2017 Annual Report
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Dear Shareholders:
We are pleased to report 2017 was yet another record year
for Energy Recovery, one which built upon previous success.
We demonstrated both execution and growth in our core
Water business as well as the expansion of applications of our
revolutionary PX® Pressure Exchanger® technology within Oil
& Gas, specifically with the announcement of the MTeq™ mud
pumping system in May. In 2017, we produced our strongest
ever top-line performance with $63.2 million in revenue. In
addition, through the team’s focus on maximizing manufacturing
efficiencies and value to the customer, the Company achieved
new highs in both product gross margin and total gross margin1.
Furthermore, the Company delivered $12.4 million in Net Income
or 22 cents per diluted share.
The recent CEO transition was swift and seamless, and the
company’s long-term strategy is largely unchanged. Management
remains committed to delivering results to our Shareholders;
to generating positive earnings per share as we did in 2017 as
well as executing against strategic growth initiatives. We will
continue to build upon our global leadership position in our core
Water business while also focusing on new applications of our
PX technology to include the commercialization of VorTeq™,
the further development of MTeq, and the broader continuous
innovation within Oil & Gas and beyond.
Driving Growth in Our Core Water Business
The exceptional quality and innovative design of our PX
technology, coupled with the dedicated leadership and singular
drive of our Water team forms the foundation of Energy
Recovery’s market leadership in global desalination energy
recovery solutions. In 2017, we captured 100 percent of Mega
Project2 awards, a clear reflection of the health of our core
Water business and the continuation of the PX technology as
the industry energy benchmark for excellence.
Looking forward, we see strong demand for our suite of Water
products throughout 2018 and have already announced over
$20 million in awards this year, including several in Saudi
Arabia which remains a key indicator of the strength of the
global desalination market at large. Despite our record results in
2017, we are not satisfied with the status quo and instead seek
to reinvest in our Water business to drive growth. Our Water
team will aggressively pursue opportunities to maximize value
through innovation of existing solutions, development of new
product offerings, increased customer access, and expansion
of partnerships with other technology leaders.
Energy Recovery was founded as a Water business and it has
grown over the past several decades to become a global leader
in desalination with an installed base of over 18,000 devices
across all seven continents, a global sales force, and a state of
the art manufacturing facility. Water currently is and will remain
a key component of our Company’s future success. We will
continue to innovate, broaden and strengthen our customer base,
and maximize growth opportunities across this business line.
Commercialization of VorTeq a Top Priority
Throughout 2018, our near-term strategic objective is clear:
ensure our Oil & Gas team is laser-focused on progress toward
the successful commercialization of VorTeq. Execution against
this objective is in the best interest of our licensing partners,
our Company and ultimately, our Shareholders.
Following analysis of data from private in-house and field
testing, we worked closely with key industry partners to execute
a comprehensive redesign of the VorTeq system, which was
completed in the second half of 2017. In the fourth quarter of
2017, the company deployed the second generation VorTeq
system and executed a battery of tests at rates of flow and
pressures emblematic of real-world hydraulic fracturing
conditions. We are currently sourcing harder grade materials
for the PX components contained in the VorTeq system as
well as exploring system design enhancements critical to
commercialization, and upon completion expect to resume
testing related to the achievement of Milestone 1.
We are confident in the talent of our engineering and operations
teams and believe firmly the VorTeq is a viable, disruptive
and transformative technology which we will successfully
commercialize in the future.
MTeq Development
While much of our Oil & Gas team’s near-term effort will be
focused on VorTeq, we are committed to the further development
of the MTeq system, our PX solution targeted at reducing
1. “Total gross margin” is a non-GAAP financial measure. Please refer to the discussion under headings “Use of Non-GAAP Financial Measures” and “Reconciliations of Non-GAAP Financial Measures.”
2. Mega Projects represent those plants with capacity greater than 50,000 cubic meters per day.
the cost and footprint of mud pumping in upstream oil and
gas operations.
In May 2017 we announced the launch of our next PX derivative,
the MTeq system. During the remainder of the year, we built our
first prototype unit and began extensive yard testing, yielding
promising results. In short, the prototype produced repeatedly
successful exchanges of pressure energy from clean fluid to
17-pound drilling mud, at rates and pressures typical of modern
shale drilling operations. We are currently implementing design
enhancements to the MTeq system with the expectation of
securing a location for further in-field testing during 2018.
Overall, 2017 was a great year for Energy Recovery, and we are
even more excited about the opportunities which lie ahead.
Record results, a strong balance sheet, and continued strength
in our Water business provide a launching platform for growth,
not only with expansion into new applications but also with
reinvestment in our core business. In the coming year, we
will focus on executing against those objectives to maximize
Shareholder value. The long-term growth opportunities for our
Company are vast, and we believe that our world-class team
and ubiquitous PX technology positions us well to take full
advantage of these exciting opportunities over the coming years.
On behalf of Energy Recovery’s Board of Directors and our entire
team, thank you for your continued investment in our company.
Sincerely,
Chris Gannon
President and CEO
Hans Peter Michelet
Chairman of the
Board of Directors
USE OF NON-GAAP FINANCIAL MEASURES
This letter includes certain non-GAAP financial measures, including total gross margin. Generally, a non-GAAP financial
measure is a numerical measure of a company’s performance, financial position, or cash flows that either exclude or include
amounts that are not normally excluded or included in the most directly comparable measure calculated and presented in
accordance with generally accepted accounting principles in the United States of America, or GAAP. These non-GAAP financial
measures do not reflect a comprehensive system of accounting, differ from GAAP measures with the same captions, and may
differ from non-GAAP financial measures with the same or similar captions that are used by other companies. As such, these
non-GAAP measures should be considered as a supplement to, and not as a substitute for, or superior to, financial measures
calculated in accordance with GAAP. We use these non-GAAP financial measures to analyze our operating performance and
future prospects, develop internal budgets and financial goals, and to facilitate period-to-period comparisons. We believe these
non-GAAP financial measures reflect an additional way of viewing aspects of our operations that, when viewed with our GAAP
results, provide a more complete understanding of factors and trends affecting our business.
ENERGY RECOVERY, INC.
RECONCILIATION OF NON-GAAP TO GAAP FINANCIAL MEASURES
(In thousands, except per share data)
(Unaudited)
Product revenue
License and development revenue
Total revenue
Product gross profit
License and development revenue
Total gross profit (non-GAAP)
Product gross margin
Total gross margin (non-GAAP)
Net income
Reversal of non-recurring expense (benefit)
Adjusted net income (non-GAAP)
Income per share:
Diluted
Diluted (non-GAAP)
$
$
$
$
$
$
$
$
Years Ended
December 31,
2017
2016
58,156
5,000
63,156
39,095
5,000
44,095
$
$
$
$
49,715
5,000
54,715
31,866
5,000
36,866
67.2%
69.8%
64.1%
67.4%
$
12,350
(8,394)
3,956
$
0.22
0.07
$
$
1,034
1,008
2,042
0.02
0.04
Number of diluted shares used in per share calculations
55,612
55,451
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington D.C. 20549
Form 10-K
(Mark One)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2017
or
☐
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission File Number: 001-34112
Energy Recovery, Inc.
(Exact Name of Registrant as Specified in Its Charter)
(State or Other Jurisdiction of Incorporation or Organization)
(I.R.S. Employer Identification No.)
Delaware
01-0616867
1717 Doolittle Drive, San Leandro, CA 94577
(Address of Principal Executive Offices)
Registrant’s telephone number, including area code: (510) 483-7370
Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:
Title of Each Class
Common stock, $0.001 par value
Name of Exchange on Which Registered
The NASDAQ Stock Market LLC
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark whether the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☐ Yes No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. ☐ Yes No
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding
12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yes ☐ No
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted
and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required
to submit and post such files). Yes ☐ No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 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, or a smaller reporting 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:
Large accelerated filer ☐
Accelerated filer
Non-accelerated filer ☐
Smaller reporting company ☐
Emerging growth company ☐
(Do not check if a smaller reporting 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
The aggregate market value of the voting stock held by non-affiliates amounted to approximately $278.9 million on June 30, 2017.
The number of shares of the registrant’s common stock outstanding as of February 28, 2018 was 53,985,515 shares.
DOCUMENTS INCORPORATED BY REFERENCE
As noted herein, the information called for by Part III is incorporated by reference to specified portions of the registrant’s definitive proxy statement to be filed in conjunction
with the registrant’s 2018 Annual Meeting of Stockholders, which is expected to be filed not later than 120 days after the registrant’s fiscal year ended December 31, 2017.
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TABLE OF CONTENTS
PART I
Item 1
Item 1A
Item 1B
Item 2
Item 3
Item 4
Item 5
Item 6
Item 7
Item 7A
Item 8
Item 9
Item 9A
Item 9B
Item 10
Item 11
Item 12
Item 13
Item 14
Business ......................................................................................................................................................................
Risk Factors ................................................................................................................................................................
Unresolved Staff Comments .......................................................................................................................................
Properties ....................................................................................................................................................................
Legal Proceedings .......................................................................................................................................................
Mine Safety Disclosures .............................................................................................................................................
PART II
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities ..
Selected Financial Data ..............................................................................................................................................
Management’s Discussion and Analysis of Financial Condition and Results of Operations ......................................
Quantitative and Qualitative Disclosures About Market Risk ....................................................................................
Financial Statements and Supplementary Data ...........................................................................................................
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure ......................................
Controls and Procedures .............................................................................................................................................
Other Information .......................................................................................................................................................
PART III
Directors, Executive Officers and Corporate Governance ..........................................................................................
Executive Compensation ............................................................................................................................................
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters ....................
Certain Relationships and Related Transactions and Director Independence .............................................................
Principal Accounting Fees and Services .....................................................................................................................
PART IV
Page
4
14
24
24
24
24
25
27
28
45
46
98
98
98
99
99
99
99
99
Exhibits and Financial Statement Schedules ............................................................................................................... 100
Item 15
Item 16
Form 10-K Summary .................................................................................................................................................. 100
SIGNATURES ................................................................................................................................................................................... 101
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FORWARD-LOOKING INFORMATION
This Annual Report on Form 10-K for the year ended December 31, 2017, including “Item 7 – Management’s
Discussion and Analysis of Financial Condition and Results of Operations” and certain information incorporated by
reference, contain forward-looking statements within the “safe harbor” provisions of the Private Securities Litigation Reform
Act of 1995. Forward-looking statements in this report include, but are not limited to, statements about our expectations,
objectives, anticipations, plans, hopes, beliefs, intentions, or strategies regarding the future.
Forward-looking statements represent our current expectations about future events, are based on assumptions, and
involve risks and uncertainties. If the risks or uncertainties occur or the assumptions prove incorrect, then our results may
differ materially from those set forth or implied by the forward-looking statements. Our forward-looking statements are not
guarantees of future performance or events.
Words such as “expects,” “anticipates,” “aims,” “projects,” “intends,” “plans,” “believes,” “estimates,” “seeks,”
variations of such words, and similar expressions are also intended to identify such forward-looking statements. These
forward-looking statements are subject to risks, uncertainties, and assumptions that are difficult to predict; therefore, actual
results may differ materially and adversely from those expressed in any forward-looking statements. Readers are directed to
risks and uncertainties identified under “Item 1A – Risk Factors” and elsewhere in this report for factors that may cause
actual results to be different from those expressed in these forward-looking statements. Except as required by law, we
undertake no obligation to revise or update publicly any forward-looking statements for any reason.
Forward-looking statements in this report include, without limitation, statements about the following:
• our belief that levels of gross profit margin are sustainable to the extent that volume grows, we experience a
favorable product mix, pricing remains stable, and we continue to realize cost savings through production
efficiencies and enhanced yields;
• our plan to improve our existing energy recovery devices and to develop and manufacture new and enhanced
versions of these devices;
• our belief that our PX® energy recovery devices are the most cost-effective energy recovery devices over time and
will result in low life-cycle costs;
• our belief that our turbocharger devices have long operating lives;
• our objective of finding new applications for our technology and developing new products for use outside of
desalination, including oil & gas applications;
• our expectation that our expenses for research and development and sales and marketing may increase as a result
of diversification into markets outside of desalination;
• our expectation that we will continue to rely on sales of our energy recovery devices in the desalination market for
a substantial portion of our revenue and that new desalination markets, including the United States, will provide
revenue opportunities to us;
• our ability to meet projected new product development dates, anticipated cost reduction targets, or revenue growth
objectives for new products;
• our belief that we can commercialize the VorTeq™ hydraulic fracturing system;
• our belief that the VorTeq enables OFS companies to migrate to more efficient pumping technology;
• our belief that we will be able to enter into a long-term licensing agreement to bring the MTeq solution to market;
• our belief that customers will accept and adopt our new products;
• our belief that our current facilities will be adequate for the foreseeable future;
- 2 -
• our expectation that sales outside of the United States will remain a significant portion of our revenue;
•
the timing of our receipt of payment for products or services from our customers;
• our belief that our existing cash balances and cash generated from our operations will be sufficient to meet our
anticipated liquidity needs for the foreseeable future, with the exception of a decision to enter into an acquisition
and/or fund investments in our latest technology arising from rapid market adoption that could require us to seek
additional equity or debt financing;
• our expectation that, as we expand our international sales, a portion of our revenue could be denominated in foreign
currencies;
• our expectations of the impact of the Tax Cuts and Jobs Act of 2017;
• our belief that new markets will grow in the water desalination market;
• our expectation that we will be able to enforce our intellectual property rights; and
• other factors disclosed under Item 1 – Business, Item 1A – Risk Factors, Item 2 – Properties, Item 7 – Management’s
Discussion and Analysis of Financial Condition and Results of Operation, Item 7A – Quantitative and Qualitative
Disclosures about Market Risks and elsewhere in this Form 10-K.
You should not place undue reliance on these forward-looking statements, which reflect management’s opinions only
as of the date of the filing of this Annual Report on Form 10-K. All forward-looking statements included in this document are
subject to additional risks and uncertainties further discussed under “Item 1A – Risk Factors” and are based on information
available to us as of March 8, 2018. We assume no obligation to update any such forward-looking statements. It is important
to note that our actual results could differ materially from the results set forth or implied by our forward-looking statements.
The factors that could cause our actual results to differ from those included in such forward-looking statements are set forth
under the heading “Item 1A – Risk Factors” and our results disclosed from time to time in our reports on Forms 10-Q and
8-K and our Annual Reports to Stockholders.
- 3 -
PART I
ITEM 1 — BUSINESS
Overview
Energy Recovery, Inc. and its wholly-owned subsidiaries (the “Company,” “Energy Recovery,” “our,” “us,” and “we”)
is an energy solutions provider to industrial fluid flow markets worldwide. Our core competencies are fluid dynamics and
advanced material science. Our products make industrial processes more operational and capital expenditure efficient. Our
solutions convert wasted pressure energy into a reusable asset and preserve or eliminate pumping technology in hostile
processing environments. Our solutions are marketed and sold in fluid flow markets, such as water desalination, oil & gas,
and chemical processing, under the trademarks ERI®, PX®, Pressure Exchanger®, PX Pressure Exchanger®, AT™, AquaBold™,
VorTeq™, MTeq™, IsoBoost®, and IsoGen®. Our solutions are owned, manufactured, and/or developed, in whole or in part, in
the United States of America (“U.S.”) and the Republic of Ireland (“Ireland”). Energy Recovery was incorporated in Virginia
in 1992, reincorporated in Delaware in 2001, and became a public company in July 2008.
Markets
Our primary industrial fluid flow markets are water and oil & gas. We are a technology leader for energy recovery
devices (“ERDs”) in the water market with our proprietary Pressure Exchanger (“PX”) and turbocharger technologies. We
also manufacture high-performance and high-efficiency pumps to provide a packaged solution for our water market
customers. Building on our technology, we have expanded our technology solutions offerings into fluid flow applications in
the oil & gas market, and are exploring other end markets for which our solutions may be applicable. In the oil & gas market,
we offer our VorTeq hydraulic fracturing system (“VorTeq”), and our MTeq mud pumping system (“MTeq”), each of which
utilizes our PX technology, as well as our IsoBoost and IsoGen systems, which utilize our turbocharger technology.
Water
Population and economic growth in regions such as the Middle East, Africa, and Asia are driving water demand for
human, agricultural, and industrial use. Apart from seasonal variations, the supply of fresh water remains fixed and cannot
keep pace with this growing demand. Desalination of seawater, brackish and wastewater into freshwater offers a solution to
water needs around the world. In many parts of the world, desalination contributes significantly to the freshwater supply.
However, highly pressurized fluid flows are generally required in the desalination process to generate fresh water. These
pressurized fluid flows are both a necessity and liability to the water industry. High rates of flow and high-pressure
differentials lead to pressure energy becoming a waste product thereby driving excessive energy usage and cost. Water
desalination operators seek ways to reduce these costs and improve overall productivity.
Seawater, brackish, and wastewater reverse osmosis desalination have been our core markets for revenue generation
to date. Because of the geographical location of many significant water desalination projects, geopolitical and economic
events can influence the timing of expected projects. We anticipate that markets traditionally not associated with desalination,
including the U.S., will inevitably develop and provide further revenue growth opportunities. The water market ranges from
small desalination plants such as those used in cruise ships and resorts, to mega-project desalination plant deployments
globally.
Energy Recovery Devices, PX and turbocharger ERD solutions for desalination application: The costs to desalinate
and purify water are high, as plants are expensive to build and operate, with energy costs being a major expense driver. Plant
operators strive to design and build the most cost-efficient plants possible. As a result, plant operators implement technologies
to reduce the energy required to produce desalinated water while maximizing plant reliability and uptime.
- 4 -
High Efficiency Pumps, High-pressure feed and high-pressure circulation pumps: In addition to ERD solutions,
the desalination of water requires specialized high pressure feed and circulation pumps. These devices in combination with
ERDs must efficiently pressurize and circulate feedwater to the membranes to purify water. Plant operators require specialized
pumps with performance matched to the requirements of the membranes and ERDs. To minimize plant costs these pumps
must provide high energy efficiency and reliability with low maintenance requirements.
Greenfield
The greenfield market typically represents newly constructed seawater reverse osmosis desalination projects. These
facilities vary in size, scope and geography. Typically, greenfield projects are public in nature and involve a formal tendering
process. Prior to project award, we work directly with the project bidders and upon award our normal sales process ensues.
The greenfield market has been the key market for our water business. This market is highly competitive and the tendering
process pays close attention to the cost to desalinate water (i.e., dollars per cubic meter of water produced).
Retrofit
The retrofit market represents existing water facilities that are currently in operation utilizing legacy technologies.
These facilities and their owners not only encounter issues with low-efficiency legacy technologies, but also encounter capital
expenditure and “know-how” issues that may prevent them from retrofitting plants. Typical retrofits include improvements
to existing operations and equipment upgrades. We leverage our best-in-class solutions to unseat existing technology by
implementing water production efficiency measures to reduce overall power consumed, repairs and maintenance costs and
avoid costly capital upgrades, as well as increase throughput or enhance revenue. These retrofit opportunities may or may not
have a formal tendering process. We typically approach the owners and / or end-users of these facilities to present our value-
proposition.
Service & Aftermarket
The service & aftermarket market is comprised of existing water facilities that have our solutions installed and/or in
operation. We provide spare and repaired components, field services and various commissioning activities to our customer
base. We leverage our water expertise in supporting our existing installed base to ensure that our solutions are being operated
effectively. Readily available aftermarket products and services are required by our industry partners and customers in order
maximize plant availability and profits.
Oil & Gas
Across oil & gas markets, highly pressurized fluid flows are required to extract and process hydrocarbons. These
pressurized fluid flows are both a necessity and liability to the oil & gas industry. High rates of flow, high pressure
differentials and hostile (e.g., corrosive, erosive or abrasive) fluids lead to rapid degradation of expensive pressure pumping
equipment. In addition, pressure energy becomes a waste product at various stages of oil and gas processing thereby driving
excessive energy usage and cost. Oil & gas operators seek ways to reduce these costs and improve overall productivity.
Upstream Sector
In the upstream sector, high rates of flow, high pressure differentials and hostile (e.g., corrosive, erosive or abrasive)
fluids lead to rapid degradation of expensive pressure pumping equipment, as well as costly repairs and maintenance,
excessive downtime and significant excess capacity requirements. We offer a solution to minimize these costs by pressurizing
hostile fluids in our proprietary PX technology, thereby only running clean fluids through the pumping equipment.
VorTeq, a PX solution for hydraulic fracturing applications: Hydraulic fracturing is a well-stimulation technique in
which pressurized liquid containing a highly abrasive, proppant-laden fluid is injected into a wellbore. Oilfield service
- 5 -
(“OFS”) providers utilize high-pressure hydraulic fracturing pumps (commonly referred to as “frac-pumps”) to pressurize
fracturing fluid (commonly referred to as “frac-fluid”) at treating pressures up to 15,000 pounds per square inch (“psi”). This
frac-fluid is sent from the frac-pumps through traditional missile manifolds into the wellbore to create cracks in the deep-
rock formations thereby permitting oil and gas extraction. These frac-pumps are routinely destroyed by the abrasive frac-
fluids used during the hydraulic fracturing process causing significant OFS operator costs associated with excessive
downtime, repairs, maintenance, and capital equipment redundancy. OFS operators have long sought ways to ruggedize or
extend the life of pumps thereby reducing costs. Further, many OFS operators have long sought the means to isolate their
high-pressure frac-pumps from abrasive frac-fluid thereby enabling OFS operators to realize immediate and long-term
savings in the form of reduced downtime, repairs and maintenance costs and capital equipment redundancy.
MTeq, a PX solution for mud pumping applications: During mud pumping, a drilling fluid (commonly referred to as
“drilling mud”) is circulated from a mud pit through the wellbore utilizing high-pressure mud pumps, which pressure the
drilling mud at treating pressures up to 7,500 psi, to remove cuttings, control formation pressures, and lubricate the drill bit.
Although the mud pumping process removes most of the solids from the drilling mud, debris and sand remain. This drilling
mud subjects the pumps circulating the fluid to extreme wear, resulting in burdensome repair and maintenance costs. These
mud pumps are routinely destroyed by the hostile drilling mud used during the mud pumping process causing OFS operators
significant costs associated with excessive downtime, repairs, maintenance, capital equipment redundancy, safety, and rig
mobilization. OFS operators have long sought ways to ruggedize or extend the life of these mud pumps thereby reducing
costs, as well as isolate high-pressure mud pumps to bypass corrosive “mud” from the mud pumping system in drilling rigs,
an integral piece of the well control system during drilling.
Midstream and Downstream Sectors
IsoBoost & IsoGen, turbocharger solutions, for gas processing & pipeline applications: Within the oil & gas
midstream and downstream sectors, pressure energy becomes a waste product at various stages of oil & gas processing thereby
driving excessive energy usage and cost. In addition, these midstream and downstream sectors incur very steep expenses as
a result of the ongoing maintenance and repair of the high-pressure pumps required to run the acid gas removal process. Our
target markets consist of gas processing plants, pipeline substations and ammonia plants worldwide.
Solutions
Energy, repairs, maintenance, and capital costs are major cost drivers in the water and oil & gas markets. We have
developed the following proprietary technology solutions to address these major cost drivers:
Water
In the water market, our energy recovery solutions reduce plant operating costs by capturing and reusing otherwise
lost pressure energy from the reject stream of the water desalination process. Our water ERDs are categorized into two
technology groups: PX Pressure Exchangers and turbochargers. Complementing these products are our high-performance,
high-efficiency pumps.
QPX and PX Prime, high efficiency ERD solutions for water applications: Our patented PX ERD technology consists
of a ceramic rotor operating on highly efficient hydrodynamic bearings. Our PX ERDs enable water desalination plant
operators to recover wasted hydraulic pressure energy from a high-pressure fluid flow and transfer the energy to a low-
pressure fluid flow. Our PX ERDs perform with up to 98% efficiency and unmatched uptime in the desalination industry,
and can reduce a desalination plant’s energy costs by up to 60%.
Turbochargers, high efficiency centrifugal ERD solutions for water applications: Our hydraulic turbochargers
(“Turbochargers”) are designed for low-pressure brackish, high-pressure seawater reverse osmosis systems and various other
water treatment applications. Our Turbochargers provide high efficiency with state-of-the-art engineering and configuration.
- 6 -
Designed for maximum durability, reliability and optimum efficiency, our turbochargers offer substantial savings, and the
custom-designed hydraulics and 3-dimensional (“3D”) geometry allow for optimum performance.
Pumps, high efficiency pumps for water applications: Our high-pressure feed and circulation pumps are designed
for low and high-pressure reverse osmosis systems. Specifically designed for the reverse osmosis industry, our pumps utilize
our material science and hydraulic design expertise. Designed for maximum durability, reliability, and optimum efficiency,
our pumping systems offer users savings, while the investment cast components and optimized fluid pathways ensure
maximum performance.
Oil & Gas
In the oil & gas market, our technology solutions preserve or eliminate pumping technology in hostile processing
environments or convert wasted pressure energy into a reusable asset. Our core oil & gas solutions based upon PX technology,
the VorTeq and MTeq, which isolate high cost pumping equipment from hostile processing fluids. Our centrifugal line of
solutions based upon turbocharger technology the IsoBoost and IsoGen, recycle otherwise lost pressure energy.
Upstream Sector
VorTeq, a PX solution for hydraulic fracturing applications: The VorTeq technology for use by OFS companies
isolates and preserves costly frac-pumps by re-routing hostile frac-fluid away from the frac-pumps, and ultimately enables a
more efficient pumping model. Using VorTeq, the frac-pumps will process only clean fluid, which leads to reduced repairs
and maintenance costs, reduced capital costs by extending frac-pump life expectancy, and the elimination of redundant capital
equipment. Furthermore, VorTeq enables the migration to more efficient pumping technology. Specifically, when frac-pumps
are no longer required to process hostile frac-fluid, OFS companies are able to utilize fewer, larger and more efficient
centrifugal pumps, which is not currently possible as such pumps cannot successfully process hostile frac-fluid. When
implemented by OFS companies, this new centrifugal pump model has the potential to revolutionize the equipment (and cost)
required to produce hydrocarbons through hydraulic fracturing. Our VorTeq is currently in the research and development
(“R&D”) stage and we are actively working towards commercialization. We completed a substantial re-design of the VorTeq
during 2017. We are focused on commercializing this technology.
MTeq, a PX solution for mud pumping applications: Our MTeq technology for use by OFS companies isolate and
preserves costly mud pumps by re-routing hostile drilling mud away from these critical pumps, and ultimately enables a more
efficient pumping model. These mud pumps will then process only clean fluid, which leads to reduced repairs and
maintenance costs and reduced capital costs by extending pump life expectancy and eliminating redundant capital equipment.
Furthermore, by processing only clean fluid, our MTeq enables the migration by the OFS companies to increasingly efficient
pumping technology which cannot otherwise handle the hostile processing fluid. This more efficient pumping model further
reduces capital expenditures and offers increased safety and reliability, as well as lower mobilization and logistics complexity
and associated cost. Our MTeq is currently in the R&D stage and we are actively working towards commercialization. We
designed the MTeq during late 2016 and early 2017 and completed building the first prototype in December 2017.
Midstream and Downstream Sectors
IsoBoost & IsoGen, turbocharger solutions, for gas processing & pipeline applications: Within the gas processing
and pipeline pressure down cycle, the IsoBoost and IsoGen technology enables the recovery of pressure energy in the fluid
flow either through the exchange of pressure within the application or by converting it to electricity. Our technology enables
gas processing plant and pipeline owners and operators to achieve immediate and long-term energy savings with little or no
operational disruption. Our IsoBoost is comprised of hydraulic turbochargers and related controls and automation systems.
The IsoBoost solution enables oil & gas operators to capture and use wasted hydraulic pressure energy within the acid gas
removal process, acting like a pump that is powered by hydraulic pressure that would otherwise be discarded through a control
valve. Our IsoGen is comprised of hydraulic turbines, generators, and related controls and automation systems. The IsoGen
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enables oil & gas operators to generate electricity from the hydraulic energy in high-pressure fluid flows, either within the
acid gas removal process in gas processing or at pipeline choke stations.
Customers
Water
We sell our ERD solutions to major international engineering, procurement, and construction (“EPC”) firms that can
design, build, own and operate large-scale desalination plants; original equipment manufacturers (“OEM”) which are
companies that supply equipment and packaged solutions for small- to medium-sized desalination plants; national, state and
local municipalities worldwide; and plant owners who can utilize our technology to upgrade or keep their plant running, or
retrofit their existing plant equipment with various efficiency measures to optimize operations by reducing overall power
consumed and reduce other operating costs in the desalination process.
Large Engineering, Procurement and Construction Firms
A significant portion of our revenue has historically come from sales of our ERD solutions to large EPC firms
worldwide which have the required desalination expertise to engineer, undertake procurement for, construct, and sometimes
own and operate, large desalination plants or mega-projects (“MPD”). We work with these firms to specify our ERD solutions
for their plants. The time between project tender and shipment can range from sixteen to thirty-six months, or more. Each
MPD project typically represents revenue opportunities ranging from $1 million to $6 million, and sometimes more.
Original Equipment Manufacturers
Our packaged solutions to OEMs include PXs, turbochargers, high-pressure pumps, and circulation “booster” pumps.
Our sale of solutions and services to OEM suppliers are for integration and use in small- to medium-sized desalination plants
located in small municipalities, hotels and resorts, power plants, cruise ships, farm operations, and other desalination facilities.
In addition, these OEMs purchase our solutions for “quick water” or emergency water solutions. The time from project tender
and shipment can range from one to 12 months. OEM projects typically represent revenue opportunities of up to $1 million.
End-users and Service Providers
Our existing and expanding installed base of ERD and pump products in water plants has created a growing customer
base comprised of plant operators and service providers. These customers purchase spare parts, replacement parts, and service
contracts, as well as utilize our field service managers to perform maintenance and repairs. Owners and operators of older
plants without effective ERDs and newer plants with ERDs manufactured by our competitors purchase our equipment to
retrofit plants to realize operational expense reductions or expansions in plant capacity. In addition, these customers may
retrofit their plants to harvest operational efficiencies through our Energy Service Agreements (“ESA”).
Oil & Gas
We license, lease or sell our oil and gas products to OFS companies, international oil companies (“IOC”), national oil
companies (“NOC”), exploration and production companies (“E&P”), OEMs and EPC firms.
Oilfield Service Companies
OFS companies provide the infrastructure, equipment, intellectual property, and services needed by the oil & gas
industry to explore for, extract, and transport crude oil and natural gas. OFS hydraulic fracturing and mud pumping operators
face significant pressure to reduce costs as oil & gas companies curtail capital expenditures and seek operational efficiencies
in response to lower commodity prices.
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Our VorTeq enables OFS hydraulic fracturing operators to isolate their frac-pumps from frac-fluid thereby reducing
operating and capital costs. In 2014, we entered into a strategic partnership with Liberty Oil Field Services (“Liberty”) to
pilot and conduct field trials with the VorTeq. Through this agreement, Liberty has the rights to lease up to twenty VorTeq
missiles for a period of up to five years following commercialization. In 2015, we entered into a 15-year license agreement
with Schlumberger Technology Corporation (the “VorTeq Licensee”) for the exclusive, worldwide right to use the VorTeq
for hydraulic fracturing onshore operations. The license agreement provides a carve out for Liberty’s contractual rights to
utilize the VorTeq. We are currently working with the VorTeq Licensee and Liberty to commercialize the VorTeq technology.
Our MTeq enables OFS mud pumping operators drilling oil and gas wells to isolate their mud pumps from harsh
drilling mud thereby reducing operating and capital costs. In the second quarter of 2017, we entered into a strategic early-
stage testing agreement with Sidewinder Drilling to conduct testing of the MTeq solution at their yard facility. As with
VorTeq, following product validation, we intend to enter into a long-term licensing agreement to bring the MTeq solution to
market. These long-term licensing partners could be OFS companies that specialize in drilling wells or OEMs that supply or
lease equipment to market participants. We are currently in the process of evaluating potential partners for the MTeq solution.
Gas Processing & Pipeline Operators
We have contracted and delivered oil & gas solutions to customers in North America, Asia, and the Middle East for
use in gas processing applications. Our target market consists of gas processing plants, pipeline substations and ammonia
plants worldwide. Our IsoGen solution has been installed in a major gas processing plant in the Middle East. Our IsoBoost
solution has been purchased for integration into a major gas processing plant to be constructed in the Middle East.
In 2016, we received our first major purchase order for multiple units of our IsoBoost solution for integration into a
major gas processing plant under construction in the Middle East. We expect to complete and ship the units to the Middle
East in the first half of 2018. In April 2017, we entered into a 10-year licensing agreement with Alderley FZE for our IsoBoost
& IsoGen technologies in gas processing and pipeline applications within the countries of the Gulf Cooperation Council
(“GCC”), as well as Iraq and Iran to the extent international sanctions and laws permit.
Competition
Water
The market for ERDs and pumps in the water treatment market is competitive. As the demand for fresh water increases
and the market expands, we expect competition to persist and intensify.
We have three main competitors for our ERDs: Flowserve Corporation (“Flowserve”), Fluid Equipment Development
Company (“FEDCO”), and Danfoss Group (“Danfoss”). Although these companies may offer competing solutions at lower
initial prices, our solutions offer a competitive advantage because we believe that they provide the lowest life-cycle cost and
are therefore the most cost-effective ERDs for the reverse osmosis desalination industry over time.
In the market for large desalination projects, our PX ERDs compete primarily with Flowserve’s DWEER product. We
believe that our PX ERDs have a competitive advantage over DWEER devices because our devices are made with highly
durable and corrosion-resistant ceramic parts that are designed for a life of more than 25 years, are warranted for high
efficiencies, cause minimal unplanned downtime, and offer lower lifecycle costs. Additionally, the PX ERDs offer optimum
scalability with a quick startup as well as minimal maintenance. We believe that our large AT turbocharger solutions also
have a competitive advantage over Flowserve’s Pelton Turbine product, particularly in countries where energy costs are low
and upfront capital costs are a critical factor in purchase decisions, because our AT turbocharger solutions have higher net
transfer efficiencies, lower upfront capital costs, a simple design with one rotating assembly, a small physical footprint, and
a long operating life that leads to low total lifecycle costs.
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In the market for small-to-medium-sized desalination plants, our solutions compete with FEDCO’s turbochargers and
Danfoss’s ERDs. We believe that our PX ERDs have a competitive advantage over these solutions because our devices
provide up to 98% energy efficiency, have lower lifecycle maintenance costs, and are made of highly durable and corrosion-
resistant ceramic parts. We also believe that our turbochargers compete favorably with FEDCO’s turbochargers on the basis
of efficiency and price and because our turbochargers have design advantages that enhance efficiency, operational flexibility,
and serviceability.
In the market for high-pressure pumps, our solutions compete with pumps manufactured by Clyde Union Ltd.;
FEDCO; Flowserve; KSB Aktiengesellschaft; Torishima Pump Mfg. Co., Ltd.; Sulzer Pumps, Ltd.; and other companies.
We believe that our pump solutions are competitive with these solutions because our pumps are developed specifically for
reverse osmosis desalination, are highly efficient, and feature product-lubricated bearings.
Oil & Gas
The landscape for our technology within the oil & gas market is competitive as the industry is continuously seeking
ways to reduce costs and extend the life of assets used in the production or transportation of hydrocarbons. As demand for
our products increase, we expect competition to intensify.
We believe our VorTeq technology represents a competitive advantage over existing missile manifold technology
because our solution re-routes abrasive proppant away from high-pressure pumps, thereby extending pump lifespan, reducing
repairs and maintenance costs, and decreasing the need for redundant capital equipment. In addition, because our VorTeq
technology isolates the high-pressure frac-pumps from abrasive proppant, OFS fracing operators will have the option to
transition to more robust, longer lived, centrifugal pumps thereby further decreasing operating and capital costs. While our
VorTeq replaces a traditional manifold, the competitors to our VorTeq are the high-pressure frac pump manufacturers. There
are a multitude of these pump manufacturers, including FMC Technologies, the Weir Group, Stewart & Stevenson and Forum
Energy Technologies.
Our latest technology offering, the MTeq, enhances the useful life of mud pumps and consumable pump components
used in land drilling by re-routing the abrasive drilling mud away from the high-pressure pumps, thereby isolating them.
Because our MTeq isolates the mud pumps from abrasive fluid, OFS operators have the option to transition to more robust,
longer life, centrifugal pumps thereby further decreasing operating and capital costs. Like the VorTeq (described in the
preceding paragraph), the competition to the MTeq is a more robust mud pump or more durable mud pump components. The
primary manufacturers of mud pumps are National Oilwell Varco, Inc., Gardner Denver, Inc. and Cameron International
Corporation.
Our IsoBoost and IsoGen technologies integrate into acid gas removal systems to reduce energy consumption and
increase the reliability and uptime of the amine circulation system. Several companies manufacture competitive technology
to the IsoGen, which primarily consist of reverse running pumps (also called hydraulic power recovery turbines or HPRTs)
and perform a basic form of energy recovery. Manufacturers of reverse running pumps include, but are not limited to,
Flowserve, Sulzer Pumps, Ltd., and Shin Nippon Machinery. Several companies manufacture hydraulic turbochargers, which
could eventually develop into competitive technology to the IsoBoost. However, none of these companies that manufacture
turbochargers have significant experience within gas processing. In order to utilize a turbocharger in gas processing, expertise
is required to validate the system level design and integration within a gas processing application.
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Sales and Marketing
Water
In the water market, our strategically located direct sales force offers our products through capital sale, ESAs, and
financing procurement vehicles. MPD opportunities are for desalination projects exceeding 50,000 cubic meters per day.
OEM opportunities include sales of PX ERDs, turbochargers, and pumps for plants typically designed to produce less than
50,000 cubic meters per day. Aftermarket opportunities include new and replacement parts and products, as well as technical
support, training, product installation, and plant commissioning.
Oil & Gas
In the oil & gas market, we target OFSs, IOCs, NOCs, E&Ps, OEMs or EPCs on behalf of oil producers and chemical
producers who have applications for our solutions and services. We endeavor to limit capital sales into the oil & gas market,
thereby minimizing installation and distribution costs, as well as associated sales and marketing expenses. As a result, our
primary go-to-market strategy in the oil & gas market is through technology licensing.
We have two agreements in place for the use of our VorTeq technology. In 2014, we entered into a strategic partnership
with Liberty Oil Field Services (“Liberty”) to pilot and conduct field trials with the VorTeq and in 2015, we entered into a
15-year license agreement with our VorTeq Licensee for the exclusive, worldwide right to use the VorTeq for hydraulic
fracturing onshore operations. The license agreement provides a carveout for Liberty’s contractual rights to utilize the VorTeq
based on a 2014 early-stage strategic partnership agreement.
We are currently evaluating potential long-term licensing partners for our MTeq technology, with the goal to license
the technology in the future.
In April 2017, we entered into a 10-year licensing agreement with Alderley FZE for our IsoBoost and IsoGen
technologies in gas processing and pipeline applications within the countries of the GCC, as well as Iraq and Iran to the extent
international sanctions and laws permit.
A significant portion of our revenue is from outside of the U.S. Additional segment and geographical information
regarding our product revenue is included in Note 13, “Geographical Information and Concentrations” of the Notes to
Consolidated Financial Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report
on Form 10-K.
Operations
Water
Our water products are manufactured at our facility located in San Leandro, California, where our PXs, turbochargers
and pumps are produced, assembled, and tested. We produce the majority of our ceramic components for our PX solutions
in our advanced ceramics manufacturing facility, where we also complete machining, assembly and performance-testing of
our PX devices. In addition, many components of our ERDs and pumps are also manufactured in San Leandro to protect the
proprietary nature of our manufacturing methods and product designs and to maintain premium quality standards.
We obtain raw, processed and certain pre-machined materials from various suppliers to support our manufacturing
operations. A limited number of these suppliers are near sole-source to maintain material consistency and support new product
development. A qualified redundant material source exists in all cases.
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Our production facility operates under the principles of Lean Manufacturing and continuously seeks ways to improve
product and process performance. Our quality management system is certified to the ISO9001 standards.
Water field activities are conducted by our aftermarket and field service organization onsite at customer locations.
Oil & Gas
Our oil & gas product manufacturing, assembly, and testing is managed through our operations in Ireland. To produce
our oil & gas products, we utilize multiple supply chain partners, in addition to our San Leandro manufacturing facility. We
complete critical machining, assembly, and testing operations in-house to protect the proprietary nature of our manufacturing
methods and product designs and to maintain premium quality standards. Our Ireland operations are also responsible for
overseeing the commercialization of the VorTeq and expanding our manufacturing activities.
Oil & gas field activities are conducted by our field operations organization, which also provides support to R&D
activities leading to VorTeq and MTeq commercialization.
Research and Development
We maintain a robust, multi-year product development road map which guides our R&D resource allocation. Specific
to new product development, our focus is overwhelmingly on our proprietary PX technology given its prohibitive nature,
broad technical aperture, and use across a broad array of markets and applications. Our corporate objective is to achieve proof
of concept of one new derivative of the pressure exchanger annually, on a 24 month cycle. Our immediate R&D efforts are
principally focused on developing new technologies for use within the oil & gas markets.
When developing products and ultimately markets for our products, we seek four distinct process criteria: (1) high
rates of fluid flow; (2) large pressure differentials; (3) hostile fluids; and (4) high degrees of capital intensity, specifically in
the form of pumping assets. Based on these criteria, our product development strategy is to identify fluid flow applications
where pumps are being destroyed and/or where pressure energy is being wasted. Our technologies isolate pumping assets
from hostile process fluids, or recover otherwise wasted pressure energy. Our R&D efforts are therefore focused on: (1)
advancing new products in markets beyond desalination, with a specific and immediate emphasis on oil & gas, where our
technology is utilized to preserve pumping assets; and (2) enhancing our existing energy recovery devices and pumps for the
water desalination market.
To support our product strategy, we invest in engineering talent with expertise in fluid physics and advanced material
science. In addition, to enable increasingly complex and shorter-cycle product development, we invest in advanced numerical
modeling and analysis infrastructure allowing for 3D, multi-phase, multi-physics, and computational fluid dynamics. These
models coupled with our existing structural interaction analytical capabilities supports our objective of achieving the proof
of concept of one new derivative of the pressure exchanger each year.
Our product development process evaluates potential technology applications across a set of criteria to determine the
allocation of finite internal resources and prioritize target applications. Once a target application is identified and we
determine conceptually how our technology can solve a problem, our product development steps start with evaluating the
concept through analytical methods. This is followed by validating the analysis experimentally at sub-scale, then full-scale
and finally as a system. Each of these stages follow a rigorous review process (business as well as technical) in order to steer
the development towards a successful new technology.
Within our Water segment, R&D investments have produced the latest and most efficient energy recovery device, the
PX Prime. In addition, we continue to advance our turbocharger and pump technologies to better service our water end
markets.
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Within our Oil & Gas segment, R&D investments are primarily focused on commercializing the VorTeq and MTeq,
as well as developing new products for applications where pumping assets are compromised due to hostile process fluids.
Our foremost priority remains the commercialization of VorTeq.
Seasonality
In our Water segment, we often experience substantial fluctuations in product revenue from quarter-to-quarter and
from year-to-year because a single order for our ERDs by a large EPC firm for a particular plant may represent significant
revenue. In addition, historically our EPC customers tend to order a significant amount of equipment for delivery in the fourth
quarter, and as a consequence, a significant portion of our annual sales typically occur during the fourth quarter.
In our Oil & Gas segment, we do not currently have enough history to determine seasonal revenue patterns.
Intellectual Property
We seek patent protection for new technologies, inventions, and improvements that are likely to be incorporated into
our solutions. We rely on patents, trade secret laws, and contractual safeguards to protect the proprietary tooling, processing
techniques, and other know-how used in the production of our solutions. We have a robust intellectual property portfolio
consisting of U.S. and International issued patents as well as pending patent applications.
We have registered the following trademarks with the United States Patent and Trademark office: “ERI,” “PX,” “PX
Pressure Exchanger,” “Pressure Exchanger,” the Energy Recovery logo, “Making Desalination Affordable,” “IsoBoost,” and
“IsoGen.” Applications are pending for “VorTeq” and “MTeq.” We have also applied for and received registrations in
international trademark offices.
Employees
As of December 31, 2017, we had 133 employees: 47 in manufacturing; 25 in engineering, research and development;
34 in corporate services and management; and 27 in sales, service, and marketing. Fourteen of these employees were located
outside of the United States. We also engage a relatively small number of independent contractors, primarily as sales agents
worldwide. We have not experienced any work stoppages, and our employees are not unionized.
Additional Information
The Energy Recovery website is www.energyrecovery.com. We use the Investor Relations section of our website as a
routine channel for distribution of important information, including news releases, presentations, and financial statements.
We intend to use the Investor Relations section of our website as a means of complying with our disclosure obligations under
Regulation FD. Accordingly, investors should monitor our Investor Relations website in addition to press releases, Securities
and Exchange Commission (“SEC”) filings, and public conference calls and webcasts. Our Annual Report on Form 10-K,
quarterly reports on Form 10-Q, current reports on Form 8-K, all amendments to those reports, and the Proxy Statement for
our Annual Meeting of Stockholders are made available, free of charge, in the Investor Relations section of our website, as
soon as reasonably practicable after the reports have been filed with or furnished to the SEC. The information contained on
our website or any other website is not part of this report nor is it considered to be incorporated by reference herein or with
any other filing we make with the SEC. Our headquarters and primary manufacturing center is located at 1717 Doolittle
Drive, San Leandro, California 94577, and our main telephone number is (510) 483-7370.
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Item 1A — Risk Factors
The following discussion sets forth what management currently believes could be the most significant risks and
uncertainties that could impact our businesses, results of operations, and financial condition. Other risks and uncertainties,
including those not currently known to the Company or its management, could also negatively impact our businesses, results
of operations, and financial conditions. Accordingly, the following should not be considered a complete discussion of all of
the risks and uncertainties the Company may face. We may amend or supplement these risk factors from time to time in other
reports we file with the SEC.
Risk Related to our Water Segment
• Our Water Segment depends on the construction of new desalination plants for revenue, and as a result, our
operating results have experienced, and may continue to experience, significant variability due to volatility in
capital spending, availability of project financing, and other factors affecting the water desalination industry.
We currently derive the majority of our revenue from sales of products and services used in desalination plants for
municipalities, hotels, mobile containerized desalination solutions, resorts, and agricultural operations in dry or drought-
ridden regions of the world. The demand for our Water segment products may decrease if the construction of desalination
plants declines for political, economic, or other factors, especially in these dry or drought-ridden regions. Other factors that
could affect the number and capacity of desalination plants built or the timing of their completion include the availability of
required engineering and design resources; a weak global economy; shortage in the supply of credit and other forms of
financing; changes in government regulation, permitting requirements, or priorities; and reduced capital spending for
desalination. Each of these factors could result in reduced or uneven demand for our Water segment products. Pronounced
variability or delays in the construction of desalination plants or reductions in spending for desalination, could negatively
impact our Water segment sales and revenue, which in turn could have an adverse effect on our entire business, financial
condition, or results of operations and make it difficult for us to accurately forecast our future sales and revenue.
• Our Water segment faces competition from a number of companies that offer competing energy recovery and pump
solutions. If any one of these companies produces superior technology or offers more cost-effective products, our
competitive position in the market could be harmed and our profits may decline.
The market for ERD and pumps for desalination plants is competitive and evolving. We expect competition, especially
competition on price, to persist and intensify as the desalination market grows and new competitors enter the market. Some
of our current and potential competitors may have significantly greater financial, technical, marketing, and other resources;
longer operating histories; or greater name recognition. They may also have more extensive products and product lines that
would enable them to offer multi-product or packaged solutions as well as competing products at lower prices or with other
more favorable terms and conditions. As a result, our ability to sustain our market share may be adversely impacted, which
would affect our business, operating results, and financial condition. In addition, if one of our competitors were to merge or
partner with another company, the change in the competitive landscape could adversely affect our continuing ability to
compete effectively.
•
If we are unable to collect unbilled receivables, which are caused in part by holdback provisions, our operating
results could be adversely affected.
Our contracts with large engineering, procurement, and construction firms generally contain holdback provisions that
typically delay final installment payments for our products by up to 24 months, after the product has been shipped and revenue
has been recognized. Generally 10% or less of the revenue we recognize pursuant to our customer contracts is subject to such
holdback provisions and is accounted for as unbilled receivables. Such holdbacks may result in relatively high unbilled
receivables. If we are unable to collect these performance holdbacks, our results of operations would be adversely affected.
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• We depend on a limited number of suppliers for some of our components. If our suppliers are not able to meet our
demand and/or requirements, our business could be harmed.
We rely on a limited number of suppliers for vessel housings, stainless steel ports, alumina powder, and tungsten
carbide for our portfolio of PX ERDs and stainless steel castings and components for our turbochargers and pumps. Our
reliance on a limited number of manufacturers for these supplies involves a number of risks, including reduced control over
delivery schedules, quality assurance, manufacturing yields, production costs, and lack of guaranteed production capacity or
product supply. We do not have long-term supply agreements with these suppliers but secure these supplies on a purchase
order basis. Our suppliers have no obligation to supply products to us for any specific period, in any specific quantity, or at
any specific price, except as set forth in a particular purchase order. Our requirements may represent a small portion of the
total production capacities of these suppliers, and our suppliers may reallocate capacity to other customers, even during
periods of high demand for our products. We have in the past experienced, and may in the future experience, product quality
issues and delivery delays with our suppliers due to factors such as high industry demand or the inability of our vendors to
consistently meet our quality or delivery requirements. If our suppliers were to cancel or materially change their commitments
to us or fail to meet quality or delivery requirements needed to satisfy customer orders for our products, we could lose time-
sensitive customer orders, be unable to develop or sell our products cost-effectively or on a timely basis, if at all, and have
significantly decreased revenue, which could harm our business, operating results, and financial condition. We may qualify
additional suppliers in the future, which would require time and resources. If we do not qualify additional suppliers, we may
be exposed to increased risk of capacity shortages due to our dependence on current suppliers.
Risk Related to our Oil & Gas Segment
• We may not be able to successfully commercialize the VorTeq.
In October 2015, we entered into the VorTeq License Agreement with the VorTeq Licensee which provides the VorTeq
Licensee with exclusive worldwide rights to our VorTeq technology for hydraulic fracturing onshore applications. Once the
VorTeq is commercialized, the VorTeq Licensee will begin paying ongoing recurring royalty fees to us for the VorTeq
technology. In order to commercialize the VorTeq, the VorTeq License Agreement provides, among other things, that we
successfully meet certain specified milestones against key performance indicators set forth in the license agreement. The
VorTeq is a relatively new technology and the hydraulic fracturing process is extremely complex which presents a wide range
of technological challenges for us. If we are unable to successfully solve these challenges and, as a result, fail to meet the
milestones, we may not be able to successfully commercialize the VorTeq. In that circumstance, we will not receive any
royalty payments from the VorTeq Licensee, which could have an adverse effect on our entire business, financial condition,
or results of operation.
•
If the VorTeq Licensee fails to adopt the VorTeq, for any reason, we may not receive royalty payments or be able to
successfully commercialize the VorTeq.
The successful commercialization of the VorTeq depends heavily on the VorTeq Licensee’s support and ultimate
adoption of the technology. If the VorTeq Licensee fails to adopt the VorTeq, for any reason, we may not be able to
successfully commercialize the VorTeq with the VorTeq Licensee and consequently, we may not receive any royalties under
the VorTeq License Agreement. In addition, we may not be able to find a suitable replacement for the VorTeq Licensee or
be able to negotiate royalties similar to those contained in the VorTeq License Agreement or to commercialize the VorTeq at
all. Failure to commercialize the VorTeq could have an adverse effect on our entire business, financial condition, or results
of operation.
• We may not meet the key performance indicators necessary to meet the two milestones in the VorTeq License
Agreement.
The VorTeq License Agreement calls for certain milestone key performance indicators that if met will result in
payments to the Company of $25 million for each of two milestones. Achievement of these milestones is uncertain, and while
we believe we can meet the milestones, if we are unable to do so, the milestone payments will be delayed until such time as
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the milestones are met or not earned and received at all. Failure to meet said milestones may also jeopardize
commercialization and the rate of adoption of our VorTeq.
• We may not be able to successfully complete early stage testing of the MTeq, enter into a long term licensing
agreement for the MTeq or fail to commercialize the MTeq.
We introduced the MTeq in 2017 and entered into a strategic early stage testing agreement in the second quarter of
2017. Like the VorTeq, we intend to find a long-term licensing partner for the MTeq and to ultimately commercialize the
MTeq. The early stage testing agreement with Sidewinder Drilling is intended to validate the MTeq system through yard
testing. However, the MTeq is a relatively new technology and those tests may prove unsuccessful. Even if early stage testing
proves to be successful, we may not be able to identify a licensing partner for the technology to assist us in bringing the MTeq
solution to the market. If we were able to enter into such a licensing agreement, we may still fail to produce a viable
commercialized solution given the complex and extreme conditions found in mud pumping, which present a wide range of
technological challenges for us. If we are unable to successfully complete early stage testing, or fail to locate and successfully
negotiate a licensing or similar agreement with a long term partner, or fail to solve any of the technological challenges, we
may not be able to successfully commercialize the MTeq, which could have an adverse effect on our entire business, financial
condition, or results of operation.
• Our Oil & Gas segment may be impacted by prolonged deflation in global oil prices which may cause delays or
cancellations of projects by Oil & Gas segment customers, negatively affecting the rate of our market penetration
and consequently our revenue and profitability.
A deflationary oil environment such as the one experienced over the last few years may delay and even stall adoption
and deployment of our products within our Oil & Gas segment including but not limited to the VorTeq as licensed for onshore
applications by the VorTeq Licensee. Emerging market economies, those dependent on commodity exports, and especially
those for whom oil exports make up a significant percent of total exports, may be unable to retrofit or expand their oil
exploration, production, and gas processing infrastructure thus negatively impacting our addressable market and future
revenue. Additionally, oil price deflation may continue to lead to widespread liquidity and insolvency issues for exploration,
production, and processing customers, which may negatively affect our addressable markets and therefore our financial
performance.
• Within our Oil & Gas segment, the use of the percentage-of-completion method of accounting for the IsoBoost and
IsoGen products requires us to make estimates and judgments, which are subject to an inherent degree of
uncertainty and which may differ from actual results.
The IsoBoost and IsoGen systems are highly engineered, customized solutions that are designed and manufactured
over an extended period of time and are built specifically to meet a customer’s specifications. It is the Company’s position
that the percentage-of-completion method of accounting is appropriate for the IsoBoost and IsoGen systems given the facts
and circumstances of these projects. This methodology requires the application of significant judgment by management in
selecting the appropriate assumptions for calculating revenue and costs. Revenue and profits are recognized over the life of
a project based on costs incurred to date compared to total estimated project costs. Revisions to revenues and profits are made
once amounts are known and can be reasonably estimated. In addition, percentage-of-completion revenue may vary from
quarter to quarter while a project is being completed due to accounting requirements. Given the uncertainties in accurately
estimating the costs of projects, as well as providing reliable estimates to completion, it is possible for actual amounts to vary
significantly from estimates previously made, which may result in the reversal of revenues and gross profit previously
recognized and publicly reported.
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Risk Related to our Entire Business
• Our diversification into new fluid flow markets, such as oil & gas, may not be successful
We have made a substantial investment in research, development, and sales to execute on our diversification strategy
into fluid flow markets such as oil & gas and chemical processing. While we see diversification as core to our growth strategy,
there is no guarantee that we will be successful in our efforts. Our model for growth is based on our ability to initiate and
embrace disruptive technology trends, to enter new markets, both in terms of geographies and product areas, and to drive
broad adoption of the products and services that we develop and market. Any inability to execute this model for growth could
damage our reputation, limit our growth, and negatively affect our operation results. For example, while we believe that our
products will enable gas processing plant operators to operate at a high level of energy efficiency with minimal downtime,
we may be subject to warranty claims if customers of these offerings experience significant downtimes or failures for which
our warranty reserves may be inadequate given the lack of historical failure rates associated with new product introductions.
We also could be subject to damage claims based on our products against which we may not be able to properly insure. In
addition, profitability, if any, in new industrial verticals may be lower than in our Water Segment, and we may not be
sufficiently successful in our diversification efforts to recoup investments.
• Our operating results may fluctuate significantly, making our future operating results difficult to predict and
causing our operating results to fall below expectations.
Our operating results may fluctuate due to a variety of factors, many of which are outside of our control.
We have experienced significant fluctuations in revenue from quarter-to-quarter and year-to-year, and we expect such
fluctuations to continue. In addition, in the past, customer buying patterns led to a significant portion of our sales occurring
in the fourth quarter. This presents the risk that delays, cancellations, or other adverse events in the fourth quarter could have
a substantial negative impact on annual results. As a result, comparing our operating results on a period-to-period basis may
not be meaningful. Since it is difficult for us to anticipate our future results, in the event our revenue or operating results fall
below the expectations of investors or securities analysts, our stock price may decline.
• Our sales cycles can be long and unpredictable, and our sales efforts require considerable time and expense. As a
result, our sales are difficult to predict and may vary substantially from quarter to quarter, which may cause our
operating results to fluctuate.
Our sales efforts involve substantial education of our current and prospective customers about the use and benefits of
our energy recovery products. This education process can be time-consuming and typically involves a significant product
evaluation process which is particularly pronounced when dealing with product introduction into new fluid flow industrial
verticals. In our Water segment, the sales cycle for our OEM customers, which are involved with smaller desalination plants,
averages one to 12 months. The Water segment sales cycle for our international engineering, procurement, and construction
firm customers, which are involved with larger desalination plants, ranges from 16 to 36 months. In our Oil & Gas segment,
experience indicates that sales efforts are prolonged due in part to customers’ reluctance to accept new technology,
procurement processes, plant turnaround dates, and budgetary constraints. The sales cycle for our Oil & Gas segment
customers ranges from 16 to 36 months. These long sales cycles make quarter-by-quarter revenue predictions difficult and
results in our expending significant resources well in advance of orders for our products.
• Our business entails significant costs that are fixed or difficult to reduce in the short term while demand for our
products is variable and subject to fluctuation, which may adversely affect our operating results.
Our business requires investments in facilities, equipment, research and development, and training that are either fixed
or difficult to reduce or scale in the short term. At the same time, the market for our products is variable and has experienced
downturns due to factors such as economic recessions, increased precipitation, uncertain global financial markets, and
political changes, many of which are outside of our control. During periods of reduced product demand, we may experience
higher relative costs and excess manufacturing capacity, resulting in high overhead and lower gross profit margins while
causing cash flow and profitability to decline. Similarly, although we believe that our existing manufacturing facilities are
- 17 -
capable of meeting current demand and demand for the foreseeable future, the continued success of our business depends on
our ability to expand our manufacturing, research and development, and testing facilities to meet market needs. If we are
unable to respond timely to an increase in demand, our revenue, gross profit margin, net income, and cash flow may be
adversely affected.
• Parts of our inventory may become excess or obsolete, which would increase our cost of revenues.
Inventory of raw materials, parts, components, work in-process, or finished products may accumulate, and we may
encounter losses due to a variety of factors, including technological change in the water desalination and oil & gas industries
that result in product changes; long delays in shipment of our products or order cancellations; our need to order raw materials
that have long lead times and our inability to estimate exact amounts and types of items needed, especially with regard to the
configuration of our high-efficiency pumps and IsoBoost and IsoGen systems; and cost reduction initiatives resulting in
component changes within the products.
In addition, we may from time to time purchase more inventory than is immediately required in order to shorten our
delivery time in case of an anticipated increase in demand for our products. If we are unable to forecast demand for our
products with a reasonable degree of certainty and our actual orders from our customers are lower than these forecasts, we
may accumulate excess inventory that we may be required to write off, and our business, financial condition, and results of
operations could be adversely affected.
• We may not generate positive returns on our research and development strategy.
Developing our products is expensive and the investment in product development may involve a long payback cycle.
For the years ended December 31, 2017, 2016 and 2015, our R&D expenses were $13.4 million, or approximately 21% of
our total revenue, $10.1 million, or approximately 19% of our total revenue, and $7.7 million, or approximately 17% of our
total revenue, respectively. We expect to continue to invest heavily in R&D in order to introduce new products and achieve
proof of concept of at least one new derivative of the pressure exchanger every year. We believe one of our greatest strengths
lies in our innovation and our product development efforts. By investing in R&D, we believe we are well positioned to
continue to execute on our product strategy, take into consideration our customers’ cost and efficiency sensitivities and take
advantage of other market opportunities. We expect that our results of operations may be impacted by the timing and size of
these investments. In addition, these investments may take several years to generate positive returns, if ever.
• We are subject to risks related to product defects, which could lead to warranty claims in excess of our warranty
provision or result in a significant or a large number of warranty or other claims in any given year.
We provide a warranty for certain products for a period of 18 to 30 months and provide up to a 5-year warranty for the
ceramic components of our PX-branded products. We test our products in our manufacturing facilities through a variety of
means; however, there can be no assurance that our testing will reveal latent defects in our products, which may not become
apparent until after the products have been sold into the market. The testing may not replicate the harsh, corrosive, and varied
conditions of the desalination and other plants in which they are installed. It is also possible that components purchased from
our suppliers could break down under those conditions. Certain components of our turbochargers and pumps are custom-
made and may not scale or perform as required in production environments. Accordingly, there is a risk that we may have
significant warranty claims or breach supply agreements due to product defects. We may incur additional cost of revenue if
our warranty provisions are not sufficient to cover the actual cost of resolving issues related to defects in our products. If
these additional expenses are significant, they could adversely affect our business, financial condition, and results of
operations.
• Business interruptions may damage our facilities or those of our suppliers.
Our operations and those of our suppliers may be vulnerable to interruption by fire, earthquake, flood, and other natural
disasters, as well as power loss, telecommunications failure, and other events beyond our control. Our facilities in California
are located near major earthquake faults and have experienced earthquakes in the past. If a natural disaster occurs, our ability
to conduct our operations could be seriously impaired, which could harm our business, financial condition, results of
- 18 -
operations, and cash flows. We cannot be sure that the insurance we maintain against general business interruptions will be
adequate to cover all of our losses.
•
If we are unable to protect our technology or enforce our intellectual property rights, our competitive position could
be harmed, and we could be required to incur significant expenses to enforce our rights.
Our competitive position depends on our ability to establish and maintain proprietary rights in our technology and to
protect our technology from copying by others. We rely on trade secret, patent, copyright, and trademark laws, as well as
confidentiality agreements with employees and third parties, all of which may offer only limited protection. We hold a number
of U.S. and counterpart international patents, and when their terms expire, we could become more vulnerable to increased
competition. The protection of our intellectual property in some countries may be limited. While we have expanded our
portfolio of patent applications, we do not know whether any of our pending patent applications will result in the issuance of
patents or whether the examination process will require us to narrow our claims, and even if patents are issued, they may be
contested, circumvented, or invalidated. Moreover, while we believe our issued patents and patent pending applications are
essential to the protection of our technology, the rights granted under any of our issued patents or patents that may be issued
in the future may not provide us with proprietary protection or competitive advantages, and as with any technology,
competitors may be able to develop similar or superior technologies now or in the future. In addition, our granted patents
may not prevent misappropriation of our technology, particularly in foreign countries where intellectual property laws may
not protect our proprietary rights as fully as those in the United States. This may render our patents impaired or useless and
ultimately expose us to currently unanticipated competition. Protecting against the unauthorized use of our products,
trademarks, and other proprietary rights is expensive, difficult, and in some cases, impossible. Litigation may be necessary
in the future to enforce or defend our intellectual property rights or to determine the validity and scope of the proprietary
rights of others. Intellectual property litigation could result in substantial costs and diversion of management resources, either
of which could harm our business.
• Claims by others that we infringe their proprietary rights could harm our business.
Third parties could claim that our technology infringes their intellectual property rights. In addition, we or our
customers may be contacted by third parties suggesting that we obtain a license to certain of their intellectual property rights
that they may believe we are infringing. We expect that infringement claims against us may increase as the number of products
and competitors in our market increases and overlaps occur. In addition, to the extent that we gain greater visibility, we
believe that we will face a higher risk of being the subject of intellectual property infringement claims. Any claim of
infringement by a third party, even those without merit, could cause us to incur substantial costs defending against the claim
and could distract management from our business. Furthermore, a party making such a claim, if successful, could secure a
judgment that requires us to pay substantial damages. A judgment against us could also include an injunction or other court
order that could prevent us from offering our products. In addition, we might be required to seek a license for the use of such
intellectual property, which may not be available on commercially reasonable terms, or at all. Alternatively, we may be
required to develop non-infringing technology, which could require significant effort and expense and may ultimately not be
successful. Any of these events could seriously harm our business. Third parties may also assert infringement claims against
our customers. Because we generally indemnify our customers if our products infringe the proprietary rights of third parties,
any such claims would require us to initiate or defend protracted and costly litigation on their behalf in one or more
jurisdictions, regardless of the merits of these claims. If any of these claims succeed, we may be forced to pay damages on
behalf of our customers.
• We are currently involved in legal proceedings, and may be subject to additional future legal proceedings, that may
result in material adverse outcomes.
In addition to intellectual property litigation risks discussed above, we are presently involved, and may become
involved in the future, in various commercial and other disputes as well as related claims and legal proceedings that arise
from time to time in the course of our business. See Note 16, “Litigation,” of the Notes to Consolidated Financial Statements
in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K for information
about certain legal proceedings in which we are involved. Our current legal proceedings and any future lawsuits to which we
- 19 -
may become a party are and will likely be expensive and time consuming to investigate, defend and resolve, and will divert
our management’s attention. Any litigation to which we are a party may result in an onerous or unfavorable judgment that
may not be reversed upon appeal or in payments of substantial monetary damages or fines, or we may decide to settle lawsuits
on similarly unfavorable terms, which could have an adverse effect on our business, financial condition, or results of
operations.
• Our global operations expose us to risks and challenges associated with conducting business internationally, and
our results of operations may be adversely affected by our efforts to comply with the laws of other countries, as well
as U.S. laws which apply to international operations, such as the Foreign Corrupt Practices Act (FCPA) and U.S.
export control laws.
We operate on a global basis with offices or activities in Europe, Africa, Asia, South America, and North America.
We face risks inherent in conducting business internationally, including compliance with international and U.S. laws and
regulations that apply to our international operations. These laws and regulations include tax laws, anti-competition
regulations, import and trade restrictions, export control laws, and laws which prohibit corrupt payments to governmental
officials or certain payments or remunerations to customers, including the U.S. Foreign Corrupt Practices Act (“FCPA”) or
other anti-corruption laws that have recently been the subject of a substantial increase in global enforcement. Many of our
products are subject to U.S. export law restrictions that limit the destinations and types of customers to which our products
may be sold, or require an export license in connection with sales outside the United States. Given the high level of complexity
of these laws, there is a risk that some provisions may be inadvertently or intentionally breached, for example through
fraudulent or negligent behavior of individual employees, our failure to comply with certain formal documentation
requirements, or otherwise. Also, we may be held liable for actions taken by our local dealers and partners. Violations of
these laws and regulations could result in fines, criminal sanctions against us, our officers or our employees, and prohibitions
or conditions on the conduct of our business. Any such violations could include prohibitions or conditions on our ability to
offer our products in one or more countries and could materially damage our reputation, our brand, our business, and our
operating results. In addition, we operate in many parts of the world that have experienced significant governmental
corruption to some degree and, in certain circumstances, strict compliance with anti-bribery laws may conflict with local
customs and practices. We may be subject to competitive disadvantages to the extent that our competitors are able to secure
business, licenses, or other preferential treatment by making payments to government officials and others in positions of
influence or through other methods that relevant law and regulations prohibit us from using. Our success depends, in part, on
our ability to anticipate these risks and manage these difficulties. These factors or any combination of these factors may
adversely affect our revenue or our overall financial performance.
• The U.S. Congress and Trump Administration may make substantial changes to fiscal, political, regulation and
other federal policies that may adversely affect our business, financial condition, operating results and cash flows.
Changes in general economic or political conditions in the United States or other regions could adversely affect our
business. For example, the administration under President Donald Trump has indicated that it may propose significant
changes with respect to a variety of issues, including international trade agreements, import and export regulations, tariffs
and customs duties, foreign relations, immigration laws, tax laws, corporate governance laws and corporate fuel economy
standards, that could have a positive or negative impact on our business. Proposals espoused by the Trump Administration
may result in changes to social, political, regulatory, and economic conditions in the United States or in laws and policies
affecting the development and investment in countries where we currently conduct business, sell our products, or procure our
raw materials. In addition, these changes could result in negative sentiments towards the United States among non-U.S.
customers. We cannot predict the impact, if any, of these changes to our business. However, it is possible that these changes
could adversely affect our business due to the substantial exposure we have to international markets which could have an
adverse effect on our business, financial condition, or results of operations.
- 20 -
• Regulations related to conflict minerals could adversely impact our business.
The Dodd-Frank Wall Street Reform and Consumer Protection Act contains provisions to improve transparency and
accountability concerning the supply of certain minerals, known as conflict minerals, originating from the Democratic
Republic of Congo (“DRC”) and adjoining countries. As a result, in August 2012, the SEC adopted annual disclosure and
reporting requirements for those companies who use conflict minerals mined from the DRC and adjoining countries in their
products. Based on our purchasing policy and supplier selection, it is considered unlikely that any conflict minerals are used
in the manufacturing of our products. Nevertheless, we are continuing reasonable country of origin inquiry and have
implemented a program of due diligence on the source and chain of custody for conflict minerals. There are costs associated
with complying with these disclosure requirements, including loss of customers and potential changes to products, processes,
or sources of supply as a consequence of our verification activities. The implementation of these rules could adversely affect
the sourcing, supply, and pricing of materials used in our products. As there may be only a limited number of suppliers
offering “conflict free” minerals, we cannot be sure that we will be able to obtain necessary materials from such suppliers in
sufficient quantities or at competitive prices. Also, we may face reputational challenges if we determine that certain of our
products contain minerals not determined to be conflict-free or if we are unable to sufficiently verify the origins for all conflict
minerals used in our products through the procedures we have implemented.
• We may have risks associated with security of our information technology systems.
We make significant efforts to maintain the security and integrity of our information technology systems and data.
Despite significant efforts to create security barriers to such systems, it is virtually impossible for us to entirely mitigate this
risk. There is a risk of industrial espionage, cyber-attacks, misuse or theft of information or assets, or damage to assets by
people who may gain unauthorized access to our facilities, systems, or information. Such cybersecurity breaches, misuse, or
other disruptions could lead to the disclosure of confidential information, improper usage and distribution of our intellectual
property, theft, manipulation and destruction of private and proprietary data, and production downtimes. Although we actively
employ measures to prevent unauthorized access to our information systems, preventing unauthorized use or infringement of
our rights is inherently difficult. These events could adversely affect our financial results and any legal action in connection
with any such cybersecurity breach could be costly and time-consuming and may divert management’s attention and
adversely affect the market’s perception of us and our products.
• We may have risks associated with our international tax optimization structure
In 2015, we implemented an international tax optimization structure. Subsidiaries were established in Ireland and we
transferred our Oil & Gas segment intellectual property via platform licenses to ERI Energy Recovery Holdings Ireland
Limited. We have undertaken extensive due diligence, implemented and continue to implement manufacturing, R&D, and
sales operations to create Irish substance, and have conferred with tax experts to ensure that uncertain tax positions are
unlikely. It is possible that the international tax structure could be examined by the Internal Revenue Service in the U.S.
and/or the Tax Authorities in Ireland, and it is possible that such an examination could result in an unfavorable impact on us.
• The enactment of legislation implementing changes in taxation of international business activities, the adoption of
other corporate tax reform policies, or changes in tax legislation or policies could materially impact our financial
position and results of operations.
Corporate tax reform, base-erosion efforts and tax transparency continue to be high priorities in many tax jurisdictions
where we have business operations. As a result, policies regarding corporate income and other taxes in numerous jurisdictions
are under heightened scrutiny and tax reform legislation is being proposed or enacted in a number of jurisdictions. For
example, on December 22, 2017, President Trump signed into law “H.R.1”, known as the “Tax Cuts and Jobs Act”, (the “Tax
Act”), which significantly changes existing U.S. tax laws.
In addition, many countries are beginning to implement legislation and other guidance to align their international tax
rules with the Organisation for Economic Co-operation’s Base Erosion and Profit Shifting recommendations and action plan
that aim to standardize and modernize global corporate tax policy, including changes to cross-border tax, transfer-pricing
documentation rules, and nexus-based tax incentive practices. As a result of the heightened scrutiny of corporate taxation
- 21 -
policies, prior decisions by tax authorities regarding treatments and positions of corporate income taxes could be subject to
enforcement activities, and legislative investigation and inquiry, which could also result in changes in tax policies or prior
tax rulings. Any such changes in policies or rulings may also result in the taxes we previously paid being subject to change.
Due to the scale of our international business activities any substantial changes in international corporate tax policies,
enforcement activities or legislative initiatives may materially and adversely affect our business, the amount of taxes we are
required to pay and our financial condition and results of operations generally.
•
If we need additional capital to fund future growth, it may not be available on favorable terms, or at all.
Our primary source of cash historically has been customer payments for our products and services and proceeds from
the issuance of common stock. This has funded our operations and capital expenditures. We may require additional capital
from equity or debt financing in the future to fund our operations or respond to competitive pressures or strategic
opportunities, such as a potential acquisition or the expansion of operations. We may not be able to secure such additional
financing on favorable terms or at all. The terms of additional financing may place limits on our financial and operational
flexibility. If we raise additional funds through further issuances of equity, convertible debt securities, or other securities
convertible into equity, our existing stockholders could suffer significant dilution in their percentage ownership of our
company, and any new securities that we issue could have rights, preferences, or privileges senior to those of existing or
future holders of our common stock. If we are unable to obtain necessary financing on terms satisfactory to us, if and when
we require it, our ability to grow or support our business and to respond to business challenges or opportunities could be
significantly limited.
• We may seek to expand through acquisitions of and investments in other businesses, technologies, and assets. These
acquisition activities may be unsuccessful or divert management’s attention.
We may consider strategic and complementary acquisitions of and investments in other businesses, technologies, and
assets, and such acquisitions or investments are subject to risks that could affect our business, including risks related to:
•
•
•
•
•
•
•
•
•
•
•
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•
•
the necessity of coordinating geographically disparate organizations;
implementing common systems and controls;
integrating personnel with diverse business and cultural backgrounds;
integrating acquired research and manufacturing facilities, technology and products;
combining different corporate cultures and legal systems;
unanticipated expenses related to integration, including technical and operational integration;
increased costs and unanticipated liabilities, including with respect to registration, environmental, health and
safety matters, that may affect sales and operating results;
retaining key employees;
obtaining required government and third-party approvals;
legal limitations in new jurisdictions;
installing effective internal controls and audit procedures;
issuing common stock that could dilute the interests of our existing stockholders;
spending cash and incurring debt;
assuming contingent liabilities; and
creating additional expenses.
We may not be able to identify opportunities or complete transactions on commercially reasonable terms, or at all, or
actually realize any anticipated benefits from such acquisitions or investments. Similarly, we may not be able to obtain
financing for acquisitions or investments on attractive terms. If we do complete acquisitions, we cannot ensure that they will
ultimately strengthen our competitive or financial position or that they will not be viewed negatively by customers, financial
markets, investors, or the media. In addition, the success of any acquisitions or investments also will depend, in part, on our
ability to integrate the acquisition or investment with our existing operations.
- 22 -
• Our actual operating results may differ significantly from our guidance.
We release guidance in our quarterly earnings conference calls, quarterly earnings releases, or otherwise, regarding
our future performance that represents our management’s estimates as of the date of release. This guidance which, includes
forward-looking statements, will be based on projections prepared by our management. These projections will not be prepared
with a view toward compliance with published guidelines of the American Institute of Certified Public Accountants, and
neither our registered public accountants nor any other independent expert or outside party compiles or examines the
projections. Accordingly, no such person will express any opinion or any other form of assurance with respect to the
projections.
Projections are based upon a number of assumptions and estimates that, while presented with numerical specificity,
are inherently subject to significant business, economic and competitive uncertainties and contingencies, many of which are
beyond our control and are based upon specific assumptions with respect to future business decisions, some of which will
change. We will continue to state possible outcomes as high and low ranges which are intended to provide a sensitivity
analysis as variables are changed but are not intended to imply that actual results could not fall outside of the suggested
ranges. The principal reason that we release guidance is to provide a basis for our management to discuss our business outlook
with analysts and investors. We do not accept any responsibility for any projections or reports published by any such third
parties.
Guidance is necessarily speculative in nature, and it can be expected that some or all of the assumptions underlying
the guidance furnished by us will not materialize or will vary significantly from actual results. Accordingly, our guidance is
only an estimate of what management believes is realizable as of the date of release. Actual results may vary from our
guidance and the variations may be material. In light of the foregoing, investors are urged not to rely upon our guidance in
making an investment decision regarding our common stock.
Any failure to successfully implement our operating strategy or the occurrence of any of the events or circumstances
set forth in this “Risk Factors” section in this Annual Report on Form 10-K could result in the actual operating results being
different from our guidance and the differences may be adverse and material.
•
Insiders and principal stockholders will likely have significant influence over matters requiring stockholder
approval.
Our directors, executive officers, and other principal stockholders beneficially own, in the aggregate, a substantial
amount of our outstanding common stock. These stockholders could likely have significant influence over all matters
requiring stockholder approval, including the election of directors and approval of significant corporate transactions such as
a merger or other sale of our company or its assets.
• The market price of our common stock may continue to be volatile.
The market price of our common stock has been, and is likely to continue to be, volatile and subject to fluctuations.
Changes in the stock market generally or as it concerns our industry, as well as geopolitical, economic, and business factors
unrelated to us, may also affect our stock price. Significant declines in the market price of our common stock or failure of the
market price to increase could harm our ability to recruit and retain key employees, reduce our access to debt or equity capital,
and otherwise harm our business or financial condition. In addition, we may not be able to use our common stock effectively
as consideration in connection with any future acquisitions.
- 23 -
• Anti-takeover provisions in our charter documents and under Delaware law could discourage, delay, or prevent a
change in control of our company and may affect the trading price of our common stock.
Provisions in our amended and restated certificate of incorporation and bylaws may have the effect of delaying or
preventing a change of control or changes in our management. Our amended and restated certificate of incorporation and
amended and restated bylaws include provisions that:
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authorize our Board of Directors to issue, without further action by the stockholders, up to 10,000,000 shares
of undesignated preferred stock;
require that any action to be taken by our stockholders be effected at a duly called annual or special meeting
and not by written consent;
specify that special meetings of our stockholders can be called only by our Board of Directors, the chairman
of the board, the chief executive officer, or the president;
establish an advance notice procedure for stockholder approvals to be brought before an annual meeting of our
stockholders, including proposed nominations of persons for election to our Board of Directors;
establish that our Board of Directors is divided into three classes, Class I, Class II, and Class III, with each
class serving staggered terms;
provide that our directors may be removed only for cause;
provide that vacancies on our Board of Directors may be filled only by a majority vote of directors then in
office, even though less than a quorum;
specify that no stockholder is permitted to cumulate votes at any election of directors; and
require a super-majority of votes to amend certain of the above mentioned provisions.
In addition, we are subject to the provisions of Section 203 of the Delaware General Corporation Law regulating
corporate takeovers. Section 203 generally prohibits us from engaging in a business combination with an interested
stockholder subject to certain exceptions.
Item 1B — Unresolved Staff Comments
None
Item 2 — Properties
We lease approximately 170,000 square feet of space in San Leandro, California for product manufacturing, research
and development, and executive headquarters under a lease that expires in November of 2019. We believe that this facility
will be adequate for our purposes for the foreseeable future. Additionally, we lease offices near Dublin, Ireland; Dubai, United
Arab Emirates; Shanghai, Peoples Republic of China; and Houston, Texas.
Item 3 — Legal Proceedings
See Note 16, “Litigation,” of the Notes to Consolidated Financial Statements in Part II, Item 8, “Financial Statements
and Supplementary Data,” of this Annual Report on Form 10-K, which is incorporated by reference into this Item 3, for a
description of the lawsuits pending against us.
Item 4 — Mine Safety Disclosures
Not applicable.
- 24 -
PART II
Item 5 — Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity
Securities
Market Information
Our common stock is quoted on the NASDAQ Stock Market under the symbol “ERII.” The following table sets forth
the high and low intra-day sales prices of our common stock for the periods indicated.
2017
2016
High
Low
High
Low
First Quarter ......................................................................... $
Second Quarter ..................................................................... $
Third Quarter ........................................................................ $
Fourth Quarter ...................................................................... $
11.46 $
8.77 $
8.43 $
11.30 $
7.11
7.11
6.13
7.48
$
$
$
$
10.82 $
13.35 $
16.67 $
16.30 $
5.28
7.77
8.35
8.53
Stockholders
As of December 31, 2017, there were approximately 31 stockholders of record of our common stock as reported by
our transfer agent, one of which is Cede & Co., a nominee for Depository Trust Company (“DTC”). All of the shares of
common stock held by brokerage firms, banks, and other financial institutions as nominees for beneficial owners are deposited
into participant accounts at DTC and are therefore considered to be held of record by Cede & Co. as one stockholder.
Dividend Policy
We have never declared or paid any dividends on our common stock, and we do not currently intend to pay any
dividends on our common stock for the foreseeable future. Any future determination to pay dividends on our common stock
will be, subject to applicable law, at the discretion of our Board of Directors, and will depend upon, among other factors, our
results of operations, financial condition, capital requirements, and contractual restrictions in loan or other agreements.
Stock Repurchase Program
In March 2017, our Board of Directors authorized a stock repurchase program under which the Company, at the
discretion of management, could repurchase up to $15.0 million in aggregate cost of our outstanding common stock through
September 30, 2017 (the “March 2017 Authorization”). At December 31, 2017, 541,177 shares, at an aggregate cost of
$4.3 million, had been repurchased under the March 2017 Authorization. The March 2017 Authorization expired in
September 2017 and there was no repurchase authorization in place at December 31, 2017.
In January 2016, our Board of Directors authorized a stock repurchase program under which the Company, at the
discretion of management, could repurchase up to $6.0 million in aggregate cost of our outstanding common stock through
June 30, 2016 (the “January 2016 Authorization”). In May 2016, our Board of Directors rescinded the January 2016
Authorization and authorized a new stock repurchase program under which the Company, at the discretion of management,
could repurchase up to $10.0 million in aggregate cost of our outstanding common stock through October 31, 2016 (the “May
2016 Authorization”). At December 31, 2016, 673,700 shares, at an aggregate cost of $4.1 million, had been repurchased
under the January 2016 Authorization and 568,500 shares, at an aggregate cost of $5.3 million, had been repurchased under
the May 2016 Authorization. The May 2016 Authorization expired in October 2016 and there was no repurchase authorization
in place at December 31, 2016.
On March 7, 2018, our Board of Directors authorized a stock repurchase program under which the Company, at the
discretion of management, may repurchase up to $10.0 million in aggregate cost of the our outstanding common stock. Under
the newly authorized repurchase program, purchases of shares of common stock may be made from time to time in the open
market, or in privately negotiated transactions, in compliance with applicable state and federal securities laws. The timing
and amounts of any purchases will be based on market conditions and other factors including price, regulatory requirements,
- 25 -
and capital availability. The share buyback program does not obligate us to acquire any specific number of shares in any
period, and may be expanded, extended, modified or discontinued at any time without prior notice.
Sales of Unregistered Securities
None
Stock Performance Graph
The following graph shows the cumulative total stockholder return of an investment of $100 on December 31, 2012
in (i) our common stock, (ii) the NASDAQ Composite Index, and (iii) common stock of a selected group of peer issuers
(“Peer Group”). Cumulative total return assumes the reinvestment of dividends, although dividends have never been declared
on our stock, and is based on the returns of the component companies weighted according to their capitalizations as of the
end of each quarterly period. The NASDAQ Composite Index tracks the aggregate price performance of equity securities
traded on the NASDAQ. The Peer Group tracks the weighted average price performance of equity securities of seven
companies in our industry: Consolidated Water Co. Ltd.; Flowserve Corp.; Hyflux Ltd., Kurita Water Industries Ltd.; Pentair
PLC; Tetra Tech, Inc.; and The Gorman-Rupp Company. The return of each component issuer of the Peer Group is weighted
according to the respective issuer’s stock market capitalization at the end of each period for which a return is indicated. Our
stock price performance shown in the graph below is not indicative of future stock price performance.
The following graph and its related information is not “soliciting material,” is not deemed “filed” with the Securities
and Exchange Commission, and is not to be incorporated by reference into any filing of the Company under the Securities
Act of 1933, as amended or the Securities Exchange Act of 1934, as amended, whether made before or after the date hereof
and irrespective of any general incorporation language contained in such filing.
COMPARISON OF FIVE-YEAR CUMULATIVE TOTAL RETURN *
Among Energy Recovery Inc., The NASDAQ Composite Index,
And A Peer Group
*
Graph represents the value of $100 invested on December 31, 2012 in stock or index, including reinvestment of dividends as of the year
ending December 31.
12/31/2012
12/31/2013
12/31/2014
12/31/2015
12/31/2016
12/31/2017
Energy Recovery, Inc. ........... $
100.00
$
163.24
$
155.00
$
207.94
$
304.41
$
NASDAQ Composite Index ..
Peer Group ............................
100.00
100.00
141.58
146.43
162.13
124.45
173.35
98.15
187.34
116.14
257.35
242.49
135.56
- 26 -
Item 6 — Selected Financial Data
The following selected financial data should be read in conjunction with Part II, Item 7, “Management’s Discussion
and Analysis of Financial Condition and Results of Operations,” and Part II, Item 8, “Financial Statements and Supplementary
Data,” included in this Annual Report on Form 10-K.
2017
Years Ended December 31,
2015
(In thousands, except per share amounts)
2014
2016
2013
Consolidated Statements of Operations Data:
Product revenue ............................................................ $
Product cost of revenue .................................................
Product gross profit ...................................................
58,156 $
19,061
39,095
49,715 $
17,849
31,866
43,671 $
19,111
24,560
30,426 $
13,713
16,713
43,045
17,323
25,722
License and development revenue ................................
5,000
5,000
1,042
—
—
Operating expenses:
General and administrative ........................................
Sales and marketing ..................................................
Research and development ........................................
Amortization of intangible assets ..............................
Restructuring charges ................................................
Total operating expenses .......................................
Income (loss) from operations .......................................
Other income (expense), net..........................................
Income (loss) before income taxes ................................
(Benefit from) provision for income taxes ....................
Net income (loss) .......................................................... $
Income (loss) per share:
17,354
9,391
13,443
631
—
40,819
3,276
680
3,956
(8,394)
12,350 $
16,626
9,116
10,136
631
—
36,509
357
287
644
(390)
1,034 $
19,773
9,326
7,659
635
—
37,393
(11,791)
(181)
(11,972)
(334)
(11,638) $
14,139
10,525
9,690
842
—
35,196
(18,483)
69
(18,414)
291
(18,705) $
15,192
7,952
4,361
921
184
28,610
(2,888)
109
(2,779)
327
(3,106)
Basic .......................................................................... $
Diluted ...................................................................... $
0.23 $
0.22 $
0.02 $
0.02 $
(0.22) $
(0.22) $
(0.36) $
(0.36) $
(0.06)
(0.06)
Number of shares used in per share calculation:
Basic ..........................................................................
Diluted ......................................................................
53,701
55,612
52,341
55,451
52,151
52,151
51,675
51,675
51,066
51,066
2017
2016
As of December 31,
2015
(In thousands)
2014
2013
Consolidated Balance Sheets Data:
Cash and cash equivalents ............................................. $
Short-term investments .................................................
Long-term investments..................................................
Total assets ....................................................................
Long-term liabilities ......................................................
Total liabilities ..............................................................
Total stockholders’ equity .............................................
27,780 $
70,020
—
161,744
59,380
79,213
82,531
61,364 $
39,073
—
149,063
66,772
83,930
65,133
99,931 $
257
—
151,799
72,116
88,140
63,659
15,501 $
13,072
267
85,941
4,501
16,023
69,918
14,371
5,856
13,694
101,935
4,338
15,020
86,915
- 27 -
Item 7 — Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following Management Discussion and Analysis of Financial Condition and Results of Operations is intended to
help the reader understand our results of operations and financial condition. It should be read in conjunction with the
Consolidated Financial Statements and related Notes included in Part II, Item 8, “Financial Statements and Supplementary
Data,” in this Annual Report on Form 10-K.
Overview
Energy Recovery, Inc. and its wholly-owned subsidiaries (the “Company,” “Energy Recovery,” “our,” “us,” and “we”)
is an energy solutions provider to industrial fluid flow markets worldwide. Our core competencies are fluid dynamics and
advanced material science. Our products make industrial processes more operating and capital expenditure efficient. Our
solutions convert wasted pressure energy into a reusable asset and preserve or eliminate pumping technology in hostile
processing environments. Our solutions are marketed and sold in fluid flow markets, such as water, oil & gas, and chemical
processing, under the trademarks ERI®, PX®, Pressure Exchanger®, PX Pressure Exchanger®, AT™, AquaBold™, VorTeq™,
IsoBoost®, and IsoGen®. Our solutions are owned, manufactured, and/or developed, in whole or in part, in the U.S. and Ireland.
Our reportable operating segments consist of the Water and the Oil & Gas segments. These segments are based on the
industries in which the technology solutions are sold, the type of energy recovery device or other technology sold, and the
related solution and service.
Water Segment
Our Water segment consists of revenues and expenses associated with solutions sold for use in seawater, brackish, and
wastewater reverse osmosis desalination. Our Water segment revenue is principally derived from the sale of energy recovery
devices (“ERDs”); however, we also derive revenue from the sale of our high-pressure and circulation pumps, which we
manufacture and sell in connection with our ERDs for use in desalination plants. Additionally, we receive revenue from the
sale of spare parts and services, including start-up and commissioning services that we provide for our customers.
Oil & Gas Segment
Our Oil & Gas segment consists of revenues and expenses associated with solutions sold or licensed for use in
hydraulic fracturing, gas processing, and chemical processing. In the past several years, we have invested significant research
and development costs to expand our business into pressurized fluid flow industries within the oil & gas industry.
Results of Operations
2017 Compared to 2016
Total Revenue
For the Year Ended December 31,
2017
2016
$
% of Total
Revenue
$
% of Total
Revenue
$ Change
% Change
(In thousands, except for percentages)
Product revenue .................... $
License and development
revenue ..............................
Total revenue .................... $
58,156
92 % $
49,715
91% $
8,441
5,000
63,156
8 %
100 % $
5,000
54,715
9%
100% $
—
8,441
17%
—%
15%
- 28 -
Product Revenue by Segment
For the Year Ended December 31,
2017
2016
$ Change
% Change
(In thousands, except for percentages)
Water .......................................................................................... $
Oil & Gas ...................................................................................
Total product revenue ............................................................. $
54,301 $
3,855
58,156 $
47,545 $
2,170
49,715 $
6,756
1,685
8,441
14%
78%
17%
Water segment product revenue increased in 2017, compared to 2016, due primarily to higher mega-project (“MPD”)
sales of $5.6 million and original equipment manufacturer (“OEM”) sales of $1.3 million, partially offset by lower aftermarket
sales of $0.1 million.
Oil & Gas segment product revenue, increased in 2017, compared to 2016, due primarily to the percentage-of-
completion revenue recognition associated with the sale of multiple IsoBoost systems, partially offset by revenue adjustments
of $0.3 million.
A limited number of our customers account for a substantial portion of our product revenue in the Water segment.
Revenue from customers representing 10% or more of product revenue varies from period to period. For the year ended
December 31, 2017, no customer represent 10% or more of the Company’s product revenue. For the years ended December
31, 2016 and 2015, one customer, the same customer in both years, represented 11% and 14% of the Company’s product
revenues, respectively. See Note 13, “Geographical Information and Concentrations,” of the Notes to Consolidated Financial
Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K for
further details on customer concentration.
Product revenue attributable to domestic and international sales as a percentage of total product revenue is presented
in the following table.
Domestic revenue ..................................................................................................................................
International revenue .............................................................................................................................
Total product revenue ........................................................................................................................
License and Development Revenue
For the Year Ended December 31,
2017
2016
3 %
97 %
100 %
2%
98%
100%
For the Year Ended December 31,
2017
2016
$ Change
% Change
(In thousands, except for percentages)
License and development revenue ..............................................
$
5,000 $
5,000 $
—
—%
In October 2015, through our subsidiary ERI Energy Recovery Ireland Ltd., we entered into a license agreement with
the VorTeq Licensee (“VorTeq License Agreement”), an international customer. The VorTeq License Agreement has a term
of 15-years for the exclusive, worldwide right to use our VorTeq technology for hydraulic fracturing onshore operations. The
VorTeq License Agreement includes $125.0 million in payments paid in stages: a $75.0 million upfront, exclusivity fee
payment and two separate $25.0 million payments upon successful achievement of two milestone tests. Following product
commercialization, the VorTeq License Agreement includes recurring royalty payments throughout the 15-year term. The
initial upfront fee of $75.0 million is recognized on a straight-line basis over the 15-year term of the arrangement based on
the performance period of the last or final deliverables, which include the license and support. There has been no change in
the rate of revenue recognition of the VorTeq License Agreement in 2017, as compared to 2016.
- 29 -
Product Gross Profit and Margin
Year Ended December 31, 2017
Year Ended December 31, 2016
Water
Oil & Gas
Total
Water
Oil & Gas
Total
(In thousands, except for percentages)
Product gross profit ............ $
Product gross margin ..........
38,269
$
70.5%
$
826
21.4 %
39,095
$
67.2%
31,192
$
65.6%
$
674
31.1%
31,866
64.1%
Product gross profit represents our product revenue less our product cost of revenue. Our product cost of revenue
consists primarily of raw materials, personnel costs (including stock-based compensation), manufacturing overhead, warranty
costs, depreciation expense, and manufactured components.
Product gross profit increased in 2017 compared to 2016, due primarily to increased Water segment sales volume and
favorable price and mix and increased Oil & Gas segment sales volume.
Product gross margin increased in 2017 compared to 2016, due primarily to increased Water segment favorable price
and mix, and operational efficiencies, partially offset by higher Oil & Gas segment project costs and revenue adjustments of
$0.3 million.
Operating Expenses
For the Year Ended December 31,
2017
2016
$
% of Total
Revenue
$
% of Total
Revenue
$ Change
% Change
(In thousands, except for percentages)
Total revenue ................................... $
63,156
100% $
54,715
100% $
8,441
15%
Operating expenses:
General and administrative ........... $
Sales and marketing .....................
Research and development ...........
Amortization of intangible assets .
Total operating expenses ........... $
17,354
9,391
13,443
631
40,819
27% $
15%
21%
1%
65% $
16,626
9,116
10,136
631
36,509
30% $
17%
19%
1%
67% $
728
275
3,307
—
4,310
4%
3%
33%
—%
12%
General and Administrative
General and administrative expense increased in 2017, compared to 2016, due primarily to higher employee-related
compensation and benefits of $0.5 million, facility costs of $0.4 million and other costs of $0.3 million, partially offset by
lower professional and legal costs of $0.5 million. Employee-related compensation and benefits included an increase in
compensation of $0.3 million and stock-based compensation of $0.2 million.
Sales and Marketing
Sales and marketing expense increased in 2017, compared to 2016, due primarily to higher employee-related
compensation and benefits of $0.4 million and higher professional services of $0.1 million, partially offset by lower marketing
and other costs of $0.2 million. Employee-related compensation and benefits included an increase in commissions of
$0.3 million and stock-based compensation of $0.3 million, partially offset by lower compensation and incentive
compensation of $0.2 million.
- 30 -
Research and Development
Research and development expense increased in 2017, compared to 2016, due primarily to higher employee-related
compensation and benefits of $1.6 million, direct research and development project costs of $1.5 million and other costs of
$0.2 million. Employee-related compensation and benefits included an increase in compensation of $1.4 million and stock-
based compensation of $0.3 million, partially offset by lower incentive compensation of $0.1 million.
Amortization of Intangible Assets
Amortization of intangible assets is related to finite-lived intangible assets acquired as a result of our purchase of Pump
Engineering, LLC in December 2009. There was no material change in our amortization amounts in 2017, compared to 2016.
Other Income (Expense), net
For the Year Ended December 31,
2017
2016
$
% of Total
Revenue
$
% of Total
Revenue
$ Change
% Change
(In thousands, except for percentages)
Total revenue ..................... $
63,156
100%
$
54,715
100%
$
8,441
15%
Other income (expense):
Interest income ............... $
Interest expense ..............
Other non-operating
expense, net ..................
Total other income
(expense), net .............. $
870
(2)
(188)
1%
$
—%
—%
309
(3)
(19)
1%
$
—%
—%
561
1
182%
(33%)
(169 )
889%
680
1%
$
287
1%
$
393
137%
Total other income (expense), net increased in 2017, compared to 2016, due primarily to interest income on higher
investment balances and by a favorable disposition of foreign currency in the prior year, partially offset by higher bank fees
related to our higher investment balance in 2017 and unfavorable foreign currency exchange, both reported in Other non-
operating income (expense).
Income Taxes
Our income tax benefit was $8.4 million for the year ended December 31, 2017 compared to a tax benefit of
$0.4 million for the year ended December 31, 2016.
The tax benefit of $8.4 million for the year ended December 31, 2017, consisted of a net $10.1 million U.S. federal
and state deferred tax benefit after taking into consideration a valuation allowance release on all but $1.4 million of our U.S.
federal and state deferred tax assets, less a valuation allowance for the Irish deferred tax assets of $1.3 million less U.S.
federal, state and foreign current tax expense of $0.4 million. See Note 9, “Income Taxes,” of the Notes to Consolidated
Financial Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-
K for a discussion of our valuation allowances.
The tax benefit of $0.4 million for the year ended December 31, 2016, consisted of $7.0 million benefit related to
losses in our Ireland subsidiary which was partially offset by tax expense of $0.3 million related to the deferred tax effects
associated with the amortization of goodwill and other taxes.
U.S. Tax Cuts and Jobs Act
On December 22, 2017, President Trump signed into law the U.S. Tax Cuts and Jobs Act (the “Tax Act”), which
significantly changes existing U.S. tax laws that will affect 2017, including, but not limited to, (1) requiring companies to
pay a one-time deemed repatriation tax on certain unrepatriated earnings of foreign subsidiaries; (2) remeasurement of
- 31 -
deferred tax assets and liabilities at the new 21% tax rate; and (3) bonus depreciation that will allow for full expensing of
qualified property.
The Tax Act also establishes new tax laws that will affect 2018, including, but not limited to, (1) a reduction in the
corporate tax rate from 35% to 21%; (2) eliminating the corporate alternative minimum tax (“AMT”) and changing how
existing AMT credits can be realized; (3) the creation of the base erosion anti-abuse tax (“BEAT”), a new minimum tax; (4)
a general elimination of U.S. federal income taxes on dividends from foreign subsidiaries; (5) a new provision designed to
tax global intangible low-taxed income, which allows for the possibility of using foreign tax credits (“FTCs”) and a deduction
of up to 50% to offset the income tax liability (subject to some limitations); (6) a new limitation on deductible interest expense;
(7) limitations on the deductibility of certain executive compensation; (8) limitations on the use of FTCs to reduce the
U.S. income tax liability; and (9) limitations on net operating losses (“NOLs”) generated after December 31, 2017 to 80% of
taxable income.
The SEC staff issued Staff Accounting Bulletin (“SAB”) No. 118 (“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 Accounting Standards Codification (“ASC”) No. 740
(“ASC 740”), Income Taxes. 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 law that were in effect immediately
before the enactment of the Tax Act. As of December 31, 2017, our accounting for the income tax effects of the Tax Act was
completed; however, it is possible that our accounting will be refined as tax authorities issue further guidance in how to apply
the law which may require updates to our tax expense for the 2017 tax year. Therefore, we did not record any provisional
estimates in 2017
As a result of enactment of the Tax Act, we incurred a one-time income tax expense during the fourth quarter of 2017
of $7.0 million related to $21.0 million of deemed repatriation of accumulated foreign earnings, of which $0.3 million is a
cash charge and the remaining $6.7 million represents a non-cash discrete tax expense largely from the utilization of net
operating loss carryovers. We will continue to review and refine this amount as additional guidance is provided on the taxation
of deemed repatriation income through the filing of the 2017 U.S. federal income tax return. We plan to use our net operating
loss carryforwards to settle this additional income tax expense. We also incurred a non-cash income tax expense of
$2.5 million related to the remeasurement of certain deferred tax assets and liabilities based on the recently enacted rates from
the Tax Act.
We continue to evaluate the impact of the tax law changes related to state income taxes, the new income tax provisions
related to global intangible low-taxed income and deductions related to foreign derived intangible income. We continue to
assert that the accumulated foreign earnings are permanently reinvested. We should have no U.S. federal income tax
obligation should we decide in the future to repatriate accumulated foreign earnings. Given the uncertainty of current foreign
and state tax laws, we have not estimated what the future foreign or state income tax impact will be if we decide to repatriate
accumulate foreign earnings in the future.
We continue to evaluate the impact the Tax Act will have on the Consolidated Financial Statements. We expect the
Tax Act to favorably impact our net income, diluted earnings per share, and cash flows in future periods, due primarily to the
reduction in the federal corporate tax rate from 35% to 21% effective for periods beginning January 1, 2018. See Note 9,
“Income Taxes,” of the Notes to Consolidated Financial Statements in Part II, Item 8, “Financial Statements and
Supplementary Data,” of this Annual Report on Form 10-K for a discussion of our income tax accounting related to the Tax
Act.
- 32 -
2016 Compared to 2015
Total Revenue
Product revenue ................. $
License and development
revenue .............................
Total revenue ................. $
Product Revenue
For the Year Ended December 31,
2016
2015
$
% of Total
Revenue
$
% of Total
Revenue
$ Change
% Change
(In thousands, except for percentages)
49,715
91%
$
43,671
98%
$
6,044
5,000
54,715
9%
100%
$
1,042
44,713
2%
100%
$
3,958
10,002
14%
380%
22%
For the Year Ended December 31,
2016
2015
$ Change
% Change
(In thousands, except for percentages)
Water ................................................................................. $
Oil & Gas ..........................................................................
Total product revenue .................................................... $
47,545
2,170
49,715
$
$
43,530
141
43,671
$
$
4,015
2,029
6,044
9%
1439%
14%
The increase in Water segment product revenue was primarily due to higher MPD, OEM, and aftermarket shipments
in 2016, as compared to 2015. The increase in our Water segment product revenue was primarily due to MPD sales of
$1.9 million, OEM sales of $1.2 million and aftermarket sales of $0.9 million.
The increase in Oil & Gas segment product revenue was primarily due to the percentage-of-completion revenue
recognition associated with the sale of multiple IsoBoost systems of $2.2 million. The increase was offset by $0.2 million
related to the commissioning of an IsoGen system and the cancellation of a purchase order for an IsoBoost in early 2015.
Product revenue attributable to domestic and international sales as a percentage of total product revenue is presented
in the following table.
Domestic revenue .................................................................................................................................
International revenue ............................................................................................................................
Total product revenue .......................................................................................................................
For the Year Ended December 31,
2016
2015
2%
98%
100%
7%
93%
100%
- 33 -
License and Development Revenue
For the Year Ended December 31,
2016
2015
$ Change
% Change
(In thousands, except for percentages)
License and development revenue .......................................... $
5,000
$
1,042
$
3,958
380%
License and development revenue relate solely to our VorTeq License Agreement. The increase in license and
development revenue in 2016, compared to 2015, was due to the recognition of a full year of amortization of the deferred
revenue compared to a partial year of amortization in 2015.
Product Gross Profit and Margin
Year Ended December 31, 2016
Year Ended December 31, 2015
Water
Oil & Gas
Total
Water
Oil & Gas
Total
(In thousands, except for percentages)
Product gross profit ....................... $
Product gross margin .....................
31,192
$
66%
674
$
31%
31,866
$
64%
24,485
$
56%
75
$
53%
24,560
56%
Product gross profit increased in 2016, compared to 2015, due primarily to increased sales volume, favorable product
price and mix, and increased operational efficiencies.
Operating Expenses
For the Year Ended December 31,
2016
2015
$
% of Total
Revenue
$
% of Total
Revenue
$ Change
% Change
(In thousands, except for percentages)
Total revenue ................................... $
54,715
100% $
44,713
100% $
10,002
22%
Operating expenses:
General and administrative ........... $
Sales and marketing .....................
Research and development ...........
Amortization of intangible assets .
Total operating expenses ........... $
16,626
9,116
10,136
631
36,509
30% $
17%
19%
1%
67% $
19,773
9,326
7,659
635
37,393
44% $
21%
17%
1%
84% $
(3,147)
(210)
2,477
(4)
(884)
(16%)
(2%)
32%
(1%)
(2%)
____________
(1)
Percents may not add up to total due to rounding.
General and Administrative
General and administrative expense decreased in 2016, compared to 2015, due primarily to lower professional, legal,
and other administrative costs of $2.1 million and stock-based compensation expense of $1.1 million. Stock-based
compensation expense was $2.1 million and $3.1 million for the years ended December 31, 2016 and 2015, respectively. The
decrease in stock-based compensation is primarily related to the decrease of non-recurring expenses associated with the
accelerated vesting and modification of options in connection with the resignation of the former Chief Executive Officer in
the first quarter of 2015.
- 34 -
Sales and Marketing
Sales and marketing expense decreased in 2016, compared to 2015, due primarily to lower compensation, sales
commissions, and employee-related compensation of $0.4 million, partially offset by an increase related to bonuses of
$0.2 million. Stock-based compensation expense was $0.5 million and $0.4 million for the years ended December 31, 2016
and 2015, respectively.
Research and Development
Research and development expense increased in 2016, compared to 2015, due primarily to direct research and
development project costs associated with new product initiatives of $1.2 million and compensation and employee-related
benefits of $1.2 million. Stock-based compensation expense was $0.6 million and $0.4 million for the years ended
December 31, 2016 and 2015, respectively.
Amortization of Intangible Assets
Amortization of intangible assets is related to finite-lived intangible assets acquired as a result of our purchase of Pump
Engineering, LLC in December 2009. There was no material change in our amortization amounts in 2016, compared to 2015.
Other Income (Expense), net
For the Year Ended December 31,
2016
2015
$
% of Total
Revenue
$
% of Total
Revenue
$ Change
% Change
(In thousands, except for percentages)
Total revenue ........................ $
54,715
100% $
44,713
100% $
10,002
22%
Other income (expense):
Interest income .................. $
Interest expense .................
Other non-operating
expense, net .....................
Total other income
(expense), net ................. $
309
(3)
(19)
287
1% $
—%
53
(42)
—% $
—%
—%
(192)
—%
256
39
173
483%
(93%)
(90%)
1% $
(181)
—% $
468
(259%)
Total other income (expense), net was income in 2016, compared to expense in 2015. The increase in Total other
income (expense), net was due primarily to interest income on higher cash and investment balances; lower interest expense;
the favorable disposition of foreign currency options; and favorable foreign currency exchange.
Income Taxes
Our income tax benefit was $0.4 million for the year ended December 31, 2016 compared to a tax benefit of
$0.3 million for the year ended December 31, 2015. The tax benefit of $0.4 million for the year ended December 31, 2016,
consisted of $0.7 million tax benefit related to the losses in our Ireland subsidiary which was partially offset by tax expense
of $0.3 million related to the deferred tax effects associated with the amortization of goodwill and other taxes.
The tax benefit of $0.3 million for the year ended December 31, 2015, consisted of $0.6 million benefit related to the
losses in our Ireland subsidiary which was partially offset by tax expense of $0.3 million related to the deferred tax effects
associated with the amortization of goodwill and other taxes.
- 35 -
Liquidity and Capital Resources
Overview
Historically, our primary source of cash to fund our operations and capital expenditures has been proceeds from
customer payments for our products and services and the issuance of common stock. As of December 31, 2017, we have
issued common stock for aggregate net proceeds of $100.3 million, excluding common stock issued in exchange for
promissory notes.
As of December 31, 2017, our principal sources of liquidity consisted of unrestricted cash and cash equivalents of
$27.8 million that are primarily invested in money market funds; short-term investments of $70.0 million that are primarily
invested in marketable debt securities; and accounts receivable, net of allowances of $12.5 million. We invest cash not needed
for current operations predominantly in high-quality, investment-grade, marketable debt instruments with the intent to make
such funds available for operating purposes as needed.
As of December 31, 2017, our unrestricted cash, cash equivalents and short-term investments held outside the U.S.
was $50.8 million. Our intent has been to reinvest the earnings of foreign subsidiaries indefinitely outside the U.S. to fund
both organic growth and acquisitions. On December 22, 2017, the Tax Act was enacted into law. This new law includes a
provision that imposes a transition tax on foreign earnings whether or not such earnings are repatriated to the U.S. In light of
this new tax, we are reviewing our prior position on the reinvestment of the earnings of our foreign subsidiaries outside of
the U.S. No decision on repatriation has been made at this time.
At December 31, 2017 and 2016, we had $1.4 million and $0.2 million, respectively, of short-term unbilled receivables.
In the Water segment, we have unbilled receivables pertaining to customer contractual holdback provisions, whereby we will
invoice the final retention payment(s) due under certain sales contracts in the next 12 months. The customer holdbacks
represent amounts intended to provide a form of security for the customer; accordingly, these receivables have not been
discounted to present value. In the Oil & Gas segment, we had estimated earnings in excess of billings, net of unbilled project
costs, of $4.2 million at December 31, 2017. See Note 4, “Other Financial Information,” of the Notes to Consolidated
Financial Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-
K for additional information about our cost and estimated earnings on uncompleted contracts.
Loan Agreements
On January 27, 2017, we entered into a loan and pledge agreement (the “Loan and Pledge Agreement”) with a financial
institution. The Loan and Pledge Agreement provides for a committed revolving credit line of $16.0 million and an
uncommitted revolving credit line of $4.0 million. Under the Loan and Pledge Agreement, we are allowed to borrow and
request letters of credit against the eligible assets held from time to time in the pledged account maintained with the financial
institution. Revolving loans incur interest per annum at a base rate equal to the LIBOR rate plus 1.5%. Any default bears the
aforementioned interest rate plus an additional 2%. The unused portion of the credit line is subject to a fee equal to the product
of 0.2% per annum multiplied by the difference, if positive, between $16.0 million and the average daily balance of all
advances under the committed facility plus aggregate average daily undrawn amounts of all letters of credit issued under the
committed facility during the immediately preceding month or portion thereof. We are subject to certain financial and
administrative covenants under the Loan and Pledge Agreement. As of December 31, 2017, we were in compliance with
these covenants. See Note 7, “Long-term Debt and Lines of Credit,” of the Notes to Consolidated Financial Statements in
Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K for additional
information about our loan agreement.
Stand-by Letters of Credit
At December 31, 2017, we have stand-by letters of credit with various financial institutions totaling $10.4 million
whereby we are required to maintain a restricted cash balance of $2.8 million and U.S. investment balance of $7.7 million.
Stand-by letters of credit at are subject to fees based on the amount of the letter of credit, that are payable quarterly and are
non-refundable. See Note 7, “Long-term Debt and Lines of Credit,” of the Notes to Consolidated Financial Statements in
- 36 -
Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K for additional
information about our stand-by letters of credit arrangements.
Share Repurchases
Our Board of Directors has authorized share repurchases since 2012 through September 30, 2017. In March 2017, our
Board of Directors authorized repurchases of $15.0 million that expired in September 2017. Through this 2017 program, we
repurchased 541,177 shares for $4.3 million. At December 31, 2017, we did not have a board authorized share repurchase
program in effect. Since the initial authorization of the share repurchase programs, we have spent an aggregate $20.4 million,
excluding commissions, to repurchase 4,262,833 shares.
On March 7, 2018, our Board of Directors authorized a stock repurchase program under which the Company, at the
discretion of management, may repurchase up to $10.0 million in aggregate cost of the our outstanding common stock. Under
the newly authorized repurchase program, purchases of shares of common stock may be made from time to time in the open
market, or in privately negotiated transactions, in compliance with applicable state and federal securities laws. The timing
and amounts of any purchases will be based on market conditions and other factors including price, regulatory requirements,
and capital availability. The share buyback program does not obligate us to acquire any specific number of shares in any
period, and may be expanded, extended, modified or discontinued at any time without prior notice.
In addition to repurchases under our repurchase program, during 2017, we spent $0.3 million to settle employee tax
withholding obligations due upon the vesting of restricted stock units and withheld an equivalent value of shares from the
shares provided to the employees upon vesting. See Note 10, “Stockholder’s Equity,” of the Notes to Consolidated Financial
Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K for
additional information about our share repurchase programs.
Cash Flows
Our cash flows are presented in the following table.
Net cash provided by operating activities ................................................................ $
Net cash (used in) provided by investing activities .................................................
Net cash provided by (used in) financing activities .................................................
Effect of exchange rate differences on cash and cash equivalents ...........................
Years Ended December 31,
2017
2016
2015
(In thousands)
2,895 $
(37,373)
951
(57)
4,965 $
(40,706)
(2,785)
(41)
69,055
14,018
1,374
(17)
Net change in cash and cash equivalents .............................................................. $
(33,584) $
(38,567) $
84,430
Cash Flows from Operating Activities
Cash provided by operating activities is generated by net income (loss) adjusted for certain non-cash items and changes
in assets and liabilities.
Cash provided by operating activities was lower in 2017, compared to 2016, by $2.1 million, due primarily to higher
non-cash used for deferred income tax adjustment of $8.4 million and cash used for operating assets and liabilities
of $6.8 million, partially offset by higher net income of $11.3 million and a benefit of other non-cash adjustments related to
operating activities of $1.8 million.
Cash provided by operating activities was lower in 2016, compared to 2015, by $64.1 million, due primarily to one-
time cash received from the VorTeq Licensee of $75.0 million in 2015, lower benefit of non-cash adjustments related to
operating activities of $1.1 million and a cash benefit from other operating assets and liabilities of $0.6 million, partially
offset by net income of $1.0 million in 2016, compared to a net loss of $11.6 million in 2015.
- 37 -
Net changes of cash used for assets and liabilities of $9.1 million in 2017 were primarily attributable to a $5.0 million
decrease in deferred revenue due to the recognition of revenue related to our exclusive license agreement, a $3.2 million
increase in cost and estimated billings related to a percentage-of-completion revenue recognition project, a $2.0 million
increase in accounts receivable and unbilled receivables due to timing of invoices and payments, a $1.3 million increase in
inventories due to increased production, and a $0.5 million decrease in product deferred revenue, partially offset by a
$2.5 million increase in accounts payable and accrued expenses and other liabilities, and a $0.4 million increase in taxes
payable.
Net changes of cash used for assets and liabilities of $2.3 million in 2016 were primarily attributable to a $5.0 million
decrease in deferred revenue due to the recognition of revenue related to our exclusive license agreement, a $1.8 million
increase in cost and estimated billings related to a percentage-of-completion revenue recognition project, a $0.4 million
increase in prepaid expenses and other assets, and a $0.4 million decrease in accounts payable, partially offset by a
$2.3 million decrease in inventories due to increased shipments, a $1.5 million decrease in accounts receivable and unbilled
receivables due to timing of invoices and payments, a $1.2 million increase in accrued expenses and other liabilities, and a
$0.3 million increase in product deferred revenue.
Net changes of cash provided from assets and liabilities of $73.3 million in 2015 were primarily attributable to the
receipt of a $75.0 million exclusive license payment, of which $1.0 million was recognized as revenue and the remainder
deferred, a $2.0 million decrease in inventories related to increased shipments, a $0.3 million increase in product deferred
revenue, and a $0.3 million decrease in prepaid expenses and other assets, partially offset by a $1.7 million litigation
settlement payment, a $0.9 million increase in accounts receivable and unbilled receivables related to increased shipments,
and a $0.7 million decrease in accrued expenses and other liabilities related to decrease legal expenses and litigation matters.
Cash Flows from Investing Activities
Cash flows from investing activities primarily relate to maturities and purchases of marketable securities to preserve
principal and liquidity while at the same time maximizing yields without significantly increasing risk, capital expenditures to
support our growth, and changes in our restricted cash used to collateralize our stand-by letters of credit and other contingent
considerations.
Cash used in 2017 was primarily attributable to $80.6 million used to purchase investments and $7.4 million for capital
expenditures. These were offset by $49.1 million in maturities of marketable security investments and $1.5 million increase
in restricted cash related to additional stand-by letters of credit.
Cash used in 2016 was primarily attributable to $46.6 million used to purchase investments, $1.1 million for capital
expenditures, and a $0.6 million increase in restricted cash related to additional stand-by letters of credit. These were offset
by $7.5 million in maturities of marketable security investments.
Cash provided in 2015 was primarily attributable to $12.9 million in maturities of investments and the release of
$1.7 million of restricted cash related to the expiration of stand-by letters of credit. These were offset by the use of $0.6 million
for capital expenditures.
Cash Flows from Financing Activities
Net cash provided in 2017 was primarily due to $5.5 million received from the issuance of common stock related to
stock option exercises, partially offset by the use of $4.2 million to repurchase our common stock and $0.3 million used for
taxes paid related to net share settlement of equity awards.
Net cash used in 2016 was primarily due to the use of $9.4 million to repurchase our common stock, partially offset
by $6.6 million received from the issuance of common stock related to option exercises.
Net cash provided in 2015 was primarily due to $1.3 million received from the issuance of common stock related to
option and warrant exercises and $0.1 million of proceeds from long-term debt.
- 38 -
Liquidity and Capital Resource Requirements
We believe that our existing resources and cash generated from our operations will be sufficient to meet our anticipated
capital requirements for at least the next 12 months. However, we may need to raise additional capital or incur additional
indebtedness to continue to fund our operations or to support acquisitions in the future and/or fund investments in our latest
technology arising from rapid market adoption that could require us to seek additional equity or debt financing. Our future
capital requirements will depend on many factors, including the continuing market acceptance of our products, our rate of
revenue growth, the timing of new product introductions, the expansion of our research and development, manufacturing,
and sales and marketing activities, the timing and extent of our expansion into new geographic territories, and the amount
and timing of cash used for stock repurchases. In addition, we may enter into potential material investments in, or acquisitions
of, complementary businesses, services, or technologies in the future, which could also require us to seek additional equity
or debt financing. Should we need additional liquidity or capital funds, these funds may not be available to us on favorable
terms, or at all.
Contractual Obligations
We lease facilities and equipment under fixed non-cancellable operating leases that expire on various dates through
2021. Additionally, in the course of our normal operations, we have entered into cancellable purchase commitments with our
suppliers for various key raw materials and component parts. The purchase commitments covered by these arrangements are
subject to change based on our sales forecasts for future deliveries.
The following is a summary of our contractual obligations as of December 31, 2017.
Payments Due by Period
1 Year
2-3 Years
4-5 Years
5+ Years
Total
(In thousands)
Operating leases ............................................. $
Loan payable ..................................................
Purchase obligations (1) ....................................
$
1,788 $
11
4,454
6,253 $
1,715 $
16
—
1,731 $
34 $
—
—
34 $
— $
—
—
— $
3,537
27
4,454
8,018
____________
(1) Purchase obligations are related to open purchase orders for materials and supplies.
This table excludes agreements with guarantees or indemnity provisions that we have entered into with customers and
others in the ordinary course of business. Based on our historical experience and information known to us as of December 31,
2017, we believe that our exposure related to these guarantees and indemnities as of December 31, 2017 was not material.
Off-Balance Sheet Arrangements
During the periods presented, we did not have any relationships with unconsolidated entities or financial partnerships
such as entities often referred to as structured finance or special purpose entities, which would have been established for the
purpose of facilitating off-balance sheet arrangements or other contractually narrow or limited purposes.
Critical Accounting Policies and Estimates
Our Consolidated Financial Statements are prepared in accordance with generally accepted accounting principles
(“GAAP”) in the United States. These accounting principles require us to make estimates and judgments that can affect the
reported amounts of assets and liabilities as of the date of the Consolidated Financial Statements as well as the reported
amounts of revenue and expense during the periods presented. We believe that the estimates and judgments upon which we
rely are reasonable based upon information available to us at the time that we make these estimates and judgments. To the
extent that there are material differences between these estimates and actual results, our consolidated financial results will be
affected. The accounting policies that reflect our more significant estimates and judgments and which we believe are the most
- 39 -
critical to aid in fully understanding and evaluating our reported financial results are revenue recognition, including
percentage-of-completion accounting for oil & gas projects; allowance for doubtful accounts; allowance for product warranty;
valuation of stock options; valuation and impairment of goodwill and acquired intangible assets; valuation adjustments for
excess and obsolete inventory; deferred taxes and valuation allowances on deferred tax assets; and evaluation and
measurement of contingencies, including contingent consideration.
The following is not intended to be a comprehensive list of all of our accounting policies or estimates. Our accounting
policies are more fully described in Note 1, “Description of Business and Significant Accounting Policies” of the Notes to
Consolidated Financial Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report
on Form 10-K.
Revenue Recognition
Product and service revenue recognition – Water Segment
We recognize revenue when the earnings process is complete, as evidenced by a written agreement with the customer,
transfer of title, fixed pricing that is determinable, and collection that is reasonably assured. Transfer of title typically occurs
upon shipment of the equipment pursuant to a written purchase order or contract. The portion of the sales agreement related
to the field services and training for commissioning of our devices in a desalination plant is deferred until we have performed
such services. We regularly evaluate our revenue arrangements to identify deliverables and to determine whether these
deliverables are separable into multiple units of accounting.
Under our revenue recognition policy, evidence of an arrangement is met when we have an executed purchase order,
sales order, or stand-alone contract. Typically, smaller projects utilize sales or purchase orders that conform to standard terms
and conditions.
The specified product performance criteria for our PX ERD pertain to the ability of our product to meet its published
performance specifications and warranty provisions, which our products have demonstrated on a consistent basis. This factor,
combined with historical performance metrics, provides our management with a reasonable basis to conclude that the PX
ERDs will perform satisfactorily upon commissioning of the plant. To ensure this successful product performance, we provide
service consisting principally of supervision of customer personnel and training to the customers during the commissioning
of the plant. The installation of the PX ERDs is relatively simple, requires no customization, and is performed by the customer
under the supervision of our personnel. We defer the value of the service and training component of the contract and recognize
such revenue as services are rendered. Based on these factors, we have concluded that, for sale of PX ERDs, as well as for
turbochargers and pumps, delivery and performance have been completed upon shipment or delivery when title transfers
based on the shipping terms.
We perform an evaluation of customer credit worthiness on an individual contract basis to assess whether collectability
is reasonably assured. As part of this evaluation, we consider many factors about the individual customer, including the
underlying financial strength of the customer and/or partnership consortium and management’s prior history or industry-
specific knowledge about the customer and its supplier relationships. For smaller projects, we require the customer to remit
payment generally within 30 to 90 days after product delivery. In some cases, if credit worthiness cannot be determined,
prepayment or other security is required.
We establish separate units of accounting for contracts, as our contracts with customers typically include one or both
of the deliverables, products or commissioning, and there is no right of return under the terms of the contract.
Commissioning includes supervision of the installation, start-up, and training to ensure that the installation performed
by the customer, which is relatively simple and straightforward, is completed consistent with the recommendations under the
factory warranty. The commissioning services’ element of our contracts represents an incidental portion of the total contract
price. The allocable consideration for these services relative to that for the underlying products has been well under 1% of
any arrangement. Commissioning is often bundled into the large stand-alone contracts, and we frequently sell products
- 40 -
without commissioning since our product can be easily installed in a plant without supervision. These facts and circumstances
validate that the delivered element has value on a stand-alone basis and should be considered a separate unit of accounting.
Having established separate units of accounting, we then allocate amounts to each unit of accounting. With respect to
products, we have established vendor specific objective evidence (“VSOE”) based on the price at which such products are
sold separately without commissioning services. With respect to commissioning, we charge out our engineers for field visits
to customers based on a stand-alone standard daily field service charge as well as a flat service rate for travel, if applicable.
This has been determined to be the VSOE of the service based on stand-alone sales of other comparable professional services
at consistent pricing.
The amount allocable to the delivered unit of account (in our case the product) is limited to the amount that is not
contingent upon the delivery of additional items or meeting specified performance conditions. We adhere to consistent pricing
in both stand-alone sale of products and professional services and the contractual pricing of products and commissioning of
services in bundled arrangements.
For large projects, stand-alone contracts are utilized. For these contracts, consistent with industry practice, our
customers typically require their suppliers, including Energy Recovery, to accept contractual holdback provisions (also
referred to as a retention payment) whereby the final amounts due under the sales contract are remitted over extended periods
of time or alternatively, stand-by letters of credit are issued to guarantee performance. These retention payments are generally
10% or less of the total contract amount and are due and payable when the customer is satisfied that certain specified product
performance criteria have been met upon commissioning of the desalination plant, which may be up to 24 months from the
date of product delivery as described further below.
Under MPD stand-alone contracts, the usual payment arrangements are summarized as follows:
•
•
•
an advance payment due upon execution of the contract, typically 10% to 20% of the total contract amount.
This advance payment is accounted for as deferred revenue until shipment or when products are delivered to
the customer, depending on the Incoterms and transfer of title;
a payment ranging from 50% to 70% of the total contract is typically due upon shipment of the product. This
payment is often divided into two parts. The first part, which is due 30 to 60 days following delivery of the
product and documentation, is invoiced upon shipment when the product revenue is recognized and results in
an open accounts receivable with the customer. The second part is typically due 90 to 120 days following
product delivery and documentation. This payment is booked to unbilled receivables upon shipment when the
product revenue is recognized, and it is invoiced to the customer upon notification that the equipment has
been received or when the time period has expired. We have no performance obligation to complete to be
legally entitled to this payment. It is invoiced based on the passage of time.
a final retention payment of generally 10% or less of the contract amount is due either at the completion of
plant commissioning or upon the issuance of a stand-by letter of credit, which is typically issued up to 24
months from the delivery date of products and documentation. This payment is recorded to unbilled
receivables upon shipment when the product revenue is recognized, and it is invoiced to the customer when it
is determined that commissioning is complete or the stand-by letter of credit has been issued. This payment is
not contingent upon the delivery of commissioning services. We have no performance obligation to complete
to be legally entitled to this payment. It is invoiced based on the passage of time.
We do not provide our customers with a right of product return; however, we will accept returns of products that are
deemed to be damaged or defective when delivered that are covered by the terms and conditions of the product warranty.
Product returns have not been significant.
Shipping and handling charges billed to customers are included in product revenue. The cost of shipping to customers
is included in cost of revenue.
- 41 -
License, milestone payment, and royalty revenue recognition – Oil & Gas Segment
License and development revenue is comprised of the amortization of the upfront non-refundable $75.0 million
exclusivity fee received in connection with the VorTeq License Agreement. See Note 15, “VorTeq Partnership and License
Agreement,” of the Notes to Consolidated Financial Statements in Part II, Item 8, “Financial Statements and Supplementary
Data,” of this Annual Report on Form 10-K. The VorTeq License Agreement comprises a 15-year exclusivity license for our
VorTeq technology, milestone payments upon achievement of successful tests in accordance with the Key Performance
Indicators (“KPIs”) and, after commercialization is achieved, royalty payments for the supply and servicing of certain
components of the VorTeq. All payments are non-refundable.
We recognize license and development revenue in accordance with Accounting Standards Codification (“ASC”)
No. 605 (“ASC 605”), “Revenue Recognition” subtopic ASC 605-25 “Revenue with Multiple Element Arrangements” and
subtopic ASC 605-28 “Revenue Recognition-Milestone Method,” which provides accounting guidance for revenue
recognition for arrangements with multiple deliverables and guidance on defining the milestone and determining when the
use of the milestone method of revenue recognition is appropriate, respectively.
For multiple-element arrangements, each deliverable is accounted for as a separate unit of accounting if both the
following criteria are met: (1) the delivered item or items have value to the customer on a standalone basis and (2) for an
arrangement that includes a general right of return relative to the delivered item(s), delivery or performance of the undelivered
item(s) is considered probable and substantially in our control. Contingent deliverables within multiple element arrangements
are excluded from the evaluation of the units of accounting. Non-refundable, upfront license fees where we have continuing
obligation to perform are recognized over the period of the continuing performance obligation. The VorTeq License
Agreement was determined to include a single unit of accounting. The initial upfront fee of $75.0 million is recognized on a
straight-line basis over the 15-year term of the arrangement based on the performance period of the last or final deliverables,
which include the license and support.
We recognize revenue from milestone payments when: (i) the milestone event is substantive and its achievability has
substantive uncertainty at the inception of the agreement, and (ii) it does not have ongoing performance obligations related
to the achievement of the milestone earned. Milestone payments are considered substantive if all of the following conditions
are met, the milestone payment: (a) is commensurate with either the Company’s performance subsequent to the inception of
the arrangement to achieve the milestone or the enhancement of the value of the delivered item or items as a result of a
specific outcome resulting from the Company’s performance subsequent to the inception of the arrangement to achieve the
milestone; (b) relates solely to past performance; and (c) is reasonable relative to all of the deliverables and payment terms
(including other potential milestone consideration) within the arrangement. The VorTeq License Agreement includes two
substantive milestones of $25.0 million each due on achievement of successful tests in accordance with KPIs. No revenues
associated with achievement of the milestones have been recognized to date.
Percentage-of-completion revenue recognition – Oil & Gas Segment
IsoBoost and IsoGen systems are highly engineered, customized solutions that are designed and manufactured over an
extended period of time and are built specifically to meet a customer’s specifications. It is our position that percentage-of-
completion method of accounting is appropriate for IsoBoost and IsoGen systems given the facts and circumstances of these
projects. In the event that a purchase order for an IsoBoost or IsoGen does not meet these facts and circumstances, then
percentage-of-completion method of accounting does not apply.
Revenue from fixed price contracts is recognized using the percentage-of-completion method of accounting in the ratio
of costs incurred to estimated final costs. Contract costs include all direct material and labor costs related to contract
performance. Pre-contract costs with no future benefit are expensed in the period in which they are incurred. Since the
financial reporting of these contracts depends on estimates, which are assessed continually during the term of the contract,
recognized revenues and profit are subject to revisions as the contract progresses to completion. Revisions in profit estimates
are reflected in the period in which the facts that give rise to the revisions become known. If material, the effects of any
changes in estimates are disclosed in the notes to the consolidated financial statements. When estimates indicate that a loss
- 42 -
will be incurred on a contract, a provision for the expected loss is recorded in the period in which the loss becomes evident.
No loss has been incurred to date. Revenue is recognized only to the extent costs have been recognized in the same period.
Allowances for Doubtful Accounts
We record a provision for doubtful accounts based on historical experience and a detailed assessment of the
collectability of our accounts receivable. In estimating the allowance for doubtful accounts, we consider, among other factors,
the aging of the accounts receivable, our historical write-offs, the credit worthiness of each customer, and general economic
conditions. Account balances are charged off against the allowance when we believe that it is probable that the receivable
will not be recovered. Actual write-offs may be in excess of our estimated allowance.
Warranty Costs
We sell products with a limited warranty for a period ranging from 18 months to 5 years. We accrue for warranty costs
based on estimated product failure rates, historical activity, and expectations of future costs. Periodically, we evaluate and
adjust the warranty costs to the extent that actual warranty costs vary from the original estimates.
Stock-based Compensation
We measure and recognize stock-based compensation expense based on the fair value measurement for all stock-based
awards made to our employees and directors — including restricted stock units (“RSUs”), restricted shares (“RS”), and
employee stock options — over the requisite service period (typically the vesting period of the awards). The fair value of
RSUs and RS is based on our stock price on the date of grant. The fair value of stock options is calculated on the date of grant
using the Black-Scholes option pricing model, which requires a number of complex assumptions including expected life,
expected volatility, risk-free interest rate, and dividend yield. The estimation of awards that will ultimately vest requires
judgment, and to the extent that actual results or updated estimates differ from our current estimates, such amounts are
recorded as a cumulative adjustment in the period in which the estimates are revised. See Note 11, “Stock-based
Compensation,” of the Notes to Consolidated Financial Statements in Part II, Item 8, “Financial Statements and
Supplementary Data,” of this Annual Report on Form 10-K for further discussion of stock-based compensation.
Goodwill and Other Intangible Assets
The purchase price of an acquired company is allocated between intangible assets and the net tangible assets of the
acquired business with the residual purchase price recorded as goodwill. The determination of the value of the intangible
assets acquired involves certain judgments and estimates. These judgments can include, but are not limited to, the cash flows
that an asset is expected to generate in the future and the appropriate weighted average cost of capital.
Acquired intangible assets with determinable useful lives are amortized on a straight-line or accelerated basis over the
estimated periods benefited, ranging from one to 20 years. Acquired intangible assets with contractual terms are amortized
over their respective legal or contractual lives. Customer relationships and other non-contractual intangible assets with
determinable lives are amortized over periods ranging from five to 20 years.
We evaluate the recoverability of intangible assets by comparing the carrying amount of an asset to estimated future
net undiscounted cash flows generated by the asset. If such assets are considered to be impaired, the impairment recognized
is measured as the amount by which the carrying amount of the assets exceeds the fair value of the assets. The evaluation of
recoverability involves estimates of future operating cash flows based upon certain forecasted assumptions, including, but
not limited to, revenue growth rates, gross profit margins, and operating expenses over the expected remaining useful life of
the related asset. A shortfall in these estimated operating cash flows could result in an impairment charge in the future.
Goodwill is not amortized, but is evaluated annually for impairment at the reporting unit level or when indicators of a
potential impairment are present. We estimate the fair value of the reporting unit using the discounted cash flow and market
approaches. Forecast of future cash flows are based on our best estimate of future net sales and operating expenses, based
primarily on expected category expansion, pricing, market segment, and general economic conditions.
- 43 -
As of December 31, 2017 and 2016, acquired intangibles, including goodwill, relate to the acquisition of Pump
Engineering, LLC during the fourth quarter of 2009. See Note 6, “Goodwill and Intangible Assets,” of the Notes to
Consolidated Financial Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report
on Form 10-K for further discussion of intangible assets.
Inventories
Inventories are stated at the lower of cost (using the first-in, first-out “FIFO” method) or market. We calculate
inventory valuation adjustments for excess and obsolete inventory based on current inventory levels, movement, expected
useful lives, and estimated future demand of the products and spare parts.
Income Taxes
Current and non-current tax assets and liabilities are based upon an estimate of taxes refundable or payable for each of
the jurisdictions in which the Company is subject to tax. In the ordinary course of business, there is inherent uncertainty in
quantifying income tax positions. We assess income tax positions and record tax benefits for all years subject to examination
based upon the Company’s evaluation of the facts, circumstances, and information available at the reporting dates. For those
tax positions where it is more likely than not that a tax benefit will be sustained, we record the largest amount of tax benefit
with a greater than 50% likelihood of being realized upon ultimate settlement with a taxing authority that has full knowledge
of all relevant information. For those income tax positions where it is not more likely than not that a tax benefit will be
sustained, no tax benefit is recognized in the financial statements. When applicable, associated interest and penalties are
recognized as a component of income tax expense. Accrued interest and penalties are included within the related tax asset or
liability on the Consolidated Balance Sheets.
Deferred income taxes are provided for temporary differences arising from differences in bases of assets and liabilities
for tax and financial reporting purposes. Deferred income taxes are recorded on temporary differences using enacted tax rates
in effect for the year in which the temporary differences are expected to reverse. The effect of a change in tax rates on deferred
tax assets and liabilities is recognized in income in the period that includes the enactment date. Deferred tax assets are reduced
by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred
tax assets will not be realized. Significant judgment is required in determining whether and to what extent any valuation
allowance is needed on the Company’s deferred tax assets. In making such a determination, we consider all available positive
and negative evidence including recent results of operations, scheduled reversals of deferred tax liabilities, projected future
income, and available tax planning strategies. See Note 9, “Income Taxes,” of the Notes to Consolidated Financial Statements
in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K for further discussion
of the tax valuation allowance.
On December 22, 2017, President Trump signed into law the Tax Act, which significantly changes existing U.S. tax
laws. Following the 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 law that were in effect immediately before the enactment of the Tax Act. We did not record any
provisional estimates in 2017. See Note 9, “Income Taxes,” of the Notes to Consolidated Financial Statements in Part II,
Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K for a discussion of our income
tax accounting related to the Tax Act.
Our operations are subject to income and transaction taxes in the U.S. and in foreign jurisdictions. Significant estimates
and judgments are required in determining our worldwide provision for income taxes. Some of these estimates are based on
interpretations of existing tax laws or regulations. The ultimate amount of tax liability may be uncertain as a result.
- 44 -
Recent Accounting Pronouncements
See Note 2, “Recent Accounting Pronouncements,” of the Notes to Consolidated Financial Statements in Part II,
Item 8, “Financial Statements and Supplementary Data,” of this Annual Report on Form 10-K regarding the impact of certain
recent accounting pronouncements on our Consolidated Financial Statements.
Item 7A — Quantitative and Qualitative Disclosures About Market Risk
Foreign Currency Risk
The majority of our revenue contracts have been denominated in U.S. Dollars (“USD”). The amount of revenue
recognized in foreign currencies during the years ended December 31, 2017, 2016 and 2015 were not material.
As we expand our international sales, we expect that a portion of our revenue could be denominated in foreign
currencies. As a result, our cash and cash equivalents and operating results could be increasingly affected by changes in
exchange rates. Our international sales and service operations incur expense that is denominated in foreign currencies. This
expense could be materially affected by currency fluctuations. Our exposures are to fluctuations in exchange rates for USD
versus the British Pound, Saudi Riyal, United Arab Emirates Dirham, Euro, Chinese Yuan and Canadian Dollar. Changes in
currency exchange rates could adversely affect our consolidated operating results or financial position. Additionally, our
international sales and services operations maintain cash balances denominated in foreign currencies. To decrease the inherent
risk associated with translation of foreign cash balances into our reporting currency, we do not maintain excess cash balances
in foreign currencies. We have not hedged our exposure to changes in foreign currency exchange rates because expenses in
foreign currencies have been insignificant to date, and exchange rate fluctuations have had little impact on our operating
results and cash flows.
Interest Rate Risk and Credit Risk
We have an investment portfolio of fixed-income marketable debt securities, including amounts classified as cash
equivalents and short-term investments. The primary objective of our investment activities is to preserve principal and
liquidity while at the same time maximizing yields without significantly increasing risk. We invest primarily in investment-
grade short-term debt instruments of high-quality corporate issuers and the U.S. government and its agencies. These
investments are subject to counterparty credit risk. To minimize this risk, we invest pursuant to a Board-approved investment
policy. The policy mandates high credit rating requirements and restricts our exposure to any single corporate issuer by
imposing concentration limits.
Our investment portfolio includes fixed income marketable debt securities, including amounts classified as cash
equivalents and short-term investments. At December 31, 2017, all of our investments were classified as short-term, with
maturity dates less than 12 months, and totaled approximately $70.3 million. These investments were presented in Cash and
cash equivalents and Short-term investments on our Consolidated Balance Sheets in 2017. These investments are subject to
interest rate fluctuations and will decrease in market value if interest rates increase. To minimize the exposure due to adverse
shifts in interest rates, we maintain investments with an average maturity of less than seven months. A hypothetical 1%
increase in interest rates would have resulted in an approximately $0.5 million decrease in the fair value of our fixed-income
debt securities as of December 31, 2017.
- 45 -
Item 8 — Financial Statements and Supplementary Data
Consolidated Financial Statements:
Reports of Independent Registered Public Accounting Firm .........................................................................................
Consolidated Balance Sheets — December 31, 2017 and 2016 .....................................................................................
Consolidated Statements of Operations — Years ended December 31, 2017, 2016 and 2015 .......................................
Consolidated Statements of Comprehensive Income (Loss) — Years ended December 31, 2017, 2016 and 2015 .......
Consolidated Statements of Stockholders’ Equity — Years ended December 31, 2017, 2016 and 2015 ......................
Consolidated Statements of Cash Flows — Years ended December 31, 2017, 2016 and 2015 .....................................
Notes to Consolidated Financial Statements ..................................................................................................................
47
49
50
51
52
53
54
Page No.
- 46 -
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Stockholders and Board of Directors
Energy Recovery, Inc.
San Leandro, California
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of Energy Recovery, Inc. (the “Company”) and
subsidiaries as of December 31, 2017 and 2016, the related consolidated statements of operations, comprehensive income
(loss), stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2017 and the related
notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements
present fairly, in all material respects, the financial position of the Company and subsidiaries at December 31, 2017 and 2016,
and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2017, in
conformity with accounting principles generally accepted in the United States of America.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United
States) (“PCAOB”), the Company’s internal control over financial reporting as of December 31, 2017, based on criteria
established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the
Treadway Commission (“COSO”) and our report dated March 8, 2018 expressed an unqualified opinion thereon.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to
express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm
registered with the 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.
Our audits included performing procedures to assess the risks of material misstatement of the consolidated 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 consolidated 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 consolidated financial statements. We believe that our audits provide a reasonable
basis for our opinion.
/s/ BDO USA, LLP
We have served as the Company’s auditor since 2007.
San Jose, California
March 8, 2018
- 47 -
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Stockholders and Board of Directors
Energy Recovery, Inc.
San Leandro, California
Opinion on the Internal Control over Financial Reporting
We have audited Energy Recovery, Inc.’s (the “Company’s”) internal control over financial reporting as of
December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee
of Sponsoring Organizations of the Treadway Commission (the “COSO criteria”). In our opinion, the Company maintained,
in all material respects, effective internal control over financial reporting as of December 31, 2017, based on the COSO
criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United
States) (“PCAOB”), consolidated balance sheets of the Company and subsidiaries as of December 31, 2017 and 2016, the
related consolidated statements of operations, comprehensive income (loss), stockholders’ equity, and cash flows for each of
the three years in the period ended December 31, 2017, and the related notes and our report dated March 8, 2018 expressed
an unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for
its assessment of the effectiveness of internal control over financial reporting, included in the accompanying “Item 9A,
Management’s Report on Internal Control over Financial Reporting and Attestation Report of the Registered Public
Accounting Firm”. Our responsibility is to express an opinion on the Company’s internal control over financial reporting
based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with
respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the
Securities and Exchange Commission and the PCAOB.
We conducted our audit of internal control over financial reporting in accordance with the standards of the PCAOB.
Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal
control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of
internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the
design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such
other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for
our opinion.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding
the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with
generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and
procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions
and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to
permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and
expenditures of the company are being made only in accordance with authorizations of management and directors of the
company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or
disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements.
Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become
inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ BDO USA, LLP
San Jose, California
March 8, 2018
- 48 -
ENERGY RECOVERY, INC.
CONSOLIDATED BALANCE SHEETS
December 31,
2017
2016
(In thousands, except share data and par value)
Current assets:
ASSETS
Cash and cash equivalents ....................................................................................................................................... $
27,780
$
Restricted cash .........................................................................................................................................................
Short-term investments ............................................................................................................................................
Accounts receivable, net of allowance for doubtful accounts of $103 and $130 at December 31, 2017 and
2016, respectively ..................................................................................................................................................
Unbilled receivables, current ...................................................................................................................................
Cost and estimated earnings in excess of billings ...................................................................................................
Inventories ................................................................................................................................................................
Prepaid expenses and other current assets ...............................................................................................................
2,664
70,020
12,465
1,413
4,998
5,514
1,342
Total current assets ................................................................................................................................................
126,196
Restricted cash, non-current ........................................................................................................................................
Deferred tax assets, non-current ..................................................................................................................................
Property and equipment, net ........................................................................................................................................
Goodwill.......................................................................................................................................................................
Other intangible assets, net ..........................................................................................................................................
Other assets, non-current .............................................................................................................................................
182
7,902
13,393
12,790
1,269
12
61,364
2,297
39,073
11,759
190
1,825
4,550
1,311
122,369
2,087
1,270
8,643
12,790
1,900
4
Total assets ............................................................................................................................................................. $
161,744
$
149,063
Current liabilities:
LIABILITIES AND STOCKHOLDERS’ EQUITY
Accounts payable ..................................................................................................................................................... $
4,091
$
Accrued expenses and other current liabilities ........................................................................................................
Income taxes payable ...............................................................................................................................................
Accrued warranty reserve ........................................................................................................................................
Deferred revenue, current ........................................................................................................................................
Current portion of long-term debt............................................................................................................................
Total current liabilities...........................................................................................................................................
Long-term debt, less current portion ...........................................................................................................................
Deferred tax liabilities, non-current .............................................................................................................................
Deferred revenue, non-current .....................................................................................................................................
Other non-current liabilities .........................................................................................................................................
Total liabilities .......................................................................................................................................................
Commitments and Contingencies (Note 8)
Stockholders’ equity:
Preferred stock, $0.001 par value; 10,000,000 shares authorized; no shares issued or outstanding at December 31,
2017 and 2016 ..........................................................................................................................................................
Common stock, $0.001 par value; 200,000,000 shares authorized; 58,168,433 shares issued and 53,905,600
shares outstanding at December 31, 2017 and 56,884,207 shares issued and 53,162,551 shares outstanding at
December 31, 2016 ..................................................................................................................................................
Additional paid-in capital ............................................................................................................................................
Accumulated comprehensive loss ................................................................................................................................
Treasury stock, at cost, 4,262,833 shares repurchased at December 31, 2017 and 3,721,656 shares repurchased at
December 31, 2016 ..................................................................................................................................................
Accumulated deficit .....................................................................................................................................................
Total stockholders’ equity ........................................................................................................................................
9,322
432
366
5,611
11
19,833
16
—
59,006
358
79,213
—
58
149,006
(125)
(20,486)
(45,922)
82,531
Total liabilities and stockholders’ equity .............................................................................................................. $
161,744
$
See Accompanying Notes to Consolidated Financial Statements
1,505
9,019
16
406
6,201
11
17,158
27
2,233
63,958
554
83,930
—
57
139,676
(118)
(16,210)
(58,272)
65,133
149,063
- 49 -
ENERGY RECOVERY, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
Years Ended December 31,
Product revenue ...................................................................................... $
Product cost of revenue ..........................................................................
Product gross profit ..............................................................................
2017
2015
2016
(In thousands, except per share data)
58,156 $
19,061
39,095
49,715 $
17,849
31,866
43,671
19,111
24,560
License and development revenue ..........................................................
5,000
5,000
1,042
Operating expenses:
General and administrative ..................................................................
Sales and marketing .............................................................................
Research and development ..................................................................
Amortization of intangible assets.........................................................
Total operating expenses ...................................................................
Income (loss) from operations ................................................................
Other income (expense):
Interest income.....................................................................................
Interest expense ...................................................................................
Other non-operating expense, net ........................................................
Total other income (expense), net .....................................................
Income (loss) before income taxes .........................................................
Benefit from income taxes ......................................................................
Net income (loss) .................................................................................... $
17,354
9,391
13,443
631
40,819
3,276
870
(2)
(188)
680
3,956
(8,394)
12,350 $
16,626
9,116
10,136
631
36,509
19,773
9,326
7,659
635
37,393
357
(11,791)
309
(3)
(19)
287
644
(390)
1,034 $
53
(42)
(192)
(181)
(11,972)
(334)
(11,638)
Income (loss) per share:
Basic .................................................................................................. $
Diluted ............................................................................................... $
0.23 $
0.22 $
0.02 $
0.02 $
(0.22)
(0.22)
Number of shares used in per share calculations:
Basic ..................................................................................................
Diluted ...............................................................................................
53,701
55,612
52,341
55,451
52,151
52,151
See Accompanying Notes to Consolidated Financial Statements
- 50 -
ENERGY RECOVERY, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Net income (loss) .................................................................................... $
Other comprehensive (loss) income, net of tax:
2017
Years Ended December 31,
2016
(In thousands)
2015
12,350 $
1,034 $
(11,638)
Foreign currency translation adjustments ............................................
Unrealized (loss) income on investments ............................................
Other comprehensive (loss) income, net of tax .................................
57
(64)
(7)
(27)
(27)
(54)
4
5
9
Comprehensive income (loss) ......................................................... $
12,343 $
980 $
(11,629)
See Accompanying Notes to Consolidated Financial Statements
- 51 -
ENERGY RECOVERY, INC.
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Years Ended December 31, 2017, 2016 and 2015
Additional
Common Stock Treasury Stock
Paid-in
Shares Amount Shares Amount Capital
Accumulated
Other
Comprehensive Accumulated
Income (Loss)
Deficit
Total
Stockholders’
Equity
Balance at December 31,
2014 .............................. 54,398 $
Net loss ........................... —
Unrealized gain on
investments ................. —
Foreign currency
translation adjustments —
Issuance of common
stock ............................
Employee stock-based
compensation .............. —
550
Balance at December 31,
2015 .............................. 54,948
Net income .................... —
Unrealized loss on
investments ................. —
Foreign currency
translation adjustments —
Issuance of common
stock ............................ 1,936
Repurchase of common
stock for treasury ......... —
Employee stock-based
compensation .............. —
Balance at December 31,
2016 .............................. 56,884
Net income .................... —
Unrealized loss on
investments ................. —
Foreign currency
translation adjustments —
Issuance of common
stock ............................ 1,284
Repurchase of common
stock for treasury ......... —
Employee stock-based
compensation .............. —
Balance at December 31,
2017 .............................. 58,168 $
(In thousands)
54 (2,479) $ (6,835) $
—
— —
124,440 $
—
(73) $
—
(47,668) $
(11,638)
69,918
(11,638)
— —
—
— —
—
—
—
1 —
—
1,325
— —
—
4,044
55 (2,479)
— —
(6,835)
—
129,809
—
— —
—
— —
—
—
—
2 —
—
6,598
— (1,243)
(9,375)
—
— —
—
3,269
57 (3,722) (16,210)
—
— —
139,676
—
— —
—
— —
—
—
—
1 —
—
5,237
—
(541)
(4,276)
—
— —
—
4,093
5
4
—
—
(64)
—
(27)
(27)
—
—
—
(118)
—
(64)
57
—
—
—
—
—
—
—
(59,306)
1,034
—
—
—
—
—
(58,272)
12,350
—
—
—
—
—
5
4
1,326
4,044
63,659
1,034
(27)
(27)
6,600
(9,375)
3,269
65,133
12,350
(64)
57
5,238
(4,276)
4,093
58 (4,263) $ (20,486) $
149,006 $
(125) $
(45,922) $
82,531
See Accompanying Notes to Consolidated Financial Statements
- 52 -
ENERGY RECOVERY, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
2017
Years Ended December 31,
2016
(In thousands)
2015
12,350 $
1,034 $
(11,638 )
Cash Flows From Operating Activities:
Net income (loss) ........................................................................................... $
Adjustments to reconcile net income (loss) to net cash provided by
operating activities:
Stock-based compensation .........................................................................
Depreciation and amortization ...................................................................
Amortization of premiums on investments ................................................
Provision for warranty claims ....................................................................
Reversal of accruals related to expired warranties .....................................
Unrealized loss on foreign currency translation .........................................
Provision for doubtful accounts .................................................................
Adjustments for excess or obsolete inventory ............................................
Deferred income taxes ................................................................................
Other non-cash adjustments .......................................................................
Changes in operating assets and liabilities:
Accounts receivable ...............................................................................
Unbilled receivables ...............................................................................
Costs and estimated earnings in excess of billings .................................
Inventories ..............................................................................................
Prepaid and other assets .........................................................................
Accounts payable ...................................................................................
Accrued expenses and other liabilities ...................................................
Income taxes payable .............................................................................
Litigation settlement ...............................................................................
Deferred revenue, product ......................................................................
Deferred revenue, license and development ...........................................
Net cash provided by operating activities ......................................................
Cash Flows From Investing Activities:
Restricted cash ...........................................................................................
Maturities of marketable securities ............................................................
Purchases of marketable securities .............................................................
Capital expenditures ...................................................................................
Net cash (used in) provided by investing activities ........................................
Cash Flows From Financing Activities:
Net proceeds from issuance of common stock ...........................................
Tax payment for employee shares withheld ...............................................
Proceeds from long-term debt ....................................................................
Repayment of long-term debt .....................................................................
Repurchase of common stock.....................................................................
Net cash provided by (used in) financing activities ........................................
Effect of exchange rate differences on cash and cash equivalents .................
Net change in cash and cash equivalents ........................................................
Cash and cash equivalents, beginning of year ................................................
Cash and cash equivalents, end of year .......................................................... $
Supplemental disclosure of cash flow information:
Cash paid for interest ................................................................................. $
Cash received for income tax refunds ........................................................ $
Cash paid for income taxes ........................................................................ $
Supplemental disclosure of non-cash transactions:
Purchases of property and equipment in trade accounts payable and
4,087
3,666
460
246
(200)
144
55
201
(8,865)
(196)
(761)
(1,223)
(3,173)
(1,250)
(39)
2,118
364
416
—
(505)
(5,000)
2,895
1,538
49,106
(80,641)
(7,376)
(37,373)
5,508
(270)
—
(11)
(4,276)
951
(57)
(33,584)
61,364
27,780 $
3,263
3,680
174
208
(236 )
13
76
(361 )
(459 )
(131 )
(244 )
1,695
(1,825 )
2,287
(402 )
(360 )
1,259
14
—
280
(5,000 )
4,965
(577 )
7,535
(46,552 )
(1,112 )
(40,706 )
6,600
—
—
(10 )
(9,375 )
(2,785 )
(41 )
(38,567 )
99,931
61,364 $
2 $
16 $
57 $
3 $
2 $
51 $
4,059
3,838
162
135
(395 )
1
112
(250 )
(326 )
23
(743 )
(128 )
—
1,951
316
48
(708 )
(3 )
(1,700 )
343
73,958
69,055
1,665
12,925
—
(572 )
14,018
1,326
—
55
(7 )
—
1,374
(17 )
84,430
15,501
99,931
42
4
24
43
accrued expenses and other liabilities .................................................... $
475 $
66 $
See Accompanying Notes to Consolidated Financial Statements
- 53 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 — Description of Business and Significant Accounting Policies
Energy Recovery, Inc. and its wholly-owned subsidiaries (the “Company,” “Energy Recovery,” “our,” “us,” or “we”)
is an energy solutions provider to industrial fluid flow markets worldwide. The Company’s core competencies are fluid
dynamics and advanced material science. The Company’s products make industrial processes more operationally and capital
expenditure efficient. The Company’s solutions convert wasted pressure energy into a reusable asset and preserve or eliminate
pumping technology in hostile processing environments. The Company’s solutions are marketed and sold in fluid flow
markets, such as water, oil & gas, and chemical processing, under the trademarks ERI®, PX®, Pressure Exchanger®, PX
Pressure Exchanger®, VorTeq™, MTeq™, IsoBoost®, IsoGen®, AT™, and AquaBold™. The Company owns, manufactures, and/or
develops its solutions, in whole or in part, in the United States of America, (“U.S.”) and the Republic of Ireland (“Ireland”).
Basis of Presentation
The Company’s Consolidated Financial Statements include the accounts of Energy Recovery, Inc. and its wholly-
owned subsidiaries. All significant intercompany accounts and transactions have been eliminated in consolidation.
Reclassifications
Certain prior year amounts have been reclassified in the Consolidated Statements of Cash Flows and certain Notes to
Consolidated Financial Statements to conform to the current year presentation.
Use of Estimates
The preparation of Consolidated Financial Statements in conformity with United States (“U.S.”) generally accepted
accounting principles (“U.S. GAAP”) requires the Company’s management to make judgments, assumptions, and estimates
that affect the amounts reported in the Consolidated Financial Statements and accompanying Notes to Consolidated Financial
Statements.
The accounting policies that reflect the Company’s more significant estimates and judgments and that the Company
believes are the most critical to aid in fully understanding and evaluating its reported financial results are revenue recognition;
capitalization of research and development assets; allowance for doubtful accounts; allowance for product warranty; valuation
of stock options; valuation and impairment of goodwill and acquired intangible assets; useful lives for depreciation and
amortization; valuation adjustments for excess and obsolete inventory; deferred taxes and valuation allowances on deferred
tax assets; and evaluation and measurement of contingencies. Those estimates could change, and as a result, actual results
could differ materially from those estimates. For example, the Company records impairment losses on long-lived assets used
in operations when events and circumstances indicate that long-lived assets might be impaired and the undiscounted cash
flows estimated to be generated by those assets are less than the carrying amounts of those assets. The Company’s estimate
of undiscounted cash flows, at December 31, 2017 and 2016 indicated that such carrying amounts were expected to be
recovered. Nonetheless, it is possible that the estimate of undiscounted cash flows may change in the future resulting in the
need to write down those assets to fair value.
Cash and Cash Equivalents
The Company considers all highly liquid investments with an original or remaining maturity of three months or less
at the time of purchase to be cash equivalents. Cash equivalents are stated at cost, which approximates fair value. The
Company’s cash and cash equivalents are maintained primarily in demand deposit accounts with large financial institutions
and in institutional money market funds. The Company monitors the creditworthiness of the financial institutions and
institutional money market funds in which the Company invests its surplus funds. The Company has experienced no credit
losses from its cash investments.
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Allowances for Doubtful Accounts
The Company records a provision for doubtful accounts based on historical experience and a detailed assessment of
the collectability of its accounts receivable. In estimating the allowance for doubtful accounts, the Company considers, among
other factors, the aging of the accounts receivable, its historical write-offs, the credit worthiness of each customer, and general
economic conditions. Account balances are charged off against the allowance when the Company believes that it is probable
that the receivable will not be recovered. Actual write-offs may be in excess of the Company’s estimated allowance.
Short-Term and Long-Term Investments
The Company’s short-term and long-term investments consist primarily of investment-grade debt securities, all of
which are classified as available-for-sale. Available-for-sale securities are carried at fair value. Amortization or accretion of
premium or discount is included in other income (expense) on the Consolidated Statements of Operations. Changes in the
fair value of available-for-sale securities are reported as a component of accumulated other comprehensive loss within
stockholders’ equity on the Consolidated Balance Sheet. Realized gains and losses on the sale of available-for-sale securities
are determined by specific identification of the cost basis of each security. Short-term investments mature within 12 months.
As of December 31, 2017 and 2016, the Company had no long-term investments.
Inventories
Inventories are stated at the lower of cost (using the first-in, first-out “FIFO” method) or market. The Company
calculates inventory valuation adjustments for excess and obsolete inventory based on current inventory levels, movement,
expected useful lives, and estimated future demand of the products and spare parts.
Property and Equipment
Property and equipment is recorded at cost and reduced by accumulated depreciation. Depreciation expense is
recognized over the estimated useful lives of the assets using the straight-line method. Estimated useful lives are three to ten
years. Certain equipment used in the development and manufacturing of ceramic components is depreciated over estimated
useful lives of up to 10 years. Leasehold improvements represent remodeling and retrofitting costs for leased office and
manufacturing space and are depreciated over the shorter of either the estimated useful lives or the term of the lease. Software
purchased for internal use consists primarily of amounts paid for perpetual licenses to third-party software providers and
installation costs. Software is depreciated over the estimated useful lives of three to five years. Tangible assets acquired for
research and development (“R&D”) activities and have alternative use are capitalized over the useful life of the acquired
asset. Estimated useful lives are periodically reviewed, and when appropriate, changes are made prospectively. When certain
events or changes in operating conditions occur, asset lives may be adjusted and an impairment assessment may be performed
on the recoverability of the carrying amounts. Maintenance and repairs are charged directly to expense as incurred.
Goodwill and Other Intangible Assets
The purchase price of an acquired company is allocated between intangible assets and the net tangible assets of the
acquired business with the residual purchase price recorded as goodwill. The determination of the value of the intangible
assets acquired involves certain judgments and estimates. These judgments can include, but are not limited to, the cash flows
that an asset is expected to generate in the future and the appropriate weighted average cost of capital.
Acquired intangible assets with determinable useful lives are amortized on a straight-line or accelerated basis over the
estimated periods benefited, ranging from one to 20 years. Acquired intangible assets with contractual terms are amortized
over their respective legal or contractual lives. Customer relationships and other non-contractual intangible assets with
determinable lives are amortized over periods ranging from five to 20 years.
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The Company evaluates the recoverability of long-lived assets by comparing the carrying amount of an asset to
estimated future net undiscounted cash flows generated by the asset. If such assets are considered to be impaired, the
impairment recognized is measured as the amount by which the carrying amount of the assets exceeds the fair value of the
assets. The evaluation of recoverability involves estimates of future operating cash flows based upon certain forecasted
assumptions, including, but not limited to, revenue growth rates, gross profit margins, and operating expenses over the
expected remaining useful life of the related asset. A shortfall in these estimated operating cash flows could result in an
impairment charge in the future.
Goodwill is not amortized, but is evaluated annually for impairment at the reporting unit level or when indicators of a
potential impairment are present. The Company estimates the fair value of the reporting unit using the discounted cash flow
and market approaches. Forecast of future cash flows are based on the Company’s best estimate of future net sales and
operating expenses, based primarily on expected category expansion, pricing, market segment, and general economic
conditions.
As of December 31, 2017 and 2016, acquired intangibles, including goodwill, relate to the acquisition of Pump
Engineering, LLC during the fourth quarter of 2009. See Note 6, “Goodwill and Intangible Assets,” for further discussion of
intangible assets.
Fair Value of Financial Instruments
The Company’s financial instruments include cash and cash equivalents, restricted cash, investments in marketable
securities, accounts receivable, accounts payable, and debt. The carrying amounts for these financial instruments reported in
the Consolidated Balance Sheets approximate their fair values. See Note 5, “Investments and Fair Value Measurements,” for
further discussion of fair value.
Revenue Recognition
Product and service revenue recognition – Water Segment
The Company recognizes revenue when the earnings process is complete, as evidenced by a written agreement with
the customer, transfer of title, fixed pricing that is determinable, and collection that is reasonably assured. Transfer of title
typically occurs upon shipment of the equipment pursuant to a written purchase order or contract. The portion of the sales
agreement related to the field services and training for commissioning of the Company’s devices in a desalination plant is
deferred until the Company performs such services. The Company regularly evaluates revenue arrangements to identify
deliverables and to determine whether these deliverables are separable into multiple units of accounting.
Under the Company’s revenue recognition policy, evidence of an arrangement is met when the Company has an
executed purchase order, sales order, or stand-alone contract. Typically, smaller projects utilize sales or purchase orders that
conform to standard terms and conditions.
The specified product performance criteria for the Company’s PX® energy recovery devices (“ERDs”) pertain to the
ability of the Company’s product to meet its published performance specifications and warranty provisions, which the
Company’s products have demonstrated on a consistent basis. This factor, combined with historical performance metrics,
provides the Company’s management with a reasonable basis to conclude that the PX ERDs will perform satisfactorily upon
commissioning of the plant. To ensure this successful product performance, the Company provides service consisting
principally of supervision of customer personnel and training to the customers during the commissioning of the plant. The
installation of the PX ERDs is relatively simple, requires no customization, and is performed by the customer under the
supervision of our personnel. The Company defers the value of the service and training component of the contract and
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
recognize such revenue as services are rendered. Based on these factors, the Company has concluded that, for sale of PX
ERDs, as well as for turbochargers and pumps, delivery and performance have been completed upon shipment or delivery
when title transfers based on the shipping terms.
The Company performs an evaluation of customer credit worthiness on an individual contract basis to assess whether
collectability is reasonably assured. As part of this evaluation, the Company considers many factors about the individual
customer, including the underlying financial strength of the customer and/or partnership consortium and the Company’s prior
history or industry-specific knowledge about the customer and its supplier relationships. For smaller projects, the Company
requires the customer to remit payment generally within 30 to 90 days after product delivery. In some cases, if credit
worthiness cannot be determined, prepayment or other security is required.
The Company establishes separate units of accounting for contracts, as the Company’s mega-project (“MPD”)
contracts with customers typically include one or both of the deliverables, products or commissioning, and there is no right
of return under the terms of the contract.
Commissioning includes supervision of the installation, start-up, and training to ensure that the installation performed
by the customer which, is relatively simple and straightforward, is completed consistent with the recommendations under the
factory warranty. The commissioning services’ element of the Company’s contracts represents an incidental portion of the
total contract price and the allocable consideration for these services relative to that for the underlying products has been well
under 1% of any arrangement. Commissioning is often bundled into the large stand-alone contracts, and the Company
frequently sells products without commissioning since its product can be easily installed in a plant without supervision. These
facts and circumstances validate that the delivered element has value on a stand-alone basis and should be considered a
separate unit of accounting.
Having established separate units of accounting, the Company then allocates amounts to each unit of accounting. With
respect to products, the Company has established vendor specific objective evidence (“VSOE”) based on the price at which
such products are sold separately without commissioning services. With respect to commissioning, the Company charges out
its engineers for field visits to customers based on a stand-alone standard daily field service charge as well as a flat service
rate for travel, if applicable. This has been determined to be the VSOE of the service based on stand-alone sales of other
comparable professional services at consistent pricing.
The amount allocable to the delivered unit of account (in our case the product) is limited to the amount that is not
contingent upon the delivery of additional items or meeting specified performance conditions. The Company adheres to
consistent pricing in both stand-alone sale of products and professional services and the contractual pricing of products and
commissioning of services in bundled arrangements.
For large projects, stand-alone contracts are utilized. For these contracts, consistent with industry practice, the
Company’s customers typically require their suppliers, including Energy Recovery, to accept contractual holdback provisions
(also referred to as a retention payment) whereby the final amounts due under the sales contract are remitted over extended
periods of time or alternatively, stand-by letters of credit are issued to guarantee performance. These retention payments are
generally 10% or less of the total contract amount and are due and payable when the customer is satisfied that certain specified
product performance criteria have been met upon commissioning of the desalination plant, which may be up to 24 months
from the date of product delivery as described further below.
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Under stand-alone MPD contracts, the usual payment arrangements are summarized as follows:
•
•
•
an advance payment due upon execution of the contract, typically 10% to 20% of the total contract amount. This
advance payment is accounted for as deferred revenue until shipment or when products are delivered to the
customer, depending on the international commercial terms (commonly referred to as “incoterms”) and transfer of
title;
a payment ranging from 50% to 70% of the total contract is typically due upon shipment of the product. This
payment is often divided into two parts. The first part, which is due 30 to 60 days following delivery of the product
and documentation, is invoiced upon shipment when the product revenue is recognized and results in an open
accounts receivable with the customer. The second part is typically due 90 to 120 days following product delivery
and documentation. This payment is booked to unbilled receivables upon shipment when the product revenue is
recognized, and it is invoiced to the customer upon notification that the equipment has been received or when the
time period has expired. The Company has no performance obligation to complete to be legally entitled to this
payment. It is invoiced based on the passage of time.
a final retention payment of generally 10% or less of the contract amount is due either at the completion of plant
commissioning or upon the issuance of a stand-by letter of credit, which is typically issued up to 24 months from
the delivery date of products and documentation. This payment is recorded to unbilled receivables upon shipment
when the product revenue is recognized, and it is invoiced to the customer when it is determined that
commissioning is complete or the stand-by letter of credit has been issued. This payment is not contingent upon
the delivery of commissioning services. The Company had no performance obligation to complete to be legally
entitled to this payment. It is invoiced based on the passage of time.
The Company does not provide its customers with a right of product return; however, the Company will accept returns
of products that are deemed to be damaged or defective when delivered that are covered by the terms and conditions of the
product warranty. Product returns have not been significant.
Shipping and handling charges billed to customers are included in product revenue. The cost of shipping to customers
is included in cost of revenue.
License, milestone payment, and royalty revenue recognition – Oil & Gas Segment
License and development revenue is comprised of the amortization of the upfront non-refundable $75.0 million
exclusivity fee received in connection with the VorTeq License Agreement entered into with Schlumberger Technology
Corporation (the “VorTeq Licensee”). See Note 15, “VorTeq Partnership and License Agreement.” The VorTeq License
Agreement comprises a 15-year exclusivity license for our VorTeq™ technology (“VorTeq”), milestone payments upon
achievement of successful tests in accordance with the Key Performance Indicators (“KPIs”), defined in the license
agreement, and, after commercialization is achieved, royalty payments for the supply and servicing of certain components of
the VorTeq. All payments are non-refundable.
The Company recognizes license and development revenue in accordance with the Financial Accounting Standards
Board (“FASB”) Accounting Standards Codification (“ASC”) 605, “Revenue Recognition,” subtopic ASC 605-25 “Revenue
with Multiple Element Arrangements” and subtopic ASC 605-28 “Revenue Recognition-Milestone Method,” which provides
accounting guidance for revenue recognition for arrangements with multiple deliverables and guidance on defining the
milestone and determining when the use of the milestone method of revenue recognition is appropriate, respectively.
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
For multiple-element arrangements, each deliverable is accounted for as a separate unit of accounting if both the
following criteria are met: (1) the delivered item or items have value to the customer on a standalone basis and (2) for an
arrangement that includes a general right of return relative to the delivered item(s), delivery or performance of the undelivered
item(s) is considered probable and substantially in the Company’s control. Contingent deliverables within multiple element
arrangements are excluded from the evaluation of the units of accounting. Non-refundable, upfront license fees where the
Company has continuing obligation to perform are recognized over the period of the continuing performance obligation. The
VorTeq License Agreement was determined to include a single unit of accounting. The initial upfront fee of $75.0 million is
recognized on a straight-line basis over the 15-year term of the arrangement based on the performance period of the last or
final deliverables, which include the license and support.
The Company recognizes revenue from milestone payments when: (i) the milestone event is substantive and its
achievability has substantive uncertainty at the inception of the agreement, and (ii) it does not have ongoing performance
obligations related to the achievement of the milestone earned. Milestone payments are considered substantive if all of the
following conditions are met, the milestone payment: (a) is commensurate with either the Company’s performance subsequent
to the inception of the arrangement to achieve the milestone or the enhancement of the value of the delivered item or items
as a result of a specific outcome resulting from the Company’s performance subsequent to the inception of the arrangement
to achieve the milestone; (b) relates solely to past performance; and (c) is reasonable relative to all of the deliverables and
payment terms (including other potential milestone consideration) within the arrangement. The VorTeq License Agreement
includes two substantive milestones of $25.0 million each due on achievement of successful tests in accordance with KPIs.
No revenues associated with achievement of the milestones have been recognized to date.
Percentage-of-completion revenue recognition – Oil & Gas Segment
IsoBoost and IsoGen systems are highly engineered, customized solutions that are designed and manufactured over an
extended period of time and are built specifically to meet a customer’s specifications. It is the Company’s position that
percentage-of-completion method of accounting is appropriate for IsoBoost and IsoGen systems given the facts and
circumstances of these projects. In the event that a purchase order for an IsoBoost or IsoGen does not meet these facts and
circumstances, then percentage-of-completion method of accounting does not apply.
Revenue from fixed price contracts is recognized using the percentage-of-completion method of accounting in the ratio
of costs incurred to estimated final costs. Contract costs include all direct material and labor costs related to contract
performance. Pre-contract costs with no future benefit are expensed in the period in which they are incurred. Since the
financial reporting of these contracts depends on estimates, which are assessed continually during the term of the contract,
recognized revenues and profit are subject to revisions as the contract progresses to completion. Revisions in profit estimates
are reflected in the period in which the facts that give rise to the revisions become known. If material, the effects of any
changes in estimates are disclosed in the notes to the consolidated financial statements. When estimates indicate that a loss
will be incurred on a contract, a provision for the expected loss is recorded in the period in which the loss becomes evident.
No loss has been incurred to date. Revenue is recognized only to the extent costs have been recognized in the same period.
Research and Development Expense
R&D expenses consist of costs incurred for internal projects and for technology licensed to third parties. These costs
include the Company’s direct and research-related overhead expenses, which include salaries and other personnel-related
expenses (including stock-based compensation), occupancy-related costs, depreciation of facilities, as well as external costs
for equipment and supplies. Costs to acquire technologies that are utilized in research and development and that have no
alternative future use are expensed when incurred. All R&D costs are expensed as incurred and are included in operating
expenses.
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Warranty Costs
The Company sells products with a limited warranty for a period ranging from 18 months to 5 years. The Company
accrues for warranty costs based on estimated product failure rates, historical activity, and expectations of future costs.
Periodically, the Company evaluates and adjusts the warranty costs to the extent that actual warranty costs vary from the
original estimates.
Stock-based Compensation
The Company measures and recognize stock-based compensation expense based on the fair value measurement for all
stock-based awards made to its employees and directors, including restricted stock units (“RSUs”), restricted shares (“RS”),
and employee stock options over the requisite service period (typically the vesting period of the awards). The fair value of
RSUs and RS is based on the Company’s stock price on the date of grant. The fair value of stock options is calculated on the
date of grant using the Black-Scholes option pricing model, which requires a number of complex assumptions including
expected life, expected volatility, risk-free interest rate, and dividend yield. The estimation of awards that will ultimately vest
requires judgment, and to the extent that actual results or updated estimates differ from our current estimates, such amounts
are recorded as a cumulative adjustment in the period in which the estimates are revised. See Note 11, “Stock-based
Compensation,” for further discussion of stock-based compensation.
Foreign Currency
The Company’s reporting currency is the U.S. dollar. The functional currency of the Company’s Irish subsidiaries is
the U.S. dollar, while the functional currency of the Company’s other foreign subsidiaries is their respective local currencies.
The asset and liability accounts of the Company’s foreign subsidiaries are translated from their local currencies at the rates
in effect on the balance sheet date. Revenue and expenses are translated at average rates of exchange prevailing during the
period. Gains and losses resulting from the translation of the Company’s subsidiary balance sheets are recorded as a
component of accumulated other comprehensive income (loss). Gains and losses from foreign currency transactions are
recorded in other income (expense) in the Consolidated Statements of Operations.
Income Taxes
Current and non-current tax assets and liabilities are based upon an estimate of taxes refundable or payable for each of
the jurisdictions in which the Company is subject to tax. In the ordinary course of business, there is inherent uncertainty in
quantifying income tax positions. The Company assesses income tax positions and record tax benefits for all years subject to
examination based upon the Company’s evaluation of the facts, circumstances, and information available at the reporting
dates. For those tax positions where it is more likely than not that a tax benefit will be sustained, the Company records the
largest amount of tax benefit with a greater than 50% likelihood of being realized upon ultimate settlement with a taxing
authority that has full knowledge of all relevant information. For those income tax positions where it is not more likely than
not that a tax benefit will be sustained, no tax benefit is recognized in the financial statements. When applicable, associated
interest and penalties are recognized as a component of income tax expense. Accrued interest and penalties are included
within the related tax asset or liability on the Consolidated Balance Sheets.
Deferred income taxes are provided for temporary differences arising from differences in bases of assets and liabilities
for tax and financial reporting purposes. Deferred income taxes are recorded on temporary differences using enacted tax rates
in effect for the year in which the temporary differences are expected to reverse. The effect of a change in tax rates on deferred
tax assets and liabilities is recognized in income in the period that includes the enactment date. Deferred tax assets are reduced
by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred
tax assets will not be realized. Significant judgment is required in determining whether and to what extent any valuation
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
allowance is needed on the Company’s deferred tax assets. In making such a determination, the Company considers all
available positive and negative evidence including recent results of operations, scheduled reversals of deferred tax liabilities,
projected future income, and available tax planning strategies. See Note 9, “Income Taxes,” for further discussion of tax
valuation allowances.
On December 22, 2017, President Trump signed into law “H.R.1”, known as the “Tax Cuts and Jobs Act”, (the “Tax
Act”), which significantly changes existing U.S. tax laws. Following the enactment of the Tax Act, the Securities and
Exchange Commission (“SEC”) staff issued Staff Accounting Bulletin (“SAB”) No. 118, (“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 No. 740
(“ASC 740”), Income Taxes. 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 law that were in effect immediately
before the enactment of the Tax Act. At December 31, 2017, the Company determined that given the Company’s facts and
circumstances, no provisional estimates were needed, and, therefore, the Company has booked no provisional estimates as of
December 31, 2017. See Note 9, “Income Taxes,” for a discussion of the Company’s income tax accounting related to the
Tax Act.
The Company’s operations are subject to income and transaction taxes in the U.S. and in foreign jurisdictions.
Significant estimates and judgments are required in determining the Company’s worldwide provision for income taxes. Some
of these estimates are based on interpretations of existing tax laws or regulations. The ultimate amount of tax liability may
be uncertain as a result.
Note 2 — Recent Accounting Pronouncements
Recently adopted accounting pronouncements
In March 2016, the FASB issued Accounting Standards Update (“ASU”) No. 2016-09 (“ASU 2016-09”),
Compensation – Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.
ASU 2016-09 requires excess tax benefits and tax deficiencies (the difference between the deduction for tax purposes and
the compensation cost recognized for financial reporting purposes) be recognized as income tax expense or benefit in the
income statement. Previously, these amounts were recognized directly to shareholder’s equity. The excess tax benefit from
share-based compensation, previously classified as a financing activity, will be classified as an operating activity.
Additionally, cash paid when directly withholding shares on an employee’s behalf for tax withholding purposes, is classified
as a financing activity. The Company adopted this guidance on January 1, 2017. The adoption resulted in an increase to the
net operating loss carryforward deferred tax asset and a corresponding increase in valuation allowance of $6.9 million
attributable to excess tax benefits not previously recognized as they did not reduce income taxes payable. The Company
elected to continue to estimate forfeitures as part of the recognition of cost associated with equity awards. The Company
applied prospectively all excess tax benefits and tax deficiencies resulting from settlement of awards after the date of adoption.
No adjustments were recorded for any windfall benefits previously recorded in additional paid-in capital.
Recently issued accounting pronouncement not yet adopted
In May 2014, the FASB issued ASU No. 2014-09 (“ASU 2014-09”), Revenue from Contracts with Customers
(Topic 606). The update requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer
of promised goods or services to customers and will replace most existing revenue recognition guidance in GAAP when it
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
becomes effective. The update also requires more detailed disclosures to enable readers of financial statements to understand
the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. ASU 2014-09
was originally effective for annual reporting periods beginning after December 15, 2016, including interim periods within
that reporting period. On July 9, 2015, the FASB voted to approve a one-year deferral of the effective date of ASU 2014-09.
Additionally, the FASB decided to permit early adoption, but not before the original effective date (that is, annual periods
beginning after December 15, 2016). ASU 2014-09 permits the use of either the full retrospective or cumulative effect
transition (modified retrospective) method.
In March and April 2016, the FASB issued ASU No. 2016-08 (“ASU 2016-08”), Revenue from Contracts with
Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) and ASU No. 2016-
10 (“ASU 2016-10”), Revenue from Contracts with Customers (Topic 606) Identifying Performance Obligations and
Licensing, respectively. The amendments in these updates are intended to improve the operability and understandability of
the implementation guidance on principal versus agent considerations and to clarify two aspects of Topic 606: identifying
performance obligations and the licensing implementation guidance, while retaining the related principles for those areas.
The effective date and transition requirements for both ASU 2016-08 and ASU 2016-10 are the same as those for ASU 2014-
09 as deferred.
To assess the impact of and to implement Topic 606, the Company formed a project team, which has operated since
2014, to evaluate internal processes. The Company plans to adopt Topic 606 as of January 1, 2018 and expects to use the full
retrospective transition method, pending the final results of our quantitative analysis of Oil & Gas segment - License Revenue
which will be completed in the first quarter of 2018. The Company continues to evaluate the effect that ASU 2014-09 will
have on its financial statements, as well as the impact that the standard will have on the Company’s disclosures. The Company
is implementing changes to its current policies and practices, and internal controls over financial reporting to address the
requirements of the standard.
Water Segment Revenue. The Company expects that the deliverables identified under the current guidance will be
consistent with the performance obligations identified under ASC 606. Revenue recognition for the performance obligations
accounted for under ASC 606 is expected to be consistent with current guidance given the transfer of control of the promised
goods or services follows the same pattern. The Company has completed the quantitative assessment of the Water segment
at December 31, 2017 and the Company does not expect the adoption of ASC 606 to have a material impact on the timing of
revenue and expense recognition.
Oil & Gas Segment - Percentage of Completion Revenue. The Company expects that the deliverables under the current
guidance will be consistent with the performance obligations identified under ASC 606. The Company is in process of
completing the quantitative assessment of the adoption impact. At this time, the Company does not expect that adoption of
ASC 606 will have a material impact on the timing of revenue and expense recognition; however, the analysis will be
completed in the first quarter of 2018. Revenue recognition for the performance obligations accounted for under ASC 606 is
expected to be materially consistent with current guidance given the transfer of control of the promised goods or services
occurs over time under ASC 606 and the Company is applying percentage of completion accounting pursuant to ASC 605-
35 under legacy GAAP.
Oil & Gas Segment - License Revenue. The Company expects to complete its assessment of the impact of ASC 606
on its licensing and development agreement during the first quarter of 2018. Based on work performed to date, the Company
expects that there may be a material difference in the timing of revenue recognition under the new standard, with the most
likely impact being an overall acceleration of the recognition of deferred revenue for this license agreement. Under existing
guidance, license revenue associated with the up-front payment is recognized on a straight-line basis over the fifteen-year
term of the license, while substantive milestone payments are to be recognized when achieved. Under ASC 606, because the
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ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Company concluded that the license represents functional intellectual property and that the license is not distinct from the
research and development services to be provided prior to product commercialization, the transaction price allocated to this
performance obligation will be recognized over the period required to result in product commercialization (which is currently
estimated to be complete in 2020) instead of over the entire license period. Further, the milestone method of accounting has
been eliminated. As such, instead of recognizing the full amount of the milestone as revenue in the period in which it is
achieved, the Company will revise its estimate of the transaction price to include development milestone payments only when
they become probable of achievement and recognized in a manner consistent with the measure of progress. The Company
also believes that its obligation to provide when and if available updates to its technology in the period subsequent to product
commercialization represents a distinct performance obligation from our license and development efforts. The transaction
price allocated to this stand-ready performance obligation will be recognized straight-line over the period commencing after
product commercialization. At this time, the Company is working closely with its engineering team to finalize the appropriate
measures of progress to be used to determine the amount of revenue to recognize in each period prior to product
commercialization.
In January 2016, the FASB issued ASU No. 2016-01 (“ASU 2016-01”), Financial Instruments - Overall (Subtopic 825-
10): Recognition and Measurement of Financial Assets and Financial Liabilities. ASU 2016-01 modifies certain aspects of
the recognition, measurement, presentation, and disclosure of financial instruments. For public entities, ASU 2016-01 is
effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. The Company adopted
ASU 2016-01 on January 1, 2018. The Company expects the adoption ASU 2016-01 will not have a material impact on its
financial statements.
In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), which supersedes ASC Topic 840, Leases
(Topic 840) and provides principles for the recognition, measurement, presentation and disclosure of leases for both lessees
and lessors. The FASB has continued to clarify this guidance through the issuance of additional ASUs. The new standard
requires lessees to apply a dual approach, classifying leases as either finance or operating leases based on the principle of
whether or not the lease is effectively a financed purchase by the lessee. This classification will determine whether lease
expense is recognized based on an effective interest method or on a straight-line basis over the term of the lease, respectively.
A lessee is also required to record a right-of-use asset and a lease liability for all leases with a term of greater than twelve
months regardless of classification. Leases with a term of twelve months or less will be accounted for similar to existing
guidance for operating leases. The standard will be effective for annual and interim periods beginning after December 15,
2018, with early adoption permitted upon issuance. The Company plans to early adopt this standard on January 1, 2018. The
Company plans to elect the available practical expedients and expects that the adoption of ASU 2016-02 will have no impact
to its Consolidated Statement of Operations; however, it will result in a net increase in a right-of-use asset of $2.9 million
and an increase in lease liability of $3.3 million on its Consolidated Balance Sheets.
In August 2016, the FASB issued ASU No. 2016-15 (“ASU 2016-15”), Statement of Cash Flows (Topic 230):
Classification of Certain Cash Receipts and Cash Payments. ASU 2016-15 impacts all entities that are required to present a
statement of cash flows under Topic 230. The amendment provides guidance on eight specific cash flow issues. For public
entities, ASU 2016-15 is effective for fiscal periods beginning after December 15, 2017 and interim periods within those
years. Adoption should be applied using a retrospective transition method to each period presented. The Company is adopting
this standard as of January 1, 2018. The Company expects the adoption of ASU 2016-15 to not have a material impact on its
financial statements.
In October 2016, the FASB issued ASU 2016-16 (“ASU 2016-16”), Income Taxes (Topic 740): Intra-Entity Transfers
of Assets Other Than Inventory. ASU 2016-16 requires recognition of the current and deferred income tax effects of an intra-
entity asset transfer, other than inventory, when the transfer occurs, as opposed to current GAAP, which requires companies
to defer the income tax effects of intra-entity asset transfers until the asset has been sold to an outside party. The income tax
- 63 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
effects of intra-entity inventory transfers will continue to be deferred until the inventory is sold. ASU 2016-16 is effective on
January 1, 2018, with early adoption permitted. The update is required to be adopted on a modified retrospective basis with
the cumulative-effect adjustment recorded to retained earnings as of the beginning of the period of adoption. The Company
is adopting this standard as of January 1, 2018. The Company expects the adoption of ASU 2016-16 to not have a material
impact on its financial statements.
In November 2016, the FASB issued ASU 2016-18 (“ASU 2016-18”), Statement of Cash Flows (Topic 230): Restricted
Cash. ASU 2016-18 is intended to reduce diversity in practice in the classification and presentation of changes in restricted
cash on the Consolidated Statement of Cash Flows. ASU 2016-18 requires that the Consolidated Statement of Cash Flows
explain the change in total cash and equivalents and amounts generally described as restricted cash or restricted cash
equivalents when reconciling the beginning-of-period and end-of-period total amounts. The standard also requires
reconciliation between the total cash and equivalents and restricted cash presented on the Consolidated Statement of Cash
Flows and the cash and cash equivalents balance presented on the Consolidated Balance Sheet. ASU 2016-18 is effective
retrospectively on January 1, 2018. The Company is adopting this standard as of January 1, 2018. The Company expects the
adoption of ASU 2016-18 to have a material impact on its Consolidated Statements of Cash Flows based on the restricted
cash balance on the balance sheet date.
In January 2017, the FASB issued ASU No. 2017-04, Goodwill and Other (Topic 350): Simplifying the Test for
Goodwill Impairment. ASU 2017-04 eliminates Step 2 of the goodwill impairment quantitative test and allows for the
determination of impairment by comparing the fair value of the reporting unit with its carrying amount. The amendments in
this update should be applied on a prospective basis. For public entities which are SEC filers, this amendment is effective for
annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. Early adoption is
permitted for testing dates after January 1, 2017. The Company expects to adopt this standard on January 1, 2020 and do not
expect the adoption of ASU 2017-04 to have a material impact on its financial statements.
In May 2017, the FASB issued ASU No. 2017-09, Compensation – Stock Compensation (Topic 718): Scope of
Modification Accounting. ASU 2017-09 provides guidance about which changes to the terms or conditions of a share-base
payment award require an entity to apply modification accounting under Topic 718. ASU 2017-09 is effective for annual
periods and interim periods within those annual periods, beginning after December 15, 2017. The Company is adopting this
standard as of January 1, 2018. The Company expects the adoption of ASU 2017-09 to not have an impact on its financial
position or results of operations.
In February 2018, the FASB issued ASU No. 2018-02 (“ASU 2018-02”), Income Statement – Reporting
Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.
ASU 2018-02 was issued to address the income tax accounting treatment of the stranded tax effects within other
comprehensive income due to the prohibition of backward tracing due to an income tax rate change that was initially recorded
in other comprehensive income. This issue came about from the enactment of the Tax Act that changed the Company’s
income tax rate from 35% to 21%. ASU 2018-02 changed current accounting whereby an entity may elect to reclassify the
stranded tax effect from accumulated other comprehensive income to retained earnings. The ASU 2018-02 is effective for
periods beginning after December 15, 2018 although early adoption is permitted. The Company does not expect the adoption
of ASU 2018-02 to have a material impact on its financial position or results of operations.
- 64 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 3 — Income (Loss) Per Share
Net income (loss) is divided by the weighted average number of common shares outstanding during the year to
calculate basic net income (loss) per common share. Basic earnings per share exclude any dilutive effects of stock options
and RSUs.
Diluted net income (loss) per common share reflects the potential dilution that would occur if outstanding stock options
to purchase common stock were exercised for common stock, using the treasury stock method, and the common stock
underlying outstanding restricted award was issued. Diluted earnings per share for the years ended December 31, 2017, 2016
and 2015, includes the dilutive effects of stock options and RSUs. Certain common stock issuable under stock options and
RSUs have been omitted from the 2017, 2016 and 2015 diluted net income per share calculations because their inclusion is
considered anti-dilutive.
The computation of basic and diluted net income (loss) per share is presented in the following table.
Year Ended December 31,
2017
2016
2015
(In thousands, except per share amounts)
Numerator:
Net income (loss) ............................................................................................. $
12,350 $
1,034 $
(11,638)
Denominator:
Basic weighted average common shares outstanding .......................................
Weighted average effect of dilutive stock awards ............................................
Diluted weighted average common shares outstanding ....................................
53,701
1,911
55,612
52,341
3,110
55,451
52,151
—
52,151
Net income (loss) per share:
Basic ................................................................................................................. $
Diluted ............................................................................................................. $
0.23 $
0.22 $
0.02 $
0.02 $
(0.22)
(0.22)
The potential common shares were excluded from the computation of diluted net income (loss) per share as their effect
would have been anti-dilutive is presented in the following table.
Anti-dilutive shares excluded from net income (loss) per share calculation ........
1,810
2,987
7,198
Year Ended December 31,
2017
2016
2015
(In thousands)
- 65 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 4 — Other Financial Information
Cash, Cash Equivalents and Restricted Cash
The Company pledged cash in connection with certain stand-by letters of credit and company credit cards. The
Company deposited corresponding amounts into accounts at several financial institutions. See Note 7, “Long-term Debt and
Lines of Credit,” for additional discussion related to the Company’s stand-by letters of credit and restricted cash requirements.
The Company’s cash, cash equivalents, and restricted cash are presented in the table below.
Cash and cash equivalents ...................................................................................................................... $
Restricted cash ........................................................................................................................................
Total Cash, cash equivalents, and Restricted cash .............................................................................. $
(In thousands)
27,780 $
2,846
30,626 $
61,364
4,384
65,748
December 31,
2017
December 31,
2016
Unbilled Receivables
The Company’s unbilled receivables pertaining to customer contractual holdback provisions, whereby the Company
will invoice the final retention payment(s) due under certain sales contracts within 12 months. Customer holdbacks represent
amounts intended to provide a form of security for the customer; accordingly, these receivables have not been discounted to
present value. As of December 31, 2017 and 2016, all unbilled receivables were current.
Cost and Estimated Earnings in Excess of Billings
Cost and estimated earnings on uncompleted contracts is presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Estimated earnings to date .................................................................................................................. $
Estimated costs to date .......................................................................................................................
Subtotal ...........................................................................................................................................
Net billings to date .............................................................................................................................
6,000 $
(4,525)
1,475
2,718
Total ............................................................................................................................................. $
4,193 $
Included in accompanying balance sheets:
Cost and estimated earnings in excess of billings ........................................................................... $
Unbilled project costs ......................................................................................................................
Total ............................................................................................................................................. $
4,998 $
(805)
4,193 $
2,170
(1,496)
674
82
756
1,825
(1,069)
756
Unbilled project costs are included in Accrued expenses and other current liabilities on the Consolidated Balance
Sheets.
- 66 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Inventories
Inventories are stated at the lower of cost (using the first-in, first-out method) or market and are presented by category
in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Raw materials ..................................................................................................................................... $
Work in process ..................................................................................................................................
Finished goods ....................................................................................................................................
Inventories, net ................................................................................................................................ $
1,899 $
2,191
1,424
5,514 $
1,783
1,146
1,621
4,550
Valuation adjustments for excess and obsolete inventory, reflected as a reduction of inventory at December 31, 2017
and 2016 was $0.7 million and $1.4 million, respectively.
Prepaid and Other Current Assets
Prepaid expenses and other current assets by category are presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Interest receivable ............................................................................................................................... $
Supplier advances ...............................................................................................................................
Insurance ............................................................................................................................................
Software license .................................................................................................................................
Other prepaid expenses and current assets..........................................................................................
439 $
124
256
193
330
272
73
231
216
519
Total prepaid and other current assets ............................................................................................. $
1,342 $
1,311
Property and Equipment
Property and equipment held for use by category are presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Machinery and equipment .................................................................................................................. $
Leasehold improvements ....................................................................................................................
Software .............................................................................................................................................
Office equipment, furniture, and fixtures ...........................................................................................
Automobiles .......................................................................................................................................
Construction in progress .....................................................................................................................
Total property and equipment .........................................................................................................
Less: accumulated depreciation and amortization ..............................................................................
Property and equipment, net ......................................................................................................... $
20,813 $
10,458
2,985
2,699
114
466
37,535
(24,142)
13,393 $
14,781
10,326
2,382
1,910
114
515
30,028
(21,385)
8,643
- 67 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Construction in progress costs at December 31, 2017 primarily relates to R&D equipment received but not placed in
service. Construction in progress costs at December 31, 2016 primarily relates to software and system upgrades.
Depreciation expense related to all depreciable property and equipment is presented in the following table.
Years Ended December 31,
2017
2016
2015
(In thousands)
Depreciation expense .......................................................................................... $
3,035 $
3,049 $
3,203
Accrued Expenses and Other Current Liabilities
Accrued expenses and other current liabilities by category are presented in the following table.
Payroll and commissions payable ....................................................................................................... $
Other accrued expenses and current liabilities ....................................................................................
Unbilled project costs .........................................................................................................................
Total accrued expenses and other current liabilities ........................................................................ $
6,071 $
2,446
805
9,322 $
5,697
2,253
1,069
9,019
December 31,
2017
December 31,
2016
(In thousands)
Deferred Revenue
Deferred revenue by category are presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Current deferred revenue
Deferred license and development revenue, current ........................................................................ $
Deferred product revenue, current ...................................................................................................
Total current deferred revenue ......................................................................................................
Non-current deferred revenue
Deferred license and development revenue, non-current ................................................................
Deferred product revenue, non-current ...........................................................................................
Total non-current deferred revenue ..............................................................................................
Total deferred revenue ............................................................................................................... $
5,000 $
611
5,611
58,958
48
59,006
64,617 $
5,000
1,201
6,201
63,958
—
63,958
70,159
- 68 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Non-Current Liabilities
Other non-current liabilities consisted only of deferred rent expense.
Deferred rent expense, non-current .................................................................................................. $
358 $
554
Accumulated Other Comprehensive Loss
Changes in accumulated other comprehensive loss by component are presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Foreign Currency
Translation
Adjustments
Unrealized Losses
on Investments
(In thousands)
Total
Accumulated
Other
Comprehensive
Loss
Balance, December 31, 2015 .............................................................................. $
Other comprehensive loss, net..........................................................................
Balance, December 31, 2016 ..............................................................................
Other comprehensive income (loss), net ..........................................................
Balance, December 31, 2017 .............................................................................. $
(63) $
(27)
(90)
57
(33) $
(1) $
(27)
(28)
(64)
(92) $
(64)
(54)
(118)
(7)
(125)
There were no reclassifications of amounts out of accumulated other comprehensive loss, as there have been no sales
of securities or translation adjustments that impacted other comprehensive loss during the years presented. The tax impact of
the changes in accumulated other comprehensive loss was not material.
Advertising Expense
Advertising expense is charged to operations during the year in which it is incurred. Total advertising expense was not
material for the years ended December 31, 2017, 2016 and 2015.
Note 5 — Investments and Fair Value Measurements
The Company’s cash, cash equivalents and short-term investments are presented in the following table.
December 31,
2017
December 31,
2016
Cash and cash equivalents ...................................................................................................................... $
Short-term investments ...........................................................................................................................
(In thousands)
27,780 $
70,020
61,364
39,073
Total cash, cash equivalents and marketable securities ....................................................................... $
97,800 $
100,437
As of December 31, 2017, available-for-sale investments of $0.3 million were reported in Cash and cash equivalents
on the Consolidated Balance Sheets. As of December 31, 2016, all available-for-sale investments were reported in Short-term
investments on the Consolidated Balance Sheets.
- 69 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Available-for-Sale Investments
The Company’s investments are all classified as available-for-sale. As of December 31, 2017 and 2016, all available-
for-sale investments were classified as short-term, with maturities less than 12 months. There were no sales of available-for-
sale investments during the years ended December 31, 2017 and 2016.
Available-for-sale investments as of December 31, 2017 and 2016 are presented in the following tables.
December 31, 2017
Amortized
Cost
Gross
Unrealized
Holding Gains
Gross
Unrealized
Holding Losses
Fair Value
U.S. Treasury securities ........................................................ $
Corporate notes and bonds ...................................................
Municipal notes and bonds ...................................................
Total available-for-sale investments .................................. $
16,755 $
53,367
247
70,369 $
(In thousands)
— $
—
—
— $
December 31, 2016
(14) $
(77)
—
(91) $
16,741
53,290
247
70,278
Amortized
Cost
Gross
Unrealized
Holding Gains
Gross
Unrealized
Holding Losses
Fair Value
Corporate notes and bonds ................................................... $
Total available-for-sale investments .................................. $
39,100 $
39,100 $
(In thousands)
6 $
6 $
(33 ) $
(33 ) $
39,073
39,073
The Company monitors investments for other-than-temporary impairment. It was determined that unrealized gains and
losses at December 31, 2017 and 2016, are temporary in nature, because the changes in market value for these securities
resulted from fluctuating interest rates, rather than a deterioration of the credit worthiness of the issuers. The Company is
unlikely to experience gains or losses if these securities are held to maturity. In the event that the Company disposes of these
securities before maturity, it is expected that the realized gains or losses, if any, will be immaterial.
Expected maturities can differ from contractual maturities because borrowers may have the right to prepay obligations
without prepayment penalties. The amortized cost and fair value of available-for-sale securities that had stated maturities as
of December 31, 2017 are shown by contractual maturity in the following table.
December 31, 2017
Amortized Cost
Fair Value
(In thousands)
Due in one year or less ....................................................................................................................... $
70,369 $
70,278
Fair Value of Financial Instruments
The Company follows the authoritative guidance for fair value measurements and disclosures that, among other things,
defines fair value, establishes a consistent framework for measuring fair value, and expands disclosure for each major asset
and liability category measured at fair value on either a recurring or nonrecurring basis. Fair value is defined as an exit price
that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. As
such, fair value is a market-based measurement that should be determined based on assumptions that market participants
would use in pricing an asset or liability.
- 70 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Level 1 — Quoted prices (unadjusted) in active markets for identical assets or liabilities;
Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable; and
Level 3 — Unobservable inputs in which little or no market activity exists, therefore requiring an entity to develop its
own assumptions that market participants would use in pricing.
The carrying values of cash and cash equivalents, restricted cash, accounts receivable, unbilled receivables, cost and
estimated earnings in excess of billings, accounts payable, and other accrued expenses approximate fair value due to the
short-term maturity of those instruments. For the Company’s investments in available-for-sale securities, if quoted prices in
active markets for identical investments are not available to determine fair value (Level 1), then the Company uses quoted
prices for similar assets or inputs other than quoted prices that are observable either directly or indirectly (Level 2). The
investments included in Level 2 consist of corporate notes and bonds, municipal notes and bonds and U.S. Treasury securities.
The fair value of financial assets and liabilities measured on a recurring basis is presented in the following tables.
Fair Value Measurement at Reporting Date Using
December 31,
2017
Level 1
Inputs
Level 2
Inputs
Level 3
Inputs
(In thousands)
Assets:
Cash equivalents
Corporate notes and bonds ................................................ $
Total cash equivalents ....................................................
258 $
258
Short-term investments
U.S. Treasury securities ....................................................
Corporate notes and bonds ................................................
Municipal notes and bonds ................................................
Total short-term investments ..........................................
Total assets................................................................... $
16,741
53,032
247
70,020
70,278 $
— $
—
—
—
—
—
— $
258 $
258
16,741
53,032
247
70,020
70,278 $
—
—
—
—
—
—
—
Fair Value Measurement at Reporting Date Using
December 31,
2016
Level 1
Inputs
Level 2
Inputs
Level 3
Inputs
(In thousands)
Assets:
Short-term investments
Corporate notes and bonds ................................................ $
Total short-term investments ..........................................
Total assets................................................................... $
39,073 $
39,073
39,073 $
— $
—
— $
39,073 $
39,073
39,073 $
—
—
—
During the years ended December 31, 2017 and 2016, the Company had no transfers of financial assets and liabilities
between Level 1 and Level 2.
The fair value and gross unrealized losses on the available-for-sale securities that have been in a continuous unrealized
loss position, aggregated by type of investment instrument as of December 31, 2017 and 2016 are summarized in the following
table. All of the Company’s available-for-sale investments were short-term with maturities less than 12 months. Available-
for-sale investments that were in an unrealized gain position have been excluded from the following table.
- 71 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2017
December 31, 2016
Fair Value
Gross
Unrealized
Losses
Fair Value
Gross
Unrealized
Losses
U.S. Treasury securities ........................................................ $
Corporate notes and bonds ...................................................
Municipal notes and bonds ...................................................
Total available-for-sale investments .................................. $
10,162 $
53,222
247
63,631 $
(In thousands)
(14) $
(77)
—
(91) $
— $
29,667
—
29,667 $
—
(33)
—
(33)
Note 6 — Goodwill and Intangible Assets
Goodwill
The net carrying amount of goodwill as of December 31, 2017 and 2016 was $12.8 million. Goodwill resulted from
the Company’s acquisition of Pump Engineering, LLC in December 2009. The Company’s annual impairment test performed
as of July 1, 2017 determined that goodwill was not impaired. As of December 31, 2017 and 2016, no impairment of goodwill
has been recorded in the accompanying Consolidated Financial Statements.
Other Intangible Assets
The components of identifiable intangible assets, all of which are finite-lived, as of the date indicated were as follows
in the table below. All intangible assets are amortized on a straight-line basis over their useful life.
December 31, 2017
Gross
Carrying
Amount
Accumulated
Amortization
Accumulated
Impairment
Losses
Net
Carrying
Amount
Weighted
Average
Useful Life
(In thousands, except for weighted average useful life)
Developed technology ............................ $
Patents ....................................................
Total .................................................... $
6,100 $
585
6,685 $
(4,931) $
(443)
(5,374) $
— $
(42)
(42) $
1,169
100
1,269
10
18
December 31, 2016
Gross
Carrying
Amount
Accumulated
Amortization
Accumulated
Impairment
Losses
Net
Carrying
Amount
Weighted
Average
Useful Life
(In thousands, except for weighted average useful life)
Developed technology ............................ $
Patents ....................................................
Total .................................................... $
6,100 $
585
6,685 $
(4,321) $
(422)
(4,743) $
— $
(42)
(42) $
1,779
121
1,900
10
18
Accumulated impairment losses for patents at December 31, 2017 and 2016 include impairment losses from 2007 and
2010. No other impairment of intangible assets was identified during the periods presented for intangible assets.
Amortization of intangibles was $0.6 million for each of the years ended December 31, 2017, 2016 and 2015.
Future estimated amortization expense as of December 31, 2017 on intangible assets is presented in the following
table.
- 72 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Future
Amortization
(In thousands)
Year:
2018 ............................................................................................................................................................................. $
2019 .............................................................................................................................................................................
2020 .............................................................................................................................................................................
2021 .............................................................................................................................................................................
2022 .............................................................................................................................................................................
Thereafter .....................................................................................................................................................................
Total .......................................................................................................................................................................... $
629
575
16
12
11
26
1,269
Note 7 — Long-term Debt and Lines of Credit
Installment Loan
In March 2015, the Company entered into a loan agreement with a financial institution for a $55 thousand fixed-rate
installment loan with an annual interest rate of 6.35%. The loan is payable in equal monthly installments and matures on
April 2, 2020. The note is secured by the asset purchased.
Long-term debt as of December 31, 2017 and 2016 is presented in the following table.
Loan payable .......................................................................................................................................... $
Less: current portion ...............................................................................................................................
Total long-term debt ............................................................................................................................ $
27 $
(11)
16 $
38
(11)
27
December 31,
2017
December 31,
2016
(In thousands)
- 73 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Future minimum principal payments due under long-term debt arrangements as of December 31, 2017 is presented in
the following table.
Year:
Future Minimum
Payments
(In thousands)
2018 ............................................................................................................................................................................... $
2019 ...............................................................................................................................................................................
2020 ...............................................................................................................................................................................
Total ............................................................................................................................................................................ $
11
12
4
27
Loans and Stand-by Letters of Credit
Loan Agreement
In June 2012, the Company entered into a loan agreement with a financial institution (“Financial Institution 1”). The
loan agreement was amended in June 2015, (as amended, the “Loan Agreement”). The Loan Agreement provided for a total
available credit line of $16.0 million. Under the Loan Agreement, the Company was allowed to draw advances not to exceed
the lesser of the $16.0 million credit line or the credit line minus all outstanding revolving loans. Revolving loans could be
in the form of a base rate loan that bore interest equal to the prime rate or a Eurodollar loan that bore interest equal to the
adjusted LIBOR rate plus 1.25%. The Loan Agreement was terminated in January 2017.
Loan and Pledge Agreement
On January 27, 2017, the Company entered into a loan and pledge agreement (the “Loan and Pledge Agreement”) with
a financial institution (“Financial Institution 2”). The Loan and Pledge Agreement provides for a committed revolving credit
line of $16.0 million and an uncommitted revolving credit line of $4.0 million. Under the Loan and Pledge Agreement, the
Company is allowed to borrow and request letters of credit against the eligible assets held from time to time in the pledged
account maintained with Financial Institution 2. Revolving loans incur interest per annum at a base rate equal to the LIBOR
rate plus 1.5%. Any default bears the aforementioned interest rate plus an additional 2%. The unused portion of the credit
line is subject to a fee equal to the product of 0.2% per annum multiplied by the difference, if positive, between $16.0 million
and the average daily balance of all advances under the committed facility plus aggregate average daily undrawn amounts of
all letters of credit issued under the committed facility during the immediately preceding month or portion thereof. The Loan
and Pledge Agreement was amended on March 17, 2017 to increase the amount of allowable stand-by letters of credit held
with financial institutions other than Financial Institution 2 from $4.1 million to $5.1 million.
Stand-by Letters of Credit
In connection with the Loan Agreement, Financial Institution 1 issued stand-by letters of credit to the Company that
were subject to customary fees and expenses for issuance or renewal. The unused portion of the credit facility was subject to
a facility fee in an amount equal to 0.25% per annum of the average unused portion of the revolving line. The Loan Agreement
required the Company to maintain a cash collateral balance equal to 101% of all outstanding advances and all outstanding
stand-by letters of credit collateralized by the line of credit. With the termination of the Loan Agreement, the cash collateral
requirement was increased to 105% on all stand-by letters of credit and corporate credit cards at Financial Institution 1.
- 74 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
In September 2016, Financial Institution 2 issued stand-by letters of credit to the Company that were subject to
customary fees and expenses for issuance or renewal. Initially, Financial Institution 2 required a cash collateral equal to the
full outstanding amount of the stand-by letters of credit until the Loan and Pledge Agreement was put in place on January 27,
2017. As of that same date, this cash collateral requirement was removed when the Company entered into a loan and pledge
agreement with Financial Institution 2 (see Loan and Pledge Agreement above) and replaced with pledged U.S. Investments
held at Financial Institution 2 equal to the full outstanding amount of the stand-by letters of credit. These stand-by letters of
credit are subject to fees, in an amount equal to 0.7% per annum of the face amount of the letter of credit, that are payable
quarterly and are non-refundable.
In October 2016, the Company entered into stand-by letters of credit with a financial institution (“Financial
Institution 3”). Financial Institution 3’s stand-by letters of credit are secured by a cash collateral balance required equal to
the full outstanding amount of the stand-by letters of credit.
The financial institutions where the outstanding amounts of stand-by letters of credit are collateralized by restricted
cash or pledged U.S. investments are presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Financial Institution 1 ......................................................................................................................... $
Financial Institution 2 .........................................................................................................................
Financial Institution 3 .........................................................................................................................
Total ................................................................................................................................................ $
1,687 $
7,745
990
10,422 $
3,080
283
990
4,353
The Company’s total restricted cash balances by financial institution are presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Financial Institution 1 ......................................................................................................................... $
Financial Institution 2 (1) ......................................................................................................................
Financial Institution 3 .........................................................................................................................
Financial Institution 4 .........................................................................................................................
Total ................................................................................................................................................ $
1,771 $
—
990
85
2,846 $
3,111
283
990
—
4,384
____________
(1) Financial Institution 2 requires pledged U.S. Investments in lieu of restricted cash balances as of January 27, 2017.
- 75 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 8 — Commitments and Contingencies
Operating Lease Obligations
The Company leases facilities under fixed non-cancellable operating leases that expire on various dates through July
2021. Future minimum lease payments are presented in the following table.
Lease Amounts
(In thousands)
Year:
2018 ............................................................................................................................................................................... $
2019 ...............................................................................................................................................................................
2020 ...............................................................................................................................................................................
2021 ...............................................................................................................................................................................
Total ............................................................................................................................................................................ $
1,788
1,565
150
34
3,537
In October 2017, the Company entered into a sublease agreement for office space in Houston, Texas. The sublease
agreement is for a term of 3 years commencing in November 2017.
Rent and lease expense related to all of the Company’s leased property is presented in the following table.
Years Ended December 31,
2017
2016
2015
(In thousands)
Rent and lease expense ...................................................................................... $
1,699
$
1,422
$
1,485
Warranty
Changes in the Company’s accrued product warranty reserve are presented in the following table.
Years Ended December 31,
2017
2016
2015
(In thousands)
Balance, beginning of year ................................................................................. $
Warranty costs charged to cost of revenue ......................................................
Utilization charges against reserve ..................................................................
Release of accrual related to expired warranties .............................................
Balance, end of year ........................................................................................... $
406 $
246
(86)
(200)
366 $
461 $
208
(27)
(236)
406 $
755
135
(34)
(395)
461
During the year ended December 31, 2015, the Company adjusted previously established warranty reserves. The
adjustment related to expired warranties which increased gross profit and reduced net loss by $0.4 million.
- 76 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Purchase Obligations
The Company has purchase order arrangements with its vendors for which the Company has not received the related
goods or services as of December 31, 2017. These arrangements are subject to change based on the Company’s sales demand
forecasts, and the Company has the right to cancel the arrangements prior to the date of delivery. The majority of these
purchase order arrangements were related to various raw materials and components parts. As of December 31, 2017, the
Company had approximately $4.5 million of open cancellable purchase order arrangements related primarily to materials and
parts.
Guarantees
The Company enters into indemnification provisions under its agreements with other companies in the ordinary course
of business, typically with customers. Under these provisions, the Company generally indemnifies and holds harmless the
indemnified party for losses suffered or incurred by the indemnified party as a result of the Company’s activities, generally
limited to personal injury and property damage caused by the Company’s employees at a customer’s desalination plant in
proportion to the employee’s percentage of fault for the accident. Damages incurred for these indemnifications would be
covered by the Company’s general liability insurance to the extent provided by the policy limitations. The Company has not
incurred material costs to defend lawsuits or settle claims related to these indemnification agreements. As a result, the
estimated fair value of these agreements is not material. Accordingly, the Company had no liabilities recorded for these
agreements as of December 31, 2017 and 2016.
In certain cases, the Company issues warranty and product performance guarantees to its customers for amounts
generally equal to 10% or less of the total sales agreement to endorse the execution of product delivery and the warranty of
design work, fabrication, and operating performance of our devices. These guarantees are generally stand-by letters of credit
that typically remain in place for periods ranging up to 24 months, and in some cases up to 68 months. All stand-by letters of
credit at December 31, 2017 and 2016, was $10.4 million and $4.4 million, respectively. See Note 7, “Long-term Debt and
Lines of Credit,” for additional information about the Company’s stand-by letters of credit arrangements.
- 77 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 9 — Income Taxes
The Company’s U.S. and foreign components of consolidated income (loss) before income taxes and the benefit from
income taxes is presented in the following table.
Years Ended December 31,
2017
2016
2015
(In thousands)
Income (loss) before income taxes:
U.S. ................................................................................................................ $
Foreign ...........................................................................................................
Total income (loss) before income taxes ..................................................... $
$
11,992
(7,726)
4,266
$
$
6,158
(5,514)
644
$
Current tax provision (benefit):
Federal ........................................................................................................... $
State ...............................................................................................................
Foreign ...........................................................................................................
Current tax provision ................................................................................... $
441
12
18
471
$
$
Deferred tax (benefit) provision:
Federal ........................................................................................................... $
State ...............................................................................................................
Foreign ...........................................................................................................
Total deferred tax benefit ............................................................................ $
Total benefit for income taxes .................................................................. $
(8,997) $
(1,138)
1,270
(8,865) $
(8,394) $
—
16
46
62
$
$
$
248
3
(703)
(452) $
(390) $
(7,566)
(4,406)
(11,972)
—
(3)
20
17
225
(17)
(559)
(351)
(334)
On December 22, 2017, President Trump signed into law the Tax Act, which significantly changes existing U.S. tax
laws, including a reduction in the corporate tax rate from 35% to 21%, a move from a worldwide tax system to a territorial
system, as well as other changes. As a result of enactment of the legislation, the Company incurred a one-time income tax
expense during the fourth quarter of 2017 of $7.0 million related to the deemed repatriation tax on accumulated foreign
earnings (of which $0.3 million is a cash charge and the remaining $6.7 million represents a non-cash discrete tax expense
largely from the utilization of net operating loss carryovers). The Company will continue to review and refine this amount as
additional guidance is provided on the taxation of deemed repatriation income through the filing of the 2017 U.S. federal
income tax return. The Company also incurred a non-cash income tax expense of $2.5 million related to the remeasurement
of certain deferred tax assets and liabilities based on the recently enacted rates from the Tax Act.
The Company continues to evaluate the impact of the tax law changes related to state income taxes, the new income
tax provisions related to global intangible low-taxed income and deductions related to foreign derived intangible income. The
Company continues to assert that the accumulated foreign earnings are permanently reinvested. The Company should have
no U.S. federal income tax obligation should the Company decide in the future to repatriate its accumulated foreign earnings.
The Company has not estimated what the future foreign income tax or state income tax impact will be if the Company decides
to repatriate its accumulate foreign earnings in the future. As of December 31, 2017, the Company did not record any
provisional estimates related to the Tax Act.
- 78 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
A reconciliation of income taxes computed at the statutory federal income tax rate to the effective tax rate implied by
the accompanying Statements of Operations is presented in the following table.
Years Ended December 31,
2017
2016
2015
U.S. federal taxes at statutory rate .....................................................................
State income tax, net of federal benefit .............................................................
Deemed repatriation transition tax .....................................................................
Deferred tax remeasurement - Change in tax rates ............................................
Foreign rate differential .....................................................................................
Stock-based compensation ................................................................................
Non-deductible expenses ...................................................................................
Federal research credits .....................................................................................
Valuation allowance ..........................................................................................
Other ..................................................................................................................
Effective tax rate ............................................................................................
34 %
3 %
165 %
55 %
44 %
(14)%
2 %
(9)%
(476)%
(1)%
(197)%
34 %
3 %
— %
— %
359 %
(1)%
13 %
(64)%
(405)%
— %
(61)%
34 %
— %
— %
— %
(17)%
(8)%
— %
2 %
(9)%
1 %
3 %
The Company’s total deferred tax assets and liabilities is presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Deferred tax assets:
Net operating loss carry forwards ................................................................................................... $
Accruals and reserves ......................................................................................................................
Research and development credit carry forwards ............................................................................
Acquired intangibles .......................................................................................................................
Charitable contributions ..................................................................................................................
Total deferred tax assets ...............................................................................................................
Valuation allowance ........................................................................................................................
Net deferred tax assets ...............................................................................................................
Deferred tax liabilities:
Depreciation on property and equipment ........................................................................................
Unrecognized gain on translation of foreign currency ....................................................................
Goodwill .........................................................................................................................................
Total deferred tax liabilities ..........................................................................................................
Net deferred tax assets (liabilities) ............................................................................................. $
5,918 $
2,816
3,957
909
11
13,611
(3,411)
10,200
(650)
(5)
(1,643)
(2,298)
7,902 $
14,082
4,896
2,609
1,415
5
23,007
(21,067)
1,940
(630)
(40)
(2,233)
(2,903)
(963)
As reported on the balance sheet:
Non-current assets ........................................................................................................................... $
Non-current liabilities .....................................................................................................................
Net deferred tax assets (liabilities)................................................................................................ $
7,902 $
—
7,902 $
1,270
(2,233)
(963)
- 79 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The Company had gross deferred tax assets of approximately $13.6 million and $23.0 million at December 31, 2017
and 2016, respectively, relating principally to accrued expenses and tax effects of net operating loss and tax credit carry-
forwards. In asserting the recoverability of deferred tax assets, management considers whether it is more likely than not that
the assets will be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable
income during the periods in which those temporary differences become deductible.
The Company assesses the available positive and negative evidence to estimate if sufficient future taxable income will
be generated to use the existing deferred tax assets. In making such a determination, we consider all available positive and
negative evidence including recent results of operations, scheduled reversals of deferred tax liabilities, projected future
income, and available tax planning strategies.
In the U.S., significant pieces of objective positive evidence evaluated were the cumulative profit incurred in the U.S.
entity. The Company’s U.S. entity emerged out of 12 quarters of cumulative loss in the third quarter of 2017 into a position
of cumulative income, and followed in the fourth quarter of 2017 with strong results. The forecast for the Company’s U.S.
entity indicates that it is likely to continue to be in a profitable position, going forward. In addition, in December 2017, due
to the Tax Act, the Company’s U.S. entity had additional deemed repatriation income of $21.0 million. The Company’s U.S.
entity plans to use its net operating loss carryforwards to settle this transition tax, and, therefore, expects that it is more likely
than not that deferred tax assets will be used up by 2020. The impact of the Tax Act was a new piece of heavily weighted
evidence in the fourth quarter of 2017.
In Ireland, a significant piece of negative evidence was the cumulative losses of $16.6 million that incurred in the
Company’s Irish entity since inception over the three year period ended December 31, 2017. A cumulative loss in recent
years is a significant piece of negative evidence that is difficult to overcome, and there was limited positive evidence.
On the basis of this evaluation, as of December 31, 2017, the Company released the valuation allowance, totaling
$10.1 million on its U.S. federal (“Federal”) deferred tax assets and all of the Company’s U.S. state deferred tax assets with
the exception of the State of California (“California”) Research and Development (“R&D”) credit carryovers. As of
December 31, 2017, the Company continues to maintain a valuation allowance on its California R&D credit carryovers of
approximately $1.4 million. The Company will maintain a valuation allowance on its California R&D credit carryovers
because it is more likely than not, based on scheduling of utilization, that utilization would likely not occur until 2022, and it
is projected at that time that the Company will only be utilizing new California R&D credits as they are generated, that is,
not resulting in a net reduction. The Company’s policy with respect to California R&D credits is that they are utilized on a
last-in first-out basis.
In addition, as of December 31, 2017, the Company established a valuation allowance on its Irish entity’s deferred tax
assets totaling $2.0 million. The valuation allowance represents a provision for uncertainty as to the realization of tax benefits
from these deferred income tax assets. The Company will continue to evaluate the tax benefit uncertainty and will adjust, if
warranted, the valuation allowance in future periods to the extent that the Company’s deferred income tax assets become
more likely than not to be realizable.
- 80 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The following table presents the Company’s Federal, California, and foreign net operating loss carryforwards.
Federal ................................................................................................................................................ $
California ............................................................................................................................................
Ireland ................................................................................................................................................
Total net operating loss carryforwards ............................................................................................ $
December 31,
2017
December 31,
2016
(In thousands)
14,227 $
12,081
16,644
42,952 $
41,801
14,009
10,043
65,853
The net operating loss carryforwards, if not utilized, will begin to expire in 2019 for Federal, and 2031 for California.
Utilization of the net operating loss carryforward may be subject to a substantial annual limitation due to the ownership
change limitations provided by the U.S. Internal Revenue Code (“IRC”) and similar California provisions. The annual
limitation will result in the expiration of the net operating loss carryforwards before utilization. The Company has estimated
the amount which may ultimately be realized and recorded deferred tax assets accordingly. The Ireland net operating loss
carryforwards does not have an expiration date.
The following table presents the Company’s Federal and California R&D credit, minimum tax credit and foreign tax
credit carryforwards.
Federal .............................................................................................................................................. $
California ..........................................................................................................................................
Total credit carryforwards ............................................................................................................. $
December 31,
2017
December 31,
2016
(In thousands)
2,572 $
1,753
4,325 $
1,635
1,476
3,111
The federal R&D credit carryforwards, if not utilized, will start to expire in 2030. The foreign tax credit carryforwards
will begin to expire in 2026. The federal minimum tax credit carryforward will be refunded if not utilized no later than 2021.
The California credit carryforwards do not expire. Utilization of the credit carryforwards may be subject to a substantial
annual limitation due to the ownership change limitations provided by the IRC and similar California provisions.
Accounting for uncertain tax positions is based on judgment regarding the largest amount that is greater than 50%
likely of being realized upon the ultimate settlement with a taxing authority. The aggregate changes in the balance of the
gross unrecognized tax benefits is presented in the following table.
December 31,
2017
December 31,
2016
(In thousands)
Gross unrecognized tax benefits as of December 31, ......................................................................... $
Gross increases related to prior year tax position ............................................................................
Gross increases related to current year tax position ........................................................................
Gross unrecognized tax benefits as of December 31, ......................................................................... $
603 $
117
191
911 $
394
—
209
603
As of December 31, 2017, the Company had $0.9 million of unrecognized tax benefits, $0.5 million of which, if
recognized, would affect our effective tax rate.
- 81 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The Company adopted the accounting policy that interest and penalties are classified as part of its income taxes. There
are no accrued interest or penalties associated with any unrecognized tax benefits.
There are currently no examinations for Federal, California taxing authorities, and foreign tax authorities. The
Company believes that, as of December 31, 2017, the gross unrecognized tax benefits will not materially change in the next
twelve months. The Company believes that it has adequately provided for any reasonably foreseeable outcomes related to
any tax audits and that any settlement will not have a material adverse effect on the consolidated financial position or results
of operations. However, there can be no assurances as to the possible outcomes.
Note 10 — Stockholder’s Equity
Preferred Stock
The Company has the authority to issue 10,000,000 shares of $0.001 par value preferred stock. The Board of Directors
has the authority, without action by the Company’s stockholders, to designate and issue shares of preferred stock in one or
more series. The Board of Directors is also authorized to designate the rights, preferences, and voting powers of each series
of preferred stock, any or all of which may be greater than the rights of the common stock including restrictions of dividends
on the common stock, dilution of the voting power of the common stock, reduction of the liquidation rights of the common
stock, and delaying or preventing a change in control of the Company without further action by the Company’s stockholders.
To date, the Board of Directors has not designated any rights, preferences, or powers of any preferred stock, and as of
December 31, 2017 and 2016, no shares of preferred stock were issued or outstanding.
Common Stock
The Company has the authority to issue 200,000,000 shares of $0.001 par value common stock. Subject to the preferred
rights of the holders of shares of any class or series of preferred stock as provided by the Board of Directors with respect to
any such class or series of preferred stock, the holders of the common stock shall be entitled to receive dividends, as and
when declared by the Board of Directors. In the event of any liquidation, dissolution, or winding up of the Company, whether
voluntary or involuntary, after the distribution or payment to the holders of shares of any class or series of preferred stock as
provided by the Board of Directors with respect to any such class or series of preferred stock, the remaining assets of the
Company available for distribution to stockholders shall be distributed among and paid to the holders of common stock
ratably in proportion to the number of shares of common stock held by them.
At December 31, 2017, 58,168,433 shares were issued and 53,905,600 shares were outstanding. At December 31,
2016, 56,884,207 shares were issued and 53,162,551 shares were outstanding.
Stock Repurchase Program
In January 2016, the Board of Directors authorized a stock repurchase program under which the Company, at the
discretion of management, could repurchase up to $6.0 million in aggregate cost of the Company’s outstanding common
stock through June 30, 2016 (the “January 2016 Authorization”). In May 2016, the Board of Directors rescinded the January
2016 Authorization and authorized a new stock repurchase program under which the Company, at the discretion of
management, could repurchase up to $10.0 million in aggregate cost of the Company’s outstanding common stock through
October 31, 2016 (the “May 2016 Authorization”). At December 31, 2016, 673,700 shares, at an aggregate cost of
$4.1 million, had been repurchased under the January 2016 Authorization and 568,500 shares, at an aggregate cost of
$5.3 million, had been repurchased under the May 2016 Authorization. The May 2016 Authorization expired in October 2016
and there was no repurchase authorization in place at December 31, 2016.
- 82 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
In March 2017, the Board of Directors authorized a stock repurchase program under which the Company, at the
discretion of management, could repurchase up to $15.0 million in aggregate cost of the Company’s outstanding common
stock through September 30, 2017 (the “March 2017 Authorization”). As of December 31, 2017, 541,177 shares, at an
aggregate cost of $4.3 million had been repurchased under the March 2017 Authorization. The Company accounts for stock
repurchases using the cost method. Cost includes fees charged in connection with acquiring the outstanding common stock.
On March 7, 2018, the Board of Directors authorized a stock repurchase program under which the Company, at the
discretion of management, may repurchase up to $10.0 million in aggregate cost of the Company’s outstanding common
stock. Under the newly authorized repurchase program, purchases of shares of common stock may be made from time to time
in the open market, or in privately negotiated transactions, in compliance with applicable state and federal securities laws.
The timing and amounts of any purchases will be based on market conditions and other factors including price, regulatory
requirements, and capital availability. The share buyback program does not obligate the Company to acquire any specific
number of shares in any period, and may be expanded, extended, modified or discontinued at any time without prior notice.
Under the Company’s stock repurchase programs, from March 2012 through December 31, 2017, the Company spent
an aggregate $20.4 million to repurchase 4.3 million shares. In addition to repurchases under the Company’s stock repurchase
programs, during the year ended December 31, 2017, the Company spent $0.3 million to settle employee tax withholding
obligations due upon the vesting of RSUs and withheld an equivalent value of shares from the shares provided to the
employees upon vesting. During the years ended December 31, 2016 and 2015, the Company did not have to settle employee
tax withholding obligations due upon the vesting of RSUs since there were no RSU vestings during these periods.
Warrants
There were no warrants outstanding as of December 31, 2017. All outstanding warrants had been exercised as of
December 31, 2015.
Note 11 — Stock-based Compensation
Stock Option Plans
In June 2016, the stockholders approved the 2016 Incentive Plan (the “2016 Plan”), that permits the grant of stock
options, stock appreciation rights (“SARs”), restricted stock (“RS, RSAs, or RSUs”), performance units, performance shares,
and other stock-based awards to employees, officers, directors, and consultants. Prior to the approval of the 2016 Plan, the
Company maintained the Amended and Restated 2008 Equity Incentive Plan (the “2008 Plan”). Stock-based awards granted
under the Plan and the 2008 Plan, generally vest over 4 years and expire no more than 10 years after the date of grant. Subject
to adjustments, as provided in the 2016 Plan, the number of shares of common stock initially authorized for issuance under
the 2016 Plan was 4,441,083 shares (which consist of 3,830,000 new share awards plus 611,083 share awards that were
authorized and unissued under the 2008 Plan) plus up to 7,635,410 shares that were set aside for awards granted under the
2008 Plan that are subsequently forfeited. The 2016 Plan supersedes all previously issued stock incentive plans (including
the 2008 Plan) and is currently the only available plan from which awards may be granted.
Shares available for grant under the Plan were 3,945,653 shares and 4,532,141 shares at December 31, 2017 and 2016,
respectively.
- 83 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Stock-based Compensation Expense
Stock-based compensation expense related to the fair value measurement of awards granted to employees by financial
line and by type of award is presented in the following table.
Stock-based compensation expense by financial line:
Cost of revenue ................................................................................................ $
General and administrative ...............................................................................
Sales and marketing .........................................................................................
Research and development ...............................................................................
Total stock-based compensation expense ...................................................... $
Stock-based compensation expense by type of award:
Options ............................................................................................................. $
RSUs ................................................................................................................
Total stock-based compensation expense ...................................................... $
Years Ended December 31,
2017
2016
2015
(In thousands)
158 $
2,218
821
890
4,087 $
3,331 $
756
4,087 $
113 $
2,057
524
569
3,263 $
3,005 $
258
3,263 $
130
3,139
436
354
4,059
3,915
144
4,059
The Company estimates forfeitures at the time of grant and revise those estimates periodically in subsequent periods
if actual forfeitures differ from those estimates. The Company uses historical data to estimate pre-vesting option forfeitures
and record stock-based compensation expense only for those awards that are expected to vest. All stock-based payment
awards are amortized on a straight-line basis over the requisite service periods of the awards, which are generally the vesting
periods. If the Company’s actual forfeiture rate is materially different from its estimate, the stock-based compensation
expense could be significantly different from what the Company has recorded in the current period.
The estimated forfeiture rates used in determining the expense in the table above are presented in the following table.
For years ended December 31,
2017
2016
2015
4-year options ........................................................................................................
16.275%
13.513%
13.737%
1-year options ........................................................................................................
—%
—%
—%
Share-based compensation cost related to unvested stock options and RSU’s will generally be amortized on a
straight-line basis over the remaining average service period. The following table presents the unamortized compensation
cost and weighted average service period of all unvested outstanding awards as of December 31, 2017.
Stock options ..................................................................................................................................... $
RSUs .................................................................................................................................................
4,964
1,859
2.3
2.8
Unamortized
Compensation
Costs
(In thousands)
Weighted
Average Service
Period
(In years)
- 84 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Vested Stock Options and RSUs
The total grant date fair value of stock options and RSUs vested during the period are presented in the following table.
Stock options ........................................................................................................... $
RSUs .......................................................................................................................
Total grant date fair value of stock options and RSUs vested during the period .. $
Stock Option Activity
Years Ended December 31,
2017
2016
2015
(In thousands)
3,375 $
783
4,158 $
2,977 $
—
2,977 $
4,657
145
4,802
The following table summarizes the stock option activity under the 2016 Plan and 2008 Plan.
Weighted
Average
Exercise
Price
Weighted
Average
Remaining
Contractual
Life (in Years)
Aggregate
Intrinsic
Value (1)
Shares
(In thousands, except for weighted average exercise price and weighted average
remaining contractual life)
Balance, December 31, 2014 ................................................
Granted ..............................................................................
Exercised ...........................................................................
Forfeited ............................................................................
Balance, December 31, 2015 ................................................
Granted ..............................................................................
Exercised ...........................................................................
Forfeited ............................................................................
Balance, December 31, 2016 ................................................
Granted ..............................................................................
Exercised ...........................................................................
Forfeited ............................................................................
Balance, December 31, 2017 ................................................
Vested and exercisable as of December 31, 2017 .................
Vested and exercisable as of December 31, 2017 and
6,276 $
2,612
(350)
(1,340)
7,198
904
(1,936)
(283)
5,883
677
(1,226)
(242)
5,092 $
3,449 $
4.51
3.01
3.22
3.18
3.97
8.63
3.41
5.30
4.81
9.57
4.49
6.60
5.43
4.65
$
942
14,665
6,798
17,735
14,218
6.6 $
5.8 $
expected to vest thereafter .................................................
4,860 $
5.32
6.5 $
17,372
____________
(1) The aggregate intrinsic value is calculated as the difference between the exercise price of the underlying options and the
fair value of the Company’s common stock at the time of exercise. The aggregate intrinsic value at December 31, 2017
is calculated as the difference between the exercise price of the underlying options and the fair value of the Company’s
common stock as of the end of the period.
- 85 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Restricted Stock Awards
There were no RSAs outstanding as of December 31, 2017.
Restricted Stock Units
RSUs awarded in 2016 vests 25% on the first anniversary of the grant date and 1/48th monthly thereafter dependent
upon continued employment. RSUs awarded in 2017 vests 25% annually over the 4 years from date of grant and is dependent
upon continued employment. As RSUs vest, the units will be settled in shares of common stock based on a one-to-one ratio.
The units were valued based on the market price on the date of grant.
The following table summarizes the RSU activity under the 2016 Plan.
Balance December 31, 2014 ...............................................................................................................
Vested .............................................................................................................................................
Balance, December 31, 2015 ..............................................................................................................
Awarded ..........................................................................................................................................
Balance, December 31, 2016 ..............................................................................................................
Awarded ..........................................................................................................................................
Vested .............................................................................................................................................
Forfeited ..........................................................................................................................................
Balance, December 31, 2017 ..............................................................................................................
Fair Value Assumptions
Stock Options
Weighted
Average
Grant-Date
Fair Value
Shares
(In thousands, except for weighted
average grant-date fair value)
28 $
(28)
—
214
214
162
(91)
(11)
274
5.27
5.27
—
8.65
8.65
10.14
8.65
8.52
9.54
The fair value of stock options granted to employees is based on the Black-Scholes option pricing model. To determine
the inputs for the Black-Scholes option pricing model, the Company is required to develop several assumptions, which are
highly subjective. The Company determines these assumptions as follows:
Expected Term: The Company uses its historical data to determine the expected term of options based on historical
exercise data. As there was no historical exercise data for non-employee directors, the Company determines the expected
term based on the simplified method.
Expected Volatility: The Company determines expected volatility based on its historical data and the corresponding
expected term that was determined using the Company’s historical exercise data.
Risk-Free Interest Rate: The risk-free rate is based on U.S. Treasury issues with remaining terms similar to the
expected term on the stock options granted.
Dividend Yield: The Company has never declared or paid any cash dividends and do not plan to pay cash dividends in
the foreseeable future; therefore, the Company uses an expected dividend yield of zero in the valuation model.
- 86 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The estimated grant date fair values of stock options granted to employees were calculated using the Black-Scholes
option pricing model based on the assumptions in the following table.
Weighted average expected life (years) .................................................................
For years ended December 31,
2017
4.50
2016
4.38
2015
4.71
Weighted average expected volatility ....................................................................
Risk-free interest rate ............................................................................................ 1.64% – 1.99% 1.03% – 1.32% 1.12% – 2.19%
80.22%
61.79%
80.35%
Weighted average dividend yield ..........................................................................
—%
—%
—%
Restricted Stock Units
The fair value of RSUs granted to employees is based on the Company’s common stock price on the date of grant.
Awards Granted in 2018
On February 1, 2018, the Company granted options and RSUs to certain officers and employees. The options and
RSUs granted are presented in the following table.
Options ...................................................................................
RSUs ......................................................................................
810,172 $
221,663
7.50
—
4 years
4 years
Total ....................................................................................
1,031,835
Shares
Exercise Price
Vesting Term(1)
Expiration from
Date of Grant
10 years
**
____________
** Not applicable.
(1) Any unvested options and RSUs are forfeited upon the employee’s termination.
Note 12 — Business Segment
The Company is an energy solutions provider to industrial fluid flow markets worldwide. The Company manufactures
and sells high-efficiency ERDs and pumps as well as related products and services. The Company’s chief operating decision-
maker (“CODM”) is the chief executive officer (“CEO”).
The Company’s reportable operating segments consist of the Water segment and the Oil & Gas segment. These
segments are based on the industries in which the products are sold, the type of energy recovery device sold, and the related
products and services. The Water segment consists of revenue associated with products sold for use in reverse osmosis water
desalination, as well as the related identifiable expenses. The Oil & Gas segment consists of product revenue associated with
products sold for use in gas processing, chemical processing, and hydraulic fracturing and license and development revenue
associated with hydraulic fracturing, as well as related identifiable expenses. Operating income for each segment excludes
other income and expenses and certain expenses managed outside the operating segment. Costs excluded from operating
income include various corporate expenses such as income taxes and other separately managed general and administrative
expenses not related to the identified segments. Assets and liabilities are reviewed at the consolidated level by the CODM
and are not accounted for by segment. The CODM allocates resources to and assesses the performance of each operating
segment using information about its revenue and operating income (loss).
- 87 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The summary of financial information by segment is presented in the following tables.
Year Ended December 31, 2017
Water
Oil & Gas
Total
Product revenue ................................................................................................ $
Product cost of revenue ....................................................................................
Product gross profit ........................................................................................
(In thousands)
54,301 $
16,032
38,269
3,855 $
3,029
826
License and development revenue ....................................................................
—
5,000
Operating expenses:
General and administrative .............................................................................
Sales and marketing .......................................................................................
Research and development .............................................................................
Amortization of intangibles ............................................................................
Operating expenses ......................................................................................
1,401
5,787
1,064
631
8,883
1,565
2,228
12,217
—
16,010
Operating income (loss) ................................................................................... $
29,386 $
(10,184)
Less: Corporate operating expenses .................................................................
Consolidated operating income ........................................................................
Non-operating income ......................................................................................
Income before income taxes ...........................................................................
$
58,156
19,061
39,095
5,000
2,966
8,015
13,281
631
24,893
19,202
15,926
3,276
680
3,956
Year Ended December 31, 2016
Water
Oil & Gas
Total
Product revenue ................................................................................................ $
Product cost of revenue ....................................................................................
Product gross profit ........................................................................................
(In thousands)
47,545 $
16,353
31,192
2,170 $
1,496
674
License and development revenue ....................................................................
—
5,000
Operating expenses:
General and administrative .............................................................................
Sales and marketing .......................................................................................
Research and development .............................................................................
Amortization of intangibles ............................................................................
Operating expenses ......................................................................................
1,081
5,076
1,331
631
8,119
1,000
2,985
8,705
—
12,690
Operating income (loss) ................................................................................... $
23,073 $
(7,016)
Less: Corporate operating expenses .................................................................
Consolidated operating income ........................................................................
Non-operating income ......................................................................................
Income before income taxes ...........................................................................
$
49,715
17,849
31,866
5,000
2,081
8,061
10,036
631
20,809
16,057
15,700
357
287
644
- 88 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Year Ended December 31, 2015
Water
Oil & Gas
(In thousand)
Total
Product revenue ................................................................................................ $
Product cost of revenue ....................................................................................
Product gross profit ........................................................................................
43,530 $
19,045
24,485
141 $
66
75
License and development revenue ....................................................................
—
1,042
Operating expenses:
General and administrative .............................................................................
Sales and marketing .......................................................................................
Research and development .............................................................................
Amortization of intangibles ............................................................................
Operating expenses ......................................................................................
936
4,918
1,126
635
7,615
1,797
4,070
6,552
—
12,419
Operating income (loss) ................................................................................... $
16,870 $
(11,302)
Less: Corporate operating expenses .................................................................
Consolidated operating loss ..............................................................................
Non-operating expense .....................................................................................
Loss before income taxes ...............................................................................
$
Depreciation and amortization expense by segment is presented in the following table.
43,671
19,111
24,560
1,042
2,733
8,988
7,678
635
20,034
5,568
17,359
(11,791)
(181)
(11,972)
Water ................................................................................................................... $
Oil & Gas ............................................................................................................
Corporate .............................................................................................................
Total depreciation and amortization ................................................................. $
2,723 $
448
495
3,666 $
3,043 $
244
393
3,680 $
3,192
203
443
3,838
Years Ended December 31,
2017
2016
2015
(In thousands)
- 89 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 13 — Geographical Information and Concentrations
Product Revenue
The following geographic information includes product revenue to the Company’s U.S. and international customers
based on the customers’ requested delivery locations, except for certain cases in which the customer directed the Company
to deliver its products to a location that differs from the known ultimate location of use. In such cases, the ultimate location
of use, rather than the delivery location, is reflected in the table below.
Years Ended December 31,
2017
2016
2015
(In thousands, except for percentages)
Product revenue by geographic location:
United States .................................................................................................. $
International ...................................................................................................
Total product revenue .................................................................................. $
1,839
56,317
58,156
$
$
1,203
48,512
49,715
$
$
2,861
40,810
43,671
Product revenue by country:
Egypt ..............................................................................................................
Saudi Arabia ...................................................................................................
China ..............................................................................................................
Qatar ...............................................................................................................
Oman ..............................................................................................................
United Arab Emirates .....................................................................................
Others (1) ..........................................................................................................
Total ............................................................................................................
____________
15%
13
9
1
9
2
51
100%
8%
14
13
8
3
2
52
100%
6%
3
8
13
12
10
48
100%
(1) Includes remaining countries not separately disclosed. No country in this line item accounted for more than 10% of the
Company’s product revenue during any of the years presented.
Product Revenue - Customer Concentration
Product revenue from customers representing 10% or more of product revenue varies from period to period. For the
year ended December 31, 2017, no customer represent 10% or more of the Company’s product revenue. For the years ended
December 31, 2016 and 2015, one customer, the same customer in both years, represented 11% and 14% of the Company’s
product revenues, respectively.
License and Development
One international Oil & Gas segment customer accounts for 100% of the Company’s license and development revenue
for the years ended December 31, 2017, 2016 and 2015.
- 90 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Customers
The Company’s accounts receivable are derived from sales to customers located around the world. The Company
generally does not require collateral to support customer receivables, but frequently requires export letters of credit securing
payment. The Company performs ongoing evaluations of its customers’ financial condition and periodically reviews credit
risk associated with receivables. An allowance for doubtful accounts is determined with respect to receivable amounts that
we have determined to be doubtful of collection using specific identification of doubtful accounts and an aging of receivables
analysis based on invoice due dates. Actual collection losses may differ from the Company’s estimates, and such differences
could be material to the financial position, results of operations, and cash flows. Uncollectible receivables are written off
against the allowance for doubtful accounts when all efforts to collect them have been exhausted, while recoveries are
recognized when they are received.
Customers accounting for 10% or more of the Company’s combined accounts receivable and unbilled receivables by
segment are presented in the following table.
Customer A .........................................................................................................
Customer B ..........................................................................................................
Customer C ..........................................................................................................
Customer D .........................................................................................................
Segment
Water
Water
Water
Water
Customer E .......................................................................................................... Oil & Gas
____________
December 31,
2017
December 31,
2016
16%
10
11
**
26
**
**
**
13 %
16
** Less than 10%
Vendor Concentration
Vendors accounting for 10% or more of the Company’s combined accounts payable by segment are presented in the
following table.
Vendor A ............................................................................................................. Oil & Gas
Vendor B ............................................................................................................. Oil & Gas
____________
11%
**
**
18 %
Segment
December 31,
2017
December 31,
2016
** Less than 10%
Long-lived Assets
All of the Company’s long-lived assets were located in the U.S. at December 31, 2017 and 2016.
- 91 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 14 — Related Party
The Company and the VorTeq Licensee signed a 15-year license agreement in 2016 which provides the VorTeq
Licensee with exclusive worldwide rights to the Company’s VorTeq for use in hydraulic fracturing onshore applications. In
2016, the Company rented equipment and personnel to perform product testing from the VorTeq Licensee. The amount of
payments made related to the rented equipment and personnel during the years ended December 31, 2017 and 2016, was
$0.4 million and $0.3 million, respectively.
In 2016, the Company extended a non-interest bearing 6-month term loan to one of its employees, which the Company
and employee has renewed at each 6-month term in 2016 and 2017. The balance on the loan was $11 thousand at both
December 31, 2017 and 2016. The current loan expired in February 2018 and was not renewed.
In 2016, the Company entered into a lease agreement with EMS USA, Inc. for the use of office space. The President
and Chief Executive Officer of EMS USA, Inc. is also a member of the Board of Directors of the Company. The lease was
for a term of 90 days with continuation on a month-to-month basis thereafter, with each month being an “Additional Term.”
The Company paid EMS USA, Inc. $5 thousand related to this agreement during the year ended December 31, 2016. The
lease was terminated as of July 2016.
Note 15 — VorTeq Partnership and License Agreement
The Company’s VorTeq technology enables oilfield service hydraulic fracturing operators to isolate their high-pressure
hydraulic fracturing pumps from fracturing fluid thereby reducing operating and capital costs. In 2014, the Company entered
into a strategic partnership with Liberty Oil Field Services (“Liberty”) to pilot and conduct field trials with the VorTeq.
Through this agreement, Liberty has the rights to lease up to twenty VorTeq missiles for a period of up to five years following
commercialization.
On October 14, 2015, the Company and the VorTeq Licensee signed a 15-year license agreement which provides the
VorTeq Licensee with exclusive worldwide rights to the Company’s VorTeq for use in hydraulic fracturing onshore
applications (the “VorTeq License Agreement”). The license agreement provides a carve out for Liberty’s contractual rights
to utilize the VorTeq.
The VorTeq is made up of cartridges though which hydraulic fracturing fluid passes and a missile that houses the
cartridges. The VorTeq License Agreement includes up to $125.0 million in consideration paid in stages: (i) a $75.0 million
non-refundable upfront exclusivity payment; and (ii) two milestone payments of $25.0 million each upon achievement of
successful tests in accord with KPIs specified in the agreement (“Milestone Payment 1 and 2”). After the milestone tests are
achieved, the VorTeq Licensee will begin paying ongoing recurring royalty fees to the Company for supply and service of
the cartridges based on the number of VorTeqs in operation which is subject to the greater of a minimum adoption curve or
the adoption rate of the technology.
- 92 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The Company applied the guidance for multi-element arrangements in identifying deliverables, determining units of
accounting, allocating total contract consideration to the units of accounting, and recognizing revenue. It was determined that
the non-contingent deliverables (15-year license, exclusivity, support services) did not have stand-alone value individually,
but did on a combined basis, and therefore represented a unit of accounting. The license will provide access to the technology
over the term of the agreement and, along with the support, is the final deliverable in this unit of accounting. The $75.0 million
upfront payment was allocated to this unit of accounting and revenue is recognized on a straight-line basis over the 15-year
term of the license, starting from the day that the license agreement was signed and all services commenced. The Company
recognized license and development revenue of $5.0 million in both 2017 and 2016, and the Company had a deferred revenue
balance of $64.0 million and $69.0 million related to the upfront exclusivity license fee as of December 31, 2017 and 2016,
respectively. The cartridge supply and support services are not assessed to have stand-alone value independent of each other
and fees for these deliverables will be recognized as earned.
Milestone Payment 1 of $25.0 million is payable upon a successful five (5) stage yard test at the VorTeq Licensee’s
test facility. If a successful yard test is not achieved by the target date, the payment will be delayed until the successful yard
test is achieved. The Milestone Payment 2 of $25.0 million is payable upon a successful twenty (20) stage hydraulic fracturing
at one of the VorTeq Licensee’s customer’s live well. If success is not achieved by the target date, the payment will be delayed
until the successful live well test is achieved. The achievement of each milestone and the receipt of each of the related
payments are subject to a high degree of uncertainty.
With respect to the Milestone Payments, the Company determined the payments did meet the definition of a substantive
milestone. The factors considered in the determination that each milestone was substantive included whether the consideration
earned from the achievement of the milestone is commensurate with the vendor’s performance or the enhancement of value;
the degree of certainty in achieving the milestone; whether the milestone relates solely to past performance; and whether the
consideration earned from the achievement of the milestone is reasonable relative to all of the deliverables and payment terms
within the arrangement. For the years ending December 31, 2017 and 2016, no revenue was recognized for the Milestones
Payments, nor in any other periods presented.
Following Milestone Payment 2, the VorTeq Licensee will begin integrating the technology into its fleets. When the
technology is integrated into the VorTeq Licensee’s fleets, the Company will begin providing cartridges and servicing those
cartridges which will generate ongoing recurring royalty revenue. The recurring royalty fee per VorTeq in use will be paid
based on the greater of a minimum adoption curve or the adoption rate of the technology. Further, a provision is made for an
advance royalty payment to which recurring royalty fees will be applied.
The exclusive nature of the agreement terminates if the VorTeq Licensee does not meet the specified minimum
adoption curves. In the event the Company is not able to achieve successful test results in accordance with the KPIs, the
exclusivity of the license continues for the full term for the VorTeq Licensee.
With respect to the cartridges and associated service, royalty revenue will be recognized as royalties are earned, that
is, in the period in which the contingency regarding royalties are resolved and the amount of royalties are fixed and
determinable based on the cartridges delivered.
- 93 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 16 — Litigation
The Company is named in and subject to various proceedings and claims in connection with our business. The
Company is contesting the allegations in these claims, and the Company believes that there are meritorious defenses in each
of these matters. The outcome of matters the Company has been, and currently are, involved in cannot be determined at this
time, and the results cannot be predicted with certainty. There can be no assurance that these matters will not have a material
adverse effect on our results of operations in any future period and a significant judgment could have a material adverse
impact on our financial condition, results of operations and cash flows. The Company may in the future become involved in
additional litigation in the ordinary course of its business, including litigation that could be material to its business.
The Company considers all claims on a quarterly basis and based on known facts assesses whether potential losses are
considered reasonably possible, probable and estimable. Based upon this assessment, the Company then evaluates disclosure
requirements and whether to accrue for such claims in its consolidated financial statements. The Company records a provision
for a liability when it is both probable that a liability has been incurred and the amount of the loss can be reasonably estimated.
These provisions are reviewed at least quarterly and adjusted to reflect the impacts of negotiations, settlements, rulings, advice
of legal counsel and other information and events pertaining to a particular case.
On September 10, 2014, the Company terminated the employment of its Senior Vice President, Sales, Borja Blanco,
on the basis of breach of duty of trust and conduct leading to conflict of interest. On October 24, 2014, Mr. Blanco filed a
labor claim against ERI Iberia in Madrid, Spain, challenging the fairness of his dismissal and seeking compensation (“Case
1”). A hearing was held on November 13, 2015, after which the labor court ruled that it did not have jurisdiction over the
matter. Mr. Blanco appealed and the appeals court reversed the labor court’s finding and instructed the labor court to make a
ruling on the merits on November 21, 2017. On February 14, 2018, the Company received notice that the labor court issued
a ruling in favor of Mr. Blanco declaring the termination an unjustified dismissal and ordered the Company to pay a dismissed
severance. The Company appealed the decision on February 21, 2018. The Company denies any allegations of wrongdoing
and intends to continue to vigorously defend against this lawsuit. Based on currently available information and review with
outside counsel, the Company has estimated and accrued a potential loss.
On November 24, 2014, Mr. Blanco filed a second action based on breach of contract theories in the same court as
Case 1 (“Case 2”), but the cases are separate. In Case 2, Mr. Blanco seeks payment of an unpaid bonus, stock options, and
non-compete compensation. The court ruled that this case is stayed until a final ruling is issued in Case 1. The Company
denies any allegations of wrongdoing and intends to continue to vigorously defend against this lawsuit. Based on currently
available information and review with outside counsel, the Company has determined that an award to Mr. Blanco is not
probable. While a loss may be reasonably possible, an estimate of loss, if any, cannot reasonably be determined at this time.
On February 18 and July 27, 2016, two derivative action complaints were filed in connection with the Company’s
previously reported stockholder class action lawsuit in the Superior Court for the State of California, County of Alameda
where the Company was named as a nominal defendant under the captions, Goldberg v. Rooney, et al., HG 16804359, and
Gerald McManiman v. Gay, et al., RG 16824960. The complaints have been consolidated under the caption, In Re Energy
Recovery, Inc. Derivative Litigation, HG16804359. The consolidated complaint is styled as a derivative action being brought
on behalf of the Company and generally alleges breach of fiduciary duty, waste of corporate assets, and unjust enrichment
causes of action against the individually named defendants. The Company filed a Notice of Demurrer on July 6, 2017. After
a hearing, the Court granted the Company’s demurrer but allowed plaintiff to amend its complaint. The plaintiff filed an
amended complaint on October 2, 2017. The Company filed another Notice of Demurrer to the amended complaint on
October 12, 2017. The Company denies any allegations of wrongdoing and intends to continue to vigorously defend against
this lawsuit. However, there is no assurance that the Company will be successful in its defense. Based on currently available
information and review with outside counsel, the Company is not able to estimate a potential loss, if any, at this time.
- 94 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 17 — Supplementary Data — Quarterly Financial Data (unaudited)
The following tables present certain unaudited consolidated quarterly financial information for each of the four fiscal
quarters in the periods ended December 31, 2017 and December 31, 2016. This quarterly information has been prepared on
the same basis as the audited Consolidated Financial Statements and includes all adjustments, consisting only of normal
recurring adjustments, necessary for a fair presentation of the information for the periods presented. The results for these
quarterly periods are not necessarily indicative of the operating results for a full year or any future period.
2017 QUARTERLY FINANCIAL DATA (1)
(unaudited)
Three Months Ended
March 31,
2017
June 30,
2017
September 30,
2017
December 31,
2017
(In thousands, except per share amounts)
Product revenue .................................................................... $
Product cost of revenue ........................................................
Product gross profit ........................................................
12,261 $
4,610
7,651
10,922 $
3,530
7,392
13,834 $
4,254
9,580
21,139
6,667
14,472
License and development revenue ........................................
1,250
1,250
1,250
1,250
Operating expenses:
General and administrative .............................................
Sales and marketing ........................................................
Research and development .............................................
Amortization of intangible assets ...................................
Total operating expenses ...................................................... $
Income (loss) from operations .............................................. $
Provision for (benefit from) income taxes (2) ......................... $
Net income (loss) .................................................................. $
Income (loss) per share:
Basic ............................................................................... $
Diluted ............................................................................ $
____________
4,408
2,453
2,509
158
9,528 $
(627 ) $
(77 ) $
(433 ) $
(0.01 ) $
(0.01 ) $
3,927
2,174
3,077
158
9,336 $
(694 ) $
(35 ) $
(548 ) $
(0.01 ) $
(0.01 ) $
4,034
2,061
3,038
157
9,290 $
1,540 $
66 $
1,706 $
0.03 $
0.03 $
4,985
2,703
4,819
158
12,665
3,057
(8,348)
11,625
0.22
0.21
(1)
(2)
Quarterly results may not add up to annual results due to rounding.
One-time tax benefit from valuation allowance release in the fourth quarter of 2017.
- 95 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
2016 QUARTERLY FINANCIAL DATA (1)
(unaudited)
Three Months Ended
March 31,
2016
June 30,
2016
September 30,
2016
December 31,
2016
(In thousands, except per share amounts)
Product revenue .................................................................... $
Product cost of revenue ........................................................
Product gross profit ........................................................
10,051 $
3,674
6,377
11,973 $
4,236
7,737
11,024 $
3,968
7,056
16,667
5,971
10,696
License and development revenue ........................................
1,250
1,250
1,250
1,250
Operating expenses:
General and administrative (2) ......................................
Sales and marketing ........................................................
Research and development .............................................
Amortization of intangible assets ...................................
Total operating expenses ...................................................... $
Income (loss) from operations .............................................. $
Net income (loss) .................................................................. $
Income (loss) per share:
Basic ............................................................................... $
Diluted ............................................................................ $
____________
4,884
2,070
2,665
157
9,776 $
(2,149) $
(1,966) $
(0.04) $
(0.04) $
3,992
1,935
2,422
158
8,507 $
480 $
456 $
0.01 $
0.01 $
3,971
2,512
2,319
158
8,960 $
(654) $
(579) $
(0.01) $
(0.01) $
3,779
2,599
2,730
158
9,266
2,680
3,123
0.06
0.06
(1) Quarterly results may not add up to annual results due to rounding.
(2)
The increase in general and administrative expense in the first quarter of 2016 was substantially related to the
termination of the former General Counsel.
Note 18 — Subsequent Events
On February 24, 2018, the Company’s President and Chief Executive Officer, Joel Gay, announced his resignation
citing the need to attend to personal family matters. The Board has accepted Mr. Gay’s resignation and appointed current
Chief Financial Officer Chris Gannon as interim President and Chief Executive Officer effective immediately.
- 96 -
ENERGY RECOVERY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 19 — Allowance for Doubtful Accounts
The allowance for doubtful accounts activities are presented in the table below.
Allowance for
Doubtful Accounts
(In thousands)
As of December 31, 2015 .......................................................................................................................................... $
Additions ................................................................................................................................................................
Changes in Estimates (1) ..........................................................................................................................................
As of December 31, 2016 ..........................................................................................................................................
Additions ................................................................................................................................................................
Changes in Estimates (1) ..........................................................................................................................................
Deductions (2) ..........................................................................................................................................................
As of December 31, 2017 .......................................................................................................................................... $
____________
166
76
(112)
130
55
(77)
(5)
103
(1)
(2)
Collections of previously reserved accounts
Uncollectible accounts written off, net of recoveries
- 97 -
Item 9 — Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.
Item 9A — Controls and Procedures
Evaluation of Disclosure Controls and Procedures
Our management has evaluated, with the participation of our Chief Executive Officer and Chief Financial Officer, the
effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities
Exchange Act of 1934, or “Exchange Act”) as of the end of the period covered by this Annual Report on Form 10-K. Based
on that evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that, as of such date, our
disclosure controls and procedures were effective to ensure that information we are required to disclose in reports that we file
or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in
Securities and Exchange Commission rules and forms and that such information is accumulated and communicated to
management as appropriate to allow for timely decisions regarding required disclosure.
Our disclosure controls and procedures are designed to provide reasonable assurance of achieving their objectives, and
our Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective at
the “reasonable assurance” level. Our management, including the Chief Executive Officer and Chief Financial Officer,
believes that a control system, no matter how well designed and operated, cannot provide absolute assurance that the
objectives of the control system are met, and that no evaluation of controls can provide absolute assurance that all control
issues and instances of fraud, if any, within a company have been detected.
Management’s Annual Report on Internal Control Over Financial Reporting and Attestation Report of the Registered
Accounting Firm
Management is responsible for establishing and maintaining adequate internal control over the Company’s financial
reporting. Management assessed the effectiveness of the Company’s internal control over financial reporting as of
December 31, 2017. In making this assessment, management used the criteria set forth by the Committee of Sponsoring
Organizations of the Treadway Commission (COSO) in Internal Control — Integrated Framework (2013). Based on the
assessment using those criteria, management concluded that, as of December 31, 2017, our internal control over financial
reporting was effective.
The Company’s independent registered public accountants, BDO USA, LLP, audited the Consolidated Financial
Statements included in this Annual Report on Form 10-K and have issued an audit report on the Company’s internal control
over financial reporting. The report on the audit of internal control over financial reporting appears in Part II, Item 8,
“Financial Statements and Supplementary Data,” in this Annual Report on Form 10-K.
Changes in Internal Control Over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during our most recent fiscal
quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
Item 9B — Other Information
None.
- 98 -
Item 10 — Directors, Executive Officers and Corporate Governance
PART III
The information required by this Item is included in and incorporated by reference from our definitive proxy statement
(the “Proxy Statement”) which will be filed with the Securities and Exchange Commission prior to April 30, 2018. The Proxy
Statement is for our Annual Meeting of Stockholders which will be held on June 14, 2018.
Item 11 — Executive Compensation
The information required by this Item is included in and incorporated by reference from the Proxy Statement under
the captions “Election of Directors,” “Director Compensation,” “Compensation Discussion and Analysis” and “Report of the
Compensation Committee of the Board of Directors on Executive Compensation.”
Item 12 — Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The following table sets forth equity compensation plan information as of December 31, 2017.
Number of
Securities to be
Issued Upon
Exercise of
Outstanding
Options,
Warrants,
and Rights
Weighted-
Average Exercise
Price of
Outstanding
Options,
Warrants, and
Rights
Number of
Securities
Remaining
Available for
Future Issuance
Under
Equity
Compensation
Plans (Excluding
Securities
Reflected in the
First Column)
5,366,368 $
3,945,653
None Not applicable Not applicable
5.43
Plan Category
Equity compensation plans approved by security holders (1) ..............................
Equity compensation plans not approved by security holders ...........................
____________
(1)
Represents shares of the Company’s common stock issuable upon exercise of options outstanding under the following
equity compensation plans: the 2006 Stock Option/Stock Issuance Plan, the 2008 Equity Incentive Plan, the Amended
and Restated 2008 Equity Incentive Plan, and the 2016 Incentive Plan.
The information under the caption “Security Ownership of Certain Beneficial Owners and Management” in the Proxy
Statement is incorporated herein by reference.
Item 13 — Certain Relationships and Related Transactions and Director Independence
The information required by this Item is included in and incorporated by reference from the Proxy Statement under
the caption “Related Person Policies and Transactions.”
Item 14 — Principal Accounting Fees and Services
The information required by this item is included in and incorporated by reference from the Proxy Statement under the
caption “Principal Accountant Fees and Services.”
With the exception of the information specifically incorporated by reference in Part III to this Annual Report on Form
10-K from the Proxy Statement, the Proxy Statement shall not be deemed to be filed as part of this report.
- 99 -
Item 15 — Exhibits and Financial Statement Schedules
PART IV
(a) The following documents are included as part of this Annual Report on Form 10-K:
(1)
(2)
Financial Statements. The financial statements included in Part II, Item 8 of this document are filed as part of
this Annual Report on Form 10-K.
Financial Statement Schedule. See Note 19, “Allowance for Doubtful Accounts,” of the Notes to Consolidated
Financial Statements in Part II, Item 8, “Financial Statements and Supplementary Data,” of this Annual Report
on Form 10-K. Schedules not listed have been omitted because information required to be set forth therein is
not applicable or is shown in the financial statements or notes thereto.
(3)
Exhibit Index. See Exhibit Index immediately following the Signature page for a list of Exhibits filed or
incorporated by reference as a part of this Report.
(b) Exhibit. See Exhibits listed under Item 15(a)(3).
(c) Financial Statement Schedules. All financial statement schedules are omitted because they are not applicable, not
required, or because the required information is included in the Consolidated Financial Statements, the Notes thereto, or
in the Exhibits listed under Item 15(a)(2).
Item 16 — Form 10-K Summary
None
- 100 -
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly
caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of San Leandro, State
of California, on the 8th day of March 2018.
ENERGY RECOVERY, INC.
By: /s/ CHRIS GANNON
Chris Gannon
President and Chief Executive Officer, and
Chief Financial Officer
Pursuant to the requirements of the Securities and Exchange Act of 1934, this Report has been signed below by the
following persons on behalf of the Registrant and in the capacities and on the dates indicated.
Signature
/s/ CHRIS GANNON
Chris Gannon
/s/ HANS PETER MICHELET
Hans Peter Michelet
/s/ ALEXANDER J. BUEHLER
Alexander J. Buehler
/s/ OLAV FJELL
Olav Fjell
/s/ SHERIF FODA
Sherif Foda
/s/ ARVE HANSTVEIT
Arve Hanstveit
/s/ OLE PETER LORENTZEN
Ole Peter Lorentzen
/s/ ROBERT YU LANG MAO
Robert Yu Lang Mao
Title
Date
President and Chief Executive Officer, and
March 8, 2018
Chief Financial Officer (Principal Executive Officer,
and Principal Financial and Accounting Officer )
Director and Chairman of the Board
March 8, 2018
March 8, 2018
March 8, 2018
March 8, 2018
March 8, 2018
March 8, 2018
March 8, 2018
Director
Director
Director
Director
Director
Director
- 101 -
EXHIBIT INDEX
Incorporated by Reference
Exhibit
Number
3.1
Exhibit Description
Amended and Restated Certificate of Incorporation, as filed
with the Delaware Secretary of State on July 7, 2008.
3.2
Amended and Restated Bylaws, effective as of July 8, 2008.
10.1*
Form of Indemnification Agreement between the Company
and its directors and officers.
Form
10-K
10-K
S-1/A
File No.
001-34112
Exhibit Filing Date
3.1
3/27/2009
001-34112
3.2
3/27/2009
333-150007
10.1
5/12/2008
Filed
Herewith
10.2*
2006 Stock Option/Stock Issuance Plan of the Company and
S-1
333-150007
10.5
4/1/2008
forms of Stock Option and Stock Purchase Agreements
thereunder.
10.3*
Amendment to 2006 Stock Option/Stock Issuance Plan of the
S-1
333-150007 10.5.1
4/1/2008
Company.
10.4*
Second Amendment to 2006 Stock Option/Stock Issuance
S-1
333-150007 10.5.2
4/1/2008
Plan of the Company.
10.5*
2008 Equity Incentive Plan of the Company and form of
S-1/A
333-150007
10.6
5/12/2008
Stock Option Agreement thereunder.
10.6*
Energy Recovery Inc. Amended and Restated 2008 Equity
DEF14A
001-34112 Appendix
4/27/2012
Incentive Plan
10.7
Modified Industrial Gross Lease Agreement dated
10-K
001-34112
November 25, 2008, between the Company and Doolittle
Williams, LLC.
A
10.17
3/27/2009
10.8
First Amendment to Modified Industrial Gross Lease dated
10-Q
001-34112 10.17.1
8/7/2009
10.9
10.10
10.11
May 28, 2009, between the Company and Doolittle Williams,
LLC.
Second Amendment to Modified Industrial Gross Lease dated
June 26, 2009, between the Company and Doolittle Williams,
LLC.
Third Amendment to Modified Industrial Gross Lease dated
November 10, 2010 between the Company and Doolittle
Williams, LLC
Control Agreement dated July 7, 2011, between the Company,
Citibank, N.A., Citigroup Global Markets Inc., and Morgan
Stanley Smith Barney LLC.
10-Q
001-34112 10.17.2
8/7/2009
10-K
001-34112
10.14
3/12/2013
10-Q
001-34112
10.43
8/8/2011
10.12*
Energy Recovery, Inc. Change in Control Severance Plan
8-K
001-34112
10.1
3/9/2012
dated March 5, 2012
10.13
Loan Agreement dated June 5, 2012 between Company and
8-K
001-34112
10.1
6/11/2012
HSBC Bank, USA, National Association
10.14*
Energy Recovery, Inc. Annual Incentive Plan dated January 1,
8-K
001-34112
10.1
4/30/2014
2014
10.15*
10.16*
10.17*
Offer Letter dated June 26, 2014, to Mr. Joel Gay
Draft Consulting Agreement with Thomas S. Rooney, Jr.
Energy Recovery, Inc. 2015 Annual Incentive Plan
10.18*
Offer Letter dated April 22, 2015 to Mr. Joel Gay
10.19*
Promotion Letter dated April 30, 2015 to Ms. Sharon Smith-
Lenox
10.20*
Offer Letter dated May 5, 2015 to Mr. Eric Siebert,
10.21
Settlement and Mutual Release Agreement
10.22*
10.23
Offer Letter dated May 13, 2015 to Mr. Chris Gannon
Second Amendment to Loan Agreement with HSBC Bank
USA, National Association
10.24*
Offer Letter dated September 17, 2015 to Ms. Emily Smith
10.25** License Agreement by and between ERI Energy Recovery
Ireland, Ltd. and Schlumberger Technology Corporation
Energy Recovery, Inc. Annual Incentive Plan effective as of
10.26*
January 1, 2016
10.27*
Transition and Separation Agreement dated March 15, 2016
by and between Energy Recovery, Inc. and Mr. Juan Otero
8-K/A
8-K
8-K
8-K
8-K
10-K
8-K
8-K
10-Q
10-K
10-K
001-34112
001-34112
001-34112
001-34112
001-34112
99.2
10.2
10.1
99.2
99.1
7/8/2014
1/13/2015
4/29/2015
4/29/2015
5/1/2015
001-34112
10.25
3/3/2016
001-34112
001-34112
001-34112
99.1
99.1
10.7
5/13/2015
5/15/2015
8/6/2015
001-34112
10.30
001-34112
10.31
3/3/2016
3/3/2016
8-K
001-34112
10.1
3/1/2016
8-K
001-34112
99.1
3/18/2016
- 102 -
Exhibit
Number
Exhibit Description
Incorporated by Reference
Form
File No.
Exhibit Filing Date
Filed
Herewith
10.28* Energy Recovery, Inc. 2016 Incentive Plan
DEF14A
001-34112 Appendix
4/27/2016
8-K
10-K
001-34112
001-34112
A
99.1
10.34
6/22/2016
3/10/2017
10-Q
001-34112
10.1
5/4/2017
10-K
001-34112
14.1
3/27/2009
10-Q
001-34112
18.1
5/8/2014
X
X
X
X
10.29* Offer Letter dated May 27, 2016 to Mr. William Yeung
10.30
10.31
14.1
18.1
21.1
23.1
31.1
32.1
Loan and Pledge Agreement between Energy Recovery, Inc.
as Borrower, and Citibank, N.A. as Lender
First Amendment to Loan and Pledge Agreement by and
between Energy Recovery, Inc. and Citibank, N.A.
Code of Ethics of Energy Recovery, Inc. Additional Conduct
and Ethics Policies for the Chief Executive Officer and Senior
Financial Officers.
BDO USA, LLP, Letter re Change in Method of Accounting
for Inventory Valuation
List of subsidiaries of the Company.
Consent of BDO USA, LLP, Independent Registered Public
Accounting Firm.
Certification of Principal Executive Officer and Principal
Financial Officer, pursuant to Exchange Act Rule 13a-14(a)
or 15d-14(a), as adopted pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002.
Certification of Principal Executive Officer and Principal
Financial Officer, pursuant to 18 U.S.C. Section 1350, as
adopted pursuant to Section 906 of the Sarbanes-Oxley Act of
2002.
101.INS XBRL Instance Document
101.SCH XBRL Taxonomy Extension Schema Document
101.CAL XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF XBRL Taxonomy Extension Definition Linkbase Document
101.LAB XBRL Taxonomy Extension Label Linkbase Document
101.PRE XBRL Taxonomy Extension Presentation Linkbase Document
Indicates management compensatory plan, contract or arrangement.
*
** Portions of this exhibit have been omitted based on a request for Confidential Treatment submitted to the Securities and Exchange
Commission (the “SEC”). The omitted information has been filed separately with the SEC as a part of the confidential treatment
request. In the event that the SEC should deny such request in whole or in part, the relevant, previously omitted portions of this
exhibit shall be publicly filed.
- 103 -
About Energy Recovery
Energy Recovery, Inc. (ERII) is an energy solutions provider to industrial
fluid flow markets worldwide. Energy Recovery solutions recycle and
convert wasted pressure energy into a usable asset and preserve pumps
that are subject to hostile processing environments. With award-winning
technology, Energy Recovery simplifies complex
improving productivity, profitability, and efficiency within the oil & gas and water
industries. Energy Recovery products save clients more than $1.8 billion (USD)
annually. Headquartered in the Bay Area, Energy Recovery has offices in Houston,
Ireland, Shanghai, and Dubai. For more information about the Company, please visit
www.energyrecovery.com.
industrial systems while
Board of Directors
Hans Peter Michelet
Alexander Buehler
Olav Fjell
Sherif Foda
Arve Hanstveit
Ole Peter Lorentzen
Robert Mao
Corporate Headquarters
1717 Doolittle Drive, San Leandro, CA 94577 USA
TEL: +1 510.483.7370 | FAX: +1 510.483.7371 | EMAIL: info@energyrecovery.com