economics of new well completions. Global supply and demand for oil and the domestic supply and demand for natural gas are critical in assessing industry outlook. Demand for oil and natural gas is cyclical and subject to large, rapid fluctuations. E&P companies tend to increase capital expenditures in response to increases in oil and natural gas prices, which generally results in greater revenues and profits for oilfield service companies such as ours. Increased capital expenditures also ultimately lead to greater production, which historically has resulted in increased supplies and reduced prices which in turn tend to reduce demand for oilfield services. For these reasons, the results of our operations may fluctuate from quarter to quarter and from year to year.
Seasonal weather and severe weather conditions can temporarily impair our operations by reducing our ability to operate for certain time periods, thereby reducing demand for our services.
At December 31, 2017, we had approximately 230 employees, all of which were full-time employees. As of December 31, 2017, approximately 90% of our Argentine employees and none of our U.S. employees were represented by unions under collective bargaining agreements.
Our principal executive offices are located at 2930 West Sam Houston Parkway North, Suite 275, Houston, Texas 77043. In addition, we own or lease additional facilities in the various areas in which we operate. For more information about our facilities, please read Part 1 – Item 2 – “Properties.”
We have registered with the United States Patent and Trademark Office for the following trademarks: Geo-Predict® and Geo-Iteration®. We have not filed any applications for the registration of our trademarks in foreign jurisdictions, but may do so in the future as we deem necessary to protect our business. In addition, we rely to a great extent on the technical expertise and know-how of our personnel to maintain our competitive position.
Research and Development
See Part II – Item 7 – Management’s Discussion and Analysis of Financial Condition and Results of Operations – Results of Operations – “Overview of Business Services.”
We are a Nevada corporation. We were formed in 2003 in connection with the domestication of a predecessor from the Province of Ontario to Nevada. Our principal executive offices are located at 2930 W. Sam Houston Pkwy. N., Suite 275, Houston, Texas 77043, and our main telephone number at that address is (281) 531-7200. Our website is available at www.ecostim-es.com. Investors should also note that we may announce material financial information in our filings with the U.S. Securities and Exchange Commission (the “SEC”), press releases and public conference calls. Based on guidance from the SEC, we may use the investor relations section of our website to communicate with our investors. It is possible that the financial and other information posted there could be deemed to be material information. Information contained on or available through our website is not part of or incorporated by reference into this Form 10-K or any other report we may file with the SEC, except to the extent explicitly stated in any such report.
We file our reports, proxy statements and other information with the SEC. You can read and copy these reports, proxy statements and other information concerning Eco-Stim at the SEC’s Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549, on official business days during the hours of 10 a.m. to 3 p.m. Please call the SEC at 1-800-SEC-0330 for further information about the operation of the SEC’s Public Reference Room. The SEC also maintains an internet site that contains all reports, proxy statements and other information that we file electronically with the SEC. The address of that website is http://www.sec.gov. We also make available free of charge on our internet website our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after we electronically file such reports with, or furnish them to, the SEC. Additionally, we make available free of charge on our internet website:
|●||our Code of Business Conduct and Ethics, which includes our Financial Code of Ethics for our Chief Executive Officer and Senior Financial Officers; and|
|●||the charters of the audit, compensation, and nominating and governance committees of the Board.|
We intend to disclose changes in or waivers of our Financial Code of Ethics for our Chief Executive Officer and Senior Financial Officers and waivers of our Code of Business Conduct and Ethics for our directors or executive officers on our internet website within four business days of such change or waiver and maintained for at least 12 months, or report such changes or waivers on Item 5.05 of Form 8-K. All of these corporate governance materials are also available free of charge in print to stockholders who request them in writing addressed to Eco-Stim Energy Solutions, Inc., Attention: Investor Relations, 2930 W. Sam Houston Pkwy N., Suite 275, Houston, Texas 77043.
Investors should be aware that while we do, at various times, communicate with securities analysts, it is against our policy to disclose to them selectively any material non-public information or other confidential information. Accordingly, investors should not assume that we agree with any statement or report issued by an analyst with respect to our past or projected performance. To the extent that reports issued by securities analysts contain any projections, forecasts or opinions, such reports are not our responsibility.
ITEM 1A. RISK FACTORS
An investment in our securities involves a number of risks. You should carefully consider the risks described in “Risk Factors,” in addition to the other information contained in this Form 10-K, including “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and related notes, before investing in our securities. These risks could materially affect our business, financial condition and results of operations, and cause the trading price of our securities to decline. You could lose part or all of your investment. You should bear in mind, in reviewing this Form 10-K, that past experience is no indication of future performance. You should read the section titled “Cautionary Statements Regarding Forward-Looking Statements” for a discussion of what types of statements are forward-looking statements, as well as the significance of such statements in the context of this Form 10-K.
Risks Related to Our Business
Our business depends on capital spending by the oil and natural gas industry, and reductions in capital spending could have a material adverse effect on our results of operations, financial condition and cash flows.
Our business is directly affected by the capital spending of E&P companies to explore for, develop and produce oil and natural gas in the United States and Argentina. The significant decline in oil and natural gas prices that began in late 2014 caused a reduction in the exploration, development and production activities of most of these companies. These cuts in spending have curtailed drilling programs, which has resulted in a reduction in the demand for our services as compared to activity levels in late 2014, as well as the prices we can charge. In addition, certain of these companies could become unable to pay their vendors and service providers, including us, as a result of the decline in commodity prices. Reduced discovery rates of new oil and natural gas reserves in our areas of operation as a result of decreased capital spending may also have a negative long-term impact on our business, even in an environment of stronger oil and natural gas prices. Any of these conditions or events could adversely affect our operating results. If the recent recovery in oil and natural gas prices does not continue or E&P companies fail to further increase their capital spending, it could have a material adverse effect on our results of operations, financial condition and cash flows.
Industry conditions are influenced by numerous factors over which we have no control, including:
|●||domestic and foreign economic conditions and supply of and demand for oil and natural gas;|
|●||the level of prices, and expectations about future prices, of oil and natural gas;|
|●||the level of global oil and natural gas exploration and production;|
|●||the level of domestic and global oil and natural gas inventories;|
|●||the supply of and demand for pressure pumping services and equipment in the United States and Argentina;|
|●||federal, state and local regulation of hydraulic fracturing and exploration and production activities, and U.S. federal, state and local and non-U.S. governmental regulations and taxes as well as public pressure on governmental bodies and regulatory agencies to regulate our industry;|
|●||governmental regulations, including the policies of governments regarding the exploration for and production and development of their oil and natural gas reserves;|
|●||political and economic conditions in oil and natural gas producing countries;|
|●||actions by the members of the Organization of Petroleum Exporting Countries (“OPEC”) with respect to oil production levels and announcements of potential changes in such levels, including the failure of such countries to comply with announced production cuts;|
|●||worldwide political, military and economic conditions;|
|●||the cost of producing and delivering oil and natural gas;|
|●||the discovery rates of new oil and natural gas reserves;|
|●||shareholder activism or activities by non-governmental organizations to restrict the exploration, development and production of oil and natural gas;|
|●||the availability of water resources, suitable proppant and chemicals in sufficient quantities for use in hydraulic fracturing fluids;|
|●||advances in exploration, development and production technologies or in technologies affecting energy consumption;|
|●||the potential acceleration of development of alternative fuels; and|
|●||uncertainty in capital and commodities markets and the ability of oil and natural gas companies to raise equity capital and debt financing.|
The volatility of oil and natural gas prices may adversely affect the demand for our services and adversely impact our results of operations.
The demand for our services is primarily determined by current and anticipated oil and natural gas prices and the related levels of capital spending and drilling activity 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 E&P companies and may result in the drilling of fewer new wells. This, in turn, could lead to lower demand for our services and may cause lower utilization of our assets. We may experience significant fluctuations in operating results as a result of the reactions of E&P companies to changes in oil and natural gas prices. For example, prolonged low commodity prices experienced by the oil and natural gas industry beginning in late 2014 and uncertainty about future prices even when prices increased, combined with adverse changes in the capital and credit markets, caused many E&P companies to significantly reduce their capital budgets and drilling activity. This resulted in a significant decline in demand for oilfield services and adversely impacted the prices oilfield services companies could charge for their services.
Prices for oil and natural gas historically have been extremely volatile and are expected to continue to be volatile. During the past four years, the posted West Texas Intermediate (“WTI”) price for oil has ranged from a low of $26.21 per barrel (“Bbl”) in February 2016 to a high of $107.26 per Bbl in June 2014. During 2016, WTI prices ranged from $26.21 to $54.06 per Bbl and during 2017, WTI prices ranged from $42.48 to $57.21 per Bbl. As of the first week of March 2018, WTI prices were around $62 per Bbl. If the prices of oil and natural gas continue to be volatile, reverse their recent increases, or decline, our operations, financial condition and cash flows may be materially and adversely affected.
We may be adversely affected by uncertainty in the global financial markets and the deterioration of the financial condition of E&P companies.
Our future results may be impacted by the uncertainty caused by an economic downturn, volatility or deterioration in the debt and equity capital markets, inflation, deflation or other adverse economic conditions that may negatively affect us or parties with whom we do business resulting in a reduction in our customers’ spending and their non-payment or inability to perform obligations owed to us, such as the failure of customers to honor their commitments or the failure of major suppliers to complete orders. Additionally, during times when the natural gas or crude oil markets weaken, E&P companies are more likely to experience financial difficulties, including being unable to access debt or equity financing, which could result in a reduction in spending for our services. In addition, in the course of our business we hold accounts receivable from our customers. In the event of the financial distress or bankruptcy of a customer, we could lose all or a portion of such outstanding accounts receivable associated with that customer. Further, if a customer was to enter into bankruptcy, it could also result in the cancellation of all or a portion of our service contracts with such customer at significant expense or loss of expected revenues to us.
Our operations are subject to inherent risks, some of which are beyond our control. These risks may be self-insured, or may not be fully covered under our insurance policies.
Our operations are subject to hazards inherent in the oil and natural gas industry, such as, but not limited to, accidents, blowouts, explosions, craterings, fires, oil spills and releases of hydraulic fracturing fluids or wastewater into the environment. These conditions can cause:
|●||disruption in operations;|
|●||substantial repair or remediation costs;|
|●||personal injury or loss of human life;|
|●||significant damage to or destruction of property and equipment;|
|●||environmental pollution, including groundwater contamination;|
|●||unusual or unexpected geological formations or pressures and industrial accidents;|
|●||impairment or suspension of operations; and|
|●||substantial revenue loss.|
In addition, our operations are subject to, and exposed to, employee/employer liabilities and risks such as wrongful termination, discrimination, labor organizing, retaliation claims and general human resource related matters.
The occurrence of a significant event or adverse claim in excess of the insurance coverage that we maintain or that is not covered by insurance could have a material adverse effect on our liquidity, combined results of operations and combined financial condition. Claims for loss of oil and natural gas production and damage to formations can occur in the oilfield services industry. Litigation arising from a catastrophic occurrence at a location where our equipment and services are being used may result in our being named as a defendant in lawsuits asserting large claims.
We do not have insurance against all foreseeable risks, either because insurance is not available or because of the high premium costs. The occurrence of an event not fully insured against or the failure of an insurer to meet its insurance obligations could result in substantial losses. In addition, we may not be able to maintain adequate insurance in the future at rates we consider reasonable. Insurance may not be available to cover any or all of the risks to which we are subject, or, even if available, it may be inadequate, or insurance premiums or other costs could rise significantly in the future so as to make such insurance prohibitively expensive
We have a limited operating history and are subject to the substantial risks inherent in the growth and development of a relatively new business enterprise.
We have a limited operating history and, accordingly, we are subject to substantial risks inherent in the growth and development of a relatively new business enterprise. We have been operating an oilfield services business in Argentina since December 2014, with 2015 as our first full year of operations in that country. We commenced our oilfield services operations in the United States in the second quarter of 2017, with our first U.S. spread commencing operations in May 2017 and our second U.S. spread commencing operations October 2017. Although the amount of revenue generated from our operations increased significantly in 2017 as compared to prior periods, we have sustained operating losses in each of the past three years and there can be no assurance that we will be able to continue to grow our revenues or attain operating profitability.
In addition, we have a very limited business history that investors can analyze to aid them in making an informed judgment as to the merits of an investment in our company. Any investment in our company should be considered a high-risk investment because the investor will be placing funds at risk in our company with unforeseen costs, expenses, competition, operational challenges, and other problems to which new ventures are often subjected. Investors should not invest in our company unless they can afford to lose their entire investment. As we are relatively early in the revenue-generation process, our prospects must be considered in light of the risks, expenses, and difficulties encountered in the establishment, growth and development of a new business in a highly competitive industry.
We may have difficulty managing growth in our business, which could adversely affect our financial condition and results of operations.
As a relatively new business enterprise, growth in accordance with our business plan, if achieved, could place a significant strain on our financial, technical, operational and management resources. As we expand the scope of our activities and our geographic coverage through either organic growth or acquisitions, there will be additional demands on our financial, technical, operational and management resources. The failure to continue to upgrade our technical, administrative, operating and financial control systems or the occurrences of unexpected expansion difficulties, including the failure to recruit and retain experienced managers, engineers and other professionals in the oilfield services industry, could have a material adverse effect on our business, financial condition, results of operations and our ability to successfully or timely execute our business plan. We do not have highly sophisticated systems to forecast our future revenue or profitability and therefore could experience difficulty in managing our growth and associated working capital needs.
If our intended expansion of our business is not successful, our financial condition, profitability and results of operations could be adversely affected, and we may not achieve increases in revenue and profitability that we hope to realize.
A key element of our business strategy involves the expansion of our services, geographic presence and customer base. These aspects of our strategy are subject to numerous risks and uncertainties, including:
|●||an inability to retain or hire experienced crews and other personnel;|
|●||a lack of customer demand for the services we intend to provide;|
|●||an inability to secure necessary equipment, raw materials (particularly sand and other proppants) or technology to successfully execute our expansion plans;|
|●||shortages of water used in our hydraulic fracturing operations;|
|●||unanticipated delays that could limit or defer the provision of services by us and jeopardize our relationships with existing customers and adversely affect our ability to obtain new customers for such services; and|
|●||competition from new and existing services providers.|
Encountering any of these or any unforeseen problems in implementing our planned expansion could have a material adverse impact on our business, financial condition, results of operations and cash flows, and could prevent us from achieving the increases in revenues and profitability that we hope to realize.
We participate in a capital-intensive industry and have limited sources of liquidity. Accordingly, we may have capital needs for which our internally generated cash flows and other sources of liquidity may not be adequate.
The oil and gas industry is capital intensive. We have substantial future capital requirements, including the need to fund growth through acquisition of additional equipment and assets, working capital and capital expenditures and any future debt service obligations. Since December 2013, our operations and growth have been funded primarily by proceeds from various equity and debt offerings and more recently by cash flows from operations. Our ability to fund future operations and our planned capital expenditures will depend upon our future operating performance and, more broadly, on the availability and terms of equity and debt financing since we have limited internal sources of liquidity. The availability and terms of financing will be affected by prevailing economic conditions, market conditions in the exploration and production industry, and financial, business and other factors, many of which are beyond our control. If we are unable to generate sufficient cash flows from operations or to obtain additional capital on favorable terms or at all, we may be unable to continue growing our business or to sustain or increase our current level of profitability. Our inability to grow our business may adversely impact our ability to generate profits. Moreover, if we cannot generate sufficient cash flows or otherwise secure sufficient liquidity to support our capital requirements, we may not be able to meet our payment obligations, which could have a material adverse effect on our results of operations or liquidity.
Our liquidity needs and indebtedness, and any indebtedness we may incur in the future, could restrict our operations and make us more vulnerable to adverse economic conditions.
Any indebtedness, whether incurred in connection with acquisitions, operations or otherwise, may adversely affect our operations and limit our growth. In addition, our obligations under our Recourse Receivables Purchase & Security Agreement with Porter Capital Corporation (the “Receivables Agreement”) are secured by liens on certain of our assets, including our accounts receivable, chattel paper, inventory and substantially all of our equipment for our U.S. operations (excluding equipment subject to vendor financing). If our obligations under the Receivables Agreement are accelerated pursuant to the terms of the agreement, we cannot assure you that we will have sufficient funds to repay such obligations and our other obligations arising under our indebtedness or other obligations.
Our level of indebtedness may affect our operations in several ways, including the following:
|●||increasing our vulnerability to general adverse economic and industry conditions;|
|●||the covenants that are contained in the agreements governing our indebtedness could limit our ability to borrow funds, dispose of assets, pay dividends and make certain investments;|
|●||our debt covenants could also affect our flexibility in planning for, and reacting to, changes in the economy and in our industry;|
|●||any failure to comply with the financial or other covenants of our debt, including covenants that impose requirements to maintain certain financial ratios, could result in an event of default, which could result in some or all of our indebtedness becoming immediately due and payable;|
|●||our level of debt could impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions or other general corporate purposes; and|
|●||our business may not generate sufficient cash flow from operations to enable us to meet our obligations under our indebtedness, and we may have difficulty making debt service payments on such indebtedness as payments become due.|
Our customer base is concentrated, and the loss of one or more of our significant customers could cause our revenues to decline substantially and have a material adverse effect on our results of operations, financial condition and cash flows.
Our customer base in both the United States and Argentina is concentrated. We commenced our operations in Argentina in December 2014 and our operations in the U.S. in May 2017. For the year ended December 31, 2017, our first two U.S. customers accounted for approximately 99% of our total U.S. revenue. In November 2017, we negotiated an early release of our first U.S. spread from our contract with our first U.S. customer and we are redeploying that spread to serve other customers; however, there can be no assurance that we will be able to successfully redeploy this spread at attractive utilization or pricing levels or within a short period of time. For the year ended December 31, 2017, our largest customer in Argentina accounted for approximately 44% of our total revenue and approximately 99% of the revenue generated from our operations in Argentina.
We will likely continue to derive a significant portion of our revenue from a relatively small number of customers in the future. If a significant customer fails to pay us, our revenue would be adversely impacted and our operating results and financial condition could be materially harmed. Additionally, if we were to lose a major customer, we may not be able to redeploy our equipment at similar utilization or pricing levels or within a short period of time and such loss could have a material adverse effect on our business until the equipment is redeployed at similar utilization or pricing levels. In addition, contracts with our existing customers may contain provisions whereby the customers may terminate the agreement in the event we are unable to perform under the terms of the contract or make adjustments to service and/or materials fees payable thereunder based on changing market conditions. Our customer contracts are also subject to termination by customers under certain circumstances, and any such termination could have a material adverse effect on our business.
We have incurred losses to date under our service contract with our largest customer in Argentina. If our efforts to renegotiate the terms of our existing contract and enter into a new agreement with more favorable terms are unsuccessful, we may continue to incur losses under the contract. Also, if our negotiations are unsuccessful and we are unable to reach agreement with our customer, we may be released from the contract. If we receive an early release from the contract, our operations in Argentina may continue to incur losses, which could be substantial, until we are able to obtain new work from other customers. In addition, we may determine to reduce the scale of, shut down, or sell our operations in Argentina, which could result in the incurrence of material losses and expenses.
In the second quarter of 2017, we entered into a two-year contract with the largest operator in Argentina to provide services for their tight gas completions program. To date, we have incurred losses under the contract due to lower than expected utilization of our assets, higher than expected third party costs incurred in order to provide the bundled services contemplated under the contract, and other factors. We have been engaged in extensive negotiations with our customer to seek modifications to the contract that would provide us with more favorable operating results. However, there can be no assurance that our efforts to renegotiate the terms of the contract will be successful, and we may continue to incur losses under the contract in the future. Our negotiations with our customer may also result in an early release from our obligations under the contract. If we receive an early release from the contract, we may incur further losses associated with our Argentina operations, which could be substantial, while we transition to new customers, and there can be no assurance that we obtain contracts with new customers on favorable terms. In addition, there can be no assurance that our negotiations will result in either modifications to the contract or a release from the contract prior to the end of its current term. In addition, our Argentina operations may require access to additional capital if we continue to incur losses under our existing contract or during any transition period from our current customer to work for new customers following an early release from our current contract, which could involve the incurrence of indebtedness, cash contributions to our Argentinian subsidiary from our parent company, or third-party financing. We may also incur other material costs in connection with our efforts to renegotiate or exit our current contract. In addition, we may determine to reduce the scale of, shut down, or sell our operations in Argentina, which could result in the incurrence of material losses and expenses.
We may not be able to fulfill, renew or replace our existing agreements on attractive terms or at all, which could adversely impact our results of operations, financial condition and cash flows.
We can provide no assurance that we will be able to successfully fulfill, renew or replace our existing agreements with new agreements on or prior to their expiration on terms satisfactory to us or the customer or that we will be able to continue to provide services under those existing agreements without service interruption. We are dependent on entering into additional service agreements to grow our business. If we are not able to either renew or enter into additional service agreements, our results of operations, financial condition and cash flows could be adversely impacted.
We are exposed to the credit risk of our customers, and any material nonpayment or nonperformance by our customers could adversely affect our financial results.
We are subject to the risk of loss resulting from nonpayment or nonperformance by our customers, many of whose operations are concentrated solely in the exploration and production industry which, as described above, is subject to volatility and, therefore, credit risk. Our credit procedures and policies may not be adequate to fully reduce customer credit risk. If we are unable to adequately assess the creditworthiness of existing or future customers or unanticipated deterioration in their creditworthiness, any resulting increase in nonpayment or nonperformance by them and our inability to re-market or otherwise use our equipment could have a material adverse effect on our financial condition, results of operations and cash flows.
We may be unable to maintain or improve pricing on our core services.
Pressures stemming from fluctuating market conditions and oil and natural gas prices may make it difficult to maintain or improve the pricing for our services. We have faced in the past, and may continue to face in the future, reductions in demand for our services as well as pricing pressure from the competitors who are also competing for those same opportunities. If we are unable to maintain or improve pricing on our core services, our financial results will be negatively impacted.
Our customers may choose to integrate their operations vertically by purchasing and operating their own well stimulation fleet, expanding the amount of well stimulation equipment they currently own or using alternative technologies for enhancing oil and gas production.
Our customers may choose to integrate their operations vertically by purchasing and operating their own well stimulation fleets in lieu of using our well stimulation services. In addition, there are other technologies available for the artificial enhancement of oil and natural gas production and our customers may elect to use these alternative technologies instead of the well stimulation services we provide. Vertical integration increases or use of alternative technologies could result in decreased demand for our well stimulation services, which may have a material adverse effect on our business, results of operations and financial condition.
Our assets require significant amounts of capital for maintenance, upgrades and refurbishment and we may require significant capital expenditures for additional equipment.
Our pressure pumping and other related equipment requires significant capital investment for maintenance, upgrades and refurbishment to maintain their competitiveness. The costs of components and labor have increased in the past and may increase in the future with increases in demand, which will require us to incur additional costs to maintain our current equipment or upgrade and maintain any spreads we may acquire in the future. Our spreads and other equipment typically do not generate revenue while they are undergoing maintenance, upgrades or refurbishment. Any maintenance, upgrade or refurbishment project for our assets could increase our indebtedness or reduce cash available for other opportunities. Furthermore, such projects may require proportionally greater capital investments as a percentage of total asset value, which may make such projects difficult to finance on acceptable terms. To the extent we are unable to fund such projects, we may have less equipment available for service or our equipment may not be attractive to potential or current customers. Additionally, competition or advances in technology within our industry may require us to update or replace existing spreads or build or acquire new spreads. Such demands on our capital or reductions in demand for our pressure pumping services and the increase in cost of labor necessary for such maintenance and improvement, in each case, could have a material adverse effect on our financial condition, results of operations, cash flows and prospects.
We rely on a limited number of third parties for sand, proppant and chemicals, and delays in deliveries of such materials, increases in the cost of such materials or our contractual obligations to pay for materials that we ultimately do not require could harm our business, results of operations and financial condition.
We have established relationships with a limited number of suppliers of our raw materials (such as guar gum, sand, proppant and chemicals). Should any of our current suppliers be unable to provide the necessary materials or otherwise fail to deliver the materials in a timely manner and in the quantities required, any resulting delays in the provision of services could have a material adverse effect on our business, results of operations and financial condition. Additionally, increasing costs of such materials may negatively impact demand for our services or the profitability of our operations. In the past, our industry has faced sporadic proppant shortages associated with hydraulic fracturing operations requiring work stoppages, which has adversely impacted the operating results of some of our competitors. We may not be able to mitigate any future shortages of materials, including proppant. Furthermore, to the extent our contracts require us to purchase more materials, including proppant, than we ultimately require, we may be forced to pay for the excess amount under “take or pay” contract provisions.
Our ability to operate successfully depends on the availability of water.
Well stimulation, and pressure pumping more generally, can require a significant supply of water, and water supply and quality are important requirements to our operations. We expect the water requirements necessary for us to conduct our operations will be obtained from sources on or near the well sites, but there is no assurance that there will be a sufficient supply of water from sources in these areas, some of which are prone to drought. For example, in December 2016, the Neuquén province in Argentina declared a 12-month state of emergency as a result of a severe drought. In response to this emergency, the Governor of Neuquén also established a special committee with broad powers to take any “urgent and immediate action deemed necessary to address the water emergency.” While we cannot predict what measures may be taken in response to drought conditions, limitations on water use or increased costs to obtain water from alternative sources has the potential to adversely affect our operations, financial position, and results of operations.
Federal or state legislative and regulatory initiatives related to induced seismicity could result in operating restrictions or delays in the drilling and completion of oil and natural gas wells that may reduce demand for our services and could have a material adverse effect on our business, financial condition and results of operations.
Our E&P company customers dispose of flowback and produced water or certain other oilfield fluids gathered from oil and natural gas E&P operations in accordance with permits issued by government authorities overseeing such disposal activities. While these permits are issued pursuant to existing laws and regulations, these legal requirements are subject to change based on concerns of the public or governmental authorities regarding such disposal activities. One such concern relates to recent seismic events near underground disposal wells that are used for the disposal by injection of flowback and produced water or certain other oilfield fluids resulting from oil and natural gas activities. 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 may 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 response to concerns regarding induced seismicity, regulators in some states have imposed, or are considering imposing, additional requirements in the permitting of produced water disposal wells or otherwise to assess any relationship between seismicity and the use of such wells. For example, Oklahoma issued rules for wastewater disposal wells that imposed certain permitting and operating restrictions and reporting requirements on disposal wells in proximity to faults and also, from time to time, is developing and implementing plans directing certain wells where seismic incidents have occurred to restrict or suspend disposal well operations. The Texas Railroad Commission adopted similar rules. More recently, in December 2016, the Oklahoma Corporation Commission’s (“OCC”) Oil and Gas Conservation Division and the Oklahoma Geological Survey released well completion seismicity guidance, which requires operators to take certain prescriptive actions, including an operator’s planned mitigation practices, following certain unusual seismic activity within 1.25 miles of hydraulic fracturing operations. In addition, in February 2017, the OCC’s Oil and Gas Conservation Division issued an order limiting future increases in the volume of oil and natural gas wastewater injected below ground into the Arbuckle formation in an effort to reduce the number of earthquakes in the state and imposed further reductions in the Edmond area in August 2017. Another consequence of seismic events may be lawsuits alleging that disposal well operations have caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal.
These developments could result in additional regulation and restrictions on the use of injection wells by our customers to dispose of flowback and produced water and certain other oilfield fluids. Increased regulation and attention given to induced seismicity also could lead to greater opposition to, and litigation concerning, oil and natural gas activities utilizing injection wells for waste disposal. Any one or more of these developments may result in our customers having to limit disposal well volumes, disposal rates or locations, or require our customers or third party disposal well operators that are used to dispose of customers’ wastewater to shut down disposal wells, which developments could adversely affect our customers’ business and result in a corresponding decrease in the need for our services, which could have a material adverse effect on our business, financial condition and results of operations.
We may not be able to provide services that meet the specific needs of oil and natural gas E&P companies at competitive prices.
The markets in which we operate are highly competitive and have relatively few barriers to entry, and the competitive environment has intensified as recent mergers among E&P companies have reduced the number of available customers. The principal competitive factors in the markets in which we operate are product and service quality and availability, responsiveness, experience, technology, equipment quality, reputation for safety and price. We compete with small companies capable of competing effectively in our markets on a local basis. We also compete with large national and multi-national companies that have longer operating histories, greater financial, technical and other resources and greater name recognition than we do. Our initial well stimulation fleet in Argentina currently does not have sufficient HHP to enable us to participate in unconventional or larger well stimulation jobs. See Part I – Item 1 – “Business—Markets.”
The inability to control the inherent risks of acquiring and integrating businesses in the future could adversely affect our operations.
As a part of our business strategy, we intend to pursue selected acquisitions or mergers. If we choose to grow our business through acquisitions or mergers, it is possible that companies acquired or merged into our company may have associated risks including:
|●||Unanticipated costs and assumption of liabilities and exposure to unforeseen liabilities;|
|●||Inherent difficulties in integrating the operations and assets of the acquired business and personnel;|
|●||Potential losses of key employees and customers of the acquired business;|
|●||Internal control weaknesses or limitations on our ability to properly assess and maintain an effective internal control environment over an acquired business, in order to comply with public reporting requirements;|
|●||Risks of entering markets in which we have limited prior experience; and|
|●||Increases in our expenses and working capital requirements.|
Unexpected equipment malfunctions, catastrophic events and scheduled maintenance may lead to decreased revenue and reduce our cash flows.
Our performance is primarily dependent upon the efficient and uninterrupted operation of our pressure pumping fleets and, to a lesser extent, the functionality of our coiled tubing unit in Argentina. If our operation of such core equipment experiences unanticipated disruption due to an accident, mechanical failure, shortage of spare parts or other unforeseen event such as a fire, explosion, violent weather conditions or unexpected operational difficulties, or if we have to schedule a temporary shutdown to perform maintenance on any of our core equipment, our ability to provide timely services to our customers could be negatively affected, which could have a material adverse effect on our business, financial condition, results of operations and cash flows.
We may not be successful in implementing technology development and enhancements.
The market for our services and products is characterized by continual technological developments to provide better and more reliable performance and services. If we are not able to provide commercially competitive services in a timely manner in response to changes in technology, our business and revenues could be materially and adversely affected. Likewise, if our technologies, equipment, or work processes become obsolete, we may no longer be competitive and our business and revenues could be materially and adversely affected.
We depend on the services of key executives, the loss of whom could materially harm our business.
The management of our Company is important to our success because they are instrumental in setting our strategic direction, operating the business, identifying, recruiting and training key personnel, and identifying expansion opportunities. Losing the services of any of these individuals could adversely affect our business until a suitable replacement could be found. We do not maintain key man life insurance on any of our management. As a result, we are not insured against any losses resulting from the death of our key employees.
We may be unable to employ a sufficient number of skilled and qualified workers.
The delivery of our services requires personnel with specialized skills and experience who can perform physically demanding work. As a result of the volatility of the oilfield service industry and the demanding nature of the work, workers may choose to pursue employment in fields that offer a more desirable work environment at wage rates that are competitive. The demand for skilled workers is high and the supply is limited.
We may be adversely impacted by work stoppages or other labor matters.
The petroleum and oil-service industries in Argentina, where we operate, and certain other countries are unionized, and it is likely that we may experience work stoppages or other labor disruptions from time to time. As of December 31, 2017, approximately 90% of our Argentine employees were represented by unions and they are working under the conditions stated in their collective bargaining agreements. No assurance can be given that the collective bargaining agreements will be successfully extended or renegotiated as they expire from time to time. If any collective bargaining agreement is not extended or renegotiated, if disputes with our unions arise, or if our unionized workers engage in a strike or other work stoppage or interruption, we could experience a significant disruption of, or inefficiencies in, our operations or incur higher labor costs, which could have a material adverse impact on our combined results of operations and financial condition by disrupting our ability to perform well stimulation or pressure pumping and other services for the customers under our service contracts. In addition, although none of our U.S. employees are currently represented by unions under collective bargaining agreements, there can be no assurance that will be the case in the future or that we will not encounter work stoppages or labor disruptions in the U.S. market.
If we become subject to warranty, similar claims or litigation, it could be time-consuming and costly to defend.
Errors, defects or other performance problems in the products that we sell or services that we offer could result in our customers seeking damages from us for losses associated with these errors, defects or other performance problems.
Our business involves certain operating risks and our insurance coverage or proceeds, if any, may not be adequate to cover all losses or liabilities that we might incur in our operations.
The technical complexities of our operations are such that we are exposed to a wide range of significant worker health, safety and environmental risks. Our services involve production-related activities, radioactive materials, explosives and other equipment and services that are deployed in challenging exploration, development and production environments. An accident involving our services or equipment, or a failure of a product, could cause personal injury, loss of life, damage to or destruction of property, equipment or the environment, or suspension of operations. Our insurance policies may not protect us against liability for some kinds of events, including events involving pollution, or against losses resulting from business interruption. Moreover, we may not be able to maintain insurance at levels of risk coverage or policy limits that we deem adequate. Any damages caused by our services or products that are not covered by insurance, or are in excess of policy limits or are subject to substantial deductibles, could adversely affect our financial condition, results of operations and cash flows.
A terrorist attack or armed conflict could harm our business.
Geopolitical and terrorism risks continue to grow in a number of countries, including those where we do business. Geopolitical and terrorism risks could lead to, among other things, a loss of our investment in the country, impairment of the safety of our employees and impairment of our ability to conduct our operations.
Recently enacted changes to the U.S. federal income tax laws could adversely affect our financial position, results of operations, and cash flows.
Recently enacted legislation, commonly referred to as the Tax Cuts and Jobs Act, made significant changes to the U.S. federal income taxation of business entities. These changes include a permanent reduction to the corporate income tax rate. Such rate reduction, however, could be offset by other changes intended to broaden the tax base, including (i) imposing new limitations on the utilization of net operating losses, (ii) limiting the deductibility of interest expense, and (iii) eliminating the deduction for certain domestic production activities. The Tax Cuts and Jobs Act is highly complex and subject to interpretation. We continue to examine the impact the Tax Cuts and Jobs Act may have on us, and it could have an adverse effect on our financial position, results of operations, and cash flows.
Our ability to use our net operating loss carryforwards and certain other tax attributes may be limited.
As of December 31, 2017, we had approximately $84.0 million of U.S. federal net operating loss carryforwards (“NOLs”), which begin to expire in 2018. Utilization of these NOLs depends on many factors, including our future income, which cannot be assured. In addition, Section 382 of the Internal Revenue Code of 1986, as amended (“Section 382”), generally imposes an annual limitation on the amount of NOLs that may be used to offset taxable income when a corporation has undergone an “ownership change” (as determined under Section 382). An ownership change generally occurs if one or more shareholders (or groups of shareholders) who are each deemed to own at least 5% of our stock change their ownership by more than 50 percentage points over their lowest ownership percentage within a rolling three-year period. In the event that an ownership change has occurred, or were to occur, utilization of our NOLs would be subject to an annual limitation under Section 382, determined by multiplying the value of our stock at the time of the ownership change by the applicable long-term tax-exempt rate as defined in Section 382, subject to certain adjustments. Any unused annual limitation may be carried over to later years. We may have previously experienced and may in the future experience one or more “ownership changes.” As a result, if we earn net taxable income, our ability to use our pre-change NOL carryforwards to offset U.S. federal taxable income may be subject to limitations, which could potentially result in increased future tax liability to us. We believe that the the Fir Tree transaction (noted in Part III – Item 13 - Certain Relationships and Related Transactions, and Director Independence-Transactions with Fir Tree) may constitute a change in control, which could impact our ability to utilize our NOLs; however, we have not yet fully evaluated the impact this transaction will have on us. Furthermore, as discussed above, we continue to examine the impact the Tax Cuts and Jobs Act may have on us with respect to our ability to utilize our NOLs as well as the value of our NOLs to us as a result of the decrease in corporate income tax rates. See “Recently enacted changes to the U.S. federal income tax laws could adversely affect our financial position, results of operations, and cash flows.”
Risks Related to Our Operations in Argentina and Other Foreign Jurisdictions
Our business may be impacted by economic conditions in Argentina.
Our business may be impacted by economic conditions prevailing in Argentina. The Argentine economy has experienced significant volatility in past decades, including numerous periods of low or negative growth and high and variable levels of inflation and devaluation. If economic conditions in Argentina contract, or if the Argentine government’s measures to attract or retain foreign investment and international financing in the future are unsuccessful, such developments could adversely affect our financial condition, results of operations, and cash flows.
Argentine economic conditions are dependent on a variety of factors, including (but not limited to) the following:
|●||international demand for Argentina’s principal exports;|
|●||international prices for Argentina’s principal commodity exports;|
|●||stability and competitiveness of the Argentine Peso against foreign currencies;|
|●||levels of consumer consumption and foreign and domestic investment and financing; and|
|●||the rate of inflation.|
In recent years, Argentina has confronted inflationary pressure. Increased rates of inflation in Argentina could increase our cost of operation and may negatively impact our results of operations and financial condition. There can be no assurance that inflation rates will not be higher in the future.
In addition, Argentina’s economy is vulnerable to adverse developments affecting its principal trading partners. A significant decline in the economic growth of any of Argentina’s major trading partners, such as Brazil, China or the U.S., could have a material adverse impact on Argentina’s balance of trade and adversely affect Argentina’s economic growth and may consequently adversely affect our financial condition, results of operations and cash flows. The Argentine Peso has been subject to significant devaluation in the past and may be subject to significant fluctuations in the future, consequently affecting our financial condition, results of operations and cash flows (see additionally Part I – Item 1A. Risk Factors – “We may be exposed to fluctuations in foreign exchange rates.”)
The Argentinian government has fixed oil and gas prices for domestic producers. Any decrease or removal of the fixed price could result in a corresponding reduction in drilling activity in Argentina, which could adversely impact our results of operations, financial condition and cash flows.
The Argentinian government has historically fixed the price of oil and natural gas. More recently, the government has been supportive of fixed prices for natural gas but has indicated a desire to allow the oil prices to adjust to international prices. We have no assurance that the government will not lower the fixed prices for oil or natural gas in the future or remove them altogether. If the fixed price for oil or natural gas were to be reduced or removed, there may be less drilling activity in Argentina, which could have a corresponding adverse effect on the demand for our products or services.
Certain risks are inherent in any investment in a company operating in an emerging market such as Argentina.
Argentina is an emerging market economy and investing in emerging markets generally carries risks. These risks include political, social and economic instability that may affect Argentina’s economic results which can stem from many factors, including the following:
|●||high interest rates;|
|●||abrupt changes in currency values;|
|●||high levels of inflation;|
|●||wage and price controls;|
|●||regulations to import equipment and other necessities relevant for operations;|
|●||changes in governmental economic or tax policies; and|
|●||political and social tensions.|
Any of these factors may adversely affect our financial condition and results of operation.
The Argentine economy has been adversely affected by economic developments in other markets.
Financial and securities markets in Argentina, and the Argentine economy, are influenced by economic and market conditions in other markets worldwide. Considering the current international turmoil, Argentina’s economy remains vulnerable to external shocks, including those relating to or similar to the global economic crisis that began in 2008 and the more recent uncertainties surrounding European sovereign debt. Although economic conditions vary from country to country, investors’ perceptions of events occurring in one country may substantially affect capital flows into and investments in securities from issuers in other countries, including Argentina.
Consequently, there can be no assurance that the Argentine financial system and securities markets will not continue to be adversely affected by events in developed countries’ economies or events in other emerging markets, which could in turn adversely affect the Argentine economy and, as a consequence, the Company’s results of operations and financial condition.
The implementation of new export duties, other taxes and import regulations could adversely affect our results.
Changes in export duties, taxes and import regulations may negatively affect our business, financial condition and cash flows. For example, in 2012, the Argentine government adopted an import procedure pursuant to which local authorities must pre-approve any import of products and services to Argentina as a precondition to allow importers access to the foreign exchange market for the payment of such imported products and services. We cannot assure you that these taxes and import regulations will not continue or be increased in the future or that other new taxes or import regulations will not be imposed.
We may be exposed to fluctuations in foreign exchange rates.
Our results of operations are exposed to currency fluctuation and any devaluation of the Argentine Peso against the U.S. dollar and other hard currencies may adversely affect our business and results of operations. The value of the Argentine Peso has fluctuated significantly in the past and may do so in the future. We are unable to predict whether, and to what extent, the value of the Argentine Peso may further depreciate or appreciate against the U.S. dollar and how any such fluctuations would affect our business.
We are subject to exchange and capital controls.
In the past, Argentina imposed exchange controls and transfer restrictions substantially limiting the ability of companies to retain foreign currency or make payments abroad. Although the Macri government lifted exchange controls and liberalized capital controls as described above, there can be no assurances regarding future modifications to exchange and capital controls. Exchange and capital controls could adversely affect our financial condition, results of operations and cash flows, and our ability to meet our foreign currency obligations and execute our financing plans.
Operating internationally subjects us to significant risks and regulations inherent in operating in foreign countries.
We may conduct operations in a number of countries as part of our growth strategy. Our international operations will be subject to a number of risks inherent to any business operating in foreign countries, and especially those with emerging markets, including the following risks, among others:
|●||government instability, which can cause investment in capital projects by our potential customers to be withdrawn or delayed, reducing or eliminating the viability of some markets for our services;|
|●||potential expropriation, seizure, nationalization or detention of assets, such as the 2012 nationalization of Repsol S.A.’s interest in YPF;|
|●||difficulty in repatriating foreign currency received in excess of local currency requirements;|
|●||foreign currency exchange rate fluctuations, import/export tariffs and quotas;|
|●||civil uprisings, riots and war, which can make it unsafe to continue operations, adversely affect both budgets and schedules and expose us to losses;|
|●||availability of suitable personnel and equipment, which can be affected by government policy, or changes in policy that limit the importation of qualified crewmembers or specialized equipment in areas where local resources are insufficient;|
|●||decrees, laws, regulations, interpretation and court decisions under legal systems, which are not always fully developed and which may be retroactively applied and cause us to incur unanticipated and/or unrecoverable costs as well as delays which may result in real or opportunity costs; and|
|●||terrorist attacks, including kidnappings of our personnel.|
We cannot predict the nature and the likelihood of any such events. However, if any of these or other similar events should occur, it could have a material adverse effect on our financial condition, results of operation and cash flow.
Certain of the equipment that we use in certain foreign countries may require prior U.S. government approval in the form of an export license and may otherwise be subject to tariffs and import/export restrictions. The delay in obtaining required governmental approvals could affect our ability to timely commence a project, and the failure to comply with all such controls could result in fines and other penalties.
We may be subject to taxation in many foreign jurisdictions and the final determination of our tax liabilities involves the interpretation of the statutes and requirements of taxing authorities worldwide. Our tax returns will be subject to routine examination by taxing authorities, and these examinations may result in assessments of additional taxes, penalties and/or interest.
Our overall success as an international company may depend, in part, upon our ability to succeed in differing economic, social and political conditions. We may not continue to succeed in developing and implementing policies and strategies that are effective in each location where we do business, which could negatively affect our profitability.
Our international operations involve the use of foreign currencies, which subjects us to exchange rate fluctuations, difficulty in repatriating foreign currencies and other currency risks.
We and our foreign subsidiaries from time to time will hold foreign currencies. Exchange rate fluctuations will subject us to currency risk as well as to other risks sometimes associated with international operations. In the future, we could experience fluctuations in financial results from our operations outside the U.S., and there can be no assurance that payments received in foreign currencies can be repatriated to the U.S. or that we will be able, contractually or otherwise, to reduce the currency risks associated with our international operations. In addition, the Tax Cuts and Jobs Act imposes one-time taxation on offshore earnings at reduced rates regardless of whether they are repatriated. The overall impact of the Tax Cuts and Jobs Act is uncertain, and our business and financial condition could be adversely affected.
We could be adversely affected by violations of the U.S. Foreign Corrupt Practices Act and similar foreign anti-bribery laws.
The United States Foreign Corrupt Practices Act (the “FCPA”) and similar worldwide anti-bribery laws generally prohibit companies and their intermediaries from making, offering or authorizing improper payments to non-U.S. government officials for the purpose of obtaining or retaining business. We do business and may do additional business in the future in countries or regions where strict compliance with anti-bribery laws may conflict with local customs and practices.
As a company subject to compliance with the FCPA, our business may suffer and we may be subject to competitive disadvantages because our efforts to comply with U.S. laws could restrict our ability to do business in foreign markets relative to our competitors who are not subject to U.S. law. Additionally, our business plan involves establishing close relationships with stakeholders in certain foreign markets. Any determination that we or foreign shareholders, directors or officer’s partners have violated the FCPA may adversely affect our business and operations.
Violations of anti-bribery laws (either due to our acts or our inadvertence) may result in criminal and civil sanctions and could subject us to other liabilities in the U.S. and elsewhere. Even allegations of such violations could disrupt our business and result in a material adverse effect on our business and operations.
Risks Related to the Oil and Natural Gas Industry
We may face intense competition in our industry and in the markets where we operate.
The industry in which we compete is highly competitive, and most of our potential competitors will have greater financial resources than we do. Our ability to renew or replace existing contracts with our customers at rates sufficient to maintain or improve current revenue and cash flows could be adversely affected by the activities of our competitors and our customers. If our competitors substantially increase the resources they devote to the development and marketing of competitive services or substantially decrease the prices at which they offer their services, we may be unable to compete effectively. Some of these competitors may expand or construct newer, more powerful or more flexible well stimulation fleets that would create additional competition for us. Furthermore, reductions in drilling activity in markets such as North America may drive other oilfield services companies to relocate their equipment to the regions outside the U.S. in which we operate or intend to operate. Such increase in supply relative to demand could negatively impact pricing and utilization of our services. All of these competitive pressures could have a material adverse effect on our business, results of operations and financial condition. There can be no assurance that additional competitors will not enter markets served or proposed to be served by us, that we will be able to compete successfully, or that we will have adequate funds to compete.
Regulatory compliance costs and restrictions, as well as delays in obtaining permits by the customers for their operations, such as for well stimulation and pressure pumping, or by us for our operations, could impair our business.
Our operations and the operations of our customers are subject to or impacted by a wide array of regulations in the jurisdictions in which our and their operations are located. As a result of changes in regulations and laws relating to the oil and natural gas industry, including well stimulation, our operations or the operations of our customers could be disrupted or curtailed by governmental authorities. The high cost of compliance with applicable regulations may cause customers to discontinue or limit their operations, and may discourage companies from continuing development activities. As a result, demand for our services could be substantially affected by regulations adversely impacting the oil and natural gas industry.
Our operations are subject to hazards and environmental risks inherent in the oil and natural gas industry.
We are a provider of well stimulation and pressure pumping services, a process involving the injection of fluids—typically consisting mostly of water and also including several chemical additives—as well as sand in order to create fractures extending from the well bore through the rock formation to enable oil or natural gas to move more easily through the rock pores to a production well. In addition, we provide a range of services to onshore oil and natural gas exploration and production operations, consisting of, among other things, coiled tubing services. Risks inherent to our industry create the potential for significant losses associated with damage to the environment or natural resources, such as the potential for contamination of drinking water resources.
We are subject to extensive environmental, worker health and safety laws and regulations that may subject us to substantial liability or require us to take actions that will adversely affect our results of operations.
The oil and natural gas industry is significantly affected by stringent and complex federal, state and local laws and regulations concerning the discharge of substances into the environment or otherwise relating to environmental protection and worker health and safety matters. The cost of compliance with these laws can be significant. Failure to properly handle, transport or dispose of these materials or otherwise conduct our operations in accordance with these and other environmental laws could expose us to substantial liability for administrative, civil and criminal penalties, cleanup and site restoration costs and liability associated with releases of such materials, damages to natural resources and other damages, as well as potentially impair our ability to conduct our operations. We could be exposed to liability for cleanup costs, natural resource damages and other damages under these and other environmental laws. Such liability can be on a strict, joint and several liability basis, without regard to fault. Liability may be imposed as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by, prior operators or other third parties. Environmental laws and regulations have changed in the past, and they are likely to change in the future. If existing environmental requirements or enforcement policies change and become more stringent, we may be required to make significant unanticipated capital and operating expenditures.
The adoption of climate change legislation or regulations restricting emissions of greenhouse gases could result in increased operating costs and reduced demand for oil and natural gas.
In recent years, many national, federal, state and local governments have taken steps to reduce emissions of greenhouse gases. For example, in the United States, the EPA has finalized a series of greenhouse gas monitoring, reporting and emissions control rules for the oil and natural gas industry, and the U.S. Congress has, from time to time, considered adopting legislation to reduce emissions including carbon dioxide and methane. In December 2015, the United States and Argentina participated in the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change in Paris, France. The resulting Paris Agreement calls for the parties to undertake “ambitious efforts” to limit the average global temperature, and to conserve and enhance sinks and reservoirs of greenhouse gases. The Agreement, which went into effect in November 2016, establishes a framework for the parties to cooperate and report actions to reduce greenhouse gas emissions. However, in August 2017, the U.S. State Department officially informed the United Nations of the intent of the United States to withdraw from the Paris Agreement. The Paris Agreement provides for a four-year exit process beginning when it took effect in November 2016, which would result in an effective exit date of November 2020. The United States’ adherence to the exit process and/or the terms on which the United States may re-enter the Paris Agreement or a separately negotiated agreement are unclear at this time. In addition, we cannot predict what additional steps, if any, Argentina may take as a result of participation in the Paris Agreement. Argentina has also passed a number of energy-efficiency related measures as well as requirements for the blending of ethanol and other biofuels with petroleum fuels. These measures could reduce demands for petroleum products, which in turn could have an adverse impact on demand for our services.
Moreover, climate change may cause more extreme weather conditions such as more intense hurricanes, thunderstorms, tornadoes and snow or ice storms, as well as rising sea levels and increased volatility in seasonal temperatures. Extreme weather conditions can interfere with our services and increase our costs and damage resulting from extreme weather. At this time, we are unable to determine the extent to which climate change may lead to increased storm or weather hazards affecting our operations.
New technology may cause us to become less competitive.
The oilfield services industry is subject to the introduction of new drilling and completion techniques and services using new technologies, some of which may be subject to patent protection. If competitors and others use or develop new technologies in the future that are more efficient or productive than ours, we may lose market share or be placed at a competitive disadvantage.
The industry is affected by excess equipment inventory levels.
Because of the long-life nature of oilfield service equipment and the lag between when a decision to build additional equipment is made and when the equipment is placed into service, the inventory of oilfield service equipment in the industry does not always correlate with the level of demand for service equipment.
Compliance with governmental regulations may impact our or our customers’ operations and may adversely affect our business and operating results.
Our operations are dependent on our customers’ decisions to develop and produce oil and natural gas reserves and on the regulatory environment in which our customers and we operate. The ability to produce oil and natural gas can be affected by the number and productivity of new wells drilled and completed, as well as the rate of production and resulting depletion of existing wells. Advanced technologies, such as horizontal drilling and well stimulation and pressure pumping, improve total recovery, but they also result in a more rapid production decline and may become subject to more stringent regulations in the future.
Access to prospects is also important to our customers and such access may be limited because host governments do not allow access to the reserves or because another oil and natural gas exploration company owns the rights to develop the prospect. Government regulations and the costs incurred by oil and natural gas exploration companies to conform to and comply with government regulations may also limit the quantity of oil and natural gas that may be economically produced. This could lead our customers to curtail their operations and result in a decrease in demand for our services, which in turn could adversely affect our financial position and results of operations.
Any of these factors could affect the supply of oil and natural gas and could have a material adverse effect on our results of operations.
Legislative and regulatory initiatives relating to well stimulation could result in increased costs and additional operating restrictions or delays for our operations or the operations of our customers.
Many national, provincial, and local governments and agencies have adopted laws and regulations or are evaluating proposed legislation and regulations that are focused on the extraction of shale gas or oil using well stimulation, which is part of the overall services we provide to our customers. Well stimulation is a treatment routinely performed on oil and gas wells in low-permeability reservoirs. Specially engineered fluids are pumped at high pressure and rate into the reservoir interval to be treated, causing cracks in the target formation. Proppant, such as sand of a particular size, is mixed with the treatment fluid to keep the cracks open when the treatment is complete. In response to concerns related to potential impacts to the environment and natural resources from well stimulation, governmental authorities have issued new rules and regulations governing the practice and are also pursuing studies related to its potential effects. Also, some national, state, and local governments have adopted bans or other measures restricting well stimulation activities. For example, the Province of Neuquén in Argentina, where we operate, has approved a set of rules regarding the extraction of shale oil and gas. These rules require, amongst other things, that operators performing well stimulation obtain permits prior to commencing drilling activities and file reports with the provincial government regarding the chemicals used in the well stimulation process and an analysis of the flowback water returning to the surface. In certain regions, the indigenous people have voiced their opposition to the increased shale development although to date these protests have been peaceful and have yet to disrupt activity in a meaningful way. In addition, several other provinces and local governments have voted to ban well stimulation within their borders, and some groups continue to advocate for a national ban on well stimulation in Argentina. The EPA and states, including Oklahoma, have also taken steps to regulate hydraulic fracturing. There has been increasing public controversy regarding hydraulic fracturing with regard to the use of fracturing fluids, induced seismic activity, impacts on drinking water supplies, use of water and the potential for impacts to surface water, groundwater and the environment generally. Legislative or regulatory changes could cause us or our customers to incur substantial compliance costs, and compliance or the consequences of any failure to comply by us could have a material adverse effect on our financial condition and results of operations. At this time, it is not possible to estimate the impact on our business of newly enacted or potential national, state or local laws governing hydraulic fracturing.
Future well stimulation-related legislation or regulations that further restrict or prohibit such activities could lead to operational delays and increased costs for our operations or the operations of our customers. Any adverse impacts on the operations of our customers could in turn reduce demand for our services. If such additional legislation or regulations are enacted and implemented, it could adversely affect our financial condition, results of operations and cash flows.
Risks Related to Ownership of Our Common Stock
We have incurred, and expect to continue to incur, increased costs and risks as a result of being a public company.
As a public company, we are required to comply with most, but not all, of the Sarbanes-Oxley Act of 2002 (“SOX”), as well as rules and regulations implemented by the SEC. Changes in the laws and regulations affecting public companies, including the provisions of SOX and rules adopted by the SEC, have resulted in, and will continue to result in, increased costs to us as we respond to these requirements. Given the risks inherent in the design and operation of internal controls over financial reporting, the effectiveness of our internal controls over financial reporting is uncertain. If our internal controls are not designed or operating effectively, we may not be able to issue an evaluation of our internal control over financial reporting as required. Investors may lose confidence in the reliability of our financial statements, which could cause the market price of our common stock to decline and which could affect our ability to run our business as we otherwise would like to. New rules could also make it more difficult or costlier for us to obtain certain types of insurance, including directors’ and officers’ liability insurance, and we may be forced to accept reduced policy limits and coverage or incur substantially higher costs to obtain the coverage that is the same or similar to our current coverage. The impact of these events could also make it more difficult for us to attract and retain qualified persons to serve on our Board, the committees of our Board, and as executive officers. We cannot predict or estimate the total amount of the costs we may incur or the timing of such costs to comply with these rules and regulations.
Compliance with SOX requirements will continue to strain our limited financial and management resources.
We incur significant legal, accounting and other expenses in connection with our status as a reporting public company. SOX and rules subsequently implemented by the SEC have imposed various requirements on public companies, including corporate governance practices. As such, our management and other personnel need to devote a substantial amount of time to these compliance initiatives. Moreover, these rules and regulations have increased our legal and financial compliance costs and made some activities more time-consuming and costly. In addition, SOX requires, among other things, that we maintain effective internal controls for financial reporting and disclosure of controls and procedures. Our testing may reveal deficiencies in our internal controls over financial reporting that are deemed to be material weaknesses. Our compliance with Section 404 of SOX requires that we incur substantial accounting expense and expend significant management efforts. We may need to hire additional accounting and financial staff with appropriate public company experience and technical accounting knowledge. Moreover, if we are not able to comply with the requirements of Section 404 of SOX in a timely manner, or if we or our independent registered public accounting firm identifies deficiencies in our internal controls over financial reporting that are deemed to be material weaknesses, the market price of our stock could decline, and we could be subject to sanctions or investigations by the SEC or other regulatory authorities, which would require additional financial and management resources.
We do not intend to pay cash dividends on our common stock in the foreseeable future, and therefore only appreciation of the price of our common stock will provide a return to our stockholders.
We currently anticipate that we will retain all future earnings, if any, to finance the growth and development of our business. We do not intend to pay cash dividends in the foreseeable future. Any payment of cash dividends will depend upon our financial condition, capital requirements, earnings and other factors deemed relevant by our Board. In addition, the terms of our existing indebtedness and any indebtedness we may incur in the future may restrict our ability to pay dividends and make other distributions. As a result, only appreciation of the price of our common stock, which may not occur, is expected to provide a return to our stockholders.
We currently have a sporadic, illiquid, volatile market for our common stock, and the market for our common stock may remain sporadic, illiquid, and volatile in the future.
We currently have a highly sporadic, illiquid and volatile market for our common stock, which market is anticipated to remain sporadic, illiquid and volatile in the future and will likely be subject to wide fluctuations in response to several factors, including, but not limited to:
|●||actual or anticipated variations in our results of operations;|
|●||our ability or inability to generate revenues, profits or positive cash flow;|
|●||the number of shares in our public float;|
|●||increased competition; and|
|●||conditions and trends in the market for oil and natural gas and oilfield services.|
Furthermore, our stock price may be impacted by factors that are unrelated or disproportionate to our operating performance. These market fluctuations, as well as general economic, political and market conditions, such as recessions, interest rates or international currency fluctuations, may adversely affect the market price of our common stock. Stockholders and potential investors in our common stock should exercise caution before making an investment in our Company and should not place undue reliance on the publicly quoted or traded stock prices in determining our common stock value.
Fir Tree may have significant influence over us, including influence over decisions that require stockholder approval, which could limit your ability to influence the outcome of key transactions, including a change of control.
As of December 31, 2017, Fir Tree beneficially owned approximately 67.1% of our outstanding common stock. In addition, Fir Tree currently has the right to nominate up to a total of three individuals to the Board. As a result, Fir Tree has influence over our decisions to take certain corporate actions including those specified in the Amended and Restated Stockholder Rights Agreement we have entered into with Fir Tree and certain other stockholders (the “A&R Stockholder Rights Agreement”).
Moreover, Fir Tree has a contractual right to maintain its percentage ownership in our Company. Specifically, under the terms of the A&R Stockholder Rights Agreement, for so long as Fir Tree beneficially owns more than 10% of our issued and outstanding common stock (calculated on a fully diluted basis), Fir Tree, subject to certain exclusions, has a preemptive right to purchase up to the amount of any new securities we propose to issue or sell as is necessary to maintain Fir Tree’s percentage ownership of us. As a result, Fir Tree’s preemptive right will apply to any securities we issue during an underwritten public offering. Therefore, while other holders of our stock would risk suffering a reduction in percentage ownership in connection with a new issuance of securities by us, Fir Tree would, through this preemptive right, have the opportunity to avoid a reduction in percentage ownership. As long as Fir Tree continues to hold a significant portion of our outstanding common stock, it will have the ability to influence the vote in any election of directors and over decisions that require stockholder approval. Please read Part III – Item 13 – “Certain Relationships and Related Party Transactions, and Director Independence.”
We may issue preferred stock with terms that could adversely affect the voting power or value of our common stock.
Our certificate of incorporation authorizes us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designations, preferences, limitations and relative rights, including preferences over our common stock respecting dividends and distributions, as our Board may determine. The terms of one or more classes or series of preferred stock could adversely impact the voting power or value of our 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 our common stock.
Item 1B. Unresolved Staff Comments
Item 2. Properties
Our principal executive offices are located at 2930 West Sam Houston Parkway North, Suite 275, Houston, Texas 77043, where we lease 6,577 square feet of general office space.
We own or lease facilities and administrative offices throughout the geographic regions in which we operate. As of December 31, 2017, we owned or leased the following principal properties:
|Location||Type of Facility||Size||Leased
West Sam Houston Pkwy|
North, Suite 275, Houston, Texas
|Leased||$||17,536||Month to month||Administrative Office|
|Uruguay 1134 Buenos Aires, Argentina||Administrative Offices||1,900
|Leased||$||4,500||Month to month||Administrative Office|
|Corporate Apartment||950 sq, ft, building space||Leased||$||1,711||Month to month||Corporate Apartment|
|Leased||$||4,500||Month to month||Neuquén Operations|
County Road 49, Fairview,
|Yard and Office||Approx,
|Leased||$||23,000||March 7, 2019||US Operations|
|Plottier, Argentina||Land||12 acres||Owned||N/A||—||Future Neuquén Operations|
Neuquén, Argentina Lote 3, Manzana D, parque industrial
|Leased||$||7,000||November 30, 2018||Argentina Operations|
Argentina Lote 4, Manzana 2C, parque industrial
|Leased||$||7,312||November 30, 2018||Argentina Operations|
Item 3. Legal Proceedings
From time to time, we may be a party or otherwise subject to legal or regulatory proceedings or other claims incidental to or arising in the ordinary course of our business. We are not currently party to any legal or regulatory proceedings that we believe will have a material adverse effect on our financial position, results of operations or cash flows, and we are not aware of any material legal or regulatory proceedings contemplated by governmental authorities.
Item 4. Mine Safety Disclosures
|Item 5.||Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity securities|
Our common stock is currently listed on the NASDAQ Capital Market under the symbol “ESES.” The reported high and low last sale prices for our common stock are shown below for the periods indicated. The quotations reflect inter-dealer prices, without retail mark-up, markdown or commission, and may not necessarily represent actual transactions. On March 16, 2018, the last reported sale price of our common stock was $1.20 per share.
|First quarter ended March 31, 2017||$||2.00||$||0.71|
|Second quarter ended June 30, 2017||$||1.45||$||1.04|
|Third quarter ended September 30, 2017||$||1.68||$||1.21|
|Fourth quarter ended December 31, 2017||$||1.60||$||1.23|
|First quarter ended March 31, 2016||$||2.95||$||2.00|
|Second quarter ended June 30, 2016||$||3.12||$||2.14|
|Third quarter ended September 30, 2016||$||2.80||$||2.09|
|Fourth quarter ended December 31, 2016||$||2.19||$||0.96|
As of March 13, 2018, we had approximately 663 record holders of our common stock.
We currently intend to retain future earnings, if any, for use in the operation and expansion of our business and, therefore, do not anticipate paying any cash dividends in the foreseeable future. However, our Board, in its discretion, may authorize the payment of dividends in the future. Any decision to pay future dividends will depend upon various factors, including our results of operations, financial condition, capital requirements and investment opportunities. In addition, the terms of indebtedness we may incur in the future may restrict our ability to make distributions to our stockholders.
Securities Authorized for Issuance under Equity Compensation Plans
We have two equity incentive plans, the 2013 Stock Incentive Plan (the “2013 Plan”) and the 2015 Stock Incentive Plan (the “2015 Plan”), which provide for the granting of stock-based incentive awards, including incentive stock options, non-qualified stock options, restricted stock, and phantom stock awards to employees, consultants and members of the Board. The 2013 Plan was adopted in 2012 and amended in 2013 and authorizes 1,000,000 shares to be issued under the 2013 Plan. The 2015 Plan, f/k/a “the 2014 Stock Incentive Plan,” was adopted in 2014; in 2015 and in 2016 it was amended and a total of 700,000 additional shares were authorized, resulting in a maximum of 1,200,000 shares being authorized for issuance under the 2015 Plan. On June 15, 2017, at our annual meeting of stockholders (the “2017 Annual Meeting”), our stockholders approved an increase to the aggregate maximum number of shares available under the 2015 Plan by 5,000,000 shares (from 1,200,000 shares to 6,200,000 shares). Both the 2013 Plan and the 2015 Plan have been approved by the stockholders of the Company.
For additional information regarding the Stock Incentive Plans, as of December 31, 2017, please see Part II – Item 8 – Financial Statements and Supplemental Data – Notes to consolidated financial statements – Note 14 – “Stock-Based Compensation.”
|Equity Compensation Plan Information|
securities to be
price of outstanding
column (a)) (c)
|Equity compensation plans approved by security holders||6,384,597||$||3.34||583,839|
|Equity compensation plans not approved by security holders||—||—||—|
Recent Sales of Unregistered Securities; Use of Proceeds from Registered Securities
Except as previously reported on our Current Reports on Form 8-K, we did not have any sales of unregistered equity securities during the fiscal year ended December 31, 2017.
Item 6. Selected Financial Data
|Item 7.||Management’s Discussion and Analysis of Financial Condition and Results of Operations|
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our condensed consolidated financial statements and the related notes thereto included in this Form 10-K. This section contains forward-looking statements that involve risks and uncertainties. Our actual results may differ materially from those discussed in any forward-looking statement because of various factors, including those described in the section titled “Cautionary Statements Regarding Forward-Looking Statements” in this Form 10-K.
We are a growth-oriented, technology-driven independent oilfield services company providing well stimulation, coiled tubing and field management services to the upstream oil and gas industry. We currently operate three well stimulation fleets, two in the United States based out of our operations facility in Fairview, Oklahoma, and one in Argentina based out of our facilities in Neuquén, Argentina. In the United States, we currently provide pressure pumping services to customers in the Anadarko Basin in Oklahoma. In Argentina, we are currently providing services to the largest operator in the country for its tight gas completions program.
Factors that may influence our outlook and performance include:
|●||capital spending by E&P companies in the United States and Argentina;|
|●||oil and natural gas prices;|
|●||the reliability and performance of our equipment;|
|●||the utilization of our assets in both the U.S. and Argentina markets and the related amount of non-productive down time for our assets;|
|●||the size of each job we perform;|
|●||the pricing levels for our services;|
|●||the location and design of the wells with respect to which we are providing services;|
|●||the service and product components of each job; and|
|●||our access to sand, proppant, chemicals and other raw materials required for us to provide our services, and the costs of such materials.|
With the start-up of our U.S. operations during the second quarter of 2017, we now manage our business through operating segments that are aligned with our two geographic regions, the United States and Argentina. We also report certain corporate and other non-operating activities under the heading “Corporate and Other”, which primarily reflects corporate personnel and activities, incentive compensation programs and other non-operational allocable costs. For financial information about our segments, see Note 19, Segment Reporting.”
Our segment operating results are frequently influenced by the number of active contracts we have in the area, and also the level of our customers’ well activity which dictates the amount of activity we will have in any given period. This directly effects our revenue, but also the level of expenses we incur.
United States Segment. Through our U.S. segment, we serve the needs of our customers’ U.S. based operations by providing pressure pumping and field management operations services. In February 2017, we signed a one-year contract to provide pressure pumping in north central Oklahoma, at which time we began setting up and thus incurring start-up related costs associated with our operations in order to properly meet our contract service obligations. We established a base of operation in Fairview, Oklahoma, and utilize this base to service the surrounding areas. Revenue recognition for this segment began in May of 2017. The third quarter of 2017 was our first full operating quarter for this segment. In July 2017, we entered into a one-year contract with a second U.S. oil and natural gas exploration and production company to expand our pressure pumping operations in the north central region of Oklahoma. The work being performed under this contract supports a second well stimulation crew. We commenced work and began recognizing revenue under this contract in mid-October 2017.
In November 2017, we negotiated an early release of our first U.S. spread from our contract with our first U.S. customer and, starting in early March 2018, we have redeployed that spread to serve other customers consisting primarily of independent E&P companies operating in the STACK play.
Argentina Segment. Through our Argentina segment, we serve the needs of our Argentine customers by providing pressure pumping and coiled tubing services. We began our service offerings in late 2014 in Argentina with our base of operation located in Neuquén City, Argentina. The majority of our revenues since inception and through the end of the third quarter of 2017 coming from the Neuquén Basin.
In the second quarter of 2017, we entered into a two-year contract with the largest operator in Argentina to provide services for their tight gas completions program which has increased our activity in the region. The majority of our revenues in our Argentina segment have come from our pressure pumping operations.
To date, we have incurred losses under the contract entered into in the second quarter of 2017 due to lower than expected utilization of our assets, higher than expected third party costs incurred in order to provide the bundled services contemplated under the contract, and other factors. We have been engaged in extensive negotiations with our customer to modify the contract in order to provide us with more favorable operating results. However, there can be no assurance that our efforts to renegotiate the terms of the contract will be successful, and we may continue to incur losses under the contract in the future. In addition, the negotiations may result in an early release from our obligations under the contract. If we receive an early release from the contract, we may incur further losses associated with our Argentina operations, which could be substantial, while we transition to new customers, and there can be no assurance that we obtain contracts with new customers on favorable terms or at all.
Operating Financial Results
During 2017, we generated $44.0 million of revenue, up from $8.4 million of revenue generated in 2016. Approximately $24.5 million of the increase was attributable to our start-up of operations in the U.S. during 2017. Revenue from our Argentina operations generated $19.6 million of revenue for 2017, up from $8.4 million of revenue generated in 2016. This increase in Argentina was attributable to a new contract with our largest customer, allowing us to secure a larger amount of stimulation stages and coiled tubing jobs. During 2016, our Argentina operations completed 75 stimulation stages and 37 coiled tubing jobs. For 2017, we completed 169 stimulation stages and 39 coiled tubing jobs in Argentina. Our U.S. operations completed 561 stimulation stages during 2017.
During 2017, we incurred a net operating loss of $25.9 million compared with a net operating loss in 2016 of $13.3 million. For 2017, we incurred cost of services of $53.0 million and for 2016, $10.6 million. Most of this increase was attributable to our new operational start-up in the U.S., including the operational start-up period prior to revenues being recognized. Depreciation and amortization expense also increased due primarily to the acquisition of equipment for our new U.S. start-up. Selling, general and administrative expenses also increased due to increased non-cash stock compensation expense, increased director compensation expense, an increase in headcount and salaries, and an increase in certain legal expenses.
The oil and gas industry is both cyclical and seasonal. The level of spending by E&P companies is highly influenced by current and expected demand and future prices of oil and natural gas. Changes in spending result in an increased or decreased demand for our services and products. Rig count is an indicator of the level of spending by oil and gas companies. Our financial performance and outlook is significantly affected by the rig count in the United States and Argentina as well as oil and natural gas prices, which are summarized in the table below.
|2017||2016||2017 to 2016 Change||2015||2016 to 2015 Change|
|Rig Count Recap (1)|
|U.S. Land (excl offshore)||856||486||76||%||943||-48||%|
|Commodity Prices (average)|
|Crude Oil (West Texas Intermediate)||$||50.80||$||43.29||17||%||$||48.66||-11||%|
|Natural Gas (Henry Hub)||$||2.99||$||2.52||19||%||$||2.62||-4||%|
(1) Average annual drilling activity as measured by active drilling rigs based on Baker Hughes Incorporated rig count information.
Baker Hughes rig count reported at December 31, 2017, the U.S. Land only rig count was 911 rigs, which represented an 87% increase from the same count at December 31, 2016 and a 44% increase from the lowest level during 2017 of 634 rigs. For our U.S. operations, which began activity during 2017, our activity was concentrated in the Anadarko Basin in Oklahoma. Oklahoma’s annual rig count average was 66 and 120 for 2016 and 2017, respectively.
According to the Baker Hughes rig count reporting at December 2017, the Argentinian rig count was 71 rigs, which represented a 20% increase from December 2016 and a 45% increase from the lowest monthly average level during 2017 of 49 rigs. For our Argentina operations, our 2016 and 2017 activity was concentrated in the Neuquén Basin in Argentina. Per Baker Hughes rig count reporting, the rig count in Argentina remained relatively flat between 2016 and 2017, with the average count for 2016 at 68 and for 2017 at 62 rigs.
Overview of our business services
Our customers utilize our pressure pumping services to enhance the production of oil and natural gas from formations with low permeability, which restricts the natural flow of hydrocarbons. The technique of well stimulation consists of pumping a fluid into a cased well at sufficient pressure to create new channels in the rock, which can increase the extraction rates and the ultimate recovery of the hydrocarbons. Our equipment is contracted by E&P companies to provide this pressure-pumping service, which is referred to as well stimulation. Demand for these services can change quickly and is highly dependent on the number of oil and natural gas wells drilled and completed. Given the cyclical nature of these drilling and completion activities, coupled with the high labor intensity of these services, operating margins can fluctuate widely depending on supply and demand at a given point in the cycle.
Our customers utilize our coiled tubing services to perform various functions associated with well-servicing operations and to facilitate completion of horizontal wells. Coiled tubing services involve the insertion of steel tubing into a well to convey materials and/or equipment to perform various applications as part of a new completion or the servicing of existing wells, including wellbore maintenance, nitrogen services, thru-tubing services, and formation stimulation using acid and other chemicals. Coiled tubing has become a preferred method of well completion, workover and maintenance projects due to speed, ability to handle heavy-duty jobs across a wide spectrum of pressure environments, safety and ability to perform services without having to shut-in a well. Our coiled tubing capabilities cover a wide range of applications for horizontal completion, work-over and well-maintenance projects. As a result, coiled tubing services are less tied to active rig count and more tied to price of oil and gas as well as customers’ expenditure budgets, which is usually also tied to the price of oil and natural gas.
|Years Ended December 31,|
|Operating cost and expenses:|
|Cost of services||53,002,499||10,630,233||42,372,266|
|Selling, general, and administrative expenses||8,441,933||5,892,235||2,549,698|
|Research and development||456,288||486,128||(29,840||)|
|Depreciation and amortization expense||8,029,247||4,667,797||3,361,450|
|Total operating costs and expenses||69,929,967||21,676,393||48,253,574|
|Other income (expense):|
|Interest expense, net of forgiven||(1,314,520||)||(3,978,728||)||2,664,208|
|Total other income (expense)||(1,668,187||)||(4,295,771||)||(2,627,584||)|
|Benefit (provision) for income taxes||633,529||(305,320||)||938,849|
For the Years Ended December 31, 2017 and 2016
Revenue for the year ended December 31, 2017 increased $35.7 million to $44.0 million from $8.4 million for the year ended December 31, 2016. Approximately $25.4 million of this increase was due to the start-up activity of our U.S. stimulation operations in Q2 of 2017. Also, well stimulation and coiled tubing operations in Argentina increased as a result of the two-year contract signed in early 2017 with the largest operator in Argentina which drove higher utilization.
Costs of services increased $42.4 million to $53.0 million for the year ended December 31, 2017 compared to $10.6 million for the year ended December 31, 2016. Of this increase, $28.1 was due to the new start-up activity in our U.S. stimulation operations, including pre-operating start-up costs associated with this new activity; and $14.3 million was due to an increase in activity levels related to our well stimulation and coiled tubing operations in Argentina attributable to the two-year contract we signed with our largest customer in 2017. The $3.4 million increase in depreciation and amortization expense was primarily attributable to the acquisition of equipment for our new U.S. operations.
Our selling, general, and administrative expenses increased $2.5 million to $8.4 million for the year ended December 31, 2017 compared to $5.9 million for the year ended December 31, 2016. This increase was a result of increases in non-cash stock compensation of $0.1 million, $1.0 million in legal costs and professional fees due to increased director compensation and certain increased legal expenses, and $0.7 million in corporate salaries due to increased headcount and salary increases.
Net other expense decreased $2.6 million to $1.7 million for the year ended December 31, 2017 compared to net other expense of $4.3 million for the year ended December 31, 2016. This decrease was primarily a result of a decrease in interest expense incurred in 2017 compared with 2016. During 2016, the Company had drawn down the full $22 million on a secured promissory note with the ACM entities. The note was fully paid effective March 6, 2017 in a transaction the Company entered into with Fir Tree as discussed below under Liquidity and Capital Resources.
During 2017, we incurred a net operating loss of $25.9 million compared with a net operating loss from 2016 of $13.3 million.
Accounts receivable increased $7.3 million to $10.2 million at December 31, 2017 from $2.9 million at December 31, 2016 due primarily to the start-up of new operations in the U.S. and the increase in sales in Argentina related to an increase in activity in our well stimulation and coil tubing operations attributable to the two year contract we signed with our largest customer in 2017.
Prepaids increased $2.4 million to $4.4 million at December 31, 2017 from $1.9 million at December 31, 2016 due to: i) Argentina VAT and other tax prepaid amounts increasing as a result of purchase tax for a larger amount of purchases in 2017 compared with 2016 exceeding sales/revenue tax; and ii) start-up activity in the U.S. with vendors and vehicles purchased. The Company will use the prepaid value added tax as it continues to invoice customers in Argentina.
Accounts payable increased $14.7 million to $17.1 million at December 31, 2017 from $2.5 million at December 31, 2016 due primarily to the start-up of new operations in the U.S. and the increase in sales in Argentina related to an increase in activity in our well stimulation and coil tubing operations attributable to the two-year contract we signed with our largest customer in 2017.
Short-term notes payable increased $5.0 million to $7.0 million at December 31, 2017 from $2.0 million at December 31, 2016 due primarily to the repayment in 2017 of the $2.0 million loan the Company held with two of the Company’s largest stockholders, offset by approximately $7.0 million of loans entered into which financed equipment purchases in 2017.
Liquidity and Capital Resources
Our primary sources of liquidity to date have been proceeds from various equity and debt offerings which are discussed in “Part II – Item 8 – Financial Statements and Supplemental Data – Notes to consolidated financial statements – Note 11 – “Equity Offerings”.”
On March 6, 2017, the Company closed a financing transaction with Fir Tree, (the “Fir Tree Transaction”) that was part of a comprehensive recapitalization designed to create a path to a potential conversion to equity of substantially all the Company’s debt, subject to stockholder approval and satisfaction of certain other conditions. In connection with the Fir Tree Transaction, the Company entered into an Amended and Restated Convertible Note Facility Agreement with Fir Tree (the “A&R Note”), which replaced the convertible note previously issued by the Company to certain funds affiliated with Albright Capital Management (collectively “ACM”), which Fir Tree purchased from ACM in connection with the 2017 Recapitalization. In addition, the Company issued to Fir Tree a new convertible note with a principal amount of $19.4 million, (the “New Convertible Note”), representing an additional $17 million aggregate principal amount of convertible notes issued by the Company to the Fir Tree affiliate on March 6, 2017 and approximately $2.4 million principal amount of convertible notes in payment of accrued and unpaid interest on the existing ACM Note acquired by the Fir Tree affiliate from ACM. The unpaid principal amount of the New Convertible Note accrued interest at a rate of 20% per annum and was scheduled to mature on May 28, 2018. Approximately $2.1 million of the proceeds of the additional $17 million aggregate principal amount of New Convertible Note issued to the Fir Tree affiliate was used to repay existing debt under the Loan Agreement described under “Short Term Stockholder Debt” below, with the balance of the proceeds used for equipment purchases, other approved capital expenditures incurred in accordance with an approved operating budget, and other working capital purposes. After giving effect to the Fir Tree Transaction, the Company had approximately $41.4 million of outstanding convertible notes which were all held by Fir Tree or an affiliate.
As part of the Fir Tree Transaction, Fir Tree agreed to convert the A&R Note and the New Convertible Note into common stock at a conversion price of $1.40 per share, subject to receipt of stockholder approval and satisfaction of certain other conditions. On June 15, 2017, stockholder approval was received and all the outstanding convertible notes were converted into approximately 29.5 million shares of common stock.
On July 6, 2017, the Company closed on a private placement of shares of the Company’s common stock providing gross proceeds of $15.0 million, and net of costs proceeds of $14.9 million (the “July 2017 PIPE”). As part of the offering, the Company issued 10,000,000 shares of its common stock for $1.50 per share to certain existing shareholders. The proceeds from the offering were used to finance capital expenditures to support existing contracts the Company has in both Oklahoma and Argentina, for working capital and for other general corporate purposes.
On August 8, 2017, the Company closed on a private placement of shares of the Company’s common stock providing gross proceeds of $28 million, with net of costs proceeds of $26.7 million (the “August 2017 PIPE”). As part of the offering, the Company issued an aggregate of 19,580,420 shares of its common stock for $1.43 per share to two existing stockholders and several new institutional investors. The proceeds from this offering were used to finance capital expenditures to support the Company’s most recent customer contract in Oklahoma, for working capital and for other general corporate purposes.
We continually monitor potential capital sources, including equity and debt financings, in order to meet our planned capital expenditures and liquidity requirements. The successful execution of our growth strategy depends on our ability to raise capital as needed to, among other things, finance the purchase of additional equipment. If we are unable to obtain additional capital on favorable terms or at all, we may be unable to sustain or increase our current level of growth in the future. The availability of equity and debt financing will be affected by prevailing economic conditions in our industry and financial, business and other factors, many of which are beyond our control.
Receivables Agreement. On February 8, 2018, we entered into a Recourse Receivables Purchase & Security Agreement (the “Receivables Agreement”) with Porter Capital Corporation (“Porter Capital” or “Buyer”). Under the terms of the Receivables Agreement, we may, from time to time, sell accounts receivable (“Accounts”) to Buyer in exchange for funds in an amount equal to 80% of the face amount of the applicable Account at the time of sale of the Account, with the remaining 20% of the face amount of the applicable Account to be held back as a required reserve amount to be paid to us following Buyer’s receipt of payment on the Account by the account debtor, less applicable fees and interest charges. The total face amount of outstanding Accounts purchased by Buyer under the Receivables Agreement may not exceed $12.5 million.
Under the terms of the Receivables Agreement, we are obligated to pay interest on the face amount of the outstanding and unpaid Accounts purchased by Buyer, less the amount of the reserve account, at an interest rate equal to the Prime Rate (as defined in the Receivables Agreement) plus 8.25%. We are also obligated under the Receivables Agreement to pay certain fees, including a fee (the “Minimum Term Fee”) payable upon termination of the agreement in an amount equal to: (i) the monthly interest rate multiplied by $5 million, multiplied by the number of months in the agreement term, less the amount of actual interest paid during the term of the agreement; or (ii) following the occurrence of an Event of Default (as defined below) that has not been cured within the time periods contemplated under the agreement, $1.8 million, less the amount of actual interest paid during the term of the agreement. The Minimum Term Fee is also subject to reduction under certain circumstances if Buyer does not purchase certain eligible Accounts that are presented for purchase by us.
All of our obligations under the Receivables Agreement are secured by liens on certain of our assets, including the accounts receivable, chattel paper, inventory relating to our U.S. operations and substantially all of our equipment for our U.S. operations (excluding equipment subject to vendor financing). The Receivables Agreement further provides for customary events of default (“Events of Default”), including but not limited to the failure to make payments when due; insolvency events; the failure to comply with covenant obligations arising under the agreement or other agreements with Buyer or its affiliates; and breaches of representations and warranties. Upon the occurrence of an Event of Default, Porter Capital may terminate the Receivables Agreement and declare all of our outstanding obligations under the Receivables Agreement to be due and payable. The Receivables Agreement has an initial term of one year, and will renew for successive one-year terms unless we provide notice of cancellation in accordance with the terms of the Agreement. We may also terminate the Receivables Agreement prior to the expiration of the term upon written notice and payment of our obligations thereunder.
Argentina Operations. In the second quarter of 2017, we entered into a two-year contract with the largest operator in Argentina to provide services for their tight gas completions program. To date, we have incurred losses under the contract due to lower than expected utilization of our assets, higher than expected third party costs incurred in order to provide the bundled services contemplated under the contract, and other factors. We have been engaged in extensive negotiations with our customer to seek modifications to the contract that would provide us with more favorable operating results. However, there can be no assurance that our efforts to renegotiate the terms of the contract will be successful, and we may continue to incur losses under the contract in the future. In addition, our negotiations with our customer may result in an early release from our obligations under the contract. If we receive an early release from the contract, we may incur further losses associated with our Argentina operations, which could be substantial, while we transition to new customers, and there can be no assurance that we obtain contracts with new customers on favorable terms. In addition, there can be no assurance that our negotiations will result in either modifications to the contract or a release from the contract prior to the end of its current term. As a result, our Argentinian operations may require access to additional working capital if we continue to incur losses under our existing contract or during any transition period from our current customer to work for new customers following an early release from our current contract. The working capital requirements of our Argentina operations could result in our incurrence of indebtedness, cash contributions to our Argentinian subsidiary from our parent company, or other third-party financings. We may also be required to incur other material costs in connection with our efforts to renegotiate or exit our current contract with our largest customer in Argentina. In addition, we may determine to reduce the scale of, shut down, or sell our operations in Argentina, which could result in the incurrence of material losses and expenses.
Sources and Uses of Cash
Net cash used in operating activities was $14.5 million for the year ended December 31, 2017 and $5.3 million for the year ended December 31, 2016. The increase was primarily due to pre-operating start-up costs associated with our U.S. start-up operations, no U.S. operations in 2016, and lower utilization of our U.S. and Argentina crews during the twelve months ended December 2017 compared to the same period ended December 31, 2016.
Net cash used in investing activities was $35.4 million for the year ended December 31, 2017 and $4.6 million for the year ended December 31, 2016. This increase was primarily due to the increase in purchase of equipment associated with the start-up and expansion of operations in our U.S. segment during the twelve months ended December 2017 compared to the same period ended December 31, 2016.
Net cash provided by (used in) financing activities was $57.0 million for the year ended December 31, 2017 and $(0.1) million for the year ended December 31, 2016. The increase in net cash provided by financing activities was primarily attributable to greater sales of common stock of $40.1 million, net of issuance cost, during 2017 as well as $16.5 million greater proceeds from notes payable, net of cost, during 2017 when compared to the same period ended December 31, 2016.
The following table summarizes our cash flows for the years ended December 31, 2017 and 2016:
|Years Ended December 31,|
|Proceeds from sale of common stock||$||43,982,386||$||1,722,596|
|Sale of common stock issuance cost||(2,357,984||)||(164,041||)|
|Proceeds from notes payable||18,719,126||2,194,611|
|Payments on notes payable||(2,587,852||)||(3,293,732||)|
|Payments on capital lease||(789,166||)||(565,449||)|
|Purchase of treasury stock||-||(37,175||)|
|Net cash provided by (used in) financing activities||$||56,966,510||$||(143,190||)|
On December 15, 2015, the Board authorized the Company to repurchase, from time to time, from December 16, 2015 through December 16, 2017, up to $5 million in shares of its outstanding common stock. Through the years ending December 31, 2015, 2016 and 2017, the Company had purchased 6,939, 14,911 and 0 shares, respectively, at a cost of $20,294, $37,175, and $0, respectively, through the repurchase arrangement.
On July 13, 2016, the Company entered into an At-Market Issuance Sale Agreement as disclosed in Note 11 – “Equity Offerings”. During 2016, the Company sold 796,573 shares through this agreement for total gross proceeds of $1,722,596 before deducting approximately $164,000 of commissions. During 2017, the Company sold 563,753 shares through this agreement for total gross proceeds of $982,385 before deducting approximately $13,105 of commissions.
In 2017, the Company converted all of its outstanding convertible notes into common stock pursuant to the Fir Tree Transactions, raised gross proceeds of $15.0 million, and net of costs proceeds of $14.9 million through the July 2017 PIPE, and raised gross proceeds of $28 million, with net of costs proceeds of $26.7 million, through the August 2017 PIPE.
For additional information, see “—Liquidity and Capital Resources” above.
We had a net increase in cash and cash equivalents of $7.1 million for the year ended December 31, 2017, compared to a net decrease in cash and cash equivalents of $10.0 million during the year ended December 31, 2016 primarily resulting from our proceeds from stock issuances in 2017, offset by an increase in operating activities and capital expenditures for 2017 compared with 2016.
We do not generate positive cash flow at this time. Further, while we believe we will begin generating positive cash flow from operations in 2018, our liquidity provided by our existing cash and cash equivalents may not be sufficient to fund our full capital expenditure plan. Our current capital commitments may require us to obtain additional equity or debt financing, which may not be available to us on favorable terms or at all.
The energy services business is capital intensive, requiring significant investment to expand, upgrade and maintain equipment. Our primary uses of capital have been the acquisition of equipment, working capital to finance the start of our operations and general administrative expenses.
Going forward, we expect our capital requirements to consist primarily of:
|●||growth capital expenditures, such as those to acquire additional equipment and other assets to grow our business; and|
|●||maintenance capital expenditures, which are capital expenditures made to extend the useful life of our assets.|
Additionally, we continually monitor new advances in well stimulation equipment and down-hole technology as well as technologies that may complement our business and opportunities to acquire additional equipment to meet our customers’ needs. We intend to incur approximately $6.0 million in capital expenditures during the first half of 2018 and will incur additional capital expenditures on a discretionary basis as necessary to meet customer demands and subject to satisfactory financing. Our ability to make any significant acquisition for cash would likely require us to obtain additional equity or debt financing, which may not be available to us on favorable terms or at all.
Our ability to fund operations, and to fund planned and committed 2018 capital expenditures will depend upon our future operating performance, and more broadly, on the availability of equity and debt financing, which will be affected by prevailing economic conditions, market conditions in the exploration and production industry and financial, business and other factors, many of which are beyond our control.
Our ability to acquire equipment could require us to obtain additional equity or debt financing, which may not be available to us on favorable terms or at all.
From time to time, we may also consider the acquisition or disposition of assets or businesses or possible joint ventures or other joint ownership arrangements with respect to assets or businesses. Any determination to take action in this regard will be based on market conditions and opportunities existing at the time, and accordingly, the timing, size or success of any efforts and the associated potential capital requirements for these activities are unpredictable. We may seek to fund all or part of any such efforts with proceeds from debt and/or equity issuances.
Impact of Inflation on Operations
Management is of the opinion that inflation has not had a significant impact on our business to date. We purchase our equipment and materials from suppliers who provide competitive prices and employ skilled workers from competitive labor markets. If inflation in the general economy increases, our costs for equipment, materials and labor could increase as well. Also, increases in activity in oilfields can cause upward wage pressures in the labor markets from which we hire employees as well as increases in the costs of certain materials and key equipment components used to provide services to our customers.
Off-Balance Sheet Arrangements
As of December 31, 2017, we do not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors. The term “off-balance sheet arrangements” generally means any transaction, agreement or other contractual arrangement to which an entity unconsolidated with us is a party, under which we have (i) any obligation arising under a guarantee contract, derivative instrument or variable interest or (ii) a retained or contingent interest in assets transferred to such entity or similar arrangement that serves as credit, liquidity or market risk support for such assets.
Critical Accounting Policies
The preparation of consolidated financial statements in conformity with generally accepted accounting principles (“GAAP”) requires management to select appropriate accounting principles from those available, to apply those principles consistently and to make reasonable estimates and assumptions that affect revenues and associated costs as well as reported amounts of assets and liabilities, and related disclosure of contingent assets and liabilities. Certain accounting policies involve judgments and uncertainties. We evaluate estimates and assumptions on a regular basis. We base our respective estimates on historical experience and various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from the estimates and assumptions used in preparation of our consolidated financial statements. We consider the following policies to be the most critical to understanding the judgments that are involved and the uncertainties that could impact our results of operations, financial condition and cash flows.
As a “smaller reporting company”, we are reporting in accordance with certain reduced public company reporting requirements permitted by applicable SEC requirements. As a result, our financial statements may not be comparable to companies that are not smaller reporting or elect to avail themselves of this provision.
We believe the following critical accounting policies involve significant areas of management’s judgments and estimates in the preparation of our consolidated financial statements.
Property and Equipment. Fixed asset additions are recorded at cost less accumulated depreciation. Cost of services consists of products, components, labor and overhead. Expenditures for renewals and betterments that extend the lives of the assets are capitalized. An allocable amount of interest on borrowings is capitalized for self-constructed assets and equipment during their construction period. Amounts spent for maintenance and repairs are charged against operations as incurred. Costs of fixed assets are depreciated on a straight-line basis over the estimated useful lives of the related assets which range from one and a half to seven years for service equipment. Leasehold improvements will be depreciated over the lesser of the estimated useful life of the improvement or the remaining lease term. Management is responsible for reviewing the carrying value of property and equipment for impairment whenever events and circumstances indicate that the carrying value of an asset may not be recoverable from estimated future cash flows expected to result from its use and eventual disposition. In cases where undiscounted expected future cash flows are less than the carrying value, an impairment loss is recognized equal to the amount by which the carrying value exceeds the fair value of assets. When making this assessment, the following factors are considered: current operating results, trends and prospects, as well as the effects of obsolescence, demand, competition and other economic factors.
Capital Lease Obligations. The Company leases certain equipment under lease agreements. The Company evaluates each lease to determine its appropriate classification as an operating or capital lease for financial reporting purposes. Any lease that does not meet the criteria for a capital lease is accounted for as an operating lease. The assets and liabilities under capital leases are recorded at the lower of the present value of the minimum lease payments or the fair market value of the related assets. Assets under capital leases are amortized using the straight-line method over the initial lease term. Amortization of assets under capital leases is included in depreciation expense.
Revenue Recognition. Revenues are recognized as services are completed and collectability is reasonably assured. With respect to hydraulic fracturing services, we expect to recognize revenue at the completion of each fracturing stage and invoice the customer upon the completion of each job. In our industry, it is not uncommon for a service provider to complete multiple fracturing stages per day during the course of a job.
Stock-Based Payments. We account for stock incentive awards issued to employees and non-employees in accordance with Financial Accounting Standards Board Accounting Standards Codification Topic 718, Stock Compensation. Accordingly, employee stock-based compensation is measured at the grant date, based on the fair value of the award, and is recognized as an expense over the requisite service period, or upon the occurrence of certain vesting events. Additionally, stock-based awards to non-employees are expensed over the period in which the related services are rendered. The grant-date fair value of awards is estimated using the Black-Scholes option-pricing model, which requires the use of highly subjective assumptions such as the estimated market value of our stock, expected term of the award, expected volatility and the risk-free interest rate. Since some of our share options were not publicly traded at the time of issuance and have not been traded privately, the value of the shares is estimated based on significant unobservable inputs, primarily consisting of the estimated value of the start-up activities completed as of the grant date, as well as other inputs that are estimated based on similar entities with publicly traded securities. We continue to use judgment in evaluating the expected term, volatility and forfeiture rate related to our stock-based compensation on a prospective basis and incorporate these factors into our option-pricing model. Each of these inputs is subjective and generally requires significant management judgment. If, in the future, we determine that another method for calculating the fair value of our unit-based awards is more reasonable, or if another method for calculating these input assumptions is prescribed by authoritative guidance, and, therefore, should be used to estimate expected volatility or expected term, the fair value calculated for our employee unit-based awards could change significantly. Higher volatility and longer expected terms generally result in an increase to stock-based compensation expense determined at the date of grant.
Income Taxes. We account for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.
Our tax filings for various periods are subject to audit by the tax authorities in most jurisdictions where we conduct business. These audits may result in assessments of additional taxes that are resolved with the authorities or through the courts. We believe these assessments may occasionally be based on erroneous and even arbitrary interpretations of local tax law. Resolution of these situations inevitably includes some degree of uncertainty; accordingly, we provide taxes only for the amounts we believe will ultimately result from these proceedings. The resulting change to our tax liability, if any, is dependent on numerous factors including, among others, the amount and nature of additional taxes potentially asserted by local tax authorities; the willingness of local tax authorities to negotiate a fair settlement through an administrative process; the impartiality of the local courts; the number of countries in which we do business; and the potential for changes in the tax paid to one country to either produce, or fail to produce, an offsetting tax change in other countries. The potential exists that the tax resulting from the resolution of current and potential future tax controversies may differ materially from the amount accrued.
Tax Cuts and Jobs Act. On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”). The Tax Act makes broad and complex changes to the U.S. tax code, including, but not limited to, (1) reducing the U.S. federal corporate tax rate from 35 percent to 21 percent; (2) requiring companies to pay a one-time transition tax on certain unrepatriated earnings of foreign subsidiaries; (3) generally eliminating U.S. federal income taxes on dividends from foreign subsidiaries; (4) a new provision designed to tax global intangible low-taxed income (GILTI); (5) eliminating the corporate alternative minimum tax (AMT) and changing how existing AMT credits can be realized; (6) creating the base erosion anti-abuse tax (BEAT), a new minimum tax, (7) creating a new limitation on deductible interest expense; and (8) changing rules related to uses and limitations of net operating loss carryforwards created in tax years beginning after December 31, 2017.
Shortly after enactment of the Tax Act, the SEC staff issued SAB 118, which provides guidance on accounting for the tax effects of the Tax Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Act enactment date for companies to complete the accounting under ASC 740. In accordance with SAB 118, a company must reflect the income tax effects of those aspects of the Tax Act for which the accounting under ASC 740 is complete. To the extent that a company’s accounting for certain income tax effects of the Tax Act is incomplete but it is able to determine a reasonable estimate, it must record a provisional estimate in the financial statements. If a company cannot determine a provisional estimate to be included in the financial statements, it should continue to apply ASC 740 on the basis of the provisions of the tax laws that were in effect immediately before the enactment of the Tax Act.
Valuation Allowance for Deferred Tax Assets. We record a valuation allowance to reduce the carrying value of our deferred tax assets when it is more likely than not that a portion or all of the deferred tax assets will expire before realization of the benefit or future deductibility is not probable. The ultimate realization of the deferred tax assets depends on the ability to generate sufficient taxable income of the appropriate character and in the related jurisdiction in the future. In evaluating our ability to recover our deferred tax assets, we consider the available positive and negative evidence, including our past operating results, the existence of cumulative losses in the most recent years and our forecast of future taxable income. In estimating future taxable income, we develop assumptions, including the amount of future pretax operating income, the reversal of temporary differences and the implementation of feasible and prudent tax planning strategies. These assumptions require significant judgment.
Recent Accounting Pronouncements
See Part II, Item 8, Notes to consolidated financial statements – Note 2 – “Basis of Presentation and Significant Accounting Policies.”
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
We are exposed to certain market risks as part of our ongoing business operations, including risks from changes in foreign currency exchange rates and commodities that could impact our financial position, results of operations and cash flows. We manage our exposure to these risks through regular operating and financing activities.
Foreign Currency Risk
During the years ended December 31, 2015, 2016 and 2017, we conducted operations in Argentina. The functional currency for our Argentina operations is the U.S. dollar. We and our foreign subsidiaries from time to time will hold foreign currencies. Exchange rate fluctuations will subject us to foreign currency risk. In the future, we could experience fluctuations in financial results from our operations outside the U.S., and there can be no assurance that payments received in foreign currencies can be repatriated to the U.S. or that we will be able, contractually or otherwise, to reduce the foreign currency risks associated with our international operations.
Commodity Price Risk
Our revenues, profitability and future rate of growth significantly depend upon the market prices of oil and natural gas. Lower prices may also reduce the amount of oil and gas that can economically be produced.
Item 8. Financial Statements and Supplemental Data
|Report of Independent Registered Public Accounting Firm||43|
|Consolidated balance sheets||44|
|Consolidated statements of operations||45|
|Consolidated statements of cash flows||46|
|Consolidated statements of changes in stockholders’ equity||47|
|Notes to consolidated financial statements||48|
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders
Eco-Stim Energy Solutions, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Eco-Stim Energy Solutions, Inc. and Subsidiaries (the “Company”) as of December 31, 2017 and 2016, and the related consolidated statements of operations, cash flows, and changes in stockholders’ equity for the years then ended, and the related notes (collectively referred to as the “financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of their operations and their cash flows for the years then ended, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of their internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
/s/ Whitley Penn LLP
We have served as the Company's auditor since 2013.
March 19, 2018
ECO-STIM ENERGY SOLUTIONS, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
|December 31, 2017||December 31, 2016|
|Cash and cash equivalents||$||8,826,076||$||1,731,364|
|Total current assets||27,843,275||8,594,773|
|Property, plant and equipment, net||75,825,539||38,382,391|
|Other non-current assets||—||325,756|
|Liabilities and stockholders’ equity|
|Short-term notes payable||7,047,020||2,000,000|
|Current portion of capital lease payable||836,855||789,166|
|Total current liabilities||29,815,340||9,745,897|
|Long-term notes payable||1,172,712||21,737,404|
|Long-term capital lease payable||—||766,687|
|Total non-current liabilities||1,172,712||22,504,091|
|Commitments and contingencies|
|Preferred stock, $0.001 par value, 50,000,000 shares authorized, none issued||—||—|
|Common stock, $0.001 par value, 200,000,000 shares authorized, 74,599,749 issued and 74,577,899 outstanding at December 31, 2017 and 14,485,937 issued and 14,464,087 outstanding at December 31, 2016||74,578||14,485|
|Additional paid-in capital||144,071,119||59,556,505|
|Treasury stock, at cost; 21,850 common shares at December 31, 2017 and December 31, 2016||(57,469||)||(57,469||)|
|Total stockholders’ equity||72,680,762||15,052,932|
|Total liabilities and stockholders’ equity||$||103,668,814||$||47,302,920|
See accompanying notes to consolidated financial statements.
ECO-STIM ENERGY SOLUTIONS, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
|Years Ended December 31,|
|Operating cost and expenses:|
|Cost of services||53,002,499||10,630,233|
|Selling, general, and administrative expenses||8,441,933||5,892,235|
|Research and development||456,288||486,128|
|Depreciation and amortization expense||8,029,247||4,667,797|
|Total operating costs and expenses||69,929,967||21,676,393|
|Other income (expense):|
|Total other expense||(1,668,187||)||(4,295,771||)|
|Benefit (provision) for income taxes||633,529||(305,320||)|
|Basic and diluted loss per share||$||(0.41||)||$||(1.32||)|
|Weighted average number of common shares outstanding-basic and diluted||66,065,417||13,615,428|
See accompanying notes to consolidated financial statements.
ECO-STIM ENERGY SOLUTIONS, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
|Years Ended December 31,|
|Depreciation and amortization||8,029,247||4,667,797|
|Amortization of debt discount and loan origination cost||459,797||255,530|
|Stock based compensation||1,754,706||695,910|
|Changes in operating assets and liabilities:|
|Prepaids and other assets||(2,141,490||)||1,468,076|
|Accounts payable and accrued expenses||13,305,679||772,223|
|Net cash used in operating activities||(14,492,357||)||(5,276,855||)|
|Purchases of equipment||(35,379,441||)||(4,591,080||)|
|Net cash used in investing activities||(35,379,441||)||(4,591,080||)|
|Proceeds from sale of common stock, net||41,624,402||1,558,555|
|Proceeds from notes payable||18,719,126||2,194,611|
|Payments on notes payable||(2,587,852||)||(3,293,732||)|
|Payments on capital lease||(789,166||)||(565,449||)|
|Purchase of treasury stock||—||(37,175||)|
|Net cash provided by (used in) financing activities||56,966,510||(143,190||)|
|Net increase (decrease) in cash and cash equivalents||7,094,712||(10,011,125||)|
|Cash and cash equivalents, beginning of year||1,731,364||11,742,489|
|Cash and cash equivalents, end of year||$||8,826,076||$||1,731,364|
|Supplemental Disclosure of Cash Flow Information|
|Cash paid during the year for interest||$||385,259||$||3,448,408|
|Cash paid during the year for income taxes||$||541,723||$||140,341|
|Property, plant and equipment additions in accounts payable||$||1,669,057||$||1,327,927|
|Notes payable settled through recapitalization||$||22,000,000||$||—|
|Conversion of debt to equity||$||41,195,599||$||—|
|Equipment purchased with notes payable||$||8,807,582||$||—|
See accompanying notes to consolidated financial statements.
ECO-STIM ENERGY SOLUTIONS, INC.
CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY YEARS ENDED
DECEMBER 31, 2017 AND 2016
|Common Stock||Additional Paid-in||Treasury||Accumulated|
|Balance at December 31, 2015||13,566,050||$||13,572||$||57,302,953||$||(20,294||)||$||(26,535,341||)||$||30,760,890|
|Sale of common stock, net||796,573||797||1,557,758||—||—||1,558,555|
|Interest converted to common stock||116,375||116||695,794||—||—||695,910|
|Balance at December 31, 2016||14,464,087||$||14,485||$||59,556,505||$||(57,469||)||$||(44,460,589||)||$||15,052,932|
|Sale of common stock, net||30,144,174||30,086||42,519,083||—||—||42,549,169|
|Stock based compensation||430,853||468||1,754,238||—||—||1,754,706|
|Stock issued upon conversion of debt, net of costs||29,538,785||29,539||40,241,293||—||—||40,270,832|
|Balance at December 31, 2017||74,577,899||$||74,578||$||144,071,119||$||(57,469||)||$||(71,407,466||)||$||72,680,762|
See accompanying notes to consolidated financial statements.
ECO-STIM ENERGY SOLUTIONS, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2017 and 2016
1. Nature of Business
Eco-Stim Energy Solutions, Inc. is a growth-oriented, technology-driven independent oilfield services company providing well stimulation, coiled tubing and field management services to the upstream oil and gas industry. We are focused on reducing the ecological impact and improving the economic performance of the well stimulation process in “unconventional” drilling formations. We currently offer our services to oil and natural gas exploration and production (“E&P”) companies in the United States and Argentina. Our focus is to bring our service offerings, technologies and processes to the most active shale resource basins both domestically and outside of North America using our technology to differentiate our service offerings.
2. Basis of Presentation and Significant Accounting Policies
The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”).
Principles of Consolidation
We consolidate all wholly-owned subsidiaries, controlled joint ventures and variable interest entities where the Company has determined it is the primary beneficiary. All material intercompany accounts and transactions have been eliminated in consolidation. Our wholly-owned subsidiaries include: Viking Rock Holding, AS (100%), Viking Rock, AS (100% owned), Cherokee Rock, Inc. (100% owned), EcoStim, Inc. (100% owned), and EcoStim Energy Solutions Argentina, SA (100% owned).
The Company has incurred net losses and losses from operations since inception and will require additional capital to continue operations. As of December 31, 2017, the Company had cash and cash equivalents of approximately $8.8 million and working capital deficit of approximately $2.0 million. These factors raise substantial doubt about the Company’s ability to continue as a going concern.
Management’s plans to alleviate substantial doubt include: (i) deploying all U.S. fleets at higher rates; (ii) securing a working capital facility to enhance liquidity and support growth; (iii) re-negotiating the contract with its largest customer in Argentina to eliminate certain third-party services which contributed negatively to the Company’s fleet level gross margins in Argentina during 2017; (iv) re-negotiating the contract with the Company’s largest customer in Argentina to improve utilization and reduce stand-by time, thus eliminating factors that have contributed to negative fleet level gross margin in Argentina; and, (v) raising additional capital for the Company.
As of March 15, 2018, the Company has all fleets deployed, and the one non-deployed fleet as of December 31, 2017 has been deployed at rates higher than rates in 2017. In February 2018, the Company secured a receivable agreement designed to enhance liquidity and support growth as described in Note 20. The Company has engaged in negotiations with its customer in Argentina to seek modifications to the contract that would provide the Company with more favorable operating results. However, there can be no assurance that the Company’s efforts to renegotiate the terms of the contract will be successful, and the Company may continue to incur losses under the contract in the future. Management believes the Company has the ability to continue as a going concern for twelve months from the date of filing of this 10-K.
Use of Estimates
The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenue and expenses during the reporting period. Estimates are used in, but are not limited to, determining the following: allowance for doubtful accounts, recoverability of long-lived assets and intangibles, useful lives used in depreciation and amortization, income taxes and stock-based compensation. The accounting estimates used in the preparation of the consolidated financial statements may change as new events occur, as more experience is acquired, as additional information is obtained and as the Company’s operating environment changes.
Cash and Cash Equivalents
The Company considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents. The Company maintains deposits in several financial institutions, which may at times exceed amounts covered by insurance provided by the U.S. Federal Deposit Insurance Corporation (“FDIC”). The Company has not experienced any losses related to amounts in excess of FDIC limits.
All revenue is recognized when persuasive evidence of an arrangement exists, specific performance completed, the price is fixed or determinable, and collection is reasonably assured as follows:
Well Stimulation Revenue
The Company provides well stimulation services based on contractual arrangements, such as term contracts and pricing agreements, or on a spot market basis. Revenue is recognized upon completion of stimulation stages and includes the components of the services, and the chemicals and proppants consumed while performing the well stimulation services. Customers are invoiced upon the completion of each job, which can consist of one or more stimulation stages.
Under term pricing agreement arrangements, customers commit to targeted utilization levels at agreed-upon pricing, but without termination penalties or obligations to pay for services not used by the customer. In addition, the agreed-upon pricing is typically subject to periodic review.
Spot market basis arrangements are based on an agreed-upon hourly spot market rate. The Company also charges fees for setup and mobilization of equipment depending on the job, additional equipment used on the job, if any, and materials that are consumed during the well stimulation process. Generally, these fees and other charges vary depending on the equipment and personnel required for the job and market conditions in the region in which the services are performed.
The Company also generates revenues from chemicals and proppants that are consumed while performing well stimulation services.
Coiled Tubing Revenue
The Company began providing coiled tubing and other well stimulation services in early 2015. Jobs for these services are typically short term in nature, lasting anywhere from a few hours to multiple days. Revenue is recognized upon completion of each job based upon a completed field ticket. The Company charges the customer for mobilization, services performed, personnel on the job, equipment used on the job, and miscellaneous consumables at agreed-upon spot market rates.
Fair Value of Financial Instruments
The Company’s financial instruments consist of cash and cash equivalents, accounts receivable, other assets, accounts payable, accrued expenses, capital lease obligations and notes payable. The recorded values of cash and cash equivalents, accounts receivable, other assets, accounts payable, and accrued expenses approximate their fair values based on their short-term nature. The carrying value of capital lease obligations and notes payable approximate their fair value, and the interest rates approximate market rates.
Functional and Presentation Currency
Items included in the financial statements of each of the Company’s entities are measured using the currency of the primary economic environment in which the entity operates (the “functional currency”). The functional currency for the Norwegian and Argentine subsidiaries is the U.S. Dollar. The consolidated financial statements are presented in U.S. Dollars, which is the Company’s presentation currency.
Net Loss per Common Share
For the years ended December 31, 2017 and 2016, the weighted average shares outstanding excluded certain stock options and convertible debt of 1,605,575 and 4,478,507, respectively, from the calculation of diluted earnings per share because these shares would be anti-dilutive. Anti-dilutive warrants of 100,000 for each of the years ended December 31, 2017 and 2016 were also excluded from the calculation.
Accounts receivable are stated at amounts management expects to collect from outstanding balances both billed and unbilled (unbilled accounts receivable represents amounts recognized as revenue for which invoices have not yet been sent to clients). Management provides for probable uncollectible amounts through a charge to earnings and a credit to a valuation allowance based on its assessment of the current status of individual accounts. To date, the Company has recognized only insignificant losses due to uncollectible accounts. Balances still outstanding after management has used reasonable collection efforts are written off through a charge to the valuation allowance and a credit to accounts receivable. The Company evaluated all accounts receivable and determined that no reserve for doubtful accounts was necessary at December 31, 2017 and 2016.
Included in the accounts receivable balance are certain unbilled receivables with a significant customer that relate to work performed before the company entered into its rotational on-call contract in 2016. Under this prior arrangement, the Company was required to go through an arduous process to collect the outstanding amounts and while the Company has a track record of collecting amounts billed under this prior arrangement, it has proven to take long periods of time. At December 31, 2017 and 2016, there were $0 and approximately $855,706, respectively, in outstanding unbilled amounts due under this prior arrangement. All amounts included in this arrangement have been collected. Further, amounts billed to this significant customer under the rotational on-call contracts signed earlier this year have been collected within a more normal timeframe.
Prepaid expenses are primarily comprised of Argentinian value added tax, revenue and gross income taxes along with prepaid insurance and prepaid vehicle registration fees. The prepaid value added tax will be reduced as the Company continues to invoice customers in Argentina.
Inventories are stated at the lower of cost or net realizable value using the average method and appropriate consideration is given to deterioration, obsolescence and other factors in evaluating net realizable value.
Property, Plant and Equipment
Property, Plant and Equipment (“PPE”) is stated at historical cost less depreciation. Historical cost includes expenditures that are directly attributable to the acquisition of the items.
Depreciation is computed using the straight-line method over the estimated useful lives of the assets for financial reporting purposes. Expenditures for major renewals and betterments that extend the useful lives are capitalized. Expenditures for normal maintenance and repairs are expensed as incurred. The cost of assets sold or abandoned and the related accumulated depreciation are eliminated from the accounts and any gains or losses are reflected in the accompanying consolidated statements of operations for the respective period.
The estimated useful lives of our major classes of PPE are as follows:
|Major Classes of PPE||Estimated Useful Lives|
|Machinery and equipment||2-7 years|
|Leasehold improvements||5 years (or the life of the lease)|
|Furniture and office equipment||3-5 years|
The Company leases certain equipment under lease agreements. The Company evaluates each lease to determine its appropriate classification as an operating or capital lease for financial reporting purposes. Any lease that does not meet the criteria for a capital lease is accounted for as an operating lease. The assets and liabilities under capital leases are recorded at the lower of the present value of the minimum lease payments or the fair market value of the related assets. Assets under capital leases are amortized using the straight-line method over the lease term. Amortization of assets under capital leases is included in depreciation expense.
The Company accounts for its stock options, warrants, and restricted stock grants under the fair value recognition provisions of the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 718. The Company currently uses the straight-line amortization method for recognizing stock option and restricted stock compensation costs. The measurement and recognition of compensation expense for all share-based payment awards made to our employees, directors or outside service providers are based on the estimated fair value of the awards on the grant dates. The grant date fair value is estimated using either an option-pricing model which is consistent with the terms of the award or a market observed price, if such a price exists. Such cost is recognized over the period during which an employee, director or outside service provider is required to provide service in exchange for the award, i.e., “the requisite service period” (which is usually the vesting period). The Company also estimates the number of instruments that will ultimately be earned, rather than accounting for forfeitures as they occur. For the years ended December 31, 2017 and 2016, the Company recorded $1,754,706 and $695,910, respectively, of stock-based compensation, which is included in cost of services, selling, general and administrative expense, and research and development in the statement of operations. Total unamortized stock-based compensation expense at December 31, 2017 was $3,247,370 compared to $928,786 at December 31, 2016, and will be fully expensed through 2020.
Impairment of Long-Lived Assets
The Company reviews its long-lived assets for impairment when changes in circumstances indicate that the carrying amount of an asset may not be recoverable. ASC Topic 360 requires the Company to review long-lived assets for impairment whenever events or changes in circumstances indicate the carrying amount of an asset or group of assets may not be recoverable. The impairment review includes a comparison of future cash flows expected to be generated by the asset or group of assets with their associated carrying value. If the carrying value of the asset or group of assets exceeds expected cash flows (undiscounted and without interest charges), an impairment loss is recognized to the extent that the carrying value exceeds the fair value. If estimated future cash flows are not achieved with respect to long-lived assets, additional write-downs may be required. During 2017, the Company evaluated its long-lived assets for impairment and determined no impairment was necessary.
Major Customers and Concentration of Credit Risk.
The majority of the Company’s business is conducted with major and independent oil and gas companies in Argentina. The Company evaluates the financial strength of its customers and provides allowances for probable credit losses when deemed necessary. The Company derives a large amount of revenue from a small number of major and independent oil and gas companies. At December 31, 2017, the Company had a concentration of receivables with three customers.
For the years ended December 31, 2017 and 2016, three major customers accounted for approximately 99% and 100% of our services revenue, respectively. Our accounts receivable at December 31, 2017 were concentrated with three major customers representing 99% and at December 31, 2016 were concentrated with one major customer representing 73%.
The Company places its cash and cash equivalents with high credit quality financial institutions.
Deferred income taxes are determined using the asset and liability method in accordance with ASC Topic 740. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred income taxes are measured using enacted tax rates expected to apply to taxable income in years in which such temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred income taxes is recognized in the consolidated statement of operations of the period that includes the enactment date. In addition, a valuation allowance is established to reduce any deferred tax asset for which it is determined that it is more likely than not that some portion of the deferred tax asset will not be realized.
The Company is subject to U.S. federal and foreign income taxes along with state income taxes in Texas and Oklahoma. When tax returns are filed, it is highly certain that some positions taken would be sustained upon examination by the taxing authorities, while others are subject to uncertainty about the merits of the position taken or the amount of the position that would be ultimately sustained. The benefit of a tax position is recognized in the financial statements in the period during which, based on all available evidence, management believes it is more likely than not that the position will be sustained upon examination, including the resolution of appeals or litigation processes, if any. Tax positions taken are not offset or aggregated with other positions. Tax positions that meet the more-likely-than-not recognition threshold are measured as the largest amount of tax benefit that is more than 50% likely of being realized upon settlement with the applicable taxing authority. The portion of the benefits associated with tax positions taken that exceeds the amount measured as described above is reflected as a liability for unrecognized tax benefits in the accompanying consolidated balance sheets along with any associated interest and penalties that would be payable to the taxing authorities upon examination.
Accounting Guidance Issued and Adopted as of December 31, 2017
In July 2015, the FASB issues ASU No. 2015-11, “Inventory (Topic 330)”, (“ASU 2015-11”) which amends and simplifies the measurement of inventory. The main provisions of the standard require that inventory be measured at the lower of cost and net realizable value. Prior to the issuance of the standard, inventory was measured at the lower of cost or market (where market was defined as replacement cost, with a ceiling of net realizable value and floor of net realizable value less a normal profit margin). The Company adopted ASU 2015-11 as of January 1, 2017. The adoption did not have a material impact on the Company’s consolidated financial statements and related disclosures.
Accounting Guidance Issued but Not Adopted as of December 31, 2017
The recent accounting standards that have been issued or proposed by the Financial Accounting Standards Board (“FASB”) or other standards-setting bodies that do not require adoption until a future date are not expected to have a material impact on the consolidated financial statements upon adoption.
In May 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers, which requires us to recognize the amount of revenue to which we expect to be entitled for the transfer of promised goods or services to customers. The ASU will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. The new standard is effective on January 1, 2018, and we will adopt accordingly. The standard permits the use of either the retrospective or cumulative effect transition method. We are evaluating the effect ASU 2014-09 will have on our consolidated financial statements and related disclosures. The Company has performed an initial evaluation of this standard and its impact on the financial statements. This included tasks such as identifying contracts, identifying performance obligations and reviewing the applicable revenue streams. In this review, nothing has been identified that would result in a material change in the current accounting for revenue. The Company will continue to evaluate, particularly as we enter into new contracts and will update its procedures and internal controls and provide additional training for its staff as necessary to comply with this standard.
On February 25, 2016, the FASB issued ASU 2016-02 Leases (Topic 842), which requires an entity to recognize assets and liabilities arising from a lease for both financing and operating leases. The ASU will also require new qualitative and quantitative disclosures to help investors and other financial statement users better understand the amount, timing, and uncertainty of cash flows arising from leases. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted. The Company is currently evaluating the effect this standard will have on its Consolidated Financial Statements.
In May 2017, the FASB issued ASU 2017-09, Compensation-Stock Compensation (Topic 718): Scope of Modification Accounting. The general model for modifications of share-based payment awards is to record the incremental value arising from a change as additional compensation costs. This guidance clarifies situations in which the existing award is not probable of vesting, and a modification gives rise to a new measurement date; no change in the total compensation cost recognized for an existing award will be required if there is no change to the fair value, vesting conditions and classification of the award. This ASU is effective prospectively for annual periods beginning on or after December 31, 2017. Early adoption is permitted. The application of this amendment is not expected to have a material impact on our future Consolidated Financial Statements or related disclosures.
3. Accounts Receivable
Accounts receivable by category were as follows:
|Total accounts receivable||$||10,167,044||$||2,865,707|
Accounts receivable (both billed and unbilled) have increased from 2016 to 2017 almost exclusively due to the new U.S. activity started in May 2017.
Inventories by category were as follows:
|Chemicals and proppants||$||1,513,373||$||897,994|
Inventory balances have increased from 2016 to 2017 almost exclusively due to the new U.S. activity started in May 2017.
Prepaid by category were as follows:
|Prepaid value added tax||1,772,733||992,979|
|Prepaid other taxes||1,162,618||690,909|
|Prepaid other vendors and vehicle registrations||1,285,182||139,554|
Prepaid balances have increased from 2016 to 2017 due to: i) Argentina VAT and other tax prepaid amounts increasing as a result of purchase tax for a larger amount of purchases in 2017 compared with 2016 exceeding sales/revenue tax; and ii) start-up activity in the U.S. with vendors and vehicles purchased. The Company will use the prepaid value added tax as it continues to invoice customers in Argentina.
6. Other Assets
|Other current assets||84,842||21,157|
|Total other current assets||$||787,846||$||31,664|
Short-term deposits increased and long-term deposits decreased from 2016 to 2017 due to the maturity of the capital lease arrangement. As the least term end is reached in 2018, the deposit is being applied to the final six payments.
|Long term deposits||$||—||$||325,756|
|Total other non-current assets||$||—||$||325,756|
7. Property, Plant and Equipment
Property, plant and equipment consists of the following:
|Computer hardware & software||737,200||547,428|
|Furniture & fixtures||600,943||210,941|
|Machinery & equipment||76,014,771||25,395,633|
|Machinery & equipment under construction||13,091,352||17,969,630|
|Work in progress||100,362||994,597|
|Property and equipment||91,916,985||46,444,590|
|Less accumulated depreciation||(16,091,446||)||(8,062,199||)|
|Property and equipment, net||$||75,825,539||$||38,382,391|
Property, plant and equipment increased from 2016 to 2017 due to the acquisition of machinery and equipment related to the start-up operations in the U.S. Depreciation expense increased from 2016 to 2017 by $3.4 million to $8.0 million at December 31, 2017 from $4.7 million at December 31, 2016 due to the acquisition of machinery and equipment related to the start-up operation in the U.S.
8. Accrued Expenses
Accrued expenses consist of the following:
|Accrued accounts payable trade expenses||2,986,689||1,449,139|
|Total accrued expenses||$||4,820,774||$||4,503,180|
Accrued accounts payable trade increase from 2016 to 2017 primarily due to the start-up of operations in the U.S. Accrued interest decreased from 2016 to 2017 primarily due to the interest owed on the ACM Note Agreement and Stockholder Note at December 31, 2016. These loans were paid off during 2017. Vendor Equipment Financing loans principle and interest are paid monthly resulting in a lower interest accrual at December 31, 2017.
The carrying values of our debt obligations, net of unamortized debt issuance costs of $0 and $262,596 as of December 31, 2017 and December 31, 2016, respectively, are as follows:
|December 31, 2017||December 31, 2016|
|Short Term||Long Term||Short Term||Long Term|
|Vendor Equipment Financing||$||7,047,020||$||1,172,712||$||—||$||—|
|ACM Note Agreement||—||—||—||21,737,404|
Short-Term Stockholder Note
On November 30, 2016, the Company entered into a Loan Agreement with two of the Company’s largest stockholders, a portion of which was used to pay the remaining amount payable (approximately $1 million) by the Company under an equipment purchase agreement dated October 10, 2014, as amended, with Gordon Brothers Commercial & Industrial, LLC for the purchase of certain TPUs.
At December 31, 2016, the Company had a balance of $2,000,000 and accrued interest of $24,548. The indebtedness created under the Loan Agreement was repaid on March 6, 2017 with a portion of the proceeds of the credit facility extended by Fir Tree under the Amended and Restated Convertible Note Facility Agreement described below.
Vendor Equipment Financing
During various dates beginning in late September through November 2017, the Company purchased equipment through a financing arrangement with NOV Rolligon at an interest rate of 8% for 12 months. At December 31, 2017, the Company had a loan balance of $6,130,567 and accrued interest of $7,438.
Beginning August 23, 2017 through September 28, 2017, the Company purchased trucks through a financing arrangement with Ford Motor Credit Corporation at an interest rate of 4.99% annual interest for 36 months. At December 31, 2017, the Company had a loan balance of $816,226 and accrued interest of $1,894.
Beginning September 21, 2017 through September 29, 2017, the Company purchased tractors through a financing arrangement with Hitachi Capital America Corporation at an interest rate of 8.59% for 24 months. At December 31, 2017, the Company had a loan balance of $903,463 and accrued interest of $3,354.
On December 20, 2017, the Company purchased tractors through a financing arrangement with Mercedes-Benz Financial Services USA, LLC at an interest rate of 8.9% for 36 months. At December 31, 2017, the Company had a loan balance of $369,475 and accrued interest of $991.
The total future minimum payments due on our Vendor Equipment Financings as of December 31, 2017 are noted as follows:
|Total payments for 2018||$||7,047,019|
|Total payments for 2019||789,313|
|Total payments for 2020||383,400|
|Total future payments||—|
Long-Term Notes Payable
Convertible Note Facility
On May 28, 2014 (the “Closing Date”), the Company entered into a Convertible Note Facility Agreement (the “Original Note Agreement”) with certain funds affiliated with Albright Capital Management (“ACM”). The proceeds from the Original Note Agreement were used primarily for capital expenditures, certain working capital needs and approved operating budget expenses.
The Original Note Agreement allowed the Company to issue ACM entities a multiple draw secured promissory note with maximum aggregate principal amount of $22,000,000, convertible into Common Stock at a price of $6.00 per share at the option of ACM entities. The outstanding debt under the facility is convertible immediately and accrues interest at 14% per annum with interest payments due annually in arrears. The debt could be prepaid in full under certain conditions after the first anniversary of the Closing Date, and was scheduled to mature on the date that is four years following the Closing Date.
As of December 31, 2016, the Company had drawn down the full $22,000,000 available under the Original Note Agreement, which was primarily used for capital expenditures, certain working capital needs and approved operating budget expenses. The accrued interest at December 31, 2016 was $1,831,123.
All obligations under the Original Note Agreement were secured by liens on substantially all of the assets of the company and have subsidiary guarantees and pledges of the capital stock of the subsidiary guarantors subject to certain terms and exceptions.
At December 31, 2016, the Company was not in compliance with certain loan covenants under the Original Note Agreement, nor had the Company received waivers or amendments to those covenants. In March 2017, the Company entered into a transaction with Fir Tree pursuant to which Fir Tree purchased from ACM entities $22 million aggregate principal amount of the Company’s outstanding convertible notes which were due in 2018. With this transaction, all obligations under the Original Note Agreement were dissolved.
On March 3, 2017, the Company entered into a transaction with Fir Tree pursuant to which Fir Tree purchased from ACM entities $22 million aggregate principal amount of the Company’s outstanding 14% convertible notes which were due in 2018, (“the ACM Note”) and 2,030,436 shares of the Company’s outstanding common stock, par value $0.001 per share. This transaction was part of a comprehensive recapitalization designed to create a path to a potential conversion to equity of substantially all the Company’s debt, subject to stockholder approval. As part of the transaction, the ACM Note was amended and restated (the “A&R Convertible Note”) and the Company issued to Fir Tree an additional $19.4 million aggregate principal amount convertible note (the “New Convertible Note”), representing an additional $17 million aggregate principal amount of convertible notes issued by the Company to Fir Tree on March 3, 2017, and approximately $2.4 million principal amount of convertible notes in payment of accrued and unpaid interest on the ACM Note. The unpaid principal amount of the A&R Convertible Note and the New