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LIVING OUR VALUES
2016 Annual Report
Living Our Values
Crisis situations demonstrate a team’s resolve and character. This past year, Civeo’s response
to the devastating Fort McMurray forest fire demonstrated our employees’ passion for service
and the Company’s values of caring, collaboration, integrity, safety and excellence.
In May 2016, an unprecedented forest fire swept through the Fort McMurray
community and surrounding areas in Alberta, Canada, leaving an immeasurable
path of destruction and leading to the largest wildfire evacuation in Alberta’s history.
As upwards of 85,000 people evacuated, Civeo opened its doors to CARE for nearly
6,000 evacuees searching for refuge in those initial hours and days, and we provided
daily accommodations and support for over 2,500 first responders. Overnight, we
transformed our lodges to respond to the diverse needs of oil sands workers, families
displaced by the fire and emergency personnel.
Operations during a disaster of this magnitude require seamless COLLABORATION
among customers, suppliers, competitors, emergency services and coworkers. Across
the Company, our staff worked closely with government agencies and industry partners
to ensure our guests were safe, emergency services remained available and safe water
supplies were never at risk.
INTEGRITY guided every aspect of our
decision-making during the fire. Our
priority was to make others’ lives easier,
and we took action solely based on how
best to assist. All internal and external
communications were open and transparent.
When a disaster occurs, the strength of an
organization’s SAFETY culture and systems
becomes clear. Throughout this hectic and
trying time, we had no safety incidents de-
spite the long hours and difficult situation.
EXCELLENCE was personified by each
member of our Canadian team in the focus,
dedication and tireless commitment they
demonstrated to professionally manage
through this crisis and ensure the welfare
of those impacted by this catastrophe.
With the support of our business partners,
we were able to keep our supply chain
open, operations running smoothly and
provide sustaining support to our custom-
ers, competitors and the local community.
This disaster brought out our best as a
Company and as individuals, and provided
living proof of our core values.
Surrounding Civeo lodges
open to evacuees and first
responders
Fort McMurray
ALBERTA, CANADA
May 5, 2016
ottawacitizen.com
1,456,810
acres of wildfire
ZERO
safety incidents
7
lodges open to evacuees
2,500+
first responders
accommodated
~6,000
evacuees housed
and cared for
“ The Civeo team worked tirelessly to give our community a safe place to lay
their heads after a long, hard day on the front lines of this natural disaster.
Meals and accommodations provided much needed mental and physical relief.
When faced with challenges at a critical time, Civeo’s support helped enable
our Alberta Royal Canadian Mounted Police Officers to do their job safely.
Your donation was important to our success.”
– M.C. (Marianne) Ryan, Deputy Commissioner, Commanding Officer “K” Division, Royal Canadian Mounted Police
4
Douglas E. Swanson
Chairman of the Board
Bradley J. Dodson
President and CEO
Frank C. Steininger
Senior Vice President
and CFO
Dear Shareholders,
I write you as we finish the second year of a historically unprecedented commodity
downturn. 2016 continued to present macroeconomic challenges in each of our
major markets – Canada, Australia and the United States. In addition, we managed
through the calamitous forest fire in Alberta, Canada, in May 2016. Despite these
considerable challenges, we continued to manage effectively through the cycle,
remain cash-flow positive, reduce leverage and position the Company for a
recovery in oil and gas and mining activity and a return to growth.
Commodity prices began 2016 at historically low
levels with the WTI oil price at $37.13 per barrel and
the metallurgical coal (met coal) contract price at
$81 per tonne. During the first half of 2016, these
prices deteriorated even further, as both commod-
ities were impacted by excess global supply and
generally anemic global economic growth.
For oil, continued overproduction by OPEC kept global
oil supply out of balance with demand, negatively
impacting oil prices and triggering deep activity
and spending reductions by our customers in both
Canada and the U.S. The most telling example of the
difficult oil environment in the first half of 2016 was
the U.S. rig count, which fell to 404 active rigs in May
2016. This low level of U.S. drilling activity had never
been recorded since Baker Hughes began reporting
the active drilling rig count in 1944. Some industry
sources indicated that the 2016 U.S. rig count trough
rivaled any in the modern oilfield industry’s history,
dating to the late 1800s. Oil prices recovered later
in 2016, as OPEC, in conjunction with several major
non-OPEC oil producers, including Russia, agreed
to cut oil production in 2017 by over one million
barrels per day. Coupled with falling U.S. oil produc-
tion, oil prices recovered to over $50 per barrel
by year end, as markets anticipated supply and
demand balancing.
The met coal market mirrored the oil market in
2016, with weakening prices in the first half of the
year and improving prices as supply disruptions
tightened the global market in the second half. Met
coal contract prices began the year at $81 per tonne
and weakened in the second quarter. However, with
reduced coal production in China in the third quarter
and weather-related supply disruptions in Australia,
met coal prices improved significantly in the second
half of 2016, with spot met coal prices exceeding
$300 per tonne in the fourth quarter. While these
supply disruptions have corrected in early 2017, met
coal prices remain at much healthier levels, such that
our customers’ profits and cash flows have materially
improved. We are hopeful that the improved met
coal economics will precipitate increased mining
activity and spending in the second half of 2017.
2016 Accomplishments
Our focus in 2016 remained consistent with that of
the prior year. Our emphasis across the organiza-
tion was on free cash-flow generation and creating
additional revenue in a capital-disciplined fashion.
Despite a deteriorating market initially in 2016, we
achieved our financial expectations for 2016 and
continued to generate significant free cash flow,
which we deployed to further reduce our leverage
and improve our financial footing. In addition, we
successfully and safely managed through the wide-
spread forest fire in Alberta, Canada, improved our
competitive position in our key markets, expanded
into new markets and further enhanced our service
offering to our customers.
I am proud of the role Civeo played in support of the evacuation
in Alberta, Canada.
During 2016:
• Captured turnaround
work in the Canadian
oil sands
• Renewed contracts
in Australia
• Secured work in
Canada for potential
LNG projects
Our 2017 focus:
• Generating free
cash flow
• Reducing debt
• Investing in new
projects and
opportunities
Beginning in May 2016, the town of Fort McMurray,
Alberta, Canada faced a terrifying forest fire that
captured worldwide media attention and required
the evacuation of over 85,000 residents in a matter
of hours. The town of Fort McMurray is located in
the heart of the Athabasca oil sands region, and
the oil sands industry was called upon to support
the safe evacuation of the town. I am proud of
the role Civeo played in support of the evacuation
and first-responder efforts, as we housed nearly
6,000 evacuees, upwards of 2,500 first responders
and many infrastructure repair teams. Our team
members at our lodges in Canada worked around
the clock to check-in, feed and ensure our new guests
were as comfortable as possible in this difficult time.
With no loss of life due to the fire, there were many
touching stories of humanitarianism. Our lodges
were designed to service oilfield workers and
contractors, and our team was called upon to care
for families and pets, while checking guests in at
a moment’s notice. We even hosted an eight year
old’s birthday party that was canceled due to the fire.
In trying situations, values and culture shine through.
Civeo’s values include safety, care and integrity;
all of which were demonstrated by our team’s
actions. I would like to again thank our lodge teams
for their herculean efforts over this time period.
Our efforts in serving our customers during the fire
solidified our already strong customer relationships;
when coupled with our continued sales initiatives,
we enhanced our competitive position and pen-
etrated new markets. During 2016, we captured
turnaround work in the Canadian oil sands region,
renewed contracts in Australia and secured work
in Canada for potential LNG projects. In the oil
sands region, we supported two turnarounds, one
for Syncrude and one for CNRL, which generated
strong occupancy in the second and third quarters
of 2016. We renewed five contracts in Australia at
our Coppabella Village, totaling A$54 million in con-
tract value. We also leveraged our contract for the
Sitka Lodge in Kitimat, British Columbia, to win the
construction contract to build a 4,500-room facility
for LNG Canada with our partner, Bird Construction.
For Civeo, this new LNG market in British Columbia
presents a significant opportunity for accommoda-
tions. While the contract win demonstrates our
abilities in the LNG region, unfortunately the
underlying LNG contract has been delayed.
During 2016, we continued to advance our service
offering, expanding our a la carte EDI food ordering
system to additional locations. We first introduced
our EDI system in our McClelland Lake Lodge in
2014 and have expanded it to our Beaver River
and Athabasca locations. The EDI system allows
guests to order from an iPad menu of over 30 items
including daily chef’s specials, steaks, pizzas and
salads. The system also allows guests to input food
preferences and allergies. After ordering, guests
can pick up their meals in under ten minutes. The
EDI is unique to Civeo and demonstrates our efforts
to improve the guest experience while living and
working away from home. We plan to install our
EDI system at our Wapasu Creek location in 2017.
Looking Ahead
Civeo is well positioned for the potential recovery
in our markets going into 2017. With improved
commodity prices, we expect our Canadian and
Australian customers to set their capital spending
plans in early 2017. While higher oil and met coal
prices have materially improved market sentiment,
we expect that customers will look for commodity
price stabilization before increasing spending and
activity, portending improved occupancy for Civeo
later in 2017. U.S. activity has begun to recover with
oil prices, and we are experiencing higher occupancy
in our West Permian Lodge and increased utilization
of our well site units. Overall, our focus remains
on generating free cash flow and reducing debt.
Accordingly, we have managed our leverage to
provide the financial flexibility, such that we can
invest in new projects and opportunities as the
commodity recovery gains momentum.
Special Recognition and Thanks
I would like to recognize and thank Doug Swanson,
our retiring Chairman of the Board of Directors, for
his leadership and mentorship. I have had the plea-
sure and honor of working with Doug since he began
leading Oil States International in 1999 and took it
public in 2001. Through the last 17 years, Doug has
led with integrity that will leave a lasting legacy on
the Company and culture of Civeo. Doug, thank you
for all that you have done to steward Civeo through
this difficult market; we wish you the best in your
retirement. You will be greatly missed.
In closing, I am pleased with our performance in
an exceedingly difficult market, encouraged by
the improvement in commodity prices and looking
forward to the opportunities an improving market
will present in 2017 and beyond.
Bradley J. Dodson
President and CEO
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
[X]
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934
For the fiscal year ended December 31, 2016
[ ]
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934
OR
For the transition period from _________________________ to
Commission file number: 001-36246
Civeo Corporation
_______________
(Exact name of registrant as specified in its charter)
British Columbia, Canada
(State or other jurisdiction of
incorporation or organization)
98-1253716
(I.R.S. Employer
Identification No.)
Three Allen Center, 333 Clay Street, Suite 4980,
Houston, Texas
(Address of principal executive offices)
77002
(Zip Code)
(713) 510-2400
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class
Common Shares, no par value
Name of Exchange on Which Registered
New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act:
None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
YES [ ]
NO [X ]
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
YES [ ]
NO [X ]
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act
of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject
to such filing requirements for the past 90 days.
YES [X]
NO [ ]
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data
File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or
for such shorter period that the registrant was required to submit and post such files).
YES [X]
NO [ ]
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained
herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in
Part III of this Form 10-K or any amendment to this form 10-K. [ ]
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting
company. See the definitions of "accelerated filer," "large accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer [ ]
Accelerated Filer [X ]
(Check one):
Non-Accelerated Filer [ ] (Do not check if a smaller reporting company)
Smaller Reporting Company [ ]
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
YES [ ]
NO [X ]
The aggregate market value of common shares held by non-affiliates computed by reference to the price at which the common equity was last
sold, or the average bid and asked price of such common equity, as of the last business day of the registrant’s most recently completed second
fiscal quarter, June 30, 2016, was $191,390,114.
The Registrant had 131,166,157 common shares outstanding as of February 21, 2017.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant's Definitive Proxy Statement for the 2017 Annual General Meeting of Shareholders, which the registrant intends to file
with the Securities and Exchange Commission not later than 120 days after the end of the fiscal year covered by this Annual Report on Form 10-
K, are incorporated by reference into Part III of this Annual Report on Form 10-K.
CIVEO CORPORATION
INDEX
PART I
Cautionary Statement Regarding Forward-Looking Statements ..................................................................................
Item 1.
Business .....................................................................................................................................................
Item 1A. Risk Factors ...............................................................................................................................................
Item 1B. Unresolved Staff Comments ......................................................................................................................
Item 2. Properties ...................................................................................................................................................
Item 3.
Legal Proceedings ......................................................................................................................................
Item 4. Mine Safety Disclosures ............................................................................................................................
PART II
Item 5. Market for Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity
Securities ...................................................................................................................................................
Item 6.
Selected Financial Data ..............................................................................................................................
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations ......................
Item 7A. Quantitative and Qualitative Disclosures About Market Risk ....................................................................
Financial Statements and Supplementary Data ..........................................................................................
Item 8.
Item 9.
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure ......................
Item 9A. Controls and Procedures ............................................................................................................................
Item 9B. Other Information ......................................................................................................................................
PART III
Item 10. Directors, Executive Officers and Corporate Governance ..........................................................................
Item 11. Executive Compensation ............................................................................................................................
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters .....
Item 13. Certain Relationships and Related Transactions, and Director Independence .............................................
Item 14. Principal Accounting Fees and Services .....................................................................................................
PART IV
Item 15. Exhibits, Financial Statement Schedules ....................................................................................................
SIGNATURES.................................................................................................................................................................
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS .......................................................................................
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i
PART I
This annual report on Form 10-K contains certain “forward-looking statements" within the meaning of Section 27A
of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 (the Exchange Act). Actual
results could differ materially from those projected in the forward-looking statements as a result of a number of
important factors. For a discussion of known material factors that could affect our results, please refer to “Part I,
Item 1. Business,” “Part I, Item 1A. Risk Factors,” “Part II, Item 7. Management's Discussion and Analysis of
Financial Condition and Results of Operations” and “Part II, Item 7A. Quantitative and Qualitative Disclosures
about Market Risk” below.
In addition, in certain places in this annual report on Form 10-K, we refer to reports published by third parties that
purport to describe trends or developments in the energy industry. We do so for the convenience of our
shareholders and in an effort to provide information available in the market that will assist our investors in a better
understanding of the market environment in which we operate. However, we specifically disclaim any responsibility
for the accuracy and completeness of such information and undertake no obligation to update such information.
Cautionary Statement Regarding Forward-Looking Statements
We include the following cautionary statement to take advantage of the "safe harbor" provisions of the Private
Securities Litigation Reform Act of 1995 for any "forward-looking statement" made by us, or on our behalf. All
statements other than statements of historical facts included in this Annual Report on Form 10-K are forward-
looking statements. The forward-looking statements can be identified by the use of forward-looking terminology
including “may,” “expect,” “anticipate,” “estimate,” “continue,” “believe” or other similar words. Such statements
may include statements regarding our future financial position, budgets, capital expenditures, projected costs, plans
and objectives of management for future operations and possible future strategic transactions. Where any such
forward-looking statement includes a statement of the assumptions or bases underlying such forward-looking
statement, we caution that, while we believe such assumptions or bases to be reasonable and make them in good
faith, assumed facts or bases almost always vary from actual results. The differences between assumed facts or bases
and actual results can be material, depending upon the circumstances. The factors identified in this cautionary
statement are important factors (but not necessarily all of the important factors) that could cause actual results to
differ materially from those expressed in any forward-looking statement made by us, or on our behalf.
In any forward-looking statement where we, or our management, express an expectation or belief as to future
results, such expectation or belief is expressed in good faith and believed to have a reasonable basis. However, there
can be no assurance that the statement of expectation or belief will result or be achieved or accomplished. Taking
this into account, the following are identified as important factors that could cause actual results to differ materially
from those expressed in any forward-looking statement made by, or on behalf of, the Company:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
the level of supply and demand for oil, coal, natural gas, iron ore and other minerals;
the level of activity, spending and development in the Canadian oil sands;
failure by our customers to reach positive final investment decisions on, or otherwise not complete, projects
with respect to which we have been awarded contracts to provide related accommodation, which may cause
those customers to terminate or postpone the contracts;
the level of demand for coal and other natural resources from Australia;
the availability of attractive oil and natural gas field assets, which may be affected by governmental actions
or environmental activists which may restrict drilling;
fluctuations in the current and future prices of oil, coal and natural gas;
fluctuations in foreign currency exchange rates;
general global economic conditions and the pace of global economic growth;
1
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
changes in tax laws, tax treaties or tax regulations or the interpretation or enforcement thereof, including
taxing authorities not agreeing with our assessment of the effects of such laws, treaties and regulations;
global weather conditions and natural disasters;
our ability to hire and retain skilled personnel;
the availability and cost of capital;
the inability to realize expected benefits from our redomicile to Canada; and
other factors identified in Item 1A, "Risk Factors."
Such risks and uncertainties are beyond our ability to control, and in many cases, we cannot predict the risks
and uncertainties that could cause our actual results to differ materially from those indicated by the forward-looking
statements.
All subsequent written and oral forward-looking statements attributable to us or to persons acting on our behalf
are expressly qualified in their entirety by reference to these risks and uncertainties. You should not place undue
reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular
statement, and we do not undertake any obligation to publicly update or revise any forward-looking statements
except as required by law.
ITEM 1. Business
Available Information
We maintain a website with the address of www.civeo.com. We are not including the information contained on
our website as a part of, or incorporating it by reference into, this Annual Report on Form 10-K. We make available
free of charge through our website our Annual Report on Form 10-K, quarterly reports on Form 10-Q and current
reports on Form 8-K, and amendments to these reports, as soon as reasonably practicable after we electronically file
such material with, or furnish such material to, the Securities and Exchange Commission (the Commission). The
filings are also available through the Commission at the Commission's Public Reference Room at 100 F Street, N.E.,
Washington, D.C. 20549 or by calling 1-800-SEC-0330. Also, these filings are available on the Internet at
www.sec.gov and free of charge upon written request to our corporate secretary at the address shown on the cover
page of this Annual Report on Form 10-K.
Spin-Off
On May 30, 2014, Oil States International, Inc. (Oil States) spun-off its Accommodations Segment
(Accommodations) into a standalone, publicly traded Delaware corporation (Civeo US). In accordance with the
Separation and Distribution Agreement, the two companies were separated by Oil States distributing to its
stockholders all 106,538,044 shares of common stock of Civeo US it held after the market closed on May 30, 2014
(the Spin-Off). In connection with the Spin-off, on May 28, 2014, we made a special cash distribution to Oil States
of $750 million. Following the Spin-Off, Oil States retained no ownership interest in Civeo US, and each company
now has separate public ownership, boards of directors and management.
Redomiciling to Canada
On July 17, 2015, we changed our place of incorporation from Delaware to British Columbia, Canada, and
Civeo Corporation, a British Columbia, Canada limited company formerly named Civeo Canadian Holdings ULC
(Civeo Canada), became the publicly traded parent company of the Civeo group of companies (the Redomicile
Transaction). The Civeo Canada common shares are listed on the NYSE under the symbol “CVEO,” the same
symbol under which the Civeo US common stock traded prior to the effective time of the Redomicile Transaction.
2
Our Company
We are one of the largest integrated providers of workforce accommodations, logistics and facility management
services to the natural resource industry. We operate in some of the world’s most active oil, coal, natural gas and
iron ore producing regions, including Canada, Australia and the U.S. We have established a leadership position in
providing a fully integrated service offering to our customers, which include major and independent oil and natural
gas companies, mining companies and oilfield and mining service companies. Our Company is built on the
foundation of the following core values: Safety, Care, Excellence, Integrity and Collaborate. We put the safety of
our employees and guests above all other concerns. We care about our people, guests, customers, communities and
the environment and we deliver excellent service with passion and pride. We act with integrity and collaborate with
our people, communities, customers and partners.
Our Develop, Own and Operate model allows our customers to focus their efforts and resources on their core
development and production operations.
Using our Develop, Own and Operate business model, we provide accommodations solutions that span the
lifecycle of customer projects from the initial exploration and resource delineation to long-term production. Initially,
as customers assess the resource potential and determine how they will develop it, they typically need
accommodations for a limited number of employees for an uncertain duration of time. Our fleet of temporary
accommodation assets is well-suited to support this initial exploratory stage as customers evaluate their development
and construction plans. As development of the resource begins, we are able to serve their needs through either our
open camp model or through our scalable lodge or village model. As projects grow and headcount needs increase,
we are able to scale our facility size to meet our customers’ growing needs. By providing infrastructure early in the
project lifecycle, we are well positioned to continue to service our customers throughout the production phase,
which typically lasts decades.
The initial component of our Develop, Own and Operate business model is site selection and permitting. We
believe there are benefits created by investing early in land in order to gain the strategic, early-mover advantage in
an emerging region or resource play. Our business development team actively assesses regions of potential future
customer demand and pursues land acquisition and permitting, a process we describe as “land banking.” We believe
that having the first available accommodations solution in a new market allows us to win contracts from customers
and gives us an early-mover advantage, as competitors may be less willing to invest in undeveloped land in the
expectation of future demand without firm customer commitments. The strength of our land banked locations
allowed us to secure contract growth in our most recent Canadian lodge location, McClelland Lake in the Canadian
oil sands region and our Sitka Lodge in the British Columbia liquefied natural gas (LNG) market.
3
Our scalable modular facilities provide workforce accommodations where, in many cases, traditional
accommodations and related infrastructure is not accessible, sufficient or cost effective. Our services help facilitate
efficient development and production of natural resources found in areas without sufficient housing, infrastructure or
local labor. We believe that many of the more recently discovered mineral deposits and hydrocarbon reservoirs are
in remote locations. We support the development of these natural resources by providing lodging, catering and food
services, housekeeping, recreation facilities, laundry services and facilities management, as well as water and
wastewater treatment, power generation, communications and personnel logistics where required. Our
accommodations services allow our customers to outsource their accommodations needs to a single supplier,
maintaining employee welfare and satisfaction while focusing their investment on their core resource production
efforts. Our primary focus is on providing accommodations to leading natural resource companies at our major
properties, which we refer to as lodges in Canada and villages in Australia. We have nineteen lodges and villages in
operation, with an aggregate of more than 24,000 rooms. Additionally, in the U.S. and Canada we have eight smaller
open camp properties, as well as a fleet of mobile accommodation assets. We have long-standing relationships with
many of our customers, many of whom are, or are affiliates of, large, investment-grade energy and mining
companies.
Demand for our accommodations and related services is influenced by three primary factors: commodity prices,
workforce requirements and competition. Current commodity prices, and our customers’ expectations for future
commodity prices, influence customers’ spending on current productive assets, maintenance on current assets,
expansion of existing assets and development of greenfield or new assets. In addition to commodity prices, different
types of customer activity require varying workforce sizes, influencing the demand for accommodations. Also,
competing locations and services will influence demand for our assets and services.
In the Canadian oil sands region, demand for our accommodations is influenced by oil prices. Spending on
construction and the development of new projects has historically decreased as the outlook for oil prices decreases.
However, spending on current operations and maintenance has historically reacted less quickly to changes in oil
prices, as customers consider their cash operating costs, rather than overall full-cycle returns. Likewise,
construction and expansion projects underway have also been less sensitive to commodity price decreases, as
generally customers focus on completion and incremental costs. Natural gas prices also influence oil sands activity
as an input cost; so as natural gas prices fall, a significant component of our customers’ operating costs fall as well.
Another factor that influences demand for our rooms and services is the type of customer project we are
supporting. Generally speaking, Canadian customers require larger workforces during construction and
expansionary periods, and therefore have higher demand for accommodations. Operational and maintenance
headcounts are typically a fraction, 20-25%, of the headcounts experienced during construction.
In addition, proximity to customer activity and availability of customer-owned rooms influences occupancy.
Typically, customers prefer to first utilize their own rooms on location, and if such customer-owned rooms are
insufficient, customers prefer to avoid busing their workforces to housing more than 45 kilometers away.
A number of multinational energy companies believe there is a potential to export LNG from Canada to meet
the increasing global demand, particularly in Asia, for LNG. Currently, Canada does not have any operational LNG
export facilities. However, as of December 2016, there were 20 proposed LNG export facilities in British Columbia
in various stages of feasibility assessment and project planning, although none have reached a final investment
decision. We expect that LNG activity in Western Canada will be influenced by the global prices for LNG, which
are largely tied to global oil prices, global supply/demand dynamics for LNG and wellhead prices for natural gas.
Should our customers or potential customers decide to invest in these LNG projects, demand for accommodations
over the next three years will be driven by (i) the construction of the LNG facilities on the coast of British Columbia
and (ii) the construction of the related natural gas pipeline infrastructure across British Columbia. Facility
construction will create demand for permanent lodge accommodations, while pipeline construction activity will
drive demand for mobile fleet accommodations.
4
Our Australian villages support similar activities for the natural resources industry. Our customers are typically
developing and producing metallurgical (met) coal and other mines which have resource lives that are measured in
decades. As such, their spending levels tend to react similarly to commodity prices as those of our Canadian
customers. Spending on producing assets is less sensitive to commodity price decreases in the short and medium
term, assuming the projects remain cash flow positive. However, new construction projects and expansionary
projects are typically cancelled or deferred during periods of lower met coal prices. During 2011 through 2013,
roughly half of our occupancy was driven by construction or expansion activity, while the other half supported
operation activities of resource production. Currently, our occupancy is primarily driven by production and
operating activities. With the reduction in met coal prices from mid-year 2012 to mid-year 2016, much of the
demand for rooms from new construction activity has ceased, and our current and expected occupancy is primarily
driven by production and operational activity. Workforce requirements and competition in the Australian market are
comparable to those in the Canadian market. New project construction activity typically requires larger workforces
than day-to-day operations, where proximity and availability of customer-owned rooms influences the demand for
workforce accommodations. The rise in met coal prices in the fourth quarter of 2016 and into early 2017 has
improved market sentiment; however, this price improvement has yet to influence customer spending or spending
outlooks. We expect that spot prices for met coal will need to be sustained at levels above $150/tonne for at least
nine to twelve months before we see an impact on customer activity levels, and therefore, the demand for
accommodations.
Our U.S. operations are primarily tied to activity in the U.S. shale formations in the Bakken, the Rockies and
West Texas. Given the shorter investment horizon and decision cycle of our U.S. customers, typically on a well-by-
well basis, U.S. customers’ spending activities typically react more quickly to changes in oil and natural gas prices.
These spending dynamics were clearly demonstrated over the past three years. With oil prices near $100 per barrel
from 2012 to late 2014, drilling and completion activity levels grew. However, as oil prices fell beginning in
August 2014 and remained at relatively low levels throughout 2015 and most of 2016, activity in the U.S. reacted
swiftly, with the U.S. rig count falling over 50% in six months from its peak in the third quarter of 2014. Unlike the
Canadian and Australian markets, headcount requirements for drilling and completion activity are fairly uniform in
the U.S. market. Given the U.S. market for accommodations is primarily supported by mobile camp assets,
competition is primarily driven by the availability of assets and price.
5
For the years ended December 31, 2016, 2015 and 2014, we generated $397.2 million, $518.0 million and
$942.9 million in revenues and $95.8 million, $145.0 million and $142.9 million in operating loss, respectively. The
majority of our operations, assets and income are derived from lodge and village facilities that have historically been
contracted by our customers on a take-or-pay basis for periods ranging from several months to several years. These
facilities generate more than 75% of our revenue. Important performance metrics include average available rooms,
average rentable rooms, revenue related to our major properties, occupancy and average daily rate (in local
currency). “Mobile and Open Camp Revenue,” shown below, consists of our revenue related to our open camp
facilities and mobile camps, as well as third party sales related to our manufacturing division. The table below
summarizes these key statistics for the periods presented in this Annual Report on Form 10-K.
2016
Year Ended December 31,
2015
(In millions, except for room counts and average
daily rate)
2014
Lodge/Village Revenue (1)
Canada
Australia
Total Lodge/Village Revenue
Mobile and Open Camp Revenue
Canada
Australia
United States
Total Mobile and Open Camp Revenue
Total Revenue
Average Available Lodge/Village Rooms (2)
Canada
Australia
Total Lodge/Village Rooms
Rentable Rooms for Lodges and Villages (3)
Canada
Australia
Total Rentable Rooms for Lodges and Villages
Average Daily Rates for Lodges and Villages (4)
Canada
Australia
$
$
$
$
$
$
Total Average Daily Rates for Lodges and Villages $
Occupancy in Lodges and Villages (5)
Canada
Australia
Total Occupancy in Lodges and Villages
Average Exchange Rate
Canadian dollar to U.S. dollar
Australian dollar to U.S. dollar
238.2
106.8
345.0
40.2
—
12.0
52.2
397.2
14,653
9,335
23,988
9,979
8,679
18,658
104
76
94
63%
44%
54%
$
$
$
$
$
267.5
136.0
403.5
76.8
—
37.7
114.5
518.0
13,435
9,180
22,615
10,054
8,862
18,916
$
$
$
$
$
497.2
213.3
710.5
164.2
—
68.2
232.4
942.9
12,557
9,271
21,828
11,007
9,079
20,086
$
$
121
74
100
$
$
146
94
125
60%
56%
58%
85%
68%
78%
$
0.7551
0.7439
$
0.7832
0.7523
$
0.9056
0.9025
__________
(1)
Includes revenue related to rooms, as well as the fees associated with catering, laundry and other services,
including facilities management.
(2) Average available rooms includes rooms that are utilized for our personnel.
(3) Rentable rooms excludes rooms that are utilized for our personnel and out of service rooms.
(4) Average daily rate is based on rentable rooms and lodge/village revenue.
(5) Occupancy represents total billed days divided by rentable days. Rentable days excludes staff rooms and out
of service rooms.
6
Our History
Our Canadian operations, founded in 1977, began by providing modular rental housing to energy customers,
primarily supporting drilling rig crews. Over the next decade, the business acquired a catering operation and a
manufacturing facility, enabling it to provide a more integrated service offering. Through our experience with
Syncrude’s Mildred Lake Village, a 2,100 bed facility that we built and sold to Syncrude in 1990 and operated and
managed for them for nearly 20 years, we recognized a need for a premium, and more permanent, solution for
workforce accommodations in the Canadian oil sands region. Pursuing this strategy, we opened PTI Lodge in 1998,
one of the first independent lodging facilities in the region.
With an integrated business model, we are able to identify, solve and implement solutions and services that
enhance the guests’ accommodations experience and reduce the customer’s total cost of housing a workforce in a
remote operating location. Through our experiences and integrated model, our accommodation services have
evolved to include fitness centers, water and wastewater treatment, laundry service and many other advancements.
As our experience in the region grew, we were the first to introduce to the Canadian oil sands market suite-style
accommodations for middle and upper level management working in the oil sands region, with our Beaver River
Executive Lodge in 2005. Since then, we have continued to innovate our service offering to meet our customers’
growing and evolving needs. From that entrepreneurial beginning, we have developed into Canada’s largest third-
party provider of accommodations in the oil sands region.
Today, in addition to providing accommodations services, we endeavor to support customers’ logistical efforts
in managing the movement of large numbers of personnel efficiently. At our Wapasu Creek location, we have
introduced services that improve efficiencies for customers in transporting personnel to mine sites on a daily basis,
as well as in rotating personnel when crews change.
During 2015, we entered the Canadian LNG market with our latest lodge location, Sitka Lodge. Most of the
Sitka Lodge’s 436 rooms are currently under contract through September 2017 to LNG Canada (LNGC), a large
LNG export project proposed by a joint venture between Shell Canada Energy, an affiliate of Royal Dutch Shell plc
(50 percent), and affiliates of PetroChina (20 percent), Korea Gas Corporation (15 percent) and Mitsubishi
Corporation (15 percent). In addition, in May 2016, we were awarded a contract with LNGC to construct a 4,500
person workforce accommodation center (Cedar Valley Lodge) for a proposed liquefaction and export facility in
Kitimat, British Columbia. Construction of Cedar Valley Lodge will not commence until LNGC’s joint venture
participants have made a positive final investment decision (FID). The FID was originally planned for the end of
2016. However, this decision has been delayed until a future time that has not yet been determined. We are
currently in discussions with LNGC to extend this contract until a positive FID is made. Should the project
ultimately move forward, British Columbia LNG activity could become a material driver of future activity for our
Sitka Lodge, as well as for our mobile fleet assets which are well suited for the related pipeline construction activity.
However, should the project, and other potential projects in the area, not move forward, the resulting impact may
negatively affect our future results of operations and our existing long-lived assets in Canada, including our Sitka
Lodge, and may require us to record further material impairment charges equal to the excess of the carrying value of
these assets over fair value. With the delay in the FID, we currently expect that LNGC will continue to utilize rooms
at our Sitka Lodge at least through September 2017 in accordance with the terms of our contract. There can be no
assurance that LNGC’s joint venture participants will reach a positive FID or that our contracts with LNGC will be
extended.
With the acquisition of our Australian business in December 2010, we began to support the Australian natural
resources industry through villages located in Queensland, New South Wales and Western Australia. Like Canada,
our Australian business has a long-history of accommodating customers in remote regions, beginning with its initial
Moranbah Village in 1996, and has grown to become Australia’s largest integrated provider of accommodations
services for people working in remote locations. Our Australian business was the first to introduce resort-style
accommodations to the mining sector, adding landscaping, outdoor kitchens, pools, fitness centers and, in some
cases, taverns. In all our operating regions, our business is built on a culture of continual service improvement to
enhance the guest experience and reduce customer remote housing costs.
7
We take an active role in minimizing the environmental impact of our operations through a number of
sustainable initiatives. Our off-site building manufacturing process in Canada allows us to minimize waste that
arises from the construction process. We also have a focus on water conservation and utilize alternative water supply
options such as recycling and rainwater collection and use. By building infrastructure such as waste-water treatment
and water treatment facilities to recycle grey and black water on some of our sites, we are able to gain cost
efficiencies as well as reduce the use of trucks related to water and wastewater hauling, which in turn, reduces our
carbon footprint. In our Australian villages, we utilize passive-solar-design principles and smart-switching systems
to reduce the need for electricity related to heating and cooling.
Our Industry
We provide services for the oil and gas and mining industries. Our scalable modular facilities provide long-term
and temporary work force accommodations where traditional accommodations and related infrastructure often are
not accessible, sufficient or cost effective. Once facilities are deployed in the field, we also provide catering and
food services, housekeeping, laundry, facility management, water and wastewater treatment, power generation,
communications and personnel logistics. Demand for our services is cyclical and substantially dependent upon
activity levels, particularly our customers’ willingness to spend capital on the exploration for, development and
production of oil, coal, natural gas and other resource reserves. Our customers’ spending plans generally are based
on their view of commodity supply and demand dynamics, as well as the outlook for near-term and long-term
commodity prices. As a result, the demand for our services is highly sensitive to current and expected commodity
prices.
We serve multiple projects and multiple customers at most of our sites, which allows those customers to share
some of the costs associated with their peak construction accommodations needs. Our facilities provide customers
with cost efficiencies as they are able to share the costs of accommodations related infrastructure (power, water,
sewer and IT) and central dining and recreation facilities with other customers operating projects in the same
vicinity.
Our business is significantly influenced by the level of production of oil sands deposits in Alberta, Canada,
activity levels in support of natural resources production in Australia and oil and gas production in Canada and the
U.S. Our two primary activity drivers are development and production activity in the Canadian oil sands region in
Western Canada and the met coal region of Australia’s Bowen Basin.
Historically, oil sands developers and Australian mining companies built, owned and in some cases operated the
accommodations necessary to house their personnel in these remote regions because local labor and third-party
owned rooms were not available. Over the past 20 years and increasingly over the past 10 years, some customers
have moved away from the insourcing business model for some of their accommodations as they recognize that
accommodations are non-core investments for their business.
Civeo is one of the few accommodations providers that service the entire value chain from site identification to
long-term facility management. We believe that our existing industry divides accommodations into three primary
types: lodges and villages, open camps and mobile assets. Civeo is principally focused on lodges and villages.
Lodges and villages typically contain a larger number of rooms and require more time and capital to develop. These
facilities typically have dining areas, meeting rooms, recreational facilities, pubs and landscaped grounds where
weather permits. Lodges and villages are generally built supported by multi-year, take-or-pay contracts. These
facilities are designed to serve the long-term needs of customers in constructing and operating their resource
developments. Open camps are usually smaller in number of rooms and typically serve customers on a spot or short-
term basis. They are “open” for any customer who needs lodging services. Finally, mobile camps are designed to
follow customers’ activities and can be deployed rapidly to scale. They are often used to support conventional and
in-situ drilling crews, as well as pipeline and seismic crews, and are contracted on a project-by-project, well-by-well
or short-term basis. Oftentimes, customers will initially require mobile accommodations as they evaluate or initially
develop a field or mine. Open camps may best serve smaller operations or the needs of customers as they expand in
a region. These open camps can also serve as an initial, small foothold in a region until the demand for a full-scale
lodge or village is required.
8
The accommodations market is segmented into competitors that serve components of the overall value chain,
but has very few integrated providers. We estimate that customer-owned rooms represent over 50% of the market.
Engineering firms such as Bechtel, Fluor and ColtAmec often design accommodations facilities. Many public and
private firms, such as ATCO Structures & Logistics Ltd. (ATCO), WesternOne Inc.’s modular building division
(Britco), Horizon North Logistics Inc. (Horizon North), Alta-Fab Structures Ltd. (Alta-Fab) and Northgate
Industries Ltd. (Northgate) will build the modular accommodations for sale. Horizon North, Black Diamond Group
Limited (Black Diamond), ATCO, Royal Camp Services Ltd. and Algeco Scotsman will primarily own and lease the
units to customers and in some cases provide facility management services, usually on a shorter-term basis with a
more limited number of rooms, similar to our open camp and mobile fleet business. Facility service companies, such
as Aramark Corporation (Aramark), Sodexo Inc. (Sodexo) or Compass Group PLC (Compass Group), typically do
not invest in and own the accommodations assets, but will manage third-party or customer-owned facilities. We
believe the integrated model provides value to our customers by reducing project timing and counterparty risks. In
addition, with our holistic approach to accommodations, we are able to identify efficiency opportunities for the
customers and execute them. With our focus on large-scale lodges and villages, our business model is most similar
to a developer of multi-family properties, such as Camden Property Trust or Post Properties, or a developer of
lodging properties who is also an owner operator, such as Hyatt Hotels Corporation or Marriott International, Inc.
Canada
Overview
During the year ended December 31, 2016, we generated approximately 70% of our revenue from our Canadian
operations. We are Canada’s largest integrated provider of accommodations services for people working in remote
locations. We provide our accommodation services through lodges, open camps and mobile assets. Our
accommodations support workforces in the Canadian oil sands and in a variety of oil and natural gas drilling, mining
and related natural resource applications, as well as disaster relief efforts.
Canadian Market
Demand for our oil sands accommodations is primarily influenced by the longer-term outlook for crude oil
prices rather than current energy prices, given the multi-year production phase of Canadian oil sands projects and
the costs associated with development of such large scale projects. Utilization of our existing Canadian capacity and
our future expansions will largely depend on continued oil sands spending related to existing production efforts,
maintenance thereon and potential future expansion of existing projects.
The Athabasca oil sands are located in northern Alberta, an area that is very remote, with a limited local labor
supply. Of Canada’s 36.3 million residents, nearly half of the population lives in ten cities, only approximately 10%
of the population lives in Alberta and less than 1% of the population lives within 100 kilometers of the oil sands.
The local municipalities, of which Fort McMurray is the largest, have grown rapidly over the last decade, stressing
their infrastructures and challenging them to respond to large-scale changes in demand. As such, the workforce
accommodations market provides a cost effective solution to the problem of staffing large oil sands projects by
sourcing labor largely throughout Canada to work on a rotational basis.
A number of multinational energy companies believe there is the potential to export LNG from Canada to meet
the increasing global demand, particularly in Asia, for LNG. Currently, Canada does not have any operational LNG
export facilities. However, as of December 2016, there were 20 proposed LNG export facilities in British Columbia
in various stages of feasibility assessment and project planning, although none have reached a final investment
decision. We expect that LNG activity in Western Canada will be influenced by the global prices for LNG, which
are largely tied to global oil prices, as well as wellhead prices for natural gas. Should our customers or potential
customers decide to invest in these LNG projects, demand for accommodations over the next three years will be
driven by (i) the construction of the LNG facilities on the coast of British Columbia and (ii) the construction of the
related pipeline infrastructure across British Columbia. Facility construction will create demand for permanent
lodge accommodations, while pipeline construction activity will drive demand for temporary mobile workforce
accommodations. As noted above, the FID for LNGC’s proposed LNG export facility, which was originally
planned for the end of 2016, has been delayed until a future time that has not yet been determined. However, should
the project, and other potential projects in the area, not move forward, the resulting impact may negatively affect our
9
future results of operations and our existing long-lived assets in Canada, including our Sitka Lodge, and may require
us to record further material impairment charges equal to the excess of the carrying value of these assets over fair
value.
Canadian Oil Sands Lodges
During the year ended December 31, 2016, activity in the Athabasca oil sands region generated over 75% of our
Canadian revenue. The oil sands region of northern Alberta, Canada continues to represent one of the world’s largest
reserves for heavy oil. Our McClelland Lake, Wapasu, Athabasca, Henday and Beaver River Lodges are focused on
the northern region of the Athabasca oil sands, where customers primarily utilize surface mining to extract the
bitumen, or oil sands. Oil sands mining operations are characterized by large capital requirements, large reserves,
large personnel requirements, very low exploration or reserve risk and relatively lower cash operating costs per
barrel of bitumen produced. Our Conklin and Anzac lodges, as well as a portion of our mobile fleet of assets, are
focused in the southern portion of the region where we primarily serve in situ operations and pipeline expansion
activity. In situ methods are used on reserves that are too deep for traditional mining methods. In situ technology
typically injects steam to the deep oil sands in place to separate the bitumen from the sand and pumps it to the
surface where it undergoes the same upgrading treatment as the mined bitumen. Reserves requiring in situ
techniques of extraction represent 80% of the established recoverable reserves in Alberta. In situ operations
generally require less capital and personnel and produce lower volumes of bitumen per development, with higher
ongoing operating expense per barrel of bitumen produced.
We opened our McClelland Lake Lodge in the summer of 2014 at an initial capacity of 1,561 rooms and
reached our full initial capacity of 1,997 rooms in the first quarter of 2015. McClelland Lake Lodge currently
supports a new oil sands mining project in the region under a three-year contract for the majority of the rentable
rooms. During the third quarter of 2015, we also redeveloped our Mariana Lake location and reclassified the
location as an oil sands lodge. The Mariana Lake Lodge has 686 rooms and is focused on the southern portion of the
region.
Our oil sands lodges support construction and operating personnel for maintenance and expansionary projects,
as well as ongoing operations associated with surface mining and in situ oil sands projects, generally under short and
medium-term contracts. All of our oil sands lodge properties are located on land, with leases obtained from the
province of Alberta with initial terms of ten years. Our leases have expiration dates that range from 2017 to 2026.
Currently, only 11% of our Canadian lodge rooms are on land with leases expiring prior to December 31, 2017. In
recent years, we have successfully renewed or extended all expiring land leases, with the exception of one lease on
private land in 2014, and expect we will be able to in the future. We provide a full service hospitality function at our
lodges, including reservation management, check in and check out, catering, housekeeping and facilities
management. Our lodge guests receive the amenity level of a full-service hotel plus three meals a day. During 2016,
we added 564 rooms (net of retirements) to our major oil sands lodges. Our Wapasu Creek Lodge is equivalent in
size to the largest hotels in North America.
During the year ended December 31, 2016, over 75% of our Canadian revenue was generated by our eight
major lodges. We provide our lodge services on a day rate or monthly rental basis and our customers typically
commit for short to medium-term contracts (from several months up to several years). Customers make a minimum
nightly or monthly room commitment for the term of the contract, and the multi-year contracts typically provide for
inflationary escalations in rates for increased food, labor and utilities costs.
Canadian LNG Lodge
During the fourth quarter of 2015, in Kitimat, British Columbia, we built 436 rooms during the initial
development of our Sitka Lodge. Most of these rooms are currently under contract through September 2017 to LNG
Canada, a large LNG export project proposed by a joint venture between Shell Canada Energy, an affiliate of Royal
Dutch Shell plc (50 percent), and affiliates of PetroChina (20 percent), Korea Gas Corporation (15 percent) and
Mitsubishi Corporation (15 percent). The initial phase of this location features catering services and recreational
facilities and the ability to expand should demand for rooms in the region warrant.
10
In addition, we were awarded a contract with LNGC to construct a 4,500 person workforce accommodation
center (Cedar Valley Lodge) for a proposed liquefaction and export facility in Kitimat, British Columbia.
Construction of Cedar Valley Lodge will not commence until LNGC’s joint venture participants have reached
positive FID. The FID was originally planned for the end of 2016; however, this decision has been delayed until a
future time that has not yet been determined. We are currently in discussions with LNGC to extend this contract
until a positive FID is made. With the delay in the FID, we currently expect that LNGC will continue to utilize
rooms at our Sitka Lodge through September 2017 in accordance with the terms of our contract. However, this
contract may be extended to a new FID date based upon our current discussions with LNGC. There can be no
assurance that LNGC’s joint venture participants will reach a positive FID or that our contracts with LNGC will be
extended.
Canadian Lodge Locations
Rooms in our Canadian Lodges
Lodges
Region
N. Athabasca
N. Athabasca
N. Athabasca
N. Athabasca
N. Athabasca
S. Athabasca
S. Athabasca
S. Athabasca
Wapasu .....................................................
Athabasca .................................................
McClelland Lake ......................................
Henday (1) ..................................................
Beaver River .............................................
Conklin .....................................................
Anzac .......................................................
Mariana Lake (2) ........................................
Subtotal – Oil Sands..................................
Sitka Lodge ...............................................
Total Rooms ............................................
Kitimat, BC
Extraction
Technique
mining
mining
mining
mining/in situ
mining
mining/in situ
in situ
mining
LNG
As of December 31,
2015
5,174
2,005
1,997
1,698
1,094
700
526
526
13,720
436
14,156
2014
5,174
2,005
1,888
1,698
1,094
700
526
---
13,085
---
13,085
2016
5,246
2,005
1,997
1,698
1,094
1,032
526
686
14,284
436
14,720
_______________
(1) Currently closed due to low activity level in the region.
(2) During the third quarter of 2015, we redeveloped our Mariana Lake location and reclassified the location as an
oil sands lodge.
11
Open Camps
In addition to our lodges, we have six open camps in Alberta, British Columbia, Saskatchewan and Manitoba.
The major differentiator between lodges and open camps is the size of the facility. Open camps are generally smaller
facilities that provide a level of amenity similar to that of one of our larger lodges, including quality accommodation
and food services, satellite television, fitness facilities and on-site laundry. We own the land where all of our open
camp assets are located, with the exception of Geetla Lodge, which is on leased land. In early 2015, we renewed our
Mariana Lake Lodge lease for a term through 2025, and this location was reclassified as an oil sands lodge in the
third quarter of 2015. In March 2015, we vacated the Redvers Lodge lease due to the negative outlook for future
occupancy. Open camps are typically utilized for exploratory, seasonal or short-term projects. Therefore, customer
commitments for open camps tend to be shorter in initial duration (six to 18 months). Open camps may be
operational for 12 months or several years or transition into lodges depending on customer demand. Over time, room
counts may fluctuate up or down depending on demand in the region. If the demand in a region decreases, open
camp assets can be relocated to areas of greater activity. We provide accommodation services at our open camps on
a day rate basis. Open camp revenue comprises a portion of “Other Revenue” in our Canadian segment.
Our Alberta open camps service the Athabasca and Peace River oil sands, as well as conventional and shale
play oil and gas developments and infrastructure expansions. Geetla Lodge services the Horn River Basin in British
Columbia.
Rooms in our Canadian Open Camps
As of December 31,
Open Camps
Province
2016
2015
2014
Mariana Lake (1) ...............
Boundary (2) .......................
Antler River (2) ...................
Red Earth ..........................
Redvers .............................
Geetla (2) ...........................
Pebble Beach (2) ................
Christina Lake (3) ...............
Total Rooms .....................
Alberta
Saskatchewan
Manitoba
Alberta
Saskatchewan
British Columbia
Alberta
Alberta
---
346
254
114
---
81
436
35
1,266
---
346
254
114
---
81
436
35
1,266
435
346
212
114
102
81
224
35
1,549
_______________
(1) During the third quarter of 2015, we redeveloped our Mariana Lake location and reclassified the location as
an oil sands lodge.
(2) Currently closed due to low activity level in the region.
(3) Currently included in assets held for sale.
Canadian Mobile Camps
Our mobile camps consists of modular, skid-mounted accommodations and central facilities that can be quickly
configured to serve a multitude of short to medium-term accommodation needs. The dormitory, kitchen and
ancillary assets can be rapidly mobilized and demobilized and are scalable to support 200 to 800 people in a single
location. In addition to asset rental, we provide catering and housekeeping, as well as camp management services,
including fresh water and sewage hauling services. Our mobile camps service the traditional oil and gas sector in
Alberta and British Columbia and in situ oil sands drilling and development operations in Alberta, as well as
pipeline construction crews throughout Western Canada. The assets have also been used in the past in disaster relief
efforts, the 2010 Vancouver Winter Olympic Games and a variety of other non-energy related projects.
Our mobile camp assets are rented on a per unit basis based on the number of days that a customer utilizes the
asset. In cases where we provide catering or ancillary services, the contract can provide for per unit pricing or cost-
plus pricing. Customers are also typically responsible for mobilization and demobilization costs. Our focus on
ancillary service contracts has allowed us to successfully pursue catering only opportunities. Due to the business
nature of servicing client-owned facilities, this business easily fits into our overall business. Aside from the
traditional workforce accommodations, we are expanding our target markets to areas such as institutional,
12
educational and entertainment facilities. Mobile camp revenue comprises a portion of “Other Revenue” in our
Canadian segment.
Australia
Overview
During the year ended December 31, 2016, we generated 27% of our revenue from our Australian
operations. As of December 31, 2016, we had 9,386 rooms across ten villages, of which 7,392 rooms service the
Bowen Basin region of Queensland, one of the premier metallurgical (met) coal basins in the world. We provide
accommodation services on a day rate basis to mining and related service companies (including construction
contractors), typically under medium-term contracts (three to five years) with minimum nightly room commitments.
During 2016, we added 90 rooms to our Karratha village in the Pilbara region of Western Australia.
Australian Market
As the largest contributor to exports and a major contributor to the country’s gross domestic product,
employment and government revenue, the Australian natural resources sector plays a vital role in the Australian
economy. Australia has broad natural resources, including met and thermal coal, conventional and coal seam gas,
base metals, iron ore and precious metals such as gold. The growth of Australian natural resource commodity
exports over the last decade has been largely driven by strong Asian demand for coal, iron ore and LNG.
Australia’s resources are primarily located in remote regions of the country that lack infrastructure and resident
labor forces to develop these resources. Approximately 60% of the Australian population is located in five cities,
which are all located on the coast of Australia, and over 90% of the population lives in the southern half of the
country. Sufficient local labor is lacking near the major natural resources developments, which are primarily inland
and in the central and northern parts of the country. As a result, much of the natural resources labor force works on a
rotational basis, which often requires a commute from a major city or the coast and a living arrangement near the
resource projects. Consequently, there is substantial need for workforce accommodations to support resource
production in the country. Workforce accommodations have historically been built by the resource developer/owner,
typical of an insourcing business model.
Since 1996, our Australian business has sought to change the insourcing business model through its integrated
service offering, allowing customers to outsource their accommodations needs and focus their investments on
resource production operations. Our Australian accommodations villages are strategically located in proximity to
long-lived, low-cost mines operated by large mining companies. The current activities of our Australian segment
are primarily related to supplying accommodations in support of met coal mining in the Bowen Basin region of
Queensland.
During the year ended December 31, 2016, our five villages in the Bowen Basin of central Queensland
generated 83% of our Australian revenue. The Bowen Basin contains one of the largest coal deposits in Australia
and is renowned for its premium met coal. Met coal is used in the steel making process and demand has largely been
driven by global demand for steel finished goods and steel construction materials. In recent years, growth in
construction demand for steel products in emerging economies, particularly China, has slowed significantly,
negatively impacting demand for the commodity. Australia is the largest exporter of met coal in the world, in
addition to being in close proximity to the largest steel producing countries in the world. Our villages are focused on
the mines in the central portion of the basin and are well positioned for the active mines in the region.
Beyond the Bowen Basin, we serve several emerging markets with four additional villages. At the end of 2016,
we had two villages with over 1,000 combined rooms in the Gunnedah Basin, an emerging thermal and met coal as
well as coal seam gas region of New South Wales. In Western Australia, we serve workforces related to iron ore
port expansions and LNG facilities operations on the Northwest Shelf through our Karratha village.
13
Australian Village Locations
Rooms in our Australian Villages
Villages
Resource
Basin
Bowen
Coppabella ................................................
Bowen
Dysart .......................................................
Bowen
Moranbah .................................................
Middlemount.............................................
Bowen
Gunnedah
Boggabri ...................................................
Gunnedah
Narrabri .....................................................
Bowen
Nebo .........................................................
Calliope (1) .................................................
---
Goldfields
Kambalda .................................................
Pilbara
Karratha ....................................................
Total Rooms ............................................
Commodity
2016
2015
2014
As of December 31,
met coal
met coal
met coal
met coal
met/thermal coal
met/thermal coal
met coal
LNG
Gold, lithium
LNG, iron ore
3,048
1,798
1,240
816
662
502
490
300
232
298
9,386
3,048
1,798
1,240
816
662
502
490
300
232
208
9,296
3,048
1,798
1,240
816
662
502
490
300
232
208
9,296
_______________
(1) Currently closed due to low activity level in the region.
Our Australian segment operated ten villages with 9,386 rooms as of December 31, 2016 and has a significant
development portfolio in Australia. Our Australian business provides accommodation services to mining and related
service companies under short- and medium-term contracts. Our Australian accommodations villages are
strategically located near long-lived, low-cost mines operated by large mining companies. Our growth plan for this
part of our business continues to include the expansion of these properties where we believe there is durable long-
term demand.
Our Coppabella, Dysart, Moranbah, Middlemount and Nebo villages are located in the Bowen Basin.
Coppabella, at over 3,000 rooms, is our largest village and provides accommodation to a variety of customers. Each
of these villages supports both operational workforce needs and contractor needs with resort style amenities,
including swimming pools, gyms, a walking track and a tavern. Our Nebo, Dysart, Moranbah and Middlemount
Villages have a long history of providing service in the region.
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Our Narrabri and Boggabri villages in New South Wales service met and thermal coal mines and coal seam gas
in the Gunnedah Basin. Karratha village, in Western Australia, services workforces related to iron ore port
expansions and LNG facilities operations on the Northwest Shelf. Our Kambalda village supports gold and lithium
mining in southern Western Australia.
U.S.
Overview
During the year ended December 31, 2016, our U.S. business generated 3% of our revenue. Our U.S. business
has operational exposure to the Rocky Mountain corridor, the Bakken Shale region, the Permian Basin region of
Texas and offshore locations in the Gulf of Mexico. The business provides open camp facilities and highly mobile
smaller camps that follow drilling rigs and completion crews as well as accommodations, office and storage modules
that are placed on offshore drilling rigs and production platforms.
U.S. Market
Onshore oil and natural gas development has historically been supported by local workforces traveling short to
moderate distances to the worksites. With the development of substantial resources in regions such as the Bakken,
Rockies and Permian Basin, labor demand has exceeded the local labor supply and accommodations infrastructure
to support the demand. Consequently, demand for remote, scalable accommodations has developed in the U.S. over
the past five years. Demand for accommodations in the U.S. has historically been tied to the level of oil and natural
gas exploration and production activity, which is primarily driven by oil and natural gas prices. Activity levels have
been, and we expect will continue to be, highly correlated with hydrocarbon commodity prices.
U.S. Locations
U.S. Mobile Camps
Our business in the U.S. consists primarily of mobile camp assets, both in the lower 48 states, including the
Rocky Mountain corridor, the Bakken Shale region, the Permian Basin region of Texas and in the Gulf of Mexico.
We provide a variety of sizes and configurations to meet the needs of drilling contractors, completion companies,
infrastructure construction projects and offshore drilling and completion activity. We provide quality catering and
housekeeping services as well.
15
Our mobile fleet is rented on a per unit basis based on the number of days that a customer utilizes the asset. In
cases where we provide catering or ancillary services, the contract can provide for per unit pricing or cost-plus
pricing. Customers are also typically responsible for mobilization and demobilization costs.
Open Camps
State
As of December 31,
2015
2014
2016
West Permian .................
Three Rivers (1) ...............
Killdeer ..........................
Stanley House (2) .............
Total Rooms ..................
TX
TX
ND
ND
310
---
235
---
545
310
274
235
157
976
310
274
235
157
976
_______________
(1) Sold in January 2016.
(2) Closed in March 2016.
We had two open camps in the U.S. comprised of 545 rooms as of December 31, 2016. We sold our Three
Rivers location in January 2016 and closed the Stanley House location in March 2016. Our Killdeer Lodge, which
we opened in October 2013, provides accommodations support to the Bakken Shale region in North Dakota. Our
West Permian Lodge supports the Permian Basin in West Texas.
Modular Construction and Manufacturing
As part of our integrated business model in Canada, we utilize a flexible modular construction and
manufacturing strategy that combines internal manufacturing capabilities and outsourced manufacturing partners to
allow us to respond quickly to changing customer needs and timing. As of December 31, 2016, we own one
modular construction and manufacturing plant near Edmonton, Alberta, Canada. Our U.S. modular construction
facility in Johnstown, Colorado was closed during the first quarter of 2015 and sold in the fourth quarter of 2015. In
Australia, accommodation rooms are sourced from third-party manufacturers. Our Canadian facility specializes in
the design, engineering, production, transportation and installation of a variety of modular buildings, predominately
for our own use. In Canada, we have a staff of engineers and architects who have designed and delivered large and
small projects. We are capable of taking highly replicable and well-designed manufactured buildings and our
expertise in site layout, combined with site-built components including landscaping, recreational facilities and
certain common facilities, to create a comfortable community within a community. We design accommodations
facilities to suit the climate, terrain and population of a specific project site.
While we have traditionally focused our manufacturing efforts on our internal needs, from time to time we sell
units to third parties. Revenues from the sale of accommodation units to third parties has been a small portion of our
revenue and is included in “Other Revenue” in our Canadian and U.S. segments. We have not historically sold units
to third parties in Australia.
Community Relations
Partnering with local and indigenous communities is part of our long term strategy. In our Canadian operations,
we have worked in close collaboration with local indigenous communities to develop mutually beneficial, long-term
partnerships focused on employment, training, business development and community investments. For over a
decade, our Canadian operations have supported Buffalo Metis Catering, a partnership with three Metis
communities in the Regional Municipality of Wood Buffalo, to provide catering and housekeeping at three of our
lodges. This partnership was expanded under a similar agreement to provide catering and housekeeping services at
our McClelland Lake Lodge. Our efforts in the indigenous relations area were recognized in 2011 and 2012 through
Alberta Chamber of Commerce industry awards of recognition for excellence in indigenous relations business
practices. During the past year, Civeo has entered into partnership arrangements with three additional First Nations.
Beyond revenue sharing, these new arrangements provide employment, training and ancillary business opportunities
for First Nations owned businesses. In 2016, we were awarded a silver level PAR Certification by the Canada
Council for Aboriginal Business.
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In Australia, our community relations program also aims to build and maintain a positive social license to
operate in regional communities by delivering consultation and engagement from project inception, through
development, construction and operations. This is a major advantage for our business model, as it facilitates
consistent communication, engenders trust and builds relationships to last throughout the resource lifecycle. There is
an emphasis on developing partnerships that create a long-term sustainable outcome to address specific community
needs. To that end, we partner with local municipalities to improve and expand municipal infrastructure. These
improvements provide necessary infrastructure, allowing the local communities an opportunity to expand and
improve.
Customers and Competitors
Our customers primarily operate in oil sands mining and development, drilling, exploration and extraction of oil
and natural gas and coal and other extractive industries. To a lesser extent, we also support other activities,
including pipeline construction, forestry, humanitarian aid and disaster relief, and support for military
operations. Our largest customers in 2016 were Imperial Oil Limited (a company controlled by ExxonMobil
Corporation) and Fort Hills Energy LP (a partnership between Suncor Energy Inc., Total E&P Canada Ltd and Teck
Resources Limited), who each accounted for more than 10% of our 2016 revenues.
Our primary competitors in Canada in the open and mobile camp accommodations include ATCO, Black
Diamond, Horizon North, Noralta Lodge and Clean Harbors, Inc. Some of these competitors have one or two
locations similar to our oil sands lodges; however, based on our estimates, these competitors do not have the breadth
or scale of our lodge operations. In Canada, we also compete against Aramark and Compass Group for facility
management services.
Our primary competitors in Australia for our village accommodations are Ausco Modular (a subsidiary of
Algeco Scotsman) and Fleetwood Corporation. We also compete against Aramark, Sodexo and Compass Group for
facility management services.
In the U.S., we primarily offer our open camp and mobile camps accommodations and compete against Stallion
Oilfield Holdings, Inc., Target Logistics Management LLC (a subsidiary of Algeco Scotsman Global S.a.r.l.), HB
Rentals (a subsidiary of Superior Energy Services) and Black Diamond.
Historically, many customers have invested in their own accommodations. We estimate that our existing and
potential customers own approximately 50% of the rooms available in the Canadian oil sands and 50% of the rooms
in the Australian coal mining regions.
Our Lodge and Village Contracts
During the year ended December 31, 2016, revenues from our lodges and villages represented over 75% of our
consolidated revenues. Our customers typically contract for accommodations services under take-or-pay contracts
with terms that most often range from several months to three years. Our contract terms generally provide for a
rental rate for a reserved room and an occupied room rate that compensates us for services, including meals, utilities
and maintenance for workers staying in the lodges and villages. In multi-year contracts, our rates typically have
annual contractual escalation provisions to cover expected increases in labor and consumables costs over the
contract term. Over the term of the contract, the customer commits to a minimum number of rooms over a
determined period. In some contracts, customers have a contractual right to terminate rooms, for reasons other than a
breach, in exchange for a termination fee. As of December 31, 2016, we had commitments for 27% of our rentable
rooms for 2017 and 18% of our rentable rooms for 2018, respectively.
17
As of December 31, 2016, we had 6,651 rooms under contract, or 39% of our rentable rooms, respectively. The
table below details the expiration of those contracts:
2017
2018
2019
2020
2021
Thereafter
Total
Contracted
Room Expiration
3,624
934
—
260
116
1,717
6,651
The contracts expire throughout the year, and for many of the near-term expirations, we are in the process of
negotiating extensions or new commitments. We cannot assure that we can renew existing contracts or obtain new
business on the same or better terms, if at all.
Seasonality of Operations
Our operations are directly affected by seasonal weather. A portion of our Canadian operations is conducted
during the winter months when the winter freeze in remote regions is required for customers’ activity to occur. The
spring thaw in these frontier regions restricts operations in the second quarter and adversely affects our operations
and our ability to provide services. Our Canadian operations have also been impacted by forest fires and flooding in
the past five years. During the Australian rainy season between November and April, our operations in Queensland
and the northern parts of Western Australia can be affected by cyclones, monsoons and resultant flooding. In the
U.S., winter weather in the first quarter and the resulting spring break up in the second quarter have historically
negatively impacted our Bakken and Rocky Mountain operations. Our U.S. offshore operations have historically
been impacted by the Gulf of Mexico hurricane season from July through November.
Employees
As of December 31, 2016, we had approximately 1,400 full-time employees on a consolidated basis, 72% of
whom are located in Canada, 21% of whom are located in Australia and 7% of whom are located in the U.S. We
were party to collective bargaining agreements covering approximately 700 employees located in Canada and 120
employees located in Australia as of December 31, 2016.
Government Regulation
Our business is significantly affected by foreign and U.S. laws and regulations at the federal, provincial, state
and local levels relating to the oil, natural gas and mining industries, worker safety and environmental protection.
Changes in these laws, including more stringent regulations and increased levels of enforcement of these laws and
regulations, and the development of new laws and regulations could significantly affect our business and result in:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
increased compliance costs or additional operating restrictions associated with our operations or our
customers’ operations;
other increased costs to our business or our customers’ business;
reduced demand for oil, natural gas, and other natural resources that our customers produce; and
reduced demand for our services.
To the extent that these laws and regulations impose more stringent requirements or increased costs or delays
upon our customers in the performance of their operations, the resulting demand for our services by those customers
may be adversely affected, which impact could be significant and long-lasting. Moreover, climate change laws or
18
regulations could increase the cost of consuming, and thereby reduce demand for, oil and natural gas, which could
reduce our customers’ demand for our services. We cannot predict changes in the level of enforcement of existing
laws and regulations, how these laws and regulations may be interpreted or the effect changes in these laws and
regulations may have on us or our customers or on our future operations or earnings. We also are not able to predict
the extent to which new laws and regulations will be adopted or whether such new laws and regulations may impose
more stringent or costly restrictions on our customers or our operations.
Our operations and the operations of our customers are subject to numerous stringent and comprehensive
foreign, federal, provincial, state and local environmental laws and regulations governing the release or discharge of
materials into the environment or otherwise relating to environmental protection. Numerous governmental agencies
issue regulations to implement and enforce these laws, for which compliance is often costly yet critical. The
violation of these laws and regulations may result in the denial or revocation of permits, issuance of corrective
action orders, modification or cessation of operations, assessment of administrative and civil penalties, and even
criminal prosecution. We believe that we are in substantial compliance with existing environmental laws and
regulations and we do not anticipate that future compliance with existing environmental laws and regulations will
have a material effect on our financial condition, results of operations or cash flows. However, there can be no
assurance that substantial costs for compliance or penalties for non-compliance with these existing requirements will
not be incurred in the future by us or our customers. Moreover, it is possible that other developments, such as the
adoption of stricter environmental laws, regulations and enforcement policies or more stringent enforcement of
existing environmental laws and regulations, could result in additional costs or liabilities upon us or our customers
that we cannot currently quantify.
Canadian Environmental Regulations
In Canada the federal, provincial and local governments have jurisdiction to regulate environmental matters. We
or our customers may be subject to environmental regulations imposed by these three levels of government. The
following addresses updates to Canadian environmental regulations in 2016 that may affect us or our customers.
Air Quality Management
The Government of Alberta (Alberta) and the Government of Canada (Canada) each have frameworks for air
quality management that may affect us and our customers.
In June 2016, Canada announced the Multi-Sector Air Pollutants Regulations as part of the implementation of
the Air Quality Management System (AQMS) under the Canadian Council of Ministers of the Environment. The
Multi-Sector Air Pollutants Regulations impose mandatory air emissions standards for industry. The proposed
standards limit the amount of:
(i) nitrogen oxides (NOX) emitted from modern (new) and pre-existing (existing), gaseous-fuel-fired non-
utility boilers and heaters used in many industrial facilities;
(ii) NOX emitted from modern and pre-existing stationary spark-ignition gaseous-fuel-fired engines used
by many industrial facilities; and
(iii) NOx and sulphur dioxide (SO2) emitted from cement kilns.
These regulations may impact emission performance standards for compressors and boilers used by our
customers in conventional and steam assisted gravity operations in the oil sands and may affect our customers’
operations.
In addition to federal requirements, emissions from facilities in Alberta are subject to provincial regulation. On
March 22, 2016, the Alberta Energy Regulator (AER), which is responsible for regulating upstream oil and gas
activity in the province, published Directive 60 which requires operators to eliminate or reduce flaring associated
with a wide variety of energy development activities and operations. Meeting these regulatory requirements may
result in additional costs or liabilities for our customers’ operations.
19
Climate Change Regulation
Scientific studies have suggested that emissions of greenhouse gases (GHG), including carbon dioxide and
methane, may be contributing to warming of the Earth’s atmosphere and other climatic changes. On January 29,
2010, Canada affirmed its desire to be associated with the Copenhagen Accord that was negotiated in
December 2009 as part of the international meetings on climate change regulation in Copenhagen. The Copenhagen
Accord, which is not legally binding, allows countries to commit to specific efforts to reduce GHG emissions,
although how and when the commitments may be converted into binding emission reduction obligations, if ever, is
currently uncertain. Pursuant to the Copenhagen Accord process, Canada has indicated an economy-wide GHG
emissions target that equates to a 17 percent reduction from 2005 levels by 2020, and the former Canadian
conservative federal government indicated an objective of reducing overall Canadian GHG emissions by 60 percent
to 70 percent from 2006 levels by 2050. However, with current climate change measures in place, Canada’s GHG
emissions are forecast to be almost exactly at 2005 levels by 2020 and federal regulations for the oil and gas sector
have yet to be introduced.
In December 2015, 195 nations, including Canada, Australia, and the U.S., adopted the Paris Agreement at the
21st “Conference of the Parties” (COP 21). The Paris Agreement does not set legally binding emission reduction
targets but does set a goal of limiting global temperature increases to less than 2° Celsius. Canada announced that it
is in favor of the decision of the COP 21 to endeavor to take action to further limit global temperature increases to
less than 1.5° Celsius. The Paris Agreement also requires parties to submit Intended Nationally Determined
Contributions (INDCs) which set out their emission reduction targets and to renew these INDCs, with the goal of
increasing the reductions, every five years. The Paris Agreement does not legally bind the parties to reach their
INDCs, nor does it prescribe the measures it must take to achieve them. These measures are left to each participating
nation. In September 2016, the new federal government confirmed that it would not commit to a more ambitious
INDC than the preceding conservative federal government. Canada has not implemented any new regulations
specifically targeted at achieving its INDC.
In March 2016, Canada and the Government of the United States jointly announced their intention to take action
to reduce methane emissions from the oil and gas sector in an effort to meet their respective INDCs pursuant to the
Paris Agreement. For its part, Canada announced its intention to reduce methane emissions from the oil and gas
sector by 40-45 percent below 2012 levels by 2025 and stated that draft regulations to implement that commitment
would be published in early 2017. Until the federal methane reduction regulations are finalized, it is not possible to
determine the impact of such regulations on our customers. The federal methane reduction regulations, when
implemented, may result in additional costs or liabilities for our customers' operations
In March 2016, as a further effort to meet Canada’s INDCs, representatives of the federal and provincial
governments committed to imposing a price on carbon pollution, beginning at $10 per tonne in 2018 and increasing
at a rate of $10 annually to $50 per tonne in 2022. The federally established carbon price will apply in any province
that does not establish an equivalent framework by 2018. Federal regulations implementing the carbon price have
not been released. If the federal carbon pricing framework is implemented as planned, these regulatory changes may
increase costs to us and our customers.
To ensure that it meets its INDC commitments under the Paris Agreement, the Canadian federal government
may elect to impose further regulation on GHG emissions and may wish to enter into equivalency agreements with
provinces to establish a consistent regulatory regime for GHGs. This may result in increased costs to us and our
customers.
Additionally, GHG regulation can take place at the provincial level. For example, Alberta’s Climate Change
and Emissions Management Act provides a framework for managing GHG emissions by reducing specified gas
emissions, relative to total production from facilities that emit over 100,000 tons of carbon dioxide equivalent per
year. The accompanying regulation, the Specified Gas Emitters Regulation, requires mandatory emissions reductions
through the use of emissions intensity targets, and a company can meet the applicable emissions limits by making
emissions intensity improvements at regulated facilities, offsetting GHG emissions by purchasing offset credits or
emission performance credits in the open market, or acquiring “fund credits” (akin to allowances) by making
20
payments for each ton of GHG emissions over the required reduction target to the Alberta Climate Change and
Emissions Management Fund.
In June 2015, the government of Alberta amended the Specified Gas Emitters Regulation to increase the price
per fund credit from $15 to $20 per credit in 2016 and to $30 per credit in 2017. In addition, the amended Specified
Gas Emitter Regulation also increased the required emission reductions for regulated facilities. Facilities in their
ninth or subsequent year of commercial operation were historically required to reduce their net emissions intensity
to 12 percent below an established baseline until 2015. These facilities were required to reduce their net emissions
intensity to 15 percent below the established baseline in 2016 and to 20 percent below the established baseline in
2017. These amendments are likely to significantly increase the cost of compliance for some of our customers.
There are financial penalties for non-compliance for every ton of carbon dioxide equivalent over a facility’s net
emission intensity limit as well as for contraventions of other provisions contained in the Specified Gas Emitters
Regulation. Further, the Specified Gas Reporting Regulation imposes GHG emissions reporting requirements on a
company that has GHG emissions of 50,000 tons or more of carbon dioxide equivalent from a facility in a calendar
year. In addition, Alberta facilities must currently report emissions of industrial air pollutants and comply with
obligations in approvals and under other environmental regulations.
In addition to the amendments to the Specified Gas Emitters Regulation discussed above, Alberta announced a
new Climate Leadership Plan (the CLP) in November 2015. The policies set out in the CLP contemplate changes to
the regulation of GHG emissions from facilities emitting over 100,000 tonnes of carbon dioxide equivalent annually.
Those regulations are expected to be released in early 2017. These changes to the regulation of GHG emissions may
significantly increase the cost of compliance for some of our customers.
The CLP also proposes introducing a broad economy-wide levy on GHG emissions from the combustion of
fossil fuels, subject to limited exceptions. In May 2016, Alberta passed the Climate Leadership Act, implementing
the broad economy-wide levy on GHG emissions contemplated in the CLP. Under that Act, all fuel consumption –
including gasoline, diesel, and natural gas consumption – is subject to a carbon levy. The levy is set at $20 per ton in
2017 and will increase to $30 per ton in 2018 and will add to the cost of most fossil based fuels. This change to the
regulation of GHG emissions may result in additional costs for us and for our customers.
The CLP also targets a 45 percent reduction in methane emissions from oil and gas operations by 2025. It is not
certain how this will be achieved, but it is contemplated that new performance standards emissions from equipment
will be incentivized and potentially mandated. Legislation and regulations requirement to implement these policies
are anticipated in 2017. Further, as contemplated in the CLP, Alberta passed the Oil Sands Emissions Limit Act
which caps oil sands emissions at 100 million tonnes annually. The CLP also targets the phasing out of coal
generated electricity (or the emissions therefrom) by 2030. The combination of the announced carbon levy, and coal
phase out is expected to increase fuel and electricity prices, which could have an impact on our operating costs. The
direct and indirect costs of these regulatory changes may adversely affect our operations and financial results as well
as those of our customers with whom we conduct business.
Finally, it should be noted that some scientists have concluded that increasing concentrations of GHGs in the
Earth’s atmosphere may produce climate changes that have significant physical effects, such as higher sea levels,
increased frequency and severity of storms, droughts, floods and other climatic events. If any such effects were to
occur, they could have an adverse effect on our financial condition and results of operations.
The Canadian Species at Risk Act is intended to prevent wildlife species in Canada from disappearing and to
provide for the recovery of wildlife species that no longer exist in the wild in Canada, or that are endangered or
threatened as a result of human activity, and to manage species of special concern to prevent them from becoming
endangered or threatened. The designation of previously unprotected species as threatened or endangered in areas of
Canada where our customers’ oil and natural gas exploration and production operations are conducted could cause
them to incur increased costs arising from species protection measures or could result in limitations on their
exploration and production activities, which could have an adverse impact on demand for our services.
21
Alberta’s Electricity Market
On November 3, 2016, Alberta released the details of its Renewable Electricity Program (REP) which includes
a procurement process for renewable generation as part of Alberta’s CLP. The first procurement process is intended
to take place in 2017 and the projects must be operational by 2019. Alberta further announced on November 23,
2016, that it would restructure its power market to include a parallel capacity market by 2021.
There is still uncertainty regarding implementing the REP and Alberta’s new capacity market, which may
increase costs to us or our customers.
Royalty Regulations
In January 2016, the Government of Alberta announced Alberta’s Modernized Royalty Framework
(Framework). In April 2016, the Government of Alberta finalized the applicable formulas for the Framework which
into effect in January 1, 2017. The implementation of the Framework could have an adverse impact on some of our
customers.
Australian Environmental Regulations
Our Australian segment is regulated by general statutory environmental controls at both the state and federal
level which may result in land use approval and compliance risk. These controls include: land use and urban design
controls; the regulation of hard and liquid waste, including the requirement for tradewaste and/or wastewater permits
or licenses; the regulation of water, noise, heat, and atmospheric gases emissions; the regulation of the production,
transport and storage of dangerous and hazardous materials (including asbestos); and the regulation of pollution and
site contamination. Some specified activities, for example, sewage treatment works, may require regulation at a state
level by way of environmental protection licenses which also impose monitoring and reporting obligations on the
holder. There is an increasing emphasis from state and federal regulators on sustainability and energy efficiency in
business operations. Federal requirements are now in place for the mandatory disclosure of energy performance
under building rating schemes. These schemes require the tracking of specific environmental performance factors.
Carbon reporting requirements currently exist for corporations which meet a reporting threshold for greenhouse
gases or energy use or production for a reporting (financial) year under national legislation.
U.S. Environmental Regulations
The Clean Water Act, as amended, and analogous state laws impose restrictions and strict controls regarding the
discharge of pollutants into state waters or waters of the U.S. The discharge of pollutants into jurisdictional waters is
prohibited unless the discharge is permitted by the U.S. Environmental Protection Agency (EPA) or authorized state
agencies. The EPA published a final rule outlining its position on the federal jurisdictional reach over waters of the
U.S. in June 2015, but this rule has been stayed nationwide by the U.S. Sixth Circuit Court of Appeals pending a
substantive decision on the merits. In January 2017, the United States Supreme Court accepted review of the rule to
determine whether jurisdiction to hear challenges to the rule rests with the federal district or appellate courts.
Litigation surrounding this rule is ongoing. Many of our U.S. properties and operations require permits for
discharges of wastewater and/or storm water, and we have developed a system for securing and maintaining these
permits. In addition, the Oil Pollution Act of 1990, as amended (OPA), imposes a variety of requirements on
responsible parties related to the prevention of oil spills and liability for damages, including natural resource
damages, resulting from such spills in waters of the U.S. A responsible party under OPA includes the owner or
operator of an onshore facility or vessel, or the lessee or permittee of the area in which an offshore facility is
located. The Clean Water Act and analogous state laws provide for administrative, civil and criminal penalties for
unauthorized discharges and, together with the OPA, require the development and implementation of spill
prevention and response plans and impose liability for the remedial costs and associated damages arising out of any
unauthorized discharges.
The EPA has adopted rules requiring the monitoring and reporting of GHG emissions from specified large GHG
emission sources in the U.S., including, offshore and onshore oil and natural gas production facilities, on an annual
basis. In October 2015, the EPA finalized rules that added new sources to the scope of the GHG monitoring and
22
reporting requirements. These new sources include gathering and boosting facilities as well as completions and
workovers from hydraulically fractured oil wells. In addition, the EPA has finalized new regulations that would
further restrict GHG emissions, such as new standards for methane and volatile organic compound (VOC) emissions
from new and modified oil and gas sources, which the EPA published in June 2016. The EPA has also announced
that it intends to impose methane emission standards for existing sources and has issued information collection
requests for oil and natural gas facilities. In November 2016, the Bureau of Land Management (BLM) issued new
regulations to reduce “waste” of natural gas—of which methane is a primary constituent—from venting, flaring and
leaks during oil and natural gas production activities on onshore federal and Indian lands. In October 2015, the EPA
finalized the Clean Power Plan, which imposes additional obligations on the power generation sector to reduce GHG
emissions. However, on February 9, 2016, the U.S. Supreme Court stayed implementation of the Clean Power Plan
pending resolution of legal challenges to the rule. While our operations are not directly affected by these actions,
their impact on our oil and natural gas exploration and production customers could result in a decreased demand for
the services that we provide.
While the U.S. Congress has from time to time considered legislation to reduce emissions of GHGs, there has
not been significant activity in the form of adopted legislation to reduce GHG emissions at the federal level in recent
years. In the absence of federal climate legislation in the U.S., a number of state and regional efforts have emerged
that are aimed at tracking and/or reducing GHG emissions by means of cap and trade programs that typically require
major sources of GHG emissions, such as electric power plants, to acquire and surrender emission allowances in
return for emitting those GHGs. The U.S. also participated in the creation of the Paris Agreement at COP 21 in
December 2015. Although it is not possible at this time to predict how legislation or new regulations that may be
adopted to address GHG emissions would impact our business, any such future laws and regulations could require
us or our customers to incur increased operating costs, such as costs to purchase and operate emissions control
systems, to acquire emission allowances or comply with new regulatory or reporting requirements. Any such
legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for oil and
natural gas, which could reduce our customers’ demand for our services. Consequently, legislation and regulatory
programs to reduce GHG emissions could have an adverse effect on our business, financial condition and results of
operations.
Our operations as well as the operations of our customers are also subject to various laws and regulations
addressing the management, disposal and releases of regulated substances. For example, in the U.S., the federal
Resource Conservation and Recovery Act, as amended (RCRA) and comparable state statutes regulate the
generation, storage, treatment, transportation, disposal and cleanup of hazardous and non-hazardous solid wastes.
Under the auspices of the EPA, most states administer some or all of the provisions of RCRA, sometimes in
conjunction with their own, more stringent requirements. Federal and state regulatory agencies can seek to impose
administrative, civil and criminal penalties for alleged non-compliance with RCRA and analogous state
requirements. In the course of our operations, we generate some amounts of ordinary industrial wastes, such as paint
wastes, waste solvents and waste oils that may be regulated as hazardous wastes. Moreover, the federal
Comprehensive Environmental Response, Compensation and Liability Act, as amended (CERCLA), also known as
the Superfund law, and comparable state laws impose liability, without regard to fault or legality of conduct, on
classes of persons considered to be responsible for the release of a “hazardous substance” into the environment.
These persons include the current and past owner or operator of the site where the release occurred and anyone who
disposed or arranged for the disposal of a hazardous substance released at the site. Under CERCLA, such persons
may be subject to joint and several strict liability for the costs of cleaning up the hazardous substances that have
been released into the environment, for damages to natural resources and for the costs of certain health studies.
CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public
health or the environment and to seek to recover from the responsible classes of persons the costs they incur. In
addition, neighboring landowners and other third parties may file claims for personal injury and property damage
allegedly caused by the hazardous substances released into the environment. We generate materials in the course of
our operations that may be regulated as hazardous substances. In the event of mismanagement or release of
regulated substances upon properties where we conduct operations, we could become subject to liability and/or
obligations under CERCLA, RCRA and/or analogous state laws. Under such laws, we could be required to
undertake response or corrective measures, which could include removal of previously disposed substances and
wastes, cleanup of contaminated property or performance of remedial operations to prevent future contamination.
23
The federal Endangered Species Act, as amended (ESA), restricts activities in the U.S. that may affect
endangered or threatened species or their habitats. If endangered species are located in areas of the U.S. where our
oil and natural gas exploration and production customers operate, such operations could be prohibited or delayed or
expensive mitigation may be required. Moreover, as a result of a settlement approved by the U.S. District Court for
the District of Columbia in 2011, the U.S. Fish and Wildlife Service is required to make a determination on listings
of more than 250 species as endangered or threatened under the ESA before the end of the agency’s 2017 fiscal year.
The designation of previously unprotected species as threatened or endangered in areas of the U.S. where our
customers’ oil and natural gas exploration and production operations are conducted could cause them to incur
increased costs arising from species protection measures or could result in limitations on their exploration and
production activities, which could have an adverse impact on demand for our services.
Hydraulic fracturing is a process sometimes used to stimulate production of hydrocarbons from tight
formations. The process involves the injection of water, sand and chemicals under pressure into formations to
fracture the surrounding rock and stimulate production. Hydraulic fracturing is typically regulated by state oil and
natural gas regulators, but EPA has asserted federal regulatory authority pursuant to the Safe Drinking Water Act
(SDWA) over, and issued permitting guidance in February 2014 for, certain hydraulic fracturing activities involving
the use of diesel fuels. In May 2014, EPA issued an advance notice of proposed rulemaking seeking comment on the
development of regulations under the Toxic Substances Control Act (TSCA) to require companies to disclose
information regarding the chemicals used in hydraulic fracturing. In March 2015, BLM issued a final rule that
imposes requirements on hydraulic fracturing activities on federal and Indian lands, including new requirements
relating to public disclosure, wellbore integrity and handling of flowback water; similar final rules were published in
November 2016 for hydraulic fracturing activities on National Park and National Wildlife Refuge System lands.
However, in June 2016, the U.S. District Court for the District of Wyoming struck down the BLM final rule, finding
that BLM lacked authority to promulgate the rule. That decision is currently being appealed by the federal
government. In addition, Congress has from time to time considered legislation to provide for federal regulation of
hydraulic fracturing under the SDWA and to require disclosure of chemicals used in the hydraulic fracturing
process. Some states and local governments also have adopted or are considering adopting regulations to restrict or
ban hydraulic fracturing in certain circumstances. Moreover, ongoing governmental reviews of the environmental
impacts of hydraulic fracturing by EPA and other agencies could lead to further regulation of hydraulic fracturing.
For example, in December 2016, the EPA released its final report on the potential impacts of hydraulic fracturing on
drinking water resources. The final report concluded that hydraulic fracturing activities can impact drinking water
under some circumstances, including large volume spills and inadequate mechanical integrity of wells. While our
operations are not directly affected by these actions, their impact on our oil and natural gas exploration and
production customers could result in a decreased demand for the services that we provide.
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ITEM 1A. Risk Factors
We are subject to various risks and hazards due to the nature of the business activities we conduct. The risks
discussed below, any of which could materially and adversely affect our business, financial condition, cash flows
and results of operations and the price of our shares, are not the only risks we face. We may experience additional
risks and uncertainties not currently known to us or, as a result of developments occurring in the future, conditions
that we currently deem to be immaterial may also materially and adversely affect our business, financial condition,
cash flows and results of operations.
Risks Related to Our Business
Decreased customer expenditure levels have adversely affected and may continue to adversely affect our
results of operations.
Demand for our services is sensitive to the level of exploration, development and production activity of, and the
corresponding capital spending by, oil and gas and mining companies. Throughout 2015 and 2016 and continuing
into 2017, our customers’ expenditures have declined significantly due to the long-term decline in commodity
prices. If our customers’ expenditures continue to decline in regions where our facilities are located, our business
will be further adversely impacted. The oil and gas and mining industries’ willingness to explore, develop and
produce depends largely upon the availability of attractive resource prospects and the prevailing view of future
commodity prices, which over the past year, has not been positive. Prices for oil, coal, natural gas, and other
minerals are subject to large fluctuations in response to changes in the supply of and demand for these commodities,
market uncertainty, and a variety of other factors that are beyond our control. Accordingly, a sudden or long-term
decline in commodity pricing, or a continuation of the current depressed commodity price environment, would have
material adverse effects on our results of operations.
During the first quarter of 2016, global oil prices dropped to their lowest level in over ten years due to concerns
over global oil demand, global crude inventory levels, worldwide economic growth and price cutting by major oil
producing countries, such as Saudi Arabia. Increasing global supply and higher than normal inventory levels have
also negatively impacted pricing. With falling Brent Crude and West Texas Intermediate (WTI) oil prices, Western
Canadian Select (WCS) has also fallen. WCS prices in the fourth quarter of 2016 averaged $34.34 per barrel
compared to a low of $20.26 in the first quarter of 2016 and a high of $83.78 in the second quarter of 2014. As of
February 20, 2017, the WTI price was $53.40, and the WCS price was $39.78. In addition, met coal prices have
decreased materially from approximately $119/metric ton as of December 31, 2014 to approximately $92.50/metric
ton as of September 30, 2016, due to a declining demand for steel and the impact of a stronger U.S. dollar. As of
February 20, 2017, contract met coal prices were approximately $285.00 per metric tonne and spot prices for met
coal were $150 per metric tonne, significantly higher than the September 2016 contract price of $92.50 per metric
tonne, due to supply side factors that have restricted met coal volumes. The existing commodity price environment
has significantly depressed exploration, development, and production activity. A sustained continuation of these
prices or further deterioration is likely to continue to depress activity levels, often reflected as reductions in
employees or resource production, and have a material adverse effect on our financial position, results of operations
or cash flows.
Additionally, significant new regulatory requirements, including climate change legislation, could have an
impact on the demand for and the cost of producing oil, coal and natural gas in the regions where we operate. Many
factors affect the supply of and demand for oil, coal, natural gas and other minerals and, therefore, influence product
prices, including:
(cid:2)
(cid:2)
(cid:2)
the level of activity and developments in the Canadian oil sands;
the global level of demand, particularly from China, for coal and other natural resources produced in
Australia;
the availability of economically attractive oil and natural gas field prospects, which may be affected by
governmental actions or environmental activists which may restrict development;
25
(cid:2)
(cid:2)
the availability of transportation infrastructure for oil, natural gas, LNG and coal, refining capacity and
shifts in end-customer preferences toward fuel efficiency and the use of natural gas;
global weather conditions and natural disasters;
(cid:2) worldwide economic activity including growth in developing countries, such as China and India;
(cid:2)
(cid:2)
(cid:2)
(cid:2)
national government political requirements, including the ability of the Organization of Petroleum
Exporting Companies (OPEC) to set and maintain production levels and prices for oil and government
policies which could nationalize or expropriate oil and natural gas exploration, production, refining or
transportation assets;
the level of oil and gas production by non-OPEC countries;
rapid technological change and the timing and extent of energy resource development, including LNG or
other alternative fuels;
environmental regulation; and
(cid:2) U.S. and foreign tax policies.
Our failure to retain our current customers, renew our existing customer contracts and obtain new customer
contracts, or the termination of existing contracts, could adversely affect our business.
Our success depends on our ability to retain our current customers, renew or replace our existing customer
contracts and obtain new business. Our ability to do so generally depends on a variety of factors, including overall
customer expenditure levels and the quality, price and responsiveness of our services, as well as our ability to
market these services effectively and differentiate ourselves from our competitors. We cannot assure you that we
will be able to obtain new business, renew existing customer contracts at the same or higher levels of pricing, or at
all, or that our current customers will not turn to competitors, cease operations, elect to self-operate or terminate
contracts with us. Because of the current depressed commodity price environment, our customers may not renew
contracts on terms favorable to us or, in some cases, at all, and we may have difficulty obtaining new business.
Additionally, several contracts have clauses that allow termination upon the payment of a termination fee. As a
result, our customers may choose to terminate their contracts. The likelihood that a customer may seek to terminate
a contract is increased during periods of market weakness like those we are currently experiencing. Further, certain
of our customers may not reach positive final investment decisions on projects with respect to which we have been
awarded contracts to provide related accommodation, which may cause those customers to terminate the contracts.
Customer contract cancellations, the failure to renew a significant number of our existing contracts or the failure to
obtain new business would have a material adverse effect on our business and results of operations.
Due to the cyclical nature of the natural resources industry, our business may be adversely affected by
extended periods of low oil, coal or natural gas prices or unsuccessful exploration results may decrease our
customers’ spending and therefore our results.
Commodity prices have been and are expected to remain volatile. This volatility causes oil and gas and mining
companies to change their strategies and expenditure levels. Prices of oil, coal and natural gas can be influenced by
many factors, including reduced demand due to lower global economic growth, surplus inventory, improved
technology such as the hydraulic fracturing of horizontally drilled wells in shale discoveries, access to potential
productive regions and availability of required infrastructure to deliver production to the marketplace. In particular,
global demand for both oil and metallurgical coal is, at least partially, dependent on the growth of the Chinese
economy. Should gross domestic product growth in China slow further or contract, demand for oil and metallurgical
coal and, correspondingly, our accommodations would fall, which would negatively impact our financial results.
Our business typically supports projects that are capital intensive and require several years to generate first
production. The economic analyses conducted by our customers in oil sands, Australian mining and LNG
investment areas have historically assumed a relatively conservative longer-term price outlook for production from
26
such projects to determine economic viability. Because of the current depressed commodity price environment, our
customers have reduced or deferred, and may continue to reduce or defer, major expenditures, particularly in Canada
and Australia, given the long-term nature of many large scale development projects, adversely affecting our
revenues and profitability. In Canada, WCS crude is the benchmark price for our oil sands accommodations’
customers. Historically, WCS has traded at a discount to WTI. Should the price of WTI decline or the WCS discount
to WTI widen further, our oil sands customers may delay or eliminate additional investments, further reduce their
spending in the oil sands region or curtail or shut-down additional existing operations. Similarly, the volumes and
prices of the mineral products of our customers, including coal and gold, have historically varied significantly and
are difficult to predict. The demand for, and price of, these minerals and commodities is highly dependent on a
variety of factors, including international supply and demand, the price and availability of alternative fuels, actions
taken by governments and global economic and political developments. Mineral and commodity prices have
fluctuated in recent years and may continue to fluctuate significantly in the future. No assurance can be given
regarding future volumes or prices relating to the activities of our customers. We have experienced in the past, and
expect to experience in the future, significant fluctuations in operating results based on these changes.
In addition, the carrying value of our lodges or villages could be reduced by extended periods of limited or no
activity by our customers, which has required us to record impairment charges equal to the excess of the carrying
value of the lodges or villages over fair value. We recorded impairments of our long-lived assets, including
intangibles, of $46.1 million and $79.7 million in 2016 and 2015, respectively. We also recorded goodwill
impairments of $43.2 million in 2015. We may incur additional asset impairment charges in the future, which
charges will affect negatively our results of operations and financial condition.
Exchange rate fluctuations could adversely affect our U.S. dollar reported results of operations and financial
position.
Currency exchange rate fluctuations can create volatility in our consolidated financial position, results of
operations and/or cash flows. Because our consolidated financial results are reported in U.S. dollars, if we generate
net revenues or earnings in countries whose currency is not the U.S. dollar, the translation of such amounts into U.S.
dollars can result in an increase or decrease in our reported revenues, net income, financial condition and cash flows
depending upon exchange rate movements. For the year ended December 31, 2016, 97% of our revenues originated
from subsidiaries outside of the U.S. and were denominated in either the Canadian dollar or the Australian dollar.
As a result, a material decrease in the value of these currencies relative to the U.S. dollar has had, and may have in
the future, a negative impact on our reported revenues, net income, financial condition and cash flows. Any
currency controls implemented by local monetary authorities in countries where we currently operate could also
adversely affect our business, financial condition and results of operations.
Our reporting currency is the U.S. dollar, and we are exposed to currency exchange risk primarily between the
U.S. dollar and the Canadian and Australian dollars. We may attempt to limit the risks of currency fluctuation
where possible by entering into financial instruments to protect against foreign currency exposure. Our efforts to
limit exchange risks may be unsuccessful, thereby exposing us to foreign currency fluctuations that could cause our
results of operations, financial condition and cash flows to deteriorate.
We do business in Canada and Australia, whose political and regulatory environments and compliance
regimes differ from those in the United States.
A significant portion of our revenue is attributable to operations in Canada and Australia. These activities
accounted for 97% of our consolidated revenue in the year ended December 31, 2016. Risks associated with our
operations in Canada and Australia include, but are not limited to:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
international currency fluctuations;
different taxing regimes;
changing political conditions;
changing international and U.S. monetary policies;
27
(cid:2)
(cid:2)
(cid:2)
regional economic downturns;
expropriation, confiscation or nationalization of assets; and
foreign exchange limitations.
The regulatory regimes in these countries are substantially different than those in the United States, and may be
unfamiliar to U.S. investors. Violations of non-U.S. laws could result in monetary and criminal penalties against us
or our subsidiaries and could damage our reputation and, therefore, our ability to do business.
All but one of our major Canadian lodges are located on land subject to leases. If we are unable to renew a
lease, we could be materially and adversely affected.
All but one of our major Canadian lodges are located on land subject to leases. Accordingly, while we own the
accommodations assets, we only own a leasehold in those properties. If we are found to be in breach of a lease, we
could lose the right to use the property. In addition, unless we can extend the terms of these leases before their
expiration, as to which no assurance can be given, we will lose our right to operate our facilities located on these
properties upon expiration of the leases. In that event, we would be required to remove our accommodations assets
and remediate the site. Generally, our leases have an initial term of ten years and will expire between 2017 and 2026
unless extended. We can provide no assurances that we will be able to renew our leases upon expiration on similar
terms, or at all. If we are unable to renew leases on similar terms, it may have an adverse effect on our business.
Due to the significant concentration of our business in the oil sands region of Alberta, Canada and in the
Bowen Basin coal region of Queensland, Australia, adverse events in these areas could negatively impact our
business, and our geographic concentration could limit the number of customers seeking our services.
Because of the concentration of our business in the oil sands region of Alberta, Canada and in the coal
producing region of Queensland, Australia, two relatively small geographic areas, we have increased exposure to
political, regulatory, environmental, labor, climate or natural disaster events or developments that could
disproportionately impact our operations and financial results. For example, in 2011, major flooding caused by
seasonal rain and a cyclone impacted areas near our villages in Australia. Also in 2011 and 2016, forest fires in
northern Alberta impacted areas near our Canadian oil sands lodges. Due to our geographic concentration, any
adverse events or developments in our operating areas may disproportionately affect our financial results.
In addition, a limited number of companies operate in the areas in which our business is concentrated, and
occupancy at each of our lodges may be constrained by the radius which potential customers are willing to transport
their workers. Our geographic concentration could limit the number of customers seeking our services, and as to
any single lodge or village, we may have few potential customers. Therefore, we are subject to volatility in
occupancy in any location based on the capital spending plans of a limited number of customers, based on their
changing decisions as to whether to outsource or use their own company-owned accommodations and whether other
potential customers move into that lodge’s radius.
Development of permanent infrastructure in the Canadian oil sands region, the west coast of British
Columbia, regions of Australia or various U.S. locations where we locate our assets could negatively impact our
business.
We specialize in providing housing and personnel logistics for work forces in remote areas which often lack the
infrastructure typically available in nearby towns and cities. If permanent towns, cities and municipal infrastructure
develop, grow or otherwise become available in the oil sands region of northern Alberta, Canada, the west coast of
British Columbia or regions of Australia where we locate villages, then demand for our accommodations could
decrease as customer employees move to the region and choose to utilize permanent housing and food services.
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We depend on several significant customers. The loss of one or more such customers or the inability of one
or more such customers to meet their obligations to us could adversely affect our results of operations.
We depend on several significant customers. The majority of our customers operate in the energy or mining
industry. For a more detailed explanation of our customers, see “Business” in Item 1. The loss of any one of our
largest customers in any of our business segments or a sustained decrease in demand by any of such customers could
result in a substantial loss of revenues and could have a material adverse effect on our results of operations. In
addition, the concentration of customers in two industries may impact our overall exposure to credit risk, either
positively or negatively, in that customers may be similarly affected by changes in economic and industry
conditions. While we perform ongoing credit evaluations of our customers, we do not require collateral in support of
our trade receivables.
As a result of our customer concentration, risks of nonpayment and nonperformance by our counterparties are a
concern in our business. We are subject to risks of loss resulting from nonpayment or nonperformance by our
customers. Many of our customers finance their activities through cash flow from operations, the incurrence of debt
or the issuance of equity. Throughout 2015 and 2016 and continuing into 2017, commodity prices have remained
depressed, and the capital markets and availability of credit have been constrained relative to historical levels.
Additionally, many of our customers’ equity values have declined and could decline further. The combination of
lower cash flow due to commodity prices, a reduction in borrowing bases under reserve-based credit facilities and
the lack of available debt or equity financing may continue to result in a significant reduction in our customers’
liquidity and could impair their ability to pay or otherwise perform on their obligations to us. Furthermore, some of
our customers may be highly leveraged and subject to their own operating and regulatory risks, which increases the
risk that they may default on their obligations to us. The inability or failure of our significant customers to meet
their obligations to us or their insolvency or liquidation may adversely affect our financial results.
We are susceptible to seasonal earnings volatility due to adverse weather conditions in our regions of
operations.
Our operations are directly affected by seasonal differences in weather in the areas in which we operate, most
notably in Canada and Australia, and, to a lesser extent, the Rocky Mountain region and the Gulf of Mexico. A
portion of our Canadian operations is conducted during the winter months when the winter freeze in remote regions
is required for exploration and production activity to occur. The spring thaw in these frontier regions restricts
operations in the spring months and, as a result, adversely affects our operations and our ability to provide services
in the second and, to a lesser extent, third quarters. During the Australian rainy season, generally between the
months of November and April, our operations in Queensland and the northern parts of Western Australia can be
affected by cyclones, monsoons and resultant flooding. Severe winter weather conditions in the Rocky Mountain
region of the United States can restrict access to work areas for our customers. Our operations in the Gulf of
Mexico are also affected by weather patterns. Furthermore, the areas in which we operate are susceptible to forest
fires, which could interrupt our operations and adversely impact our earnings.
Our customers are exposed to a number of unique operating risks and challenges which could also adversely
affect us.
We could be materially adversely affected by disruptions to our clients’ operations caused by any one of or all
of the following singularly or in combination:
(cid:2) U.S. and international pricing and demand for the natural resource being produced at a given project (or
proposed project);
(cid:2)
(cid:2)
(cid:2)
unexpected problems, higher costs and delays during the development, construction and project start-up
which may delay the commencement of production;
unforeseen and adverse geological, geotechnical, seismic and mining conditions;
lack of availability of sufficient water or power to maintain their operations;
29
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
lack of availability or failure of the required infrastructure necessary to maintain or to expand their
operations;
the breakdown or shortage of equipment and labor necessary to maintain their operations;
risks associated with the natural resources industry being subject to various regulatory approvals. Such
risks may include a government agency failing to grant an approval or failing to renew an existing
approval, or the approval or renewal not being provided by the government agency in a timely manner or
the government agency granting or renewing an approval subject to materially onerous conditions;
risks to land titles, mining titles and use thereof as a result of native title claims;
claims by persons living in close proximity to mining projects, which may have an impact on the consents
granted;
interruptions to the operations of our customers caused by industrial accidents or disputes; and
delays in or failure to commission new infrastructure in timeframes so as not to disrupt customer
operations.
We may be adversely affected if customers reduce their accommodations outsourcing.
Our business and growth strategies depend in large part on customers outsourcing some or all of the services
that we provide. Many oil and gas and mining companies in our core markets own their own accommodations
facilities, while others outsource all or part of their accommodations requirements. Customers have largely built
their accommodations in the past but will outsource if they perceive that outsourcing may provide quality services at
a lower overall cost or allow them to accelerate the timing of their projects. We cannot be certain that these customer
preferences will continue or that customers that have outsourced accommodations will not decide to perform these
functions themselves or only outsource accommodations during the development or construction phases of their
projects. In addition, labor unions representing customer employees and contractors have, in the past, opposed
outsourcing accommodations to the extent that the unions believe that third-party accommodations negatively
impact union membership and recruiting. The reversal or reduction in customer outsourcing of accommodations
could negatively impact our financial results and growth prospects.
Increased operating costs and obstacles to cost recovery due to the pricing and cancellation terms of our
accommodation services contracts may constrain our ability to make a profit.
Our profitability can be adversely affected to the extent we are faced with cost increases for food, wages and
other labor related expenses, insurance, fuel and utilities, especially to the extent we are unable to recover such
increased costs through increases in the prices for our services, due to one or more of general economic conditions,
competitive conditions or contractual provisions in our customer contracts. Substantial increases in the cost of fuel
and utilities have historically resulted in cost increases in our lodges and villages. From time to time we have
experienced increases in our food costs. While we believe a portion of these increases were attributable to fuel
prices, we believe the increases also resulted from rising global food demand. In addition, food prices can fluctuate
as a result of foreign exchange rates and temporary changes in supply, including as a result of incidences of severe
weather such as droughts, heavy rains and late freezes. While our long term contracts often provide for annual
escalation in our room rates for food, labor and utility inflation, we may be unable to fully recover costs and such
increases would negatively impact our profitability on contracts that do not contain such inflation protections.
A failure to maintain food safety or comply with government regulations related to food and beverages or
serving alcoholic beverages may subject us to liability.
Claims of illness or injury relating to food quality or food handling are common in the food service industry,
and a number of these claims may exist at any given time. Because food safety issues could be experienced at the
source or by food suppliers or distributors, food safety could, in part, be out of our control. Regardless of the source
30
or cause, any report of food-borne illness or other food safety issues such as food tampering or contamination at one
of our locations could adversely impact our reputation, hindering our ability to renew contracts on favorable terms
or to obtain new business, and have a negative impact on our sales. Future food product recalls and health concerns
associated with food contamination may also increase our raw materials costs and, from time to time, disrupt our
business.
A variety of regulations at various governmental levels relating to the handling, preparation and serving of food
(including, in some cases, requirements relating to the temperature of food), and the cleanliness of food production
facilities and the hygiene of food-handling personnel are enforced primarily at the local public health department
level. We cannot assure you that we are in full compliance with all applicable laws and regulations at all times or
that we will be able to comply with any future laws and regulations. Furthermore, legislation and regulatory
attention to food safety is very high. Additional or amended regulations in this area may significantly increase the
cost of compliance or expose us to liabilities.
We serve alcoholic beverages at some of our facilities, and must comply with applicable licensing laws, as well
as local service laws. These laws generally prohibit serving alcoholic beverages to certain persons such as an
individual who is intoxicated or a minor. If we violate these laws, we may be liable to the patron and/or third parties
for the acts of the patron. We cannot guarantee that intoxicated or minor patrons will not be served or that liability
for their acts will not be imposed on us. There can be no assurance that additional regulation in this area would not
limit our activities in the future or significantly increase the cost of regulatory compliance. We must also obtain and
comply with the terms of licenses in order to sell alcoholic beverages in the jurisdictions in which we serve alcoholic
beverages. If we are unable to maintain food safety or comply with government regulations related to food,
beverages or alcoholic beverages, the effect could be materially adverse to our business or results of operations.
Our land banking strategy may not be successful.
Our land banking strategy is focused on investing early in land in order to gain a strategic, early mover
advantage in an emerging region or resource play. However, we cannot assure you that all land that we purchase or
lease will be in a region in which our customers require our services in the future. We also cannot assure you that the
property acquired by us will be profitably developed. Our land banking strategy involves significant risks that could
adversely affect our financial condition, results of operations, cash flow and the market price of our securities, which
include the following risks:
(cid:2)
the regions in which we invest may not develop or sustain adequate customer demand;
(cid:2) we may incur costs to acquire land and/or construct assets without securing a customer contract or prior to
finalization of an accommodations contract with a customer and, if the contract is not obtained or delayed,
the resulting impact could result in an impairment of the related investment;
(cid:2)
during the time between acquisition and use, and depending on adjacent uses of the land, the property may
become unusable or require costly remediation efforts due to environmental damage;
(cid:2) we may not be able to obtain financing for development projects on favorable terms or at all;
(cid:2) we may not be able to obtain, or may experience delays in obtaining, all necessary zoning, land-use,
building, occupancy and other governmental permits and authorizations, and the issuance of permits is
dependent upon a number of factors, including water and waste treatment alternatives available, road traffic
volumes and fire conditions in forested areas;
(cid:2)
(cid:2)
(cid:2)
development opportunities that we explore may be abandoned and the related investment impaired;
the properties may perform below anticipated levels, producing cash flow below budgeted amounts;
construction costs, total investment amounts and our share of remaining funding may exceed our estimates
and projects may not be completed, delivered or stabilized as planned;
31
(cid:2) we may experience delays (temporary or permanent) if there is public, government or aboriginal opposition
to our activities; and
(cid:2)
substantial renovation, new development and redevelopment activities, regardless of their ultimate success,
typically require a significant amount of management’s time and attention, diverting their attention from
our day-to-day operations.
Our business is contract intensive and may lead to customer disputes or delays in receipt of payments.
Our business is contract intensive and we are party to many contracts with customers. We periodically review
our compliance with contract terms and provisions. If customers were to dispute our contract determinations, the
resolution of such disputes in a manner adverse to our interests could negatively affect sales and operating results. In
the past, our customers have withheld payment due to contract or other disputes, which has delayed our receipt of
payments. While we do not believe any reviews, audits, delayed payments or other such matters should result in
material adjustments, if a large number of our customer arrangements were modified or payments withheld in
response to any such matter, the effect could be materially adverse to our business or results of operations.
We are subject to extensive and costly environmental laws and regulations that may require us to take
actions that will adversely affect our results of operations.
All of our operations are significantly affected by stringent and complex foreign, federal, provincial, state and
local laws and regulations governing the discharge of substances into the environment or otherwise relating to
environmental protection. We could be exposed to liabilities for cleanup costs, natural resource damages and other
damages as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by,
prior operators or other third-parties. Environmental laws and regulations are subject to change in the future,
possibly resulting in more stringent requirements. The implementation of new laws and regulations could result in
materially increased costs, stricter standards and enforcement, larger fines and liability and increased capital
expenditures and operating costs, particularly for our customers, and could have an adverse effect on our business or
demand for our services. See “Business - Government Regulation” in Item 1 for a more detailed description of our
risks associated with environmental laws and regulations.
Any failure by us to comply with applicable environmental laws and regulations may result in governmental
authorities taking actions against our business that could adversely impact our operations and financial condition,
including the:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
issuance of administrative, civil and criminal penalties;
denial or revocation of permits or other authorizations;
reduction or cessation of operations; and
performance of site investigatory, remedial or other corrective actions.
Construction risks exist which may adversely affect our results of operations.
There are a number of general risks that might impinge on companies involved in the development,
construction, manufacture and installation of facilities as a prerequisite to the management of those assets in an
operational sense. We might be exposed to these risks from time to time by relying on these corporations and/or
other third parties which could include any and/or all of the following:
(cid:2)
(cid:2)
the construction activities of our accommodations are partially dependent on the supply of appropriate
construction and development opportunities;
development approvals, slow decision making by counterparties, complex construction specifications,
changes to design briefs, legal issues and other documentation changes may give rise to delays in
32
completion, loss of revenue and cost over-runs which may, in turn, result in termination of accommodation
supply contracts;
(cid:2)
(cid:2)
other time delays that may arise in relation to construction and development include supply of labor,
scarcity of construction materials, lower than expected productivity levels, inclement weather conditions,
land contamination, cultural heritage claims, difficult site access or industrial relations issues;
objections to our activities or those of our customers aired by aboriginal or community interests,
environment and/or neighborhood groups which may cause delays in the granting or approvals and/or the
overall progress of a project;
(cid:2) where we assume design responsibility, there is a risk that design problems or defects may result in
rectification and/or costs or liabilities which we cannot readily recover; and
(cid:2)
there is a risk that we may fail to fulfill our statutory and contractual obligations in relation to the quality of
our materials and workmanship, including warranties and defect liability obligations.
The cyclical nature of our business and a severe prolonged downturn has and could in the future negatively
affect the value of our long-lived assets.
We recorded impairments of our long-lived assets, including intangibles, of $46.1 million and $79.7 million in
2016 and 2015, respectively. We also recorded goodwill impairments of $43.2 million in 2015.
Extended periods of limited or no activity by our customers at our lodges or villages could require us to record
further impairment charges equal to the excess of the carrying value of the lodges or villages over fair value. We
may recognize additional impairment losses on our long-lived assets in the future if, among other factors:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
global economic conditions remain depressed or further deteriorate, including a further decrease in the
price of or demand for oil, natural gas and minerals;
the outlook for future profits and cash flow for our Canadian and Australian reporting units deteriorates as
the result of many possible factors, including, but not limited to, increased or unanticipated competition,
technology becoming obsolete, need to satisfy changes in customers’ accommodations requirements,
further reductions in customer capital spending plans, loss of key personnel, adverse legal or regulatory
judgment(s), future operating losses at a reporting unit, downward forecast revisions or restructuring plans
or if certain of our customers do not reach positive final investment decisions on projects with respect to
which we have been awarded contracts to provide related accommodation, which may cause those
customers to terminate the contracts;
costs of equity or debt capital increase; or
valuations for comparable public companies or comparable acquisition valuations deteriorate.
An accidental release of pollutants into the environment may cause us to incur significant costs and
liabilities.
There is inherent risk of environmental costs and liabilities in our business as a result of our handling of
petroleum hydrocarbons, because of air emissions and waste water discharges related to our operations, and due to
historical industry operations and waste disposal practices. Certain environmental statutes impose joint and several
strict liability for these costs. For example, an accidental release by us in the performance of services at one of our
or our customers’ sites could subject us to substantial liabilities arising from environmental cleanup, restoration
costs and natural resource damages, claims made by neighboring landowners and other third parties for personal
injury and property damage and fines or penalties for related violations of environmental laws or regulations. We
may not be able to recover some or any of these costs from insurance.
33
We may be exposed to certain regulatory and financial risks related to climate change.
Climate change is receiving increasing attention from scientists and legislators alike. The debate is ongoing as
to the extent to which our climate is changing, the potential causes of any change and its potential impacts. Some
attribute global warming to increased levels of greenhouse gases, including carbon dioxide, which has led to
significant legislative and regulatory efforts to limit greenhouse gas emissions. Significant focus is being made on
companies that are active producers of depleting natural resources.
There are a number of legislative and regulatory proposals to address greenhouse gas emissions, which are in
various phases of discussion or implementation. The outcome of Canadian, Australian, U.S. federal, regional,
provincial and state actions to address global climate change could result in a variety of regulatory programs
including potential new regulations, additional charges to fund energy efficiency activities, or other regulatory
actions. These actions could:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
result in increased costs associated with our operations and our customers’ operations;
increase other costs to our business;
reduce the demand for carbon-based fuels; and
reduce the demand for our services.
Any adoption of these or similar proposals by Canadian, Australian, U.S. federal, regional, provincial or state
governments mandating a substantial reduction in greenhouse gas emissions could have far-reaching and significant
impacts on the energy industry. Although it is not possible at this time to predict how legislation or new regulations
that may be adopted to address greenhouse gas emissions would impact our business, any such future laws and
regulations could result in increased compliance costs or additional operating restrictions, and could have a material
adverse effect on our business or demand for our services. See “Business—Government Regulation” in Item 1 for a
more detailed description of our climate-change related risks.
Our inability to control the inherent risks of identifying, acquiring and integrating businesses that we may
acquire, including any related increases in debt or issuances of equity securities, could adversely affect our
operations.
Acquisitions have been, and our management believes acquisitions will continue to be, a key element of our
growth strategy. We may not be able to identify and acquire acceptable acquisition candidates on favorable terms in
the future. We may be required to incur substantial indebtedness to finance future acquisitions and also may issue
equity securities in connection with such acquisitions. Such additional debt service requirements could impose a
significant burden on our results of operations and financial condition. The issuance of additional equity securities
could result in significant dilution to shareholders.
We expect to gain certain business, financial and strategic advantages as a result of business combinations we
undertake, including synergies and operating efficiencies. Our forward-looking statements assume that we will
successfully integrate our business acquisitions and realize these intended benefits. An inability to realize expected
strategic advantages as a result of the acquisition would negatively affect the anticipated benefits of the acquisition.
Additional risks we could face in connection with acquisitions include:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
retaining key employees of acquired businesses;
retaining and attracting new customers of acquired businesses;
retaining supply and distribution relationships key to the supply chain;
increased administrative burden;
34
(cid:2)
developing our sales and marketing capabilities;
(cid:2) managing our growth effectively;
(cid:2)
(cid:2)
potential impairment resulting from the overpayment for an acquisition;
integrating operations;
(cid:2) managing tax and foreign exchange exposure;
(cid:2)
(cid:2)
(cid:2)
potentially operating a new line of business;
increased logistical problems common to large, expansive operations; and
inability to pursue and protect patents covering acquired technology.
Additionally, an acquisition may bring us into businesses we have not previously conducted and expose us to
additional business risks that are different from those we have previously experienced. If we fail to manage any of
these risks successfully, our business could be harmed. Our capitalization and results of operations may change
significantly following an acquisition, and our shareholders may not have the opportunity to evaluate the economic,
financial and other relevant information that we will consider in evaluating future acquisitions.
We may not have adequate insurance for potential liabilities and insurance may not cover certain liabilities,
including litigation.
Our operations are subject to many hazards. In the ordinary course of business, we become the subject of
various claims, lawsuits and administrative proceedings seeking damages or other remedies concerning our
commercial operations, products, employees and other matters, including occasional claims by individuals alleging
exposure to hazardous materials as a result of our products or operations. Some of these claims relate to the
activities of businesses that we have acquired, even though these activities may have occurred prior to our
acquisition of such businesses. We maintain insurance to cover many of our potential losses, and we are subject to
various self-retentions and deductibles under our insurance policies. It is possible, however, that a judgment could
be rendered against us in cases in which we could be uninsured and beyond the amounts that we currently have
reserved or anticipate incurring for such matters. Even a partially uninsured or underinsured claim, if successful and
of significant size, could have a material adverse effect on our results of operations or consolidated financial
position. In addition, we are insured under Oil States’ insurance policies for occurrences prior to the completion of
the Spin-off. The specifications and insured limits under those policies, however, may be insufficient for such
claims. We also face the following other risks related to our insurance coverage:
(cid:2) we may not be able to continue to obtain insurance on commercially reasonable terms;
(cid:2)
the counterparties to our insurance contracts may pose credit risks; and
(cid:2) we may incur losses from interruption of our business that exceed our insurance coverage.
Our operations may suffer due to increased industry-wide capacity of certain types of assets.
The demand for and/or pricing of rooms and accommodation service is subject to the overall availability of
rooms in the marketplace. If demand for our assets were to decrease, or to the extent that we and our competitors
increase our capacity in excess of current demand, we may encounter decreased pricing for or utilization of our
assets and services, which could adversely impact our operations and profits.
In addition, we significantly increased our capacity in the Canadian oil sands region and in Australia over the
past several years based on our previous expectations for customer demand for accommodations in these areas.
However, due to the sustained decline in commodity prices throughout 2015 and 2016 and the continued lower
prices in 2017, customer demand for accommodations in those areas has decreased significantly, and we have
35
experienced a corresponding significant decrease in our occupancy and profitability. Should our customers build
their own facilities to meet their accommodations needs or our competitors likewise increase their available
accommodations, or activity in the oil sands or natural resources regions declines further, demand and/or pricing for
our accommodations could further decrease, negatively impacting our profitability.
We operate in a highly competitive industry, and if we fail to compete effectively, our business will suffer.
The workforce accommodation, logistics and facility management industry in which we operate is highly
competitive. To be successful, we must provide services that meet the specific needs of our customers at competitive
prices. The principal competitive factors in the markets in which we operate are service quality and availability,
price, technical knowledge and experience and reputation for safety. We compete with international and regional
competitors, several of which are significantly larger than us. These competitors offer similar services in the
geographic regions in which we operate. Many oil and gas and mining companies in our core markets own their own
accommodations facilities, while others outsource all or part of their accommodations requirements. As a result of
competition, we may be unable to continue to provide our present services, to provide such services at historical
operating margins or to acquire additional business opportunities, which could have a material adverse effect on our
business, financial condition, results of operations and cash flows. Reduced levels of activity in the workforce
accommodation industry can intensify competition and result in lower revenue to us.
Loss of key members of our management could adversely affect our business.
We depend on the continued employment and performance of key members of our management. If any of our
key managers resign or become unable to continue in their present roles and are not adequately replaced, our
business operations could be materially adversely affected. We do not maintain “key man” life insurance for any of
our officers.
Employee and customer labor problems could adversely affect us.
As of December 31, 2016, we were party to collective bargaining agreements covering approximately 700
employees in Canada and 120 employees in Australia. In addition, our facilities serving oil sands development work
in Northern Alberta, Canada and mining operations in Australia house both union and non-union customer
employees. We have not experienced strikes, work stoppages or other slowdowns in the past, but we cannot
guarantee that we will not experience such events in the future. A prolonged strike, work stoppage or other
slowdown by our employees or by the employees of our customers could cause us to experience a disruption of our
operations, which could adversely affect our business, financial condition and results of operations. Collective
bargaining agreements in our Canadian operations have individual expiration dates, extending in some cases to
2019. Two enterprise bargaining agreements exist in our Australian operation covering certain employees working
at our villages in Queensland and New South Wales. These agreements expired in 2016 and we are currently in
negotiations with our employees for renewal of the agreements. A majority vote by the covered employees is
required for ratification of the enterprise bargaining agreements. Terms of the enterprise bargaining agreements will
continue while the negotiations continue. Should the negotiations fail, pay rates and conditions may become based
on those specified in the Hospitality Industry (General) Award 2010 set by the Australian Federal Government.
Failure to maintain positive relationships with the indigenous people in the areas where we operate could
adversely affect our business.
A component of our business strategy is based on developing and maintaining positive relationships with the
indigenous people and communities in the areas where we operate. These relationships are important to our
operations and customers who desire to work on traditional aboriginal lands. The inability to develop and maintain
relationships and to be in compliance with local requirements could have an adverse effect on our business, results
of operations or financial condition.
36
The enforcement of civil liabilities against Civeo may be more difficult.
Civeo is a British Columbia company and a substantial portion of its assets are located outside the U.S. As a
result, investors could experience more difficulty enforcing judgments obtained against us in U.S. courts than would
be the case for U.S. judgments obtained against a U.S. company. In addition, some claims may be more difficult to
bring against Civeo in Canadian courts than it would be to bring similar claims against a U.S. company in a U.S.
court.
Our historical combined financial information may not be representative of the results we would have
achieved as a stand-alone public company and may not be a reliable indicator of our future results.
The historical combined financial information for periods prior to the Spin-off that we have included in this
report has been derived from Oil States’ accounting records and may not necessarily reflect what our financial
position, results of operations or cash flows would have been had we been an independent, stand-alone entity during
the periods presented or those that we will achieve in the future. Oil States did not account for us, and we were not
operated, as a separate, stand-alone company for the historical periods prior to the Spin-off. The costs and expenses
reflected in such financial information include an allocation for certain corporate functions historically provided by
Oil States, including expense allocations for: (1) certain corporate functions historically provided by Oil States,
including, but not limited to finance, legal, risk management, tax, treasury, information technology, human
resources, and certain other shared services; (2) certain employee benefits and incentives; and (3) equity-based
compensation, that may be different from the comparable expenses that we would have incurred had we operated as
a stand-alone company. These expenses were allocated to us on the basis of direct usage when identifiable, with the
remainder allocated based on estimated time spent by Oil States personnel, a pro-rata basis of headcount or other
relevant measures of our business and Oil States and its subsidiaries. We have not adjusted our historical combined
financial information for periods prior to the Spin-off to reflect changes that occurred in our cost structure and
operations as a result of our transition to becoming a stand-alone public company, including increased costs
associated with an independent board of directors, SEC reporting and the NYSE requirements. For additional
information, see “Selected Historical Financial Data” in Item 6 and “Management’s Discussion and Analysis of
Financial Condition and Results of Operations” in Item 7 and our consolidated financial statements and related notes
in Item 8 of this annual report.
We may increase our debt or issue equity in the future, which could affect our financial condition, may
decrease our profitability or could dilute our shareholders.
We may increase our debt or issue equity in the future, subject to restrictions in our debt agreements. If our cash
flow from operations is less than we anticipate, or if our cash requirements are more than we expect, we may require
more financing. However, debt or equity financing may not be available to us on terms acceptable to us, if at all. If
we incur additional debt or raise equity through the issuance of our preferred shares, the terms of the debt or our
preferred shares issued may give the holders rights, preferences and privileges senior to those of holders of our
common shares, particularly in the event of liquidation. The terms of the debt may also impose additional and more
stringent restrictions on our operations than we currently have. If we raise funds through the issuance of additional
equity, your ownership in us would be diluted. If we are unable to raise additional capital when needed, it could
affect our financial health, which could negatively affect your investment in us.
Our Amended Credit Facility contains operating and financial restrictions that may restrict our business and
financing activities
Our Amended Credit Facility contains, and any future indebtedness we incur may contain, a number of
restrictive covenants that will impose significant operating and financial restrictions on us. The Amended Credit
Facility contains customary affirmative and negative covenants that, among other things, limit or restrict (i)
subsidiary indebtedness, liens and fundamental changes, (ii) asset sales, (iii) margin stock, (iv) specified
acquisitions, (v) restrictive agreements, (vi) transactions with affiliates and (vii) investments and other restricted
payments, including dividends and other distributions. Specifically, we must maintain an interest coverage ratio,
defined as the ratio of consolidated EBITDA (as defined in the Amended Credit Facility) to consolidated interest
expense, of at least 3.0 to 1.0 and our maximum leverage ratio, defined as the ratio of total debt to consolidated
EBITDA, of no greater than 5.5 to 1.0 (as of December 31, 2016).
37
The permitted level of the maximum leverage ratio changes over time, as illustrated in the table below.
Period Ended
Maximum Leverage
Ratio
December 31, 2016 .......................
March 31, 2017 .............................
June 30, 2017 ................................
September 30, 2017 .......................
December 31, 2017 .......................
March 31, 2018 .............................
June 30, 2018 ................................
September 30, 2018 .......................
December 31, 2018 .......................
March 31, 2019 & thereafter .........
5.50 : 1.00
5.25 : 1.00
5.25 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.50 : 1.00
5.25 : 1.00
Each of the factors considered in the calculations of these ratios are defined in the Amended Credit Facility.
EBITDA and consolidated interest, as defined, exclude goodwill and asset impairments, debt discount amortization
and other non-cash charges.
We may be prevented from taking advantage of business opportunities that arise because of the limitations
imposed on us by the restrictive covenants under the Amended Credit Facility. The restrictions contained in the
Amended Credit Facility could:
(cid:2)
(cid:2)
limit our ability to plan for, or react to, market conditions, to meet capital needs or otherwise to restrict
our activities or business plan; and
adversely affect our ability to finance our operations, enter into acquisitions or to engage in other
business activities that would be in our interest.
Additionally, our ability to comply with some of the covenants, ratios or tests contained in the Amended Credit
Facility may be affected by events beyond our control and, as a result, we may be unable to meet these ratios and
financial condition tests. These financial ratio restrictions and financial condition tests could limit our ability to
obtain future financings, make needed capital expenditures, withstand a continued downturn in our business or a
downturn in the economy in general or otherwise conduct necessary corporate activities. Declines in commodity
prices, or a prolonged period of commodity prices at depressed levels, could eventually result in our failing to meet
one or more of the financial covenants under the Amended Credit Facility, which could require us to refinance or
amend such obligations resulting in the payment of consent fees or higher interest rates, or require us to raise
additional capital at an inopportune time or on terms not favorable to us.
We may not be able to reduce our indebtedness to comply with these covenants. A failure to comply with these
covenants, ratios or tests could result in an event of default. A default under the Amended Credit Facility, if not
cured or waived, could result in acceleration of all indebtedness outstanding thereunder. The accelerated debt would
become immediately due and payable. If that should occur, we may be unable to pay all such debt or to borrow
sufficient funds to refinance it. Even if new financing were then available, it may not be on terms that are acceptable
to us. In addition, in the event of an event of default under the Amended Credit Facility, the lenders could foreclose
on the collateral securing the credit facility and require repayment of all borrowings outstanding. If the amounts
outstanding under the credit facility or any of our other indebtedness were to be accelerated, our assets may not be
sufficient to repay in full the money owed to the lenders or to our other debt holders. Moreover, any new
indebtedness we incur may impose financial restrictions and other covenants on us that may be more restrictive than
our existing debt agreements.
38
Our indebtedness could restrict our operations and make us more vulnerable to adverse economic conditions.
We currently have a substantial amount of indebtedness. As of December 31, 2016, we had approximately
$318.1 million outstanding under the term loan portion of the Amended Credit Facility, $39.1 million outstanding
under the revolving portion of the Amended Credit Facility, $1.6 million of outstanding letters of credit and capacity
to borrow an additional $164.5 million under the revolving portion of the Amended Credit Facility. As of December
31, 2016, our borrowing capacity under the revolving portion of the Credit Facility was reduced by approximately
$144.8 million due to the negative covenants. If market or other economic conditions remain depressed or further
deteriorate, our borrowing capacity may be further reduced.
Our level of indebtedness may adversely affect our operations and limit our growth, and we may have difficulty
making debt service payments on our indebtedness as such payments become due. Our level of indebtedness may
affect our operations in several ways, including the following:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
our indebtedness may increase our vulnerability to general adverse economic and industry conditions;
the covenants contained in the Amended Credit Facility limit our ability to borrow funds, dispose of
assets, pay dividends and make certain investments;
our debt covenants also affect our flexibility in planning for, and reacting to, changes in the economy
and in its industry; and
our indebtedness could impair our ability to obtain additional financing in the future for working
capital, capital expenditures, acquisitions or other general corporate purposes.
Our ability to service our debt will depend upon, among other things, our future financial and operating
performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other
factors, some of which are beyond our control. If our business does not generate sufficient cash flows from
operations to enable us to meet our obligations under our indebtedness, we will be forced to take actions such as
reducing or delaying business activities, acquisitions, investments and/or capital expenditures, selling assets,
restructuring or refinancing our indebtedness or seeking additional equity capital. We may not be able to effect any
of these remedies on satisfactory terms or at all, which could have a material adverse effect on our business,
financial condition, results of operations and cash flows.
Our business could be negatively impacted by security threats, including cybersecurity threats and other
disruptions.
We face various security threats, including cybersecurity threats to gain unauthorized access to sensitive
information or to render data or systems unusable; threats to the safety of our employees; threats to the security of
our facilities and infrastructure or third-party facilities and infrastructure; and threats from terrorist acts. Although
we utilize various procedures and controls to monitor these threats and mitigate our exposure to such threats, there
can be no assurance that these procedures and controls will be sufficient in preventing security threats from
materializing. If any of these events were to materialize, they could lead to losses of sensitive information, critical
infrastructure, personnel or capabilities essential to our operations and could have a material adverse effect on our
reputation, financial position, results of operations or cash flows. Cybersecurity attacks in particular are evolving
and include, but are not limited to, malicious software, attempts to gain unauthorized access to data and other
electronic security breaches that could lead to disruptions in critical systems, unauthorized release of confidential or
otherwise protected information and corruption of data.
39
Risks Related to the Redomicile Transaction
The anticipated benefits of the Redomicile Transaction may not be realized.
We may not realize the benefits we anticipate from the Redomicile Transaction, particularly as the realization of
those benefits are in many important respects subject to factors that we do not control. These factors would include
such things as the reactions of third parties with whom we enter into contracts and do business and the reactions of
investors, analysts and Canadian and U.S. taxing authorities and other regulatory authorities, and other factors
discussed in these risk factors. Our failure to realize those benefits could have an adverse effect on our business,
results of operations or financial condition.
We are subject to various Canadian and other taxes as a result of the Redomicile Transaction.
While we expect the Redomicile Transaction will enable us to take advantage of lower Canadian tax rates in the
years after the year of implementation to a greater extent than would likely have been available if the Redomicile
Transaction was not completed, these benefits may not be achieved. In particular, tax authorities may challenge our
application and/or interpretation of relevant tax laws, regulations or treaties, valuations and methodologies or other
supporting documentation, and, if they are successful in doing so, we may not experience the level of benefits we
anticipate or we may be subject to adverse tax consequences. Even if we are successful in maintaining our tax
positions, we may incur significant expense in contesting these positions or other claims made by tax authorities. In
addition, changes in tax laws or increased rates of tax could have the effect of negatively impacting our anticipated
effective tax rates. Our effective tax rates and the benefits described herein are also subject to a variety of other
factors, many of which are beyond our ability to control, such as changes in the rate of economic growth in Canada,
the financial performance of our business in various jurisdictions, currency exchange rate fluctuations (especially as
between Canadian and U.S. dollars), and significant changes in trade, monetary or fiscal policies of Canada,
including changes in interest rates, withholding taxes, tax treaties and federal and provincial tax rates generally. The
impact of these factors, individually and in the aggregate, is difficult to predict, in part because the occurrence of the
events or circumstances described in such factors may be (and, in fact, often seem to be) interrelated, and the impact
to us of the occurrence of any one of these events or circumstances could be compounded or, alternatively, reduced,
offset, or more than offset, by the occurrence of one or more of the other events or circumstances described in such
factors.
More specifically, Canada’s tax rules under the Income Tax Act (Canada) (the “Canadian Tax Act”) allow for
favorable tax treatment insofar as the repatriation of certain dividends from foreign affiliates. These tax rules are
complicated and could change over time. Any such changes could have a material impact on our overall tax rate.
Canada has also introduced tax rules governing “foreign affiliate dumping” in the Canadian Tax Act that can
have adverse tax consequences for Canadian corporations that are controlled by non-Canadian corporations in
respect of non-Canadian business activities and investments. These rules would have a negative impact on us to the
extent that we became controlled by a non-Canadian resident corporation.
The Canada Revenue Agency (CRA) may disagree with our conclusions on tax treatment and the CRA has
not provided (and we have not requested) a ruling on the Canadian tax aspects of the Redomicile Transaction.
Based on the current provisions of the Canadian Tax Act, we expect that the Redomicile Transaction will not
result in any material Canadian federal income tax liability to us. However, if the CRA disagrees with this view, it
may take the position that material Canadian federal income tax liabilities or amounts on account thereof are payable
by us as a result of the Redomicile Transaction, in which case, we expect that we would contest such assessment. To
contest such assessment, we would be required to remit cash equal to half of the amount in dispute, or provide
security acceptable to the CRA, to prevent the CRA from seeking enforcement actions pending the dispute of such
assessment. If we were unsuccessful in disputing the assessment, the implications could be materially adverse to us.
The CRA has not provided (and we have not requested) a ruling on the Canadian tax aspects of the Redomicile
Transaction. There can be no assurance that the CRA will agree with our interpretation of the tax aspects of the
Redomicile Transaction or any related matters associated therewith.
40
The Internal Revenue Service (IRS) may not agree with the conclusion that we should be treated as a foreign
corporation for U.S. federal tax purposes, and no ruling has been sought from the IRS.
For U.S. federal income tax purposes, a corporation generally is considered a tax resident in the jurisdiction of
its organization or incorporation. Because we are a British Columbia incorporated entity, we generally will be
classified as a foreign corporation (and, therefore, a non-U.S. tax resident) under U.S. federal income tax law. Even
so, the IRS may assert that we should be treated as a U.S. corporation (and, therefore, a U.S. tax resident) for U.S.
federal income tax purposes pursuant to Section 7874 of the Internal Revenue Code.
Under Section 7874 of the Internal Revenue Code, if the former stockholders of Civeo US hold 80% or more of
the vote or value of our common shares by reason of holding stock in Civeo US (the “ownership test”), and our
expanded affiliated group after the Redomicile Transaction does not have substantial business activities in Canada
relative to its worldwide activities (the “substantial business activities test”), we would be treated as a U.S.
corporation. For this purpose, “substantial business activities” generally requires at least 25% of the employees (by
number and compensation), assets and gross income of our expanded affiliated group to be based, located and
derived, respectively, in Canada (“25% test”).
We believe that we have satisfied this 25% test because Civeo US had significant operations in Canada prior to
the Redomicile Transaction (with its remaining operations occurring in Australia and the United States), and we
have continued these operations following the Redomicile Transaction. Therefore, under current U.S. federal income
tax law, we believe that we will not be treated as a U.S. corporation for U.S. federal income tax purposes. If it were
determined, however, that we should be taxed as a U.S. corporation for U.S. federal income tax purposes, we could
be liable for substantial additional U.S. federal income taxes.
Future potential changes to U.S. tax laws could result in Civeo being treated as a U.S. corporation for U.S.
federal income tax purposes.
Under current U.S. federal income tax law, Civeo is generally treated as a foreign corporation for U.S. federal
income tax purposes. Changes to Section 7874 of the Internal Revenue Code or the U.S. Treasury regulations
promulgated thereunder or official interpretations thereof, could adversely affect Civeo’s status as a foreign
corporation for U.S. federal income tax purposes. For example, members of Congress from time to time have
proposed changes to the Internal Revenue Code, and the U.S. Treasury has taken and may continue to take
regulatory action, in connection with so-called inversion transactions. The timing and substance of any such change
in law or regulatory action is presently uncertain. Any such change of law or regulatory action could adversely
impact the treatment of Civeo as a foreign corporation for U.S. federal income tax purposes and could adversely
impact its tax position and financial position and results in a material manner. The precise scope and application of
any legislative or regulatory proposals will not be clear until they are actually issued, and, accordingly, until such
legislation or regulations are issued and fully understood, we cannot be certain as to their potential impact. Any such
changes could apply retroactively to a date prior to the date of the Redomicile Transaction. If Civeo were to be
treated as a U.S. corporation for U.S. federal income tax purposes, it could be subject to substantially greater U.S.
federal income tax liability.
We remain subject to changes in tax law and other factors that may not allow us to achieve a lower effective
corporate tax rate.
While we believe that the Redomicile Transaction should allow for a lower effective corporate tax rate, we
cannot give any assurance as to what our effective tax rate will be after the Redomicile Transaction because of,
among other things, the tax policies of the jurisdictions where we operate, primarily Canada and Australia. Also, the
tax laws of Canada, Australia and other jurisdictions could change in the future, and such changes could cause a
material change in our effective corporate tax rate. As a result, our actual effective tax rate may be materially
different from our expectation. Our provision for income taxes will be based on certain estimates and assumptions
made by management in consultation with our tax and other advisors. Our consolidated income tax rate will be
affected by the amount of net income earned in Canada and our other operating jurisdictions, the availability of
benefits under tax treaties, and the rates of taxes payable in respect of that income. We will enter into many
transactions and arrangements in the ordinary course of business in respect of which the tax treatment is not entirely
41
certain. We will therefore make estimates and judgments based on our knowledge and understanding of applicable
tax laws and tax treaties, and the application of those tax laws and tax treaties to our business, in determining our
consolidated tax provision. The final outcome of any audits by taxation authorities may differ from the estimates and
assumptions we may use in determining our consolidated tax provisions and accruals. This could result in a material
adverse effect on our consolidated income tax provision, financial condition and the net income for the period in
which such determinations are made.
Our tax position may be adversely affected by changes in tax law relating to multinational corporations, or
increased scrutiny by tax authorities.
Recent legislative proposals have aimed to expand the scope of U.S. corporate tax residence, to limit the ability
of foreign-owned corporations to deduct interest expense, and to make other changes in the taxation of multinational
corporations.
Additionally, the U.S. Congress, government agencies in non-U.S. jurisdictions where we and our affiliates do
business, and the Organization for Economic Co-operation and Development have recently focused on issues related
to the taxation of multinational corporations. One example is found in the area of “base erosion and profit shifting”,
where profits are claimed to be earned for tax purposes in low-tax jurisdictions, or payments are made between
affiliates from a jurisdiction with high tax rates to a jurisdiction with lower tax rates. As a result, the tax laws in the
U.S. and other countries in which we and our affiliates do business could change on a prospective or retroactive
basis, and any such changes could materially adversely affect us.
Moreover, U.S. and international tax authorities may carefully scrutinize companies that have redomiciled, such
as our company, which may lead such authorities to assert that we owe additional taxes.
We may be subject to Australian stamp duty as a result of the Redomicile Transaction.
Some states of the Commonwealth of Australia impose stamp duty, which is a tax payable on documents that
affect interests in property and on transfers of marketable securities. If it were determined that Australian stamp duty
applied to the Redomicile Transaction, Civeo Canada could be liable for substantial Australian stamp duty taxes.
We may be subject to additional Canadian and British Columbia laws and regulations as a result of the
Redomicile Transaction.
Now that we are a British Columbia company, we may be subject to additional Canadian and British Columbia
laws and regulations, which can increase compliance costs for us and result in delays in future transactions we
propose to complete.
Risks Related to the Spin-Off from Oil States
We potentially could have received better terms from unaffiliated third parties than the terms we receive in
our agreements with Oil States.
The agreements we entered into with Oil States in connection with the Spin-off, including the separation and
distribution agreement, tax sharing agreement, employee matters agreement, indemnification and release agreement
and transition services agreement, were negotiated in the context of the separation while we were still a wholly
owned subsidiary of Oil States. Accordingly, during the period in which the terms of those agreements were
negotiated, we did not have an independent board of directors or a management team independent of Oil States. As a
result, the terms of those agreements may not reflect terms that would have resulted from arm’s-length negotiations
between unaffiliated third parties. The terms of the agreements negotiated in the context of the Spin-off relate to,
among other things, the allocation of assets, liabilities, rights and other obligations between Oil States and us.
Arm’s-length negotiations between Oil States and an unaffiliated third party in another form of transaction, such as a
buyer in a sale of a business transaction, may have resulted in more favorable terms to the unaffiliated third party.
See Note 13 – Commitments and Contingencies and Note 17 – Related Party Transactions to the notes to
consolidated financial statements in Item 8 of this annual report.
42
Our tax sharing agreement with Oil States may require us to indemnify Oil States for significant tax
liabilities.
Under the tax sharing agreement, we are required to indemnify Oil States against certain tax-related liabilities
incurred by Oil States (including any of its subsidiaries) relating to the Spin-off, to the extent caused by our breach
of any representations or covenants made in the tax sharing agreement or the separation and distribution agreement,
or made in connection with the private letter ruling or the tax opinion obtained with respect to the Spin-off. These
liabilities include the substantial tax-related liability (calculated without regard to any net operating loss or other tax
attribute of Oil States) that would result if the Spin-off of our stock to Oil States stockholders failed to qualify as a
tax-free transaction. In addition, we have agreed to pay 50% of any taxes arising from the Spin-off to the extent that
the tax is not attributable to the fault of either party.
We could have significant tax liabilities for periods during which our subsidiaries and operations were those
of Oil States.
For any tax periods (or portion thereof) in which Oil States owned at least 80% of the total voting power and
value of Civeo US’s common stock, our U.S. subsidiaries will be included in Oil States’ consolidated group for U.S.
federal income tax purposes. In addition, one or more of our U.S. subsidiaries may be included in the combined,
consolidated or unitary tax returns of Oil States or one or more of its subsidiaries for U.S. state or local income tax
purposes. Under the tax sharing agreement, for each period in which we or any of our subsidiaries are consolidated
or combined with Oil States for purposes of any tax return, and with respect to which such tax return has not yet
been filed, Oil States will prepare a pro forma tax return for us as if we filed our own consolidated, combined or
unitary return, except that such pro forma tax return will generally include current income, deductions, credits and
losses from us (with certain exceptions), will not include any carryovers or carrybacks of losses or credits and will
be calculated without regard to the federal Alternative Minimum Tax. We will reimburse Oil States for any taxes
shown on the pro forma tax returns, and Oil States will reimburse us for any current losses or credits we recognize
based on the pro forma tax returns. In addition, by virtue of Oil States’ controlling ownership and the tax sharing
agreement, Oil States will effectively control all of our U.S. tax decisions in connection with any consolidated,
combined or unitary income tax returns in which any of our subsidiaries are included. The tax sharing agreement
provides that Oil States will have sole authority to respond to and conduct all tax proceedings (including tax audits)
relating to us, to prepare and file all consolidated, combined or unitary income tax returns in which we are included
on our behalf (including the making of any tax elections), and to determine the reimbursement amounts in
connection with any pro forma tax returns. This arrangement may result in conflicts of interest between Oil States
and us. For example, under the tax sharing agreement, Oil States will be able to choose to contest, compromise or
settle any adjustment or deficiency proposed by the relevant taxing authority in a manner that may be beneficial to
Oil States and detrimental to us; provided, however, that Oil States may not make any settlement that would
materially increase our tax liability without our consent. See Note 13 – Commitments and Contingencies and Note
17 – Related Party Transactions to the notes to consolidated financial statements in Item 8 of this annual report.
Moreover, notwithstanding the tax sharing agreement, U.S. federal law provides that each member of a
consolidated group is liable for the group’s entire tax obligation. Thus, to the extent Oil States or other members of
Oil States’ consolidated group fail to make any U.S. federal income tax payments required by law, one or more of
our U.S. subsidiaries could be liable for the shortfall with respect to periods in which such subsidiary was a member
of Oil States’ consolidated group. Similar principles may apply for foreign, state or local income tax purposes where
we file combined, consolidated or unitary returns with Oil States or its subsidiaries for federal, foreign, state or local
income tax purposes.
If there is a determination that the Spin-off is taxable for U.S. federal income tax purposes because the facts,
assumptions, representations, or undertakings underlying the tax opinion are incorrect or for any other reason, then
Oil States and its stockholders could incur significant income tax liabilities, and we could incur significant
liabilities.
Oil States received a private letter ruling from the IRS and an opinion of its outside counsel regarding certain
aspects of the Spin-off transaction. The private letter ruling and the opinion rely on certain facts, assumptions,
representations and undertakings from Oil States and us regarding the past and future conduct of the companies’
43
respective businesses and other matters. If any of these facts, assumptions, representations, or undertakings are, or
become, incorrect or not otherwise satisfied, Oil States and its stockholders may not be able to rely on the private
letter ruling or the opinion of its tax advisor and could be subject to significant tax liabilities. In addition, an opinion
of counsel is not binding upon the IRS, so, notwithstanding the opinion of Oil States’ tax advisor, the IRS could
conclude upon audit that the Spin-off is taxable in full or in part if it disagrees with the conclusions in the opinion, or
for other reasons, including as a result of certain significant changes in the stock ownership of Oil States or us. If the
Spin-off is determined to be taxable for U.S. federal income tax purposes for any reason, Oil States and/or its
stockholders could incur significant income tax liabilities, and we could incur significant liabilities. For a description
of the sharing of such liabilities between Oil States and us, see Note 13 – Commitments and Contingencies and Note
17 – Related Party Transactions to the notes to consolidated financial statements in Item 8 of this annual report.
Third parties may seek to hold us responsible for liabilities of Oil States that we did not assume in our
agreements.
Third parties may seek to hold us responsible for retained liabilities of Oil States. Under our agreements with
Oil States, Oil States agreed to indemnify us for claims and losses relating to these retained liabilities. However, if
those liabilities are significant and we are ultimately held liable for them, we cannot assure you that we will be able
to recover the full amount of our losses from Oil States.
Our prior and continuing relationship with Oil States exposes us to risks attributable to businesses of Oil
States.
Oil States is obligated to indemnify us for losses that a party may seek to impose upon us or our affiliates for
liabilities relating to the business of Oil States that are incurred through a breach of the separation and distribution
agreement or any ancillary agreement by Oil States or its affiliates other than us, or losses that are attributable to Oil
States in connection with the Spin-off or are not expressly assumed by us under our agreements with Oil States. Any
claims made against us that are properly attributable to Oil States in accordance with these arrangements would
require us to exercise our rights under our agreements with Oil States to obtain payment from Oil States. We are
exposed to the risk that, in these circumstances, Oil States cannot, or will not, make the required payment.
The Spin-Off may have exposed us to potential liabilities arising out of state and federal fraudulent
conveyance laws and legal dividend requirements.
The Spin-off is subject to review under various state and federal fraudulent conveyance laws. Under these laws,
if a court in a lawsuit by an unpaid creditor or an entity vested with the power of such creditor (including without
limitation a trustee or debtor-in-possession in a bankruptcy by us or Oil States or any of our respective subsidiaries)
were to determine that Oil States or any of its subsidiaries did not receive fair consideration or reasonably equivalent
value for distributing shares of our common stock or taking other action as part of the Spin-Off, or that we or any of
our subsidiaries did not receive fair consideration or reasonably equivalent value for incurring indebtedness,
including the debt incurred by us in connection with the Spin-off, transferring assets or taking other action as part of
the Spin-off and, at the time of such action, we, Oil States or any of our respective subsidiaries (i) was insolvent or
would be rendered insolvent, (ii) had reasonably small capital with which to carry on its business and all business in
which it intended to engage or (iii) intended to incur, or believed it would incur, debts beyond its ability to repay
such debts as they would mature, then such court could void the Spin-off as a constructive fraudulent transfer. If
such court made this determination, the court could impose a number of different remedies, including without
limitation, voiding our liens and claims against Oil States, or providing Oil States with a claim for money damages
against us in an amount equal to the difference between the consideration received by Oil States and the fair market
value of our company at the time of the Spin-Off.
The measure of insolvency for purposes of the fraudulent conveyance laws will vary depending on which
jurisdiction’s law is applied. Generally, however, an entity would be considered insolvent if the present fair saleable
value of its assets is less than (i) the amount of its liabilities (including contingent liabilities) or (ii) the amount that
will be required to pay its probable liabilities on its existing debts as they become absolute and mature. No assurance
can be given as to what standard a court would apply to determine insolvency or that a court would determine that
we, Oil States or any of our respective subsidiaries were solvent at the time of or after giving effect to the Spin-Off,
including the distribution of shares of our common stock.
44
Under the separation and distribution agreement, Oil States is and we are responsible for the debts, liabilities
and other obligations related to the business or businesses which Oil States and we, respectively, own and operate
following the Spin-Off. Although we do not expect to be liable for any such obligations not expressly assumed by us
pursuant to the separation and distribution agreement, it is possible that a court would disregard the allocation
agreed to between the parties, and require that we assume responsibility for obligations allocated to Oil States,
particularly if Oil States were to refuse or were unable to pay or perform the subject allocated obligations. See Note
13 – “Commitments and Contingencies” and Note 17 – “Related Party Transactions” to the notes to consolidated
financial statements in Item 8 of this annual report.
Risks Related to Our Common Shares
If we cannot meet the NYSE continued listing requirements, the NYSE may delist our common shares.
Our common shares are currently listed on the NYSE, and the continued listing of our common shares is subject
to our compliance with a number of listing standards. To maintain compliance with these continued listing
standards, we are required to maintain an average closing price of $1.00 or more over a consecutive 30 trading-day
period. On February 24, 2016, we received a notice from the NYSE that the average closing price of our common
shares over a 30 consecutive trading day period was below $1.00 per share, and, as a result, the price per share of the
common shares was below the minimum average closing price required to maintain listing on the NYSE. Though
we regained compliance with the NYSE continued listing requirements on April 4, 2016, we cannot assure you that
the average closing price of our common shares over a consecutive 30 trading-day period will not fall below $1.00
per share in the future. A delisting of our common shares could negatively impact us by, among other things:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
reducing the liquidity and market price of our common shares;
reducing the number of investors, including institutional investors, willing to hold or acquire our
common shares, which could negatively impact our ability to raise equity;
decreasing the amount of news and analyst coverage of us;
limiting our ability to issue additional securities, obtain additional financing or pursue strategic
restructuring, refinancing or other transactions; and
impacting our reputation and, as a consequence, our ability to attract new business.
The market price and trading volume of our common shares may be volatile.
The market price of our common shares has historically experienced and may continue to experience volatility.
For example, during 2015, the market price of our common shares ranged from a low of $1.17 per share to a high of
$4.95 per share, and during 2016, the market price of our common shares ranged from a low of $0.75 per share to a
high of $2.81 per share. From January 1, 2017 to February 20, 2017, the market price of our common shares has
ranged between a low of $2.21 per share to a high of $3.70 per share. The market price of our common shares may
be influenced by many factors, some of which are beyond our control, including those described above and the
following:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
changes in financial estimates by analysts and our inability to meet those financial estimates;
strategic actions by us or our competitors;
announcements by us or our competitors of significant contracts, acquisitions, joint marketing relationships,
joint ventures or capital commitments;
variations in our quarterly operating results and those of our competitors;
general economic and stock market conditions;
45
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
risks related to our business and our industry, including those discussed above;
changes in conditions or trends in our industry, markets or customers;
terrorist acts;
future sales of our common shares or other securities by us, members of our management team or our
existing shareholders; and
investor perceptions of the investment opportunity associated with our common shares relative to other
investment alternatives.
These broad market and industry factors may materially reduce the market price of our common shares,
regardless of our operating performance. In addition, price volatility may be greater if the public float and trading
volume of our common shares is low.
Our financial position, cash flows, results of operations and share price could be materially adversely affected if
commodity prices do not improve or decline further. In addition, in recent years the stock market has experienced
substantial price and volume fluctuations. This volatility has had a significant effect on the market prices of
securities issued by many companies for reasons potentially unrelated to their operating performance. Our share
price may experience substantial volatility due to uncertainty regarding commodity prices. These market
fluctuations, regardless of the cause, may materially and adversely affect our share price, regardless of our operating
results.
If securities or industry analysts do not publish research or reports about our business, if they adversely
change their recommendations regarding our common shares or if our operating results do not meet their
expectations, our share price could decline.
The trading market for our common shares is influenced by the research and reports that industry or securities
analysts publish about us or our business. If one or more of these analysts cease coverage of our company or fail to
publish reports on us regularly, we could lose visibility in the financial markets, which in turn could cause our share
price or trading volume to decline.
We cannot assure you that we will pay dividends in the future, and our indebtedness could limit our ability to
pay dividends on our common shares.
We paid quarterly dividends in the amount of $0.13 per share during the third and fourth quarters of 2014. In
late December 2014, we suspended our quarterly dividend in order to maintain our financial flexibility and best
position our company for long-term success. The declaration and amount of all dividends will be at the discretion of
our board of directors and will depend upon many factors, including our financial condition, results of operations,
cash flows, prospects, industry conditions, capital requirements of our business, covenants associated with certain
debt obligations, legal requirements, regulatory constraints, industry practice and other factors the board of directors
deems relevant. In addition, our ability to pay dividends on our common shares is limited by covenants in the
Amended Credit Facility. Future agreements may also limit our ability to pay dividends. If we elect to pay dividends
in the future, the amount per share of our dividend payments may be changed, or dividends may again be suspended,
without advance notice. The likelihood that dividends will be reduced or suspended is increased during periods of
market weakness. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations”
in Item 7. There can be no assurance that we will pay a dividend in the future.
Provisions contained in our articles and applicable Canadian and British Columbia laws could discourage a
take-over attempt, which may reduce or eliminate the likelihood of a change of control transaction and,
therefore, the ability of our shareholders to sell their shares for a premium.
Provisions contained in our articles provide for a classified board of directors, limitations on the removal of
directors, limitations on shareholder proposals at meetings of shareholders and limitations on shareholder action by
46
written consent, which could make it more difficult for a third party to acquire control of us. Our articles, subject to
the corporate law of British Columbia, also authorize our board of directors to issue series of preferred shares
without shareholder approval. If our board of directors elects to issue preferred shares, it could increase the difficulty
for a third party to acquire us, which may reduce or eliminate our shareholders’ ability to sell their common shares at
a premium. In addition, in Canada, we may become subject to applicable securities laws, including National
Instrument 62-104 Take-Over Bids and Issuer Bids of the Canadian Securities Administrators (the “Take-Over Bid
Rules”), which provide a heightened threshold for shareholder acceptance of third-party acquisition offers and could
discourage take-over attempts that could result in a premium over the market price for our common shares.
As a British Columbia company, we may be subject to additional Canadian laws and regulations. The
application of additional Canadian laws and regulations could make it more difficult for third parties to acquire
control of us. For example, such laws and regulations may, depending on the circumstances, result in regulatory
reviews of and may require regulatory approval for any proposed take-over attempts.
Any of the foregoing could prevent or delay a change of control and may deprive or limit strategic opportunities
for our shareholders to sell their common shares and/or affect the market price of our common shares.
Our business could be negatively affected as a result of the actions of activist shareholders.
Publicly traded companies have increasingly become subject to campaigns by investors seeking to increase
shareholder value by advocating corporate actions such as financial restructuring, increased borrowing, special
dividends, share repurchases or even sales of assets or the entire company. It is possible activist shareholders may
attempt to effect such changes or acquire control over us. Responding to proxy contests and other actions by such
activist shareholders or others in the future would be costly and time-consuming, disrupt our operations and divert
the attention of our board of directors and senior management from the pursuit of business strategies, which could
adversely affect our results of operations and financial condition. Additionally, perceived uncertainties as to our
future direction as a result of shareholder activism or changes to the composition of the board of directors may lead
to the perception of a change in the direction of the business, instability or lack of continuity which may be exploited
by our competitors, cause concern to our current or potential customers, and make it more difficult to attract and
retain qualified personnel. If customers choose to delay, defer or reduce transactions with us or transact with our
competitors instead of us because of any such issues, then our revenue, earnings and operating cash flows could be
adversely affected.
We are governed by the corporate laws in British Columbia, Canada which in some cases have a different
effect on shareholders than the corporate laws in Delaware, United States.
There are material differences between the Business Corporations Act (British Columbia) (“BCBCA”) as
compared to the Delaware General Corporation Law (“DGCL”). For example, some of these material differences
include the following: (a) for material corporate transactions (such as amalgamations, arrangements, the sale of all
or substantially all of our undertaking, and other extraordinary corporate transactions) the BCBCA, subject to the
provisions of our Articles, generally requires two-thirds majority vote by shareholders, whereas DGCL generally
only requires a majority vote of shareholders for similar material corporate transactions; and (b) under the BCBCA a
holder of 5% or more of our common shares can requisition a general meeting of shareholders for the purpose of
transacting any business that may be transacted at a general meeting, whereas the DGCL does not give this right.
We cannot predict if investors will find our common shares less attractive because of these material differences. If
some investors find our common shares less attractive as a result, there may be a less active trading market for our
common shares and our share price may be more volatile.
ITEM 1B. Unresolved Staff Comments
None.
47
ITEM 2. Properties
The following table presents information about our principal properties and facilities as of December 31, 2016.
Except as indicated below, we own all of the properties or facilities listed below. Each of the properties is
encumbered by our secured credit facilities. See in Item 7 “Management’s Discussion and Analysis of Financial
Condition and Results of Operations” and Note 10 – Debt to the notes to consolidated financial statements included
in Item 8 for additional information concerning our credit facilities. For a discussion about how each of our business
segments utilizes its respective properties, please see Item 1, “Business”.
Canada:
Location
Fort McMurray, Alberta (leased land)
Fort McMurray, Alberta (leased land)
Fort McMurray, Alberta (leased land)
Fort McMurray, Alberta (leased land)
Fort McMurray, Alberta (leased land)
Fort McMurray, Alberta (leased land)
Fort McMurray, Alberta
Kitimat, British Columbia
Acheson, Alberta (lease)
Edmonton, Alberta
Grimshaw, Alberta (lease)
Fort McMurray, Alberta (leased land)
Edmonton, Alberta (lease)
Australia:
Coppabella, Queensland, Australia
Calliope, Queensland, Australia
Narrabri, New South Wales, Australia
Boggabri, New South Wales, Australia
Dysart, Queensland, Australia
Middlemount, Queensland, Australia
Karratha, Western Australia, Australia
(own and lease)
Kambalda, Western Australia, Australia
Nebo, Queensland, Australia
Moranbah, Queensland, Australia
Sydney, New South Wales, Australia
(lease)
Brisbane, Queensland, Australia (lease)
United States:
Houston, Texas (lease)
Killdeer, North Dakota
Pecos, Texas
Dickinson, North Dakota (lease)
Vernal, Utah (lease)
Casper, Wyoming (lease)
Belle Chasse, Louisiana
Big Piney, Wyoming (lease)
Stanley, North Dakota (lease)
LaSalle, Colorado (lease)
Longmont, Colorado (lease)
Approximate
Square
Footage/Acreage
Description
Wapasu Creek and Henday Lodges
Pebble Beach open camp
Conklin Lodge
Beaver River and Athabasca Lodges
McClelland Lake Lodge
Mariana Lake Lodge
Christina Lake Lodge
Sitka Lodge
Office and warehouse
Manufacturing facility
Equipment yard
Anzac Lodge
Office and warehouse
Coppabella Village
Calliope Village
Narrabri Village
Boggabri Village
Dysart Village
Middlemount Village
Karratha Village
Kambalda Village
Nebo Village
Moranbah Village
Office
Office
Principal executive offices
Open camp
Open camp
Mobile asset facility and yard
Mobile asset facility and yard
Accommodations facility and yard
Manufacturing facility and yard
Mobile asset facility and yard
Open camp
Mobile asset facility and yard
Office
240 acres
140 acres
135 acres
128 acres
80 acres
43 acres
45 acres
60 acres
40 acres
33 acres
20 acres
18 acres
86,376
198 acres
124 acres
82 acres
52 acres
50 acres
37 acres
34 acres
27 acres
26 acres
17 acres
17,276
7,115
8,900
42 acres
35 acres
26 acres
21 acres
14 acres
10 acres
7 acres
7 acres
6 acres
4,377
48
We own various undeveloped properties in British Columbia. We also have various offices supporting our
business segments which are both owned and leased. We believe that our leases are at competitive or market rates
and do not anticipate any difficulty in leasing additional suitable space upon expiration of our current lease terms.
Leased land for our lodge properties in Canada refers to land leased from the Alberta government. We also
lease land for our Karratha Village from the provincial government in Australia. Generally, our leases have an initial
term of ten years and are scheduled to expire between 2017 and 2026.
ITEM 3. Legal Proceedings
We are a party to various pending or threatened claims, lawsuits and administrative proceedings seeking damages
or other remedies concerning our commercial operations, products, employees and other matters, including
occasional claims by individuals alleging exposure to hazardous materials as a result of our products or operations.
Some of these claims relate to matters occurring prior to our acquisition of businesses, and some relate to businesses
we have sold. In certain cases, we are entitled to indemnification from the sellers of businesses, and in other cases,
we have indemnified the buyers of businesses from us. Although we can give no assurance about the outcome of
pending legal and administrative proceedings and the effect such outcomes may have on us, we believe that any
ultimate liability resulting from the outcome of such proceedings, to the extent not otherwise provided for or
covered by indemnity or insurance, will not have a material adverse effect on our consolidated financial position,
results of operations or liquidity.
ITEM 4. Mine Safety Disclosures
Not applicable.
49
ITEM 5. Market for Registrant's Common Equity, Related Shareholder Matters and Issuer Purchases of Equity
PART II
Securities
Market for Our Common Shares
Our common shares trade on the NYSE under the trading symbol “CVEO.” Set forth in the table below for the
periods presented are the high and low sale prices for our common shares.
First Quarter ........................................................
Second Quarter ....................................................
Third Quarter .......................................................
Fourth Quarter .....................................................
Holders of Record
2016
High
$1.64
$2.40
$1.96
$2.81
Low
$0.75
$1.01
$1.00
$1.06
2015
High
$4.20
$4.96
$3.12
$2.39
Low
$2.25
$2.55
$1.17
$1.29
As of February 21, 2017, there were 17 holders of record of Civeo common shares.
Dividend Information
We paid quarterly dividends in the amount of $0.13 per share during the third and fourth quarters of 2014. In
late December 2014, we suspended our quarterly dividend in order to maintain our financial flexibility and best
position our company for long-term success. Our management team and board of directors regularly evaluate our
business, operations, cost structure, capital structure, capital return and capital allocation policies. The declaration
and amount of all dividends will be at the discretion of our board of directors and will depend upon many factors,
including our financial condition, results of operations, cash flows, prospects, industry conditions, capital
requirements of our business, covenants associated with certain debt obligations, legal requirements, regulatory
constraints, industry practice and other factors the board of directors deems relevant. We can give no assurances
that we will pay a dividend in the future.
50
Performance Graph
The share price performance shown on the graph is not necessarily indicative of future price performance.
Information used in the graph was obtained from Research Data Group, Inc., a source believed to be reliable, but we
are not responsible for any errors or omissions in such information.
The performance graph above is furnished and not filed for purposes of the Securities Act of 1933 and the
Securities Act of 1934. The performance graph is not soliciting material subject to Regulation 14A.
Unregistered Sales of Equity Securities and Use of Proceeds
None.
Repurchases of Equity Securities by Registrant or its Affiliates in the Fourth Quarter
None.
ITEM 6. Selected Financial Data
The following tables present the selected historical consolidated financial information of Civeo and combined
financial information of the accommodations business. The term “accommodations business” refers to Oil States’
historical accommodations segment reflected in its historical combined financial statements discussed herein and
included in Item 8 of this report. The balance sheet data as of December 31, 2016 and 2015 and the statement of
operations data for each of the years ended December 31, 2016, 2015 and 2014 are derived from our audited
financial statements included in Item 8 of this report. The balance sheet data as of December 31, 2014, 2013 and
2012 and statement of operations data for the years ended December 31, 2013 and 2012 are derived from our
audited combined financial statements not included in this annual report.
All financial information presented after our Spin-off from Oil States represents the consolidated results of
operation and financial position of Civeo. Accordingly,
51
(cid:2) Our consolidated statement of operations data for the years ended December 31, 2016 and 2015
consists entirely of the consolidated results of Civeo. Our consolidated statement of operations data for
the year ended December 31, 2014 consists of (i) the combined results of the Oil States
accommodations business for the five months ended May 30, 2014 and (ii) the consolidated results of
Civeo for the seven months ended December 31, 2014. Our consolidated statements of operations data
for the years ended December 31, 2013 and 2012 consist entirely of the combined results of the Oil
States accommodations business.
(cid:2) Our consolidated balance sheet data at December 31, 2016, 2015 and 2014 consists entirely of the
consolidated balances of Civeo, while at December 31, 2013 and 2012, it consists entirely of the
combined balances of the Oil States accommodations business.
The historical financial information presented below should be read in conjunction with our consolidated
financial statements and accompanying notes in Item 8 and “Management’s Discussion and Analysis of Financial
Condition and Results of Operations” in Item 7 of this report. The financial information may not be indicative of our
future performance and does not necessarily reflect what the financial position and results of operations would have
been had we operated as a separate, stand-alone entity during the periods presented, including changes that have
occurred in our operations as a result of our Spin-off from Oil States.
Statement of Operations Data:
Revenues
Operating income (loss)
Net income (loss) attributable to Civeo or the
Accommodations Business of Oil States
International, Inc., as applicable
Diluted net income (loss) per share
attributable to Civeo or the
Accommodations Business of Oil States
International, Inc., as applicable (1)
2016
For the year ended December 31,
2013
2014
2015
(In thousands, except per share data)
2012
$
397,230
(95,760)
$
517,963 $
(145,003)
942,891
(142,891)
$ 1,041,104
259,456
$ 1,108,875
352,929
(96,388)
(131,759)
(189,043)
181,876
244,721
(0.90)
(1.24)
(1.77)
1.70
2.29
2016
As of December 31,
2014
(In thousands, except per share data)
2015
2013
2012
Balance Sheet Data:
Total assets
Long-term debt to affiliates
Long-term debt to third-parties
Total Civeo shareholders’ equity or Oil States
net investment, as applicable
Cash dividends per share
$
910,446
—
337,800
$ 1,066,529
—
379,416
$ 1,829,161
—
755,625
$2,123,237
335,171
—
$2,132,925
358,316
123,497
475,467
—
563,245
—
858,001
0.26
1,591,034
—
1,410,397
—
(1) On May 30, 2014, 106,538,044 shares of our common stock were distributed to Oil States stockholders in
connection with the Spin-Off. For comparative purposes, and to provide a more meaningful calculation of
weighted-average shares outstanding in our diluted net income (loss) per share calculation, we have assumed
these shares were outstanding as of the beginning of each period prior to the separation presented in the
calculation of weighted-average shares. In addition, we have assumed the dilutive securities outstanding at May
30, 2014 were also outstanding for each of the periods presented prior to the Spin-Off.
52
ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
“Management’s Discussion and Analysis of Financial Condition and Results of Operations” contains “forward-
looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act
that are based on management’s current expectations, estimates and projections about our business operations.
Please read “Cautionary Statement Regarding Forward Looking Statements.” Our actual results may differ
materially from those currently anticipated and expressed in such forward-looking statements as a result of
numerous factors, including the known material factors set forth in Item 1A, “Risk Factors.” You should read the
following discussion and analysis together with our consolidated financial statements and the notes to those
statements in Item 8 of this annual report.
Spin-Off
On May 30, 2014, Oil States International, Inc. (Oil States) spun-off its Accommodations Segment
(Accommodations) into a standalone, publicly traded Delaware corporation (Civeo US). In accordance with the
Separation and Distribution Agreement, the two companies were separated by Oil States distributing to its
stockholders all 106,538,044 shares of common stock of Civeo US it held after the market closed on May 30, 2014
(the Spin-Off). In connection with the Spin-off, on May 28, 2014, we made a special cash distribution to Oil States
of $750 million. Following the Spin-Off, Oil States retained no ownership interest in Civeo US, and each company
now has separate public ownership, boards of directors and management.
Redomiciling to Canada
On July 17, 2015, we completed our change in place of incorporation from Delaware to British Columbia,
Canada (the Redomicile Transaction). In the Redomicile Transaction, Civeo Corporation, a British Columbia,
Canada limited company formerly named Civeo Canadian Holdings ULC (Civeo Canada), became the publicly
traded parent company of the Civeo group of companies, and our former publicly traded Delaware parent, Civeo
US, became a wholly owned subsidiary of Civeo Canada. Each issued share of Civeo US common stock, other than
those shares of Civeo US common stock held by Civeo US in treasury, was effectively transferred to Civeo Canada
and converted into one common share, no par value, of Civeo Canada. An aggregate of approximately 107.5 million
Civeo Canada common shares were issued in the Redomicile Transaction. The Civeo Canada common shares are
listed on the NYSE under the symbol “CVEO,” the same symbol under which the Civeo US common stock traded
prior to the effective time.
The Redomicile Transaction qualified as a “self-directed redomiciling” of the Company as permitted under the
U.S. Internal Revenue Code. U.S. federal income tax laws permit a company to change its domicile to a foreign
jurisdiction without corporate-level U.S. federal income taxes provided that such company has “substantial business
activity” in the relevant jurisdiction. “Substantial business activity” is defined as foreign operations consisting of
over 25% of the company’s total (i) revenues, (ii) assets, (iii) employees and (iv) employee compensation. With
approximately 50% or more of our operations in Canada based on these metrics, we qualified for a self-directed
redomiciling.
We incurred costs related to the Redomicile Transaction totaling $1.3 million, $7.0 million and $2.6 million for
the years ended December 31, 2016, 2015 and 2014, respectively.
Description of the Business
We are one of the largest integrated providers of workforce accommodations, logistics and facility management
services to the natural resource industry. Our scalable modular facilities provide long-term and temporary
accommodations where traditional accommodations and related infrastructure is insufficient, inaccessible or not cost
effective. Once facilities are deployed in the field, we also provide catering and food services, housekeeping,
laundry, facility management, water and wastewater treatment, power generation, communications and
redeployment logistics. Our accommodations support our customers’ employees and contractors in the Canadian oil
sands and in a variety of oil and natural gas drilling, mining and related natural resource applications as well as
disaster relief efforts, primarily in Canada, Australia and the United States. We operate in three principal reportable
business segments – Canada, Australia and U.S.
53
Basis of Presentation
Unless otherwise stated or the context otherwise indicates, all references in these consolidated financial
statements to “Civeo,” “the Company,” “us,” “our” or “we” for the time period prior to the Spin-Off mean the
Accommodations business of Oil States. For time periods after the Spin-Off, but prior to July 17, 2015, these terms
refer to Civeo US and its consolidated subsidiaries. For time periods after July 17, 2015, these terms refer to Civeo
Canada and its consolidated subsidiaries.
Prior to the Spin-Off, our financial position, results of operations and cash flows consisted of the Oil States’
Accommodations business and an allocable portion of its corporate costs, which represented a combined reporting
entity. The combined financial statements for periods prior to the Spin-Off have been prepared on a stand-alone
basis and are derived from the consolidated financial statements and accounting records of Oil States. The combined
financial statements reflect our historical financial position, results of operations and cash flows as we were
historically managed, in conformity with accounting principles generally accepted in the U.S. (U.S. GAAP). The
combined financial statements include certain assets and liabilities that have historically been held at the Oil States
corporate level, but are specifically identifiable or otherwise attributable to us.
All financial information presented after the Spin-Off represents the consolidated results of operations, financial
position and cash flows of Civeo. Accordingly:
(cid:2) Our consolidated statements of operations, comprehensive income (loss), cash flows and changes in
shareholders’ equity / net investment for the years ended December 31, 2016 and 2015 consist entirely
of the consolidated results of Civeo.
(cid:2) Our consolidated statements of operations, comprehensive income (loss), cash flows and changes in
shareholders’ equity / net investment for the year ended December 31, 2014 consist of (i) the combined
results of the Oil States’ Accommodations business for the five months ended May 30, 2014 and (ii)
the consolidated results of Civeo for the seven months ended December 31, 2014.
(cid:2) Our consolidated balance sheets at December 31, 2016 and December 31, 2015 consist entirely of the
consolidated balances of Civeo.
The assets and liabilities in our consolidated financial statements have been reflected on a historical basis, as
immediately prior to the Spin-Off all of the assets and liabilities presented were wholly owned by Oil States and
were transferred within the Oil States consolidated group. All intercompany transactions and accounts have been
eliminated. All affiliate transactions between Civeo and Oil States have been included in these consolidated
financial statements.
The consolidated financial statements for periods prior to the Spin-Off included expense allocations for: (1)
certain corporate functions historically provided by Oil States, including, but not limited to finance, legal, risk
management, tax, treasury, information technology, human resources, and certain other shared services, (2) certain
employee benefits and incentives and (3) equity-based compensation. These expenses were allocated to us on the
basis of direct usage when identifiable, with the remainder allocated based on estimated time spent by Oil States
personnel, a pro-rata basis of headcount or other relevant measures of Oil States and its subsidiaries. We consider
the basis on which the expenses were allocated to be a reasonable reflection of the utilization of services provided to
or the benefit received by us during the periods presented. The allocations may not, however, reflect the expense we
would have incurred as an independent, publicly traded company for the periods presented. Actual costs that may
have been incurred if we had been a stand-alone company would depend on a number of factors, including the
chosen organizational structure, which functions were outsourced or performed by employees and strategic
decisions made in areas such as information technology and infrastructure. Following the Spin-Off, we perform
these functions using our own resources or purchase external services. Until February 28, 2015, however, some of
these functions were provided by Oil States under a transition services agreement. Please see Note 17 – Related
Party Transactions to the notes to consolidated financial statements in Item 8 of this annual report.
54
Macroeconomic Environment
We provide workforce accommodations to the natural resource industry in Canada, Australia and the U.S.
Demand for our services can be attributed to two phases of our customers’ projects: (1) the development or
construction phase and (2) the operations or production phase. Initial demand for our services is driven by our
customers’ capital spending programs related to the construction and development of oil sands and coal mines and
associated infrastructure as well as the exploration for oil and natural gas. Long-term demand for our services is
driven by continued development and expansion of natural resource production and operation of oil sands and
mining facilities. Industry capital spending programs are generally based on the outlook for commodity prices,
economic growth and estimates of resource production. As a result, demand for our products and services is largely
sensitive to expected commodity prices, principally related to crude oil, metallurgical (met) coal and natural gas.
In Canada, Western Canadian Select (WCS) crude is the benchmark price for our oil sands accommodations
customers. Pricing for WCS is driven by several factors, including the underlying price for West Texas Intermediate
(WTI) crude and the availability of transportation infrastructure. Historically, WCS has traded at a discount to WTI,
creating a “WCS Differential,” due to transportation costs and limited capacity to move Canadian heavy oil
production to refineries, primarily in the U.S. Gulf Coast. The WCS Differential has varied depending on the extent
of transportation capacity availability.
During the first quarter of 2016, global oil prices dropped to their lowest level in over ten years due to concerns
over global oil demand, global crude inventory levels, worldwide economic growth and price cutting by major oil
producing countries, such as Saudi Arabia. Increasing global supply, including increased U.S. shale oil production,
also negatively impacted pricing. With falling Brent Crude and WTI oil prices, WCS also fell. Prices began to
increase in March 2016, and have continued to increase in the first quarter of 2017. WCS prices in the fourth
quarter of 2016 averaged $34.34 per barrel compared to a low of $20.26 in the first quarter of 2016 and a high of
$83.78 in the second quarter of 2014. The WCS Differential increased from $13.25 per barrel at the end of the
fourth quarter of 2015 to $16.10 per barrel at the end of the fourth quarter of 2016. As of February 20, 2017, the
WTI price was $53.40 and the WCS price was $39.78, resulting in a WCS Differential of $13.62.
There remains a risk that prices for Canadian oil sands crude oil related products could deteriorate or remain at
current depressed levels for an extended period of time, and the discount between WCS crude prices and WTI crude
prices could widen. The depressed price levels through the first quarter of 2016 negatively impacted exploration,
development, maintenance and production spending and activity by Canadian operators and, therefore, demand for
our services in late 2014, 2015 and 2016. Our Canadian oil sands customers could continue to delay maintenance
spending and additional investments in their oil sands assets as well.
In Australia, approximately 80% of our rooms are located in the Bowen Basin and primarily serve met coal
mines in that region. Met coal pricing and growth in production in the Bowen Basin region is predominantly
influenced by the levels of global steel production, which increased by 0.7% during 2016 compared to 2015. As of
February 20, 2017, contract met coal prices were approximately $285 per metric tonne, significantly higher than the
September 2016 contract price of $92.50 per metric tonne, due to supply side factors that have restricted met coal
volumes. Despite the increase, we have not yet seen a significant impact on customers’ willingness to increase
activity. We expect that spot prices for met coal will need to be sustained at levels above $150 per metric tonne for
at least nine to twelve months before we see an impact on customer activity levels, and therefore, the demand for
accommodations. Long-term demand for steel will be driven by increased steel consumption per capita in
developing economies, such as China and India, whose current consumption per capita is a fraction of developed
countries. Our customers continue to actively implement cost, productivity and efficiency measures to drive down
their cost base.
Natural gas and WTI crude oil prices, discussed above, have an impact on the demand for our U.S.
accommodations business. With limited export capabilities, U.S. natural gas prices are primarily influenced by
domestic supply/demand dynamics and resultant inventory levels. U.S. natural gas production has continued to
outpace demand, which has caused prices to continue to be weak relative to historical prices over the past decade.
U.S. natural gas inventory levels at December 31, 2016 were 3.31 Tcf, 12% lower than inventory levels from
December 31, 2015 and 1% under seasonally comparable average inventory levels over the past five years. Prices
55
for natural gas in the U.S. averaged $2.55 per mcf in 2016, a 3% decrease from the average price in 2015. Although
the prices have increased slightly in the fourth quarter of 2016 and into 2017, at these levels, it is uneconomic to
increase development in several domestic, gas-focused basins. If natural gas production growth continues to surpass
demand in the U.S. and/or the supply of natural gas were to increase, whether the supply comes from conventional
or unconventional production or associated natural gas production from oil wells, prices for natural gas could be
constrained for an extended period and result in fewer rigs drilling for natural gas in the near-term.
Recent WTI crude, WCS crude, met coal and natural gas pricing trends are as follows:
Average Price (1)
WTI
WCS
Crude
(per bbl)
Crude
(per bbl)
Hard
Coking Coal
(Met Coal)
(per tonne)
Henry
Hub
Natural
Gas
(per mcf)
$
52.78
49.16
44.88
45.53
33.41
42.02
46.48
57.64
48.49
73.21
97.60
103.06
98.68
97.50
$ 38.96
34.34
30.67
32.84
20.26
27.82
31.54
48.09
35.03
57.75
78.69
83.78
77.76
66.34
$
285.00
200.00
92.50
84.00
81.00
89.00
93.00
109.50
117.00
119.00
120.00
120.00
143.00
152.00
$
3.19
3.18
2.79
2.25
1.98
2.23
2.73
2.73
2.81
3.83
3.95
4.58
5.18
3.85
Quarter
ended
First Quarter
through 2/20/2017
12/31/2016
9/30/2016
6/30/2016
3/31/2016
12/31/2015
9/30/2015
6/30/2015
3/31/2015
12/31/2014
9/30/2014
6/30/2014
3/31/2014
12/31/2013
__________
(1) Source: WTI crude and natural gas prices are from U.S. Energy Information Administration (EIA), and WCS
crude prices and Seaborne hard coking coal contract prices are from Bloomberg.
Overview
As noted above, demand for our services is primarily tied to the outlook for crude oil and met coal prices. Other
factors that can affect our business and financial results include the general global economic environment and
regulatory changes in Canada, Australia, the U.S. and other markets.
Our business is predominantly located in northern Alberta, Canada and Queensland, Australia, and we derive
most of our business from resource companies who are developing and producing oil sands and met coal resources
and, to a lesser extent, other hydrocarbon and mineral resources. More than three-fourths of our revenue is generated
by our large-scale lodge and village facilities. Where traditional accommodations and infrastructure are insufficient,
inaccessible or cost ineffective, our lodge and village facilities provide comprehensive accommodations services
similar to those found in an urban hotel. We typically contract our facilities to our customers on a fee per day basis
that covers lodging and meals and that is based on the duration of their needs which can range from several weeks to
several years.
Generally, our customers are making multi-billion dollar investments to develop their prospects, which have
estimated reserve lives ranging from ten years to in excess of thirty years. Consequently, these investments are
dependent on those customers’ longer-term view of commodity demand and prices.
In response to decreases in crude oil prices beginning in late 2014, many of our customers in Canada curtailed
their operations and spending, and most major oil sands mining operators are continuing to seek to reduce their costs
and limit capital spending, accordingly limiting the demand for accommodations like we provide. In Australia,
approximately 80% of our rooms are located in the Bowen Basin and primarily serve met coal mines in that region
where our customers continue to actively implement cost productivity and efficiency measures to drive down their
cost base.
56
In recent months, however, several catalysts have emerged that we believe could have favorable intermediate to
long-term implications for our core end markets. Since the announcement by OPEC in late November 2016 to cut
production quotas and the subsequent rise in oil prices and oil price expectations, certain operators with steam-
assisted gravity drainage operations in the Canadian oil sands have announced increased capital budgets for 2017. In
addition, the recent regulatory approval of major pipeline projects has the potential to both drive incremental
demand for mobile accommodations assets and to improve take-away capacity for Canadian oil sands producers
over the longer term. Additionally, we believe that the Keystone XL pipeline in the U.S., if constructed, would be a
positive catalyst for Canadian oil sands producers, as it would bolster confidence in future take-away capacity from
the region to Gulf Coast refiners. In Australia, we believe prices are currently at a level that may contribute to
increased activity over the longer term.
While we believe that these macroeconomic developments are positive for our customers and for the underlying
demand for the accommodations services we provide, we do not expect an immediate improvement in our business
and are expecting our full year 2017 revenues and EBITDA to be materially lower compared to 2016. Accordingly,
we plan to focus on enhancing the quality of our operations and maintaining financial discipline and to proactively
manage our business as market conditions continue to evolve.
We began expansion of our room count in Kitimat, British Columbia during the second half of 2015 to support
potential liquefied natural gas (LNG) projects on the west coast of British Columbia. We were awarded a contract
with LNG Canada (LNGC) for the provision of open lodge rooms and associated services that runs through
September 2017. To support this contract, we have developed a new accommodations facility, named Sitka Lodge,
which includes private washrooms, recreational facilities and other amenities. This lodge currently has 436 rooms,
with the potential to expand to serve future accommodations demand in the region.
In addition, we were awarded a contract with LNGC to construct a 4,500 person workforce accommodation
center (Cedar Valley Lodge) for a proposed liquefaction and export facility in Kitimat, British Columbia.
Construction of Cedar Valley Lodge will not commence until LNGC’s joint venture participants have made a
positive final investment decision (FID). The FID was originally planned for the end of 2016; however, this decision
has been delayed until a future time that has not yet been determined. We are currently in discussions with LNGC
to extend this contract until a positive FID is made. Should the project ultimately move forward, British Columbia
LNG activity could become a material driver of future activity for our Sitka Lodge, as well as for our mobile fleet
assets which are well suited for the related pipeline construction activity. However, should the project, and other
potential projects in the area, not move forward, the resulting impact may negatively affect our future results of
operations and our existing long-lived assets in Canada, including our Sitka Lodge, and may require us to record
further material impairment charges equal to the excess of the carrying value of these assets over fair value. With the
delay in the FID, we currently expect that LNGC will continue to utilize rooms at our Sitka Lodge through
September 2017 in accordance with the terms of our contract. However, this contract may be extended to a new FID
date based upon our current discussions with LNGC. There can be no assurance that LNGC’s joint venture
participants will reach a positive FID or that our contracts with LNGC will be extended.
During the third quarter of 2016, we identified an indicator that certain asset groups used, or expected to be
used, in conjunction with potential LNG projects in British Columbia may be impaired as a result of recent market
developments, including the delay in FID discussed above. As a result, we assessed the carrying values of each of
the asset groups to determine if they continued to be recoverable based on their estimated future cash flows. Based
on the assessment, the carrying values of our mobile camp assets and certain undeveloped land positions in British
Columbia were determined to not be recoverable, and an impairment charge totaling $37.7 million was recorded in
the third quarter of 2016.
In estimating future cash flows, we made numerous assumptions with respect to future circumstances that might
directly impact each of the asset groups’ operations in the future and are therefore uncertain. These assumptions
with respect to future circumstances included future oil, coal and natural gas prices, anticipated customer spending,
and industry and/or local market conditions. These assumptions represented our best judgment based on the current
facts and circumstances. However, different assumptions could result in a determination that the carrying values of
additional asset groups are no longer recoverable based on estimated future cash flows. If estimates of future cash
flows for certain of our assets included in this assessment that were not impaired were reduced by 10%, an
additional impairment of between $25 million and $35 million could be indicated. Our estimate of fair value was
57
primarily calculated using the Income Approach, which derives a present value of the asset group based on the asset
groups estimated future cash flows. We discounted our estimated future cash flows using a long-term weighted
average cost of capital based on our estimate of investment returns required by a market participant.
We expanded our Australian room capacity in 2012 and 2013 to meet increasing demand, notably in the Bowen
Basin in Queensland and in the Gunnedah Basin in New South Wales to support coal production, and in Western
Australia to support LNG and other energy-related projects. In early 2013, a confluence of falling met coal prices,
additional carbon and mining taxes on our Australian customers and several years of cost inflation caused several of
our customers to curtail or cease production from higher cost mines and delay or materially reduce their growth
plans. This has negatively affected our ability to expand our room count and has led to a decrease in occupancy
levels. With supply disruptions in the fourth quarter of 2016 due to Chinese production policy and Australian
weather, the supply / demand balance in global met coal has improved. As a result, met coal prices have increased
materially. We expect our Australian customers will wait for a stabilization in prices above $150/tonne before
significantly increasing their spending, which may take nine months or longer.
If oil and coal prices decline from current levels, the resulting impact may negatively affect the value of our
long-lived assets. Impairment expense of $46.1 million associated with long-lived assets was recorded in 2016.
Impairment expense of $122.9 million was recorded in 2015, of which $79.7 million was associated with long-lived
assets and the remaining $43.2 million was associated with goodwill. Impairment expense of $290.5 million was
recorded in 2014, of which $87.8 million was associated with long-lived assets and the remaining $202.7 million
was associated with goodwill.
Exchange rates between the U.S. dollar and each of the Canadian dollar and the Australian dollar influence our
U.S. dollar reported financial results. Our business has historically derived the vast majority of its revenues and
operating income in Canada and Australia. These revenues and profits are translated into U.S. dollars for U.S.
Generally Accepted Accounting Principles (U.S. GAAP) financial reporting purposes. The Canadian dollar was
valued at an average exchange rate of U.S. $0.76 for 2016 compared to U.S. $0.78 for 2015, a decrease of
approximately 4%. The Canadian dollar was valued at an exchange rate of $0.74 on December 31, 2016 and $0.72
on December 31, 2015. The Australian dollar was valued at an average exchange rate of U.S. $0.74 for 2016
compared to U.S. $0.75 for 2015, a decrease of approximately 1%. The Australian dollar was valued at an exchange
rate of $0.72 on December 31, 2016 and $0.73 on December 31, 2015. These fluctuations of the Canadian and
Australian dollars have had and will continue to have an impact on the translation of earnings generated from our
Canadian and Australian subsidiaries and, therefore, our financial results.
We continue to monitor the global economy, the demand for crude oil, met coal and natural gas and the
resultant impact on the capital spending plans of our customers in order to plan our business. We currently expect
that our 2017 capital expenditures, exclusive of any business acquisitions, will total approximately $15 million to
$18 million, compared to 2016 capital expenditures of $19.8 million. Please see “Liquidity and Capital Resources”
below for further discussion of 2017 and 2016 capital expenditures.
During January 2017, we closed a public offering of 23 million common shares. We expect to use the net
proceeds of $64.9 million from the offering to repay amounts outstanding under our revolving credit facilities and
for general corporate purposes.
58
Results of Operations
Unless otherwise indicated, discussion of results for the years ended December 31, 2016 and 2015 is based on a
comparison with the corresponding period of 2015 and 2014, respectively.
Results of Operations – Year Ended December 31, 2016 Compared to Year Ended December 31, 2015
2016
Year Ended
December 31,
2015
($ in thousands)
Change
$ 344,249
135,964
37,750
517,963
$
(65,785)
(29,149)
(25,799)
(120,733)
Revenues
Canada ................................................................. $ 278,464
106,815
Australia ..............................................................
11,951
United States and other ........................................
Total revenues .................................................
397,230
Costs and expenses
Cost of sales and services
Canada ............................................................
Australia ..........................................................
United States and other ..................................
Total cost of sales and services ...................
Selling, general and administrative expenses .......
Depreciation and amortization expense ...............
Impairment expense .............................................
Other operating expense (income) ......................
Total costs and expenses .................................
Operating loss ........................................................
190,878
51,688
17,084
259,650
55,297
131,302
46,129
612
492,990
(95,760)
230,713
60,585
36,315
327,613
68,441
152,990
122,926
(9,004)
662,966
(145,003)
Interest expense and income, net ...........................
Other income (expense) .........................................
Loss before income taxes ................................
Income tax benefit .................................................
Net loss ...........................................................
Less: Net income attributable to noncontrolling
(22,817)
2,645
(115,932)
20,105
(95,827)
(22,026)
3,276
(163,753)
33,089
(130,664)
(39,835)
(8,897)
(19,231)
(67,963)
(13,144)
(21,688)
(76,797)
9,616
(169,976)
49,243
(791)
(631)
47,821
(12,984)
34,837
interest .............................................................
Net loss attributable to Civeo ................................. $
561
1,095
(96,388) $ (131,759)
$
(534)
35,371
We reported net loss attributable to Civeo for the year ended December 31, 2016 of $96.4 million, or $0.90 per
diluted share. As further discussed below, net loss included (i) a $46.1 million pre-tax loss ($35.9 million after-tax,
or $0.34 per diluted share) resulting from the impairment of fixed assets, included in Impairment expense, and (ii) a
$1.3 million pre-tax loss ($1.2 million after-tax, or $0.01 per diluted share) from costs incurred in connection with
the Redomicile Transaction, included in Selling, general and administrative (SG&A) expense below.
We reported net loss attributable to Civeo for the year ended December 31, 2015 of $131.8 million, or $1.24 per
diluted share. As further discussed below, net loss included the following items:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
an $80.7 million pre-tax loss ($56.0 million after-tax, or $0.52 per diluted share) resulting from the
impairment of fixed assets and intangible assets, included in Impairment expense below;
a $43.2 million pre-tax loss ($43.2 million after-tax, or $0.40 per diluted share) resulting from the
impairment of goodwill in our Canadian reporting unit, included in Impairment expense below;
a $7.0 million pre-tax loss ($4.6 million after-tax, or $0.05 per diluted share) from costs incurred in
connection with the Redomicile Transaction, included in Selling, general and administrative (SG&A)
expense below; and
a $1.5 million pre-tax loss ($1.5 million after-tax, or $0.01 per diluted share) from the write off of debt
issuance costs, included in Interest expense and income, net below.
Revenues. Consolidated revenues decreased $120.7 million, or 23%, in 2016 compared to 2015. This decline
was largely driven by decreases in Canada due to lower room rates, Australia and the U.S. due to lower occupancy,
as well as weaker Canadian dollars in 2016 compared to 2015. Please see the discussion of segment results of
operations below for further information.
59
Cost of Sales and Services. Our consolidated cost of sales decreased $68.0 million, or 21%, in 2016 compared
to 2015, primarily due to decreases in occupancy in both Canada and Australia, as well as the weaker Canadian
dollars in 2016 compared to 2015. Please see the discussion of segment results of operations below for further
information.
Selling, General and Administrative Expenses. SG&A expense decreased $13.1 million, or 19%, in 2016
compared to 2015. This decrease was primarily due to reduced compensation as a result of workforce reductions in
2016 and 2015, lower professional fees due to lower costs associated with the Redomicile Transaction, lower bad
debt expense when compared to 2015, lower incentive compensation costs and the impact of the weaker Canadian
dollars. These items were partially offset by higher share based compensation expense associated with phantom
share awards. The increase in share based compensation was largely due to an increase in our share price during
2016. We use current market prices to remeasure these awards at each reporting date.
Depreciation and Amortization Expense. Depreciation and amortization expense decreased $21.7 million, or
14%, in 2016 compared to 2015, primarily due to reduced depreciation expense resulting from impairments recorded
in 2015, as well as the impact of the weaker Canadian dollars.
Impairment Expense. Impairment expense of $46.1 million in 2016 consisted of:
(cid:2) Pre-tax impairment losses of $37.7 million related to mobile camp assets and certain undeveloped land
positions in the British Columbia LNG market in our Canadian segment; and
(cid:2) Pre-tax impairment losses of $8.4 million related to the impairment of fixed assets in our U.S. segment.
Impairment expense of $122.9 million in 2015 consisted of:
(cid:2) Pre-tax impairment losses of $33.5 million related to fixed assets in our Australian segment;
(cid:2) Pre-tax impairment totaling $2.7 million in 2015 related to a decision to sell our U.S. manufacturing
facility;
(cid:2) Goodwill impairment losses of $43.2 million in our Canadian reporting unit;
(cid:2) Pre-tax impairment losses totaling $20.5 million associated with long-lived assets in our U.S. segment;
and
(cid:2) Pre-tax impairment losses totaling $23.0 million associated with long-lived assets in our Canadian
segment.
Please see Note 3 - Impairment Charges to the notes to the consolidated financial statements of this annual
report for further discussion.
Other Operating Expense (Income). Other operating expense (income) decreased from income of $9.0
million in 2015 to an expense of $0.6 million in 2016. The 2015 income was primarily due to foreign currency gains
on the remeasurement of U.S. dollar denominated cash in Canadian bank accounts, as a result of the strengthening of
the U.S. dollar.
Operating Loss. Consolidated operating loss decreased $49.2 million, or 34%, in 2016 compared to 2015,
primarily due to lower impairment expense in the 2016 period, partially offset by lower occupancy levels in Canada
and Australia and the weaker Canadian dollars.
Interest Expense and Interest Income, net. Net interest expense increased by $0.8 million, or 4%, in 2016
compared to 2015, primarily resulting from decreased interest income due to lower average cash balances in 2016 as
compared to 2015 and lower capitalized interest in 2016. This was partially offset by decreased interest expense
associated with lower amounts outstanding under the Amended Credit Facility and the 2015 write-off of $1.5
million of debt issuance costs associated with the Amended Credit Facility.
60
Income Tax Benefit. Our income tax benefit for the year ended December 31, 2016 totaled $20.1 million, or
17.3% of pre-tax income, compared to a benefit of $33.1 million, or 20.2% of pre-tax income, for the year ended
December 31, 2015. Our effective tax rate in 2016 was lower than the Canadian statutory rate of 27%, primarily due
to losses in Australia and U.S. for which no tax benefit was recorded. As a result, a valuation allowance of $15.1
million established against net deferred tax assets in the U.S. and Australia.
In 2015, our income tax benefit and effective tax rate were impacted by the effect of non-deductible goodwill
charges, dividend income generated as part of a global restructuring, foreign tax credits, the reversal of deferred tax
liabilities recorded on a portion of our unremitted earnings of approximately $25.3 million and a valuation
allowance of $11.2 million established against net deferred tax assets in the U.S. and Australia.
Other Comprehensive Income (Loss). Other comprehensive income increased $171.8 million in 2016
compared to 2015 primarily as a result of foreign currency translation adjustments, due to changes in the Canadian
and Australian dollar exchange rates compared to the U.S. dollar. The Canadian dollar exchange rate compared to
the U.S. dollar increased 3% from December 31, 2015 to December 31, 2016 compared to a 16% decrease from
December 31, 2014 to December 31, 2015. The Australian dollar exchange rate compared to the U.S. dollar
decreased 1% from December 31, 2015 to December 31, 2016 compared to a 11% decrease from December 31,
2014 to December 31, 2015.
61
Segment Results of Operations – Canadian Segment
Year Ended
December 31,
2016
2015
Change
Revenues ($ in thousands)
Lodge revenue (1) ................................................ $ 238,220
Mobile, open camp and product revenue ............
40,244
Total revenues ................................................. $ 278,464
$ 267,486
76,763
$ 344,249
$ (29,266)
(36,519)
$ (65,785)
Cost of sales and services ($ in thousands) ............ $ 190,878
$ 230,713
$ (39,835)
Gross margin as a % of revenues ...........................
31.5%
33.0%
(1.5%)
Average available lodge rooms (2) ..........................
14,653
13,435
1,218
Rentable rooms for lodges (3) ................................
9,979
10,054
(75)
Average daily rate for lodges (4) ........................... $
104
$
121
$
(17)
Occupancy in lodges (5) ........................................
63%
60%
3%
Average Canadian dollar to U.S. dollar ................. $
0.755
$
0.783
$
(0.028)
_____________
(1) Includes revenue related to rooms as well as the fees associated with catering, laundry and other services,
including facilities management.
(2) Average available rooms include rooms that are utilized for our personnel.
(3) Rentable rooms exclude rooms that are utilized for our personnel and out-of-service rooms.
(4) Average daily rate is based on rentable rooms and lodge/village revenue.
(5) Occupancy represents total billed days divided by rentable days. Rentable days excludes staff rooms and out-of-
service rooms
Our Canadian segment reported revenues in 2016 that were $65.8 million, or 19%, lower than 2015. The
weakening of the average exchange rates for the Canadian dollar relative to the U.S. dollar by 4% in 2016 compared
to 2015 resulted in a $10.6 million year-over-year reduction in revenues. In addition, excluding the impact of the
weaker Canadian exchange rates, the segment experienced an 8% decline in lodge revenues, primarily due to lower
room rates. This decline was partially mitigated by room needs related to the Fort McMurray fires. Finally, mobile,
open camp and product revenues all declined due to overall lower activity levels.
Our Canadian segment cost of sales and services decreased $39.8 million, or 17%, in 2016 compared to 2015,
primarily due to the decline in mobile and open camp activity, as well as a focus on cost containment and
operational efficiencies. Additionally, the weakening of the average exchange rates for the Canadian dollar resulted
in reduced cost of sales.
Our Canadian segment gross margin as a percentage of revenues decreased from 33% in 2015 to 31% in 2016,
primarily due to lower contracted room rates, partially offset by room needs related to the Fort McMurray fires and
lower costs due to a focus on cost containment and operational efficiencies.
62
Segment Results of Operations – Australian Segment
Revenues ($ in thousands)
Village revenue (1) ..............................................
Total revenues .................................................
Year Ended
December 31,
2016
2015
Change
$ 106,815
106,815
$ 135,964
135,964
$ (29,149)
(29,149)
Cost of sales ($ in thousands) ................................
$ 51,688
$ 60,585
$
(8,897)
Gross margin as a % of revenues ...........................
51.6%
55.4%
(3.8%)
Average available village rooms (2) ........................
9,335
Rentable rooms for villages (3) ..............................
8,679
9,180
8,862
155
(183)
Average daily rate for villages (4)..........................
$
76
$
74
$
2
Occupancy in Villages (5) .....................................
44%
56%
(12%)
Average Australian dollar to U.S. dollar ................ $
0.744
$
0.752
$
(0.008)
_____________
(1) Includes revenue related to rooms as well as the fees associated with catering, laundry and other services,
including facilities management.
(2) Average available rooms include rooms that are utilized for our personnel.
(3) Rentable rooms exclude rooms that are utilized for our personnel and out-of-service rooms.
(4) Average daily rate is based on rentable rooms and lodge/village revenue.
(5) Occupancy represents total billed days divided by rentable days. Rentable days excludes staff rooms and out-of-
service rooms.
Our Australian segment reported revenues in 2016 that were $29.1 million, or 21%, lower than 2015. The
weakening of the average exchange rates for Australian dollars relative to the U.S. dollar by 1% in 2016 compared
to 2015 resulted in a $1.2 million year-over-year reduction in revenues. Excluding the impact of the weaker
Australian exchange rates, the segment experienced a 20% decline in revenues due to lower occupancy levels in
2016 compared to 2015, primarily as a result of the continued slowdown in mining activity.
Our Australian segment cost of sales decreased $8.9 million, or 15%, in 2016 compared to 2015. The decrease
was driven by lower occupancy levels.
Our Australian segment gross margin as a percentage of revenues decreased to 52% in 2016 from 55% in 2015.
This was primarily driven by reduced revenues from take or pay contracts and lower occupancy compared to 2015.
63
Segment Results of Operations – United States Segment
Year Ended
December 31,
2016
2015
Change
Revenues ($ in thousands) ..................................... $ 11,951
$ 37,750
$ (25,799)
Cost of sales ($ in thousands) ................................ $ 17,084
$ 36,315
$ (19,231)
Gross margin as a % of revenues ...........................
(43.0%)
3.8%
(46.8%)
Our United States segment reported revenues in 2016 that were $25.8 million, or 68%, lower than 2015. The
reduction was primarily due to continued lower U.S. drilling activity in the Bakken, Rockies and Texas markets and
decreased sales in our offshore business.
Our United States cost of sales decreased $19.2 million, or 53%, in 2016 compared to 2015. The decrease was
driven by overall lower activity levels.
Our United States segment gross margin as a percentage of revenues decreased from 4% in 2015 to (43%) in
2016, primarily due to overall lower activity levels, which were insufficient to cover the fixed cost structure of our
United States segment.
Results of Operations – Year Ended December 31, 2015 Compared to Year Ended December 31, 2014
2015
Year Ended
December 31,
2014
($ in thousands)
Change
Revenues
Canada .........................................................................................
Australia ......................................................................................
United States and other ................................................................
Total revenues .......................................................................
$ 344,249
135,964
37,750
517,963
$ 661,416
213,279
68,196
942,891
$ (317,167)
(77,315)
(30,446)
(424,928)
Costs and expenses
Cost of sales and services
Canada ..................................................................................
Australia................................................................................
United States and other ........................................................
Total cost of sales and services......................................
Selling, general and administrative expenses ...............................
Spin-off and formation costs .......................................................
Depreciation and amortization expense .......................................
Impairment expense .....................................................................
Other operating expense (income) ..............................................
Total costs and expenses .......................................................
Operating loss ..................................................................................
Interest expense and income, net ......................................................
Other income ...................................................................................
Loss before income taxes .................................................................
Income tax benefit (provision) .........................................................
Net loss ............................................................................................
Less: Net income (loss) attributable to noncontrolling interest ..........
Net loss attributable to Civeo ...........................................................
230,713
60,585
36,315
327,613
68,441
--
152,990
122,926
(9,004)
662,966
(145,003)
(22,026)
3,276
(163,753)
33,089
(130,664)
1,095
$ (131,759)
402,182
89,507
53,232
544,921
70,345
4,350
174,970
290,508
688
1,085,782
(142,891)
(20,916)
7,524
(156,283)
(31,379)
(187,662)
1,381
$ (189,043)
(171,469)
(28,922)
(16,917)
(217,308)
(1,904)
(4,350)
(21,980)
(167,582)
(9,692)
(422,816)
(2,112)
(1,110)
(4,248)
(7,470)
64,468
56,998
(286)
57,284
$
We reported net loss attributable to Civeo for the year ended December 31, 2015 of $131.8 million, or $1.24 per
diluted share. As further discussed below, net loss included the following items:
(cid:2)
(cid:2)
(cid:2)
an $80.7 million pre-tax loss ($56.0 million after-tax, or $0.52 per diluted share) resulting from the
impairment of fixed assets and intangible assets, included in Impairment expense below;
a $43.2 million pre-tax loss ($43.2 million after-tax, or $0.40 per diluted share) resulting from the
impairment of goodwill in our Canadian reporting unit, included in Impairment expense below;
a $7.0 million pre-tax loss ($4.6 million after-tax, or $0.05 per diluted share) from costs incurred in
64
connection with the Redomicile Transaction, included in Selling, general and administrative (SG&A)
expense below; and
a $1.5 million pre-tax loss ($1.5 million after-tax, or $0.01 per diluted share) from the write off of debt
issuance costs, included in Interest expense and income, net below.
(cid:2)
We reported net loss attributable to Civeo for the year ended December 31, 2014 of $189.0 million, or $1.77 per
diluted share. As further discussed below, net loss included the following items:
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
(cid:2)
a $202.7 million pre-tax loss ($201.2 million after-tax, or $1.89 per diluted share) from goodwill
impairments, included in Impairment expense below;
a $75.6 million pre-tax loss ($50.9 million after-tax, or $0.48 per diluted share) from fixed asset
impairments, included in Impairment expense below;
a $34.9 million tax expense ($0.33 per diluted share) from the establishment of a deferred tax liability
related to a portion of our undistributed foreign earnings which we no longer intend to indefinitely
reinvest and a valuation allowance related to deferred tax assets related to capital losses that are not
expected to be realized, included in Income tax provision below;
a $12.2 million pre-tax loss ($8.4 million after-tax, or $0.08 per diluted share) from intangible asset
impairments, included in Impairment expense below,
a $7.8 million pre-tax loss ($5.1 million after-tax, or $0.05 per diluted share) from transition costs and
debt extinguishment costs incurred in connection with the Spin-Off from Oil States, included Spin-Off
and formation costs and Interest expense below;
a $4.1 million pre-tax loss ($3.1 million after-tax, or $0.03 per diluted share) from severance costs
associated with the termination of an executive, included in SG&A expenses below; and
a $2.6 million pre-tax loss ($1.7 million after-tax, or $0.02 per diluted share) from costs associated
with the proposed migration to Canada, included in SG&A expenses below.
Revenues. Consolidated revenues decreased $424.9 million, or 45%, in 2015 compared to 2014. This decline
was largely driven by decreases in Canada and Australia, due to lower occupancy, as well as weakening Canadian
and Australian dollars. Please see further description in the segment discussion below.
Cost of Sales and Services. Our consolidated cost of sales decreased $217.3 million, or 40%, in 2015
compared to 2014 primarily due to decreases in occupancy in both Canada and Australia, as well as the weakening
Canadian and Australian dollars. Please see further description in the segment discussion below.
Selling, General and Administrative Expenses. SG&A expense decreased $1.9 million, or 3%, in 2015
compared to 2014. Increased costs associated with being a publicly traded company for a full year and costs
associated with the Redomicile Transaction of $7.0 million were more than offset by lower employee costs, as well
as the impact of the weakening Canadian and Australian dollars.
Spin-Off and Formation Costs. Spin-off and formation costs of $4.3 million relate to transition costs incurred
during 2014 associated with becoming a stand-alone company.
Depreciation and Amortization Expense. Depreciation and amortization expense decreased $22.0 million, or
13%, in 2015 compared to 2014, primarily due to reduced depreciation expense resulting from impairments recorded
in 2014 and 2015, as well as the impact of the weakening Canadian and Australian dollars. These items were
partially offset by capital expenditures made during 2014 largely related to investments in our Canadian segment.
Impairment Expense. Impairment expense of $122.9 million in 2015 included the following items:
(cid:2) Goodwill impairment losses of $43.2 million in our Canadian reporting unit;
(cid:2) Pre-tax impairment losses of $33.5 million related to long-lived assets in our Australian segment;
(cid:2) Pre-tax impairment losses of $23.0 million associated with long-lived assets in our Canadian segment,
including $11.9 million related to assets that should have been impaired in the fourth quarter of 2014.
We determined that the error was not material to our financial statements for the year ended December
31, 2014 and therefore corrected the error in the third quarter of 2015;
(cid:2) Pre-tax impairment losses of $20.5 million associated with long-lived assets in our U.S. segment; and
65
(cid:2) Pre-tax impairment loss of $2.7 million in 2015 related to a decision to sell our U.S. manufacturing
facility.
Impairment expense of $290.5 million in 2014 included the following items:
(cid:2) Goodwill impairment losses of $202.7 million, of which $16.6 million related to our U.S. segment and
$186.1 million related to our Australian segment;
(cid:2) Pre-tax impairment losses associated with long-lived assets of $76.2 million, of which $59.0 million
related to our U.S. segment and $17.2 million related to our Canadian segment. Of the $59.0 million
impairment related to our U.S. segment, $55.8 million reduced the value of our fixed assets and $3.2
million reduced the value of our amortizable intangible assets;
(cid:2) A $9.0 million impairment of an intangible asset in Australia; and
(cid:2) An impairment totaling $2.6 million on assets that are in the custody of non-paying customers in
Mexico, and for which the return or reimbursement is unlikely.
Please see Note 3 – Impairment Charges to the notes to consolidated financial statements in Item 8 of this
annual report for further discussion.
Other Operating Expense (Income). Other operating expense (income) changed from an expense of $0.7
million in 2014 to income of $9.0 million in 2015. The 2015 income was primarily due to foreign currency gains on
the remeasurement of U.S. dollar denominated cash in Canadian bank accounts, as a result of the strengthening of
the U.S. dollar.
Operating Loss. Consolidated operating loss increased $2.1 million, or 2%, in 2015 compared to 2014
primarily due to lower occupancy levels in Canada and Australia, as well as the weakening Canadian and Australian
dollars, partially offset by lower impairments of goodwill and long-lived assets in 2015 compared to 2014.
Interest Expense and Interest Income, net. Net interest expense, including interest expense and income
to/from affiliates, increased by $1.1 million, or 5%, in 2015 compared to 2014, primarily due to increased interest
expense associated with our new credit facility in 2015 and the 2015 write-off of $1.5 million of debt issuance costs
associated with the Amended Credit Facility, partially offset by reduced interest expense in 2015 associated with the
affiliate debt, which was eliminated as of the Spin-Off, as well as the 2014 write-off of $3.5 million of debt issuance
costs associated with the credit agreement that was terminated in conjunction with the Spin-Off. In addition, interest
income decreased due to lower average cash balances in 2015 as compared to 2014.
Income Tax Benefit (Provision). Our income tax benefit for the year ended December 31, 2015 totaled $33.1
million, or 20.2% of pre-tax loss, compared to income tax expense of $31.4 million, or 20.1% of pre-tax loss, for the
year ended December 31, 2014. In 2015, our income tax benefit and effective tax rate were impacted by the effect
of non-deductible goodwill charges, dividend income generated as part of a global restructuring, foreign tax credits,
the reversal of deferred tax liabilities recorded on a portion of our unremitted earnings of approximately $25.3
million and a valuation allowance of $11.2 million established against net deferred tax assets in the U.S. and
Australia.
Previously, our effective tax rates were lower than U.S. statutory rates because of lower foreign income tax
rates. However, in 2014, our income tax provision and effective tax rate were impacted by the effect of non-
deductible goodwill impairment charges, a valuation allowance of approximately $51.4 million established against
deferred tax assets in Australia that related to capital losses and were not expected to be realized and a deferred tax
liability of $25.3 million related to a portion of our undistributed foreign earnings that we no longer intend to
continue to indefinitely reinvest.
Other Comprehensive Loss. Other comprehensive loss increased $29.7 million in 2015 compared to 2014,
primarily as a result of foreign currency translation adjustments due to changes in the Canadian and Australian
dollar exchange rates compared to the U.S. dollar. The Canadian dollar exchange rate compared to the U.S. dollar
decreased 16% in 2015 compared to an 8% decrease in 2014. The Australian dollar exchange rate compared to the
U.S. dollar decreased 11% in 2015 compared to an 8% decrease in 2014.
66
Segment Results of Operations – Canadian Segment
Year Ended
December 31,
2015
2014
Change
Revenues ($ in thousands)
Lodge revenue (1) ................................................ $267,486
Mobile, open camp and product revenue ............
76,763
Total revenues ................................................. $ 344,249
$ 497,216
164,200
$ 661,416
$(229,730)
(87,437)
$(317,167)
Cost of sales and services ($ in thousands) ............ $ 230,713
$ 402,182
$(171,469)
Gross margin as a % of revenues ...........................
33.0%
39.2%
(6.2)%
Average available lodge rooms (2) ..........................
13,435
12,557
Rentable rooms for lodges (3) ...................................
10,054
11,007
878
(953)
Average daily rate for lodges (4) ........................... $
121
$
146
$
(25)
Occupancy in lodges (5) ........................................
60%
85%
(25%)
Average Canadian dollar to U.S. dollar ................. $
0.783
$
0.906
$
(0.123)
_____________
(1) Includes revenue related to rooms as well as the fees associated with catering, laundry and other services,
including facilities management.
(2) Average available rooms includes rooms that are utilized for our personnel.
(3) Rentable rooms excludes rooms that are utilized for our personnel and out of service rooms.
(4) Average daily rate is based on rentable rooms and lodge/village revenue.
(5) Occupancy represents total billed days divided by rentable days. Rentable days excludes staff rooms and out of
service rooms.
Our Canadian segment reported revenues in 2015 that were $317.2 million, or 48%, lower than 2014. The
weakening of the average exchange rates for the Canadian dollar relative to the U.S. dollar by 14% in 2015
compared to 2014 resulted in a $51.9 million year over year reduction in revenues. In addition, excluding the
impact of the weaker Canadian exchange rates, the segment experienced a 38% decline in lodge revenues, primarily
due to reduced occupancy and lower room rates, partially offset by the opening of the McClelland Lake Lodge,
which commenced operations in the summer of 2014. Mobile, open camp and product revenue decreased due to a
reduced number of large projects during 2015, as compared to 2014. Excluding the impact of weaker Canadian
exchange rates, product sales were essentially flat year over year.
Our Canadian segment cost of sales and services decreased $171.5 million, or 43%, in 2015 compared to 2014
due to lower occupancy, as well as the weakening of the average exchange rates.
Our Canadian segment gross margin as a percentage of revenues decreased from 39% in 2014 to 33% in 2015,
primarily due to lower contracted room rates and occupancy in Canada.
67
Segment Results of Operations – Australian Segment
Year Ended
December 31,
2015
2014
Change
Revenues ($ in thousands)
Village revenue (1) .............................................. $ 135,964
$ 213,279
$ (77,315)
Cost of sales ($ in thousands) ................................ $ 60,585
$ 89,507
$ (28,922)
Gross margin as a % of revenues ...........................
55.4%
58.0%
(2.6)%
Average available village rooms (2) ........................
9,180
Rentable rooms for villages (3) ................................
8,862
9,271
9,079
(91)
(217)
Average daily rate for villages (4).......................... $
74
$
94
$
(20)
Occupancy in villages (5) ......................................
56%
68%
(12)%
Average Australian dollar to U.S. dollar ................ $
0.752
$
0.902
$
(0.150)
_____________
(1) Includes revenue related to rooms as well as the fees associated with catering, laundry and other services,
including facilities management.
(2) Average available rooms includes rooms that are utilized for our personnel.
(3) Rentable rooms excludes rooms that are utilized for our personnel and out of service rooms.
(4) Average daily rate is based on rentable rooms and lodge/village revenue.
(5) Occupancy represents total billed days divided by rentable days. Rentable days excludes staff rooms and out of
service rooms.
Our Australian segment reported revenues in 2015 that were $77.3 million, or 36%, lower than 2014. The
weakening of the average exchange rates for Australian dollars relative to the U.S. dollar by 17% in 2015 compared
to 2014 resulted in a $26.5 million year-over-year reduction in revenues. Excluding the impact of the weaker
Australian exchange rates, the segment experienced a 19% decline in revenues due to lower occupancy levels in
2015 compared to 2014, primarily as a result of the continued slowdown in mining activity.
Our Australian segment cost of sales decreased $28.9 million, or 32%, in 2015 compared to 2014. The decrease
was driven by the weakening of the Australian dollar, as well as lower occupancy levels.
Our Australian segment gross margin as a percentage of revenues decreased to 55% in 2015 from 58% in 2014.
This was primarily driven by reduced take or pay revenues on expired contracts compared to 2014.
Segment Results of Operations – U.S. Segment
Year Ended
December 31,
2015
2014
Change
Revenues ($ in thousands) ..................................... $ 37,750
$ 68,196
$ (30,446)
Cost of sales ($ in thousands) ................................ $ 36,315
$ 53,232
$ (16,917)
Gross margin as a % of revenues ...........................
3.8%
21.9%
(18.1)%
Our U.S. segment reported revenues in 2015 that were $30.4 million, or 45%, lower than 2014. The reduction
was primarily due to lower U.S. drilling activity in the Bakken, Rockies and Texas markets and decreased sales in
our offshore business.
68
Our U.S. cost of sales decreased $16.9 million, or 32%, in 2015 compared to 2014. The decrease was driven by
overall lower activity levels, partially offset by a $1.1 million write-down of inventory at our U.S. manufacturing
facility.
Our U.S. segment gross margin as a percentage of revenues decreased from 22% in 2014 to 4% in 2015,
primarily due to the $1.1 million inventory write-down, as well as overall lower activity levels.
Liquidity and Capital Resources
Our primary liquidity needs are to fund capital expenditures, which in the past have included expanding and
improving our accommodations, developing new lodges and villages, purchasing or leasing land under our land
banking strategy, and for general working capital needs. In addition, capital has been used to repay debt, fund
strategic business acquisitions and pay dividends. Historically, our primary sources of funds have been available
cash, cash flow from operations, borrowings under our credit facility and proceeds from equity issuances. In
addition, we may seek to access the debt and equity capital markets from time to time to raise additional capital,
increase liquidity, fund acquisitions and refinance debt.
The following table summarizes our consolidated liquidity position as of December 31, 2016 and 2015:
Lender commitments (1) ....................................
Reductions in availability (2) ..........................
Borrowings against revolver capacity ...........
Outstanding letters of credit ..........................
Unused availability ...........................................
Cash and cash equivalents ................................
Total available liquidity ....................................
December 31,
2016
$
$
350,000
(144,803)
(39,129)
(1,571)
164,497
1,785
166,282
$
December 31,
2015
375,000
(121,690)
(52,020)
(5,070)
196,220
7,837
204,057
$
_____________
(1) In connection with the February 2017 amendment to the Amended Credit Facility, lender commitments were reduced
to $275 million. We also have a A$2.0 million bank guarantee facility. We had bank guarantees of A$0.8 million and
A$1.3 million under this facility outstanding as of December 31, 2016 and 2015, respectively.
(2) As of December 31, 2016 and 2015, $144.8 million and $121.7 million, respectively, of our borrowing capacity under
our Amended Credit Facility could not be utilized in order to maintain compliance with the maximum leverage ratio
financial covenant in our Amended Credit Facility.
Cash totaling $62.1 million was provided by operations during 2016 compared to $186.1 million provided by
operations during 2015 and $291.1 million during 2014. The decreases in operating cash flow in 2016 compared to
2015 and in 2015 compared to 2014, respectively, primarily were due to lower revenue resulting from reduced rates
and occupancy levels in lodges and villages. Net cash used in operating assets and liabilities was $13.6 million
during 2016 compared to net cash provided by changes in operating assets and liabilities of $67.1 million during
2015 and $5.2 million during 2014. The decrease in 2016 compared to 2015 was primarily the result of a greater
reduction in accounts receivable balances during 2015 than during 2016. The increase in 2015 compared to 2014
was primarily the result of decreased accounts receivable balances during 2015 compared to 2014.
Cash was used in investing activities during 2016, 2015 and 2014 in the amounts of $12.7 million, $49.8 million
and $239.1 million respectively. Capital expenditures totaled $19.8 million, $62.5 million and $251.2 million
respectively. Capital expenditures in 2016 consisted primarily of investments in an enterprise information system
and maintenance. Capital expenditures in 2015 consisted principally of costs for the construction and installation of
assets for our Sitka lodge in British Columbia and our Mariana Lake lodge in Alberta. Capital expenditures in 2014
consisted principally of construction and installation of assets for our lodges and villages primarily in support of
Canadian oil sands projects, including the McClelland Lake Lodge in the Athabasca oil sands region, and Australian
mining production and development projects. The significant decrease in capital expenditures in 2015 compared to
2014 was primarily a result of the construction of the McClelland Lake Lodge, which was largely completed in
2014. No comparable project was under construction in 2015.
We expect our capital expenditures for 2017 to be in the range of $15 million to $18 million, which excludes
any expenditures for unannounced and uncommitted projects, the spending for which is contingent on obtaining
69
customer contracts. Whether planned expenditures will actually be spent in 2017 depends on industry conditions,
project approvals and schedules, customer room commitments and project and construction timing. We expect to
fund these capital expenditures with available cash, cash flow from operations and borrowings under our Amended
Credit Facility. The foregoing capital expenditure forecast does not include any funds for strategic acquisitions,
which we could pursue depending on the economic environment in our industry and the availability of transactions
at prices deemed to be attractive to us.
The table below delineates historical capital expenditures split between development spending on our lodges
and villages, land banking spending, mobile and open camp spending and other capital expenditures. We classify
capital expenditures for rooms and central facilities at our lodges and villages as development capital expenditures.
Land banking spending consists of land acquisition and initial permitting or zoning costs. Other capital expenditures
in the table below relate to routine capital spending for support equipment, upgrades to infrastructure at our lodge
and village properties and spending related to our manufacturing facilities, among other items. We have also
classified the expenditures between expansionary and maintenance spending.
Based on management’s judgment of capital spending classifications, we believe the following table represents
the components of capital expenditures for the years ended December 31, 2016, 2015 and 2014 (in millions):
Development ..............
Lodge/village..............
Land banking ..............
Mobile/open camp ......
Other... .......................
Total .......................
Expansion
2.4
$
0.5
0.1
--
11.8
14.8
$
2016
Maint
$ 0.7
3.6
--
0.1
0.6
$ 5.0
Year Ended December 31,
2015
Total
$
3.1
4.1
0.1
0.1
12.4
$ 19.8
Expansion
28.7
$
3.5
1.0
1.1
13.3
47.6
$
$
Maint
3.9
4.7
--
3.6
2.7
$ 14.9
$
Total
32.6
8.2
1.0
4.7
16.0
62.5
$
2014
Maint
$
$
4.3
15.9
--
22.5
4.1
46.8
Expansion
$ 164.0
14.3
7.2
14.5
4.4
$ 204.4
Total
$ 168.3
30.2
7.2
37.0
8.5
$ 251.2
Development spending in 2015 was primarily related to the construction of our Sitka lodge in British Columbia
and our Mariana Lake lodge in Alberta. Development spending in 2014 was primarily related to the construction of
our McClelland Lake lodge in the northern Athabasca oil sands region of Canada.
Open and mobile camp spending in 2014 was primarily related to additions to our Canadian mobile camp
assets, as well as spending on our Antler River open camp in Melita, Manitoba.
Other spending in 2016 and 2015 was primarily related to investments in an enterprise information system.
Net cash of $58.3 million was used in financing activities during 2016, primarily due to repayments of term
loan borrowings of $41.0 million, net repayments of revolver borrowings of $15.2 million and debt issuance costs of
$2.1 million. Net cash of $349.6 million was used in financing activities during 2015, primarily due to repayments
of term loan borrowings of $729.4 million, offset by borrowings of term loans of $325 million and net revolver
borrowings of $59.1 million. Net cash of $16.2 million was provided by financing activities during 2014, in part due
to contributions from Oil States of $28.3 million. Borrowings of $775.0 million under our new term loan facility
funded a cash distribution of $750.0 million to Oil States on May 28, 2014.
The following table summarizes the changes in debt outstanding during 2016 (in thousands):
Balance at December 31, 2015 .........................
Borrowings on revolving credit facilities ...
Repayments of revolving credit facilities ...
Repayments of term loans ..........................
Translation .................................................
Balance at December 31, 2016 .........................
Canada
$
$
352,185
241,293
(263,329)
(16,023)
12,259
326,385
Australia
$
--
37,446
(30,609)
--
(330)
6,507
$
U.S.
49,375
31,800
(31,800)
(25,000)
--
24,375
$
$
Total
401,560
310,539
(325,738)
(41,023)
11,929
357,267
$
$
We believe that cash on hand and cash flow from operations will be sufficient to meet our anticipated liquidity
needs in the coming 12 months. If our plans or assumptions change, or are inaccurate, or if we make acquisitions,
we may need to raise additional capital. Acquisitions have been, and our management believes acquisitions will
continue to be, an element of our business strategy. The timing, size or success of any acquisition effort and the
70
associated potential capital commitments are unpredictable and uncertain. We may seek to fund all or part of any
such efforts with debt and/or equity issuances. Our ability to obtain capital for additional projects to implement our
growth strategy over the longer term will depend upon our future operating performance, financial condition and,
more broadly, on the availability of equity and debt financing. Capital availability will be affected by prevailing
conditions in our industry, the global economy, the global financial markets and other factors, many of which are
beyond our control. In addition, such additional debt service requirements could be based on higher interest rates
and shorter maturities and could impose a significant burden on our results of operations and financial condition,
and the issuance of additional equity securities could result in significant dilution to shareholders. In addition, in
some cases, we may incur costs to acquire land and/or construct assets without securing a customer contract or prior
to finalization of an accommodations contract with a customer. If the contract is not obtained or delayed, the
resulting impact could result in an impairment of the related investment.
We have filed a shelf registration statement with the SEC registering the offering of $300 million of common
shares, preferred shares, debt securities and warrants. On February 7, 2017, we closed a public offering of
23,000,000 common shares at a price to the public of $3.00 per share. We expect to use the net proceeds of $64.9
million from the offering to repay amounts outstanding under our revolving credit facilities and for general
corporate purposes.
Credit Facility and Long Term Debt
On February 17, 2017, the third amendment to the Amended Credit Facility became effective, which:
(cid:2) Provided for the reduction by US$75 million of the aggregate revolving loan commitments under the
Amended Credit Facility, to a maximum principal amount of $275 million. Accordingly, after the
reduction, the revolving credit facility consists of (A) a $40.0 million senior secured revolving credit
facility in favor of certain of our U.S. subsidiaries, as borrower, (B) a $90.0 million senior secured
revolving credit facility in favor of Civeo and certain of our Canadian subsidiaries, as borrowers, (C) a
$60.0 million senior secured revolving credit facility in favor of Civeo, as borrower, and (D) a $85.0
million senior secured revolving credit facility in favor of one of our Australian subsidiaries, as borrower;
(cid:2)
(i) Established one additional level to the total leverage-based grid such that the interest rates for the loans
range from LIBOR +2.25% to LIBOR +5.50% and (ii) increased the undrawn commitment fee from a
range of 0.51% to 1.13% to a range of 0.51% to 1.24% based on total leverage;
(cid:2) Adjusted the maximum leverage ratio financial covenant, as follows; and
Maximum Leverage Ratio
Period Ended
December 31, 2016 (no change) .................
March 31, 2017 (no change) .......................
June 30, 2017 (no change) ..........................
September 30, 2017 ....................................
December 31, 2017 .....................................
March 31, 2018 ...........................................
June 30, 2018 ..............................................
September 30, 2018 ....................................
December 31, 2018 .....................................
March 31, 2019 & thereafter .......................
5.50 : 1.00
5.25 : 1.00
5.25 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.50 : 1.00
5.25 : 1.00
(cid:2) Provided for other technical changes and amendments to the Amended Credit Facility.
The following table summarizes the revolving capacity available under the Amended Credit Facility, as
compared to the second amendment to the Credit Facility (in thousands):
71
Total capacity under revolving credit facilities:
U.S. revolving credit facility ..................................
Canadian revolving credit facility ..........................
New Canadian revolving credit facility ..................
Australian revolving credit facility ........................
Total capacity under revolving credit facilities ..............
Second
Amendment to
the Credit
Facility
$
$
50,000
100,000
100,000
100,000
350,000
Third
Amendment to
the Credit
Facility
$
$
40,000
90,000
60,000
85,000
275,000
U.S. dollar amounts outstanding under the Amended Credit Facility bear interest at a variable rate equal to
LIBOR plus a margin of 2.25% to 5.50%, or a base rate plus 1.25% to 4.50%, in each case based on a ratio of our
total leverage to EBITDA (as defined in the Amended Credit Facility). Canadian dollar amounts outstanding under
the Amended Credit Facility bear interest at a variable rate equal to CDOR plus a margin of 2.25% to 5.50%, or a
base rate plus a margin of 1.25% to 4.50%, in each case based on a ratio of our consolidated total leverage to
EBITDA (as defined in the Amended Credit Facility). Australian dollar amounts outstanding under the Amended
Credit Facility bear interest at a variable rate equal to BBSY plus a margin of 2.25% to 5.50%, based on a ratio of
our consolidated total leverage to EBITDA (as defined in the Amended Credit Facility).
The Amended Credit Facility contains customary affirmative and negative covenants that, among other things,
limit or restrict (i) subsidiary indebtedness, liens and fundamental changes, (ii) asset sales, (iii) margin stock, (iv)
specified acquisitions, (v) restrictive agreements, (vi) transactions with affiliates and (vii) investments and other
restricted payments, including dividends and other distributions. Specifically, we must maintain an interest coverage
ratio, defined as the ratio of consolidated EBITDA (as defined in the Amended Credit Facility) to consolidated
interest expense, of at least 3.0 to 1.0 and a maximum leverage ratio, defined as the ratio of total debt to consolidated
EBITDA, of no greater than 5.50 to 1.0 (as of December 31, 2016). As noted above, the permitted level of the
maximum leverage ratio changes over time. Each of the factors considered in the calculations of these ratios are
defined in the Amended Credit Facility. EBITDA and consolidated interest, as defined in the Amended Credit
Facility, exclude goodwill and asset impairments, debt discount amortization and other non-cash charges. We were
in compliance with these covenants as of December 31, 2016.
Borrowings under the Amended Credit Facility are secured by a pledge of substantially all of our assets and all
the assets of our subsidiaries. Obligations under the Amended Credit Facility are guaranteed by our significant
subsidiaries. We have 15 lenders in our Amended Credit Facility with commitments ranging from $1.1 million to
$116.5 million.
Dividends
We do not currently pay dividends. The declaration and amount of all potential future dividends will be at the
discretion of our Board of Directors and will depend upon many factors, including our financial condition, results of
operations, cash flows, prospects, industry conditions, capital requirements of our business, covenants associated
with certain debt obligations, legal requirements, regulatory constraints, industry practice and other factors the
Board of Directors deems relevant. In addition, our ability to pay dividends is limited by covenants in our Amended
Credit Facility. Future agreements may also limit our ability to pay dividends, and we may incur incremental taxes
in the U.S. if we are required to repatriate foreign earnings to pay such dividends. If we elect to pay dividends in the
future, the amount per share of our dividend payments may be changed, or dividends may again be suspended,
without advance notice. The likelihood that dividends will be reduced or suspended is increased during periods of
market weakness. There can be no assurance that we will pay a dividend in the future.
Effects of Inflation
Our revenues and results of operations have not been materially impacted by inflation in the past three fiscal
years.
72
Off-Balance Sheet Arrangements
As of December 31, 2016, we had no off-balance sheet arrangements as defined in Item 303(a)(4)(ii) of
Regulation S-K.
Contractual Obligations
The following summarizes our contractual obligations at December 31, 2016, and the effect such obligations are
expected to have on our liquidity and cash flow over the next five years (in thousands):
Total debt ...............................................
Interest payments(1) ................................
Purchase obligations ..............................
Non-cancelable operating lease
obligations .......................................
Asset retirement obligations –
$
Total
357,267
34,322
11,753
23,369
Less Than 1
Year
$
15,667
14,728
11,753
4,260
expected cash payments ...................
Total contractual cash obligations ..........
46,640
473,351
$
2,374
48,782
$
5,004
372,730
$
1 – 3 Years
3 – 5 Years
$
341,600
19,594
--
6,532
$
$
--
--
--
4,657
2,650
7,307
More
Than 5
Years
$
--
--
--
7,920
36,612
$ 44,532
(1) Interest payments due under the Amended Credit Facility, which matures on May 28, 2019; based on a weighted
average interest rate of 3.8% to 5.2% for the twelve month period ended December 31, 2016.
Our debt obligations at December 31, 2016 are reflected in our consolidated balance sheet, which is a part of
our consolidated financial statements in Item 8 of this annual report. We have not entered into any material leases
subsequent to December 31, 2016.
Critical Accounting Policies
Our consolidated financial statements in Item 8 of this annual report have been prepared in accordance with
U.S. GAAP, which require that management make numerous estimates and assumptions. Actual results could differ
from those estimates and assumptions, thus impacting our reported results of operations and financial position. The
critical accounting policies and estimates described in this section are those that are most important to the depiction
of our financial condition and results of operations and the application of which requires management’s most
subjective judgments in making estimates about the effect of matters that are inherently uncertain. We describe our
significant accounting policies more fully in Note 2 - Summary of Significant Accounting Policies to the notes to
consolidated financial statements in Item 8 of this annual report.
Accounting for Contingencies
We have contingent liabilities and future claims for which we have made estimates of the amount of the
eventual cost to liquidate these liabilities or claims. These liabilities and claims sometimes involve threatened or
actual litigation where damages have been quantified and we have made an assessment of our exposure and recorded
a provision in our accounts to cover an expected loss. Other claims or liabilities have been estimated based on their
fair value or our experience in these matters and, when appropriate, the advice of outside counsel or other outside
experts. Upon the ultimate resolution of these uncertainties, our future reported financial results will be impacted by
the difference between our estimates and the actual amounts paid to settle a liability. Examples of areas where we
have made important estimates of future liabilities include litigation, taxes, interest, insurance claims, contract
claims and obligations and asset retirement obligations.
73
Impairment of Tangible and Intangible Assets, including Goodwill
Goodwill. Goodwill represents the excess of the purchase price paid for acquired businesses over the allocated
fair value of the related net assets after impairments, if applicable. In connection with the preparation of our
financial statements for the three months ended September 30, 2015, we performed a goodwill impairment test as of
September 30, 2015, and we reduced the value of our goodwill to zero. Please see Note 3 – Impairment Charges to
the notes to consolidated financial statements in Item 8 of this annual report for further discussion of goodwill
impairments recorded in the years ended December 31, 2015 and 2014.
We do not amortize goodwill. We evaluate goodwill for impairment, at the reporting unit level, annually and
when an event occurs or circumstances change to suggest that the carrying amount may not be recoverable. A
reporting unit is the operating segment, or a business one level below that operating segment (the “component”
level) if discrete financial information is prepared and regularly reviewed by management at the component level.
Each segment of our business represents a separate reporting unit, and all three of our reporting units previously had
goodwill. We recognize an impairment loss for any amount by which the carrying amount of a reporting unit’s
goodwill exceeds the reporting unit’s implied fair value (IFV) of goodwill. We conduct our annual impairment test
as of November 30 of each year.
Our assessment consisted of a two-step impairment test. In the first step, we compared each reporting unit’s
carrying amount, including goodwill, to the IFV of the reporting unit. If the carrying amount of the reporting unit
exceeded its fair value, goodwill was considered impaired, and a second step was performed to determine the
amount of impairment. Future impairment tests will be impacted by new accounting guidance which eliminates the
second step of the goodwill impairment test.
We are given the option to test for impairment of our goodwill by first performing a qualitative assessment to
determine whether it is more likely than not (that is, likelihood of more than 50 percent) that the fair value of a
reporting unit is less than its carrying amount, including goodwill. If it is determined that it is more likely than not
that the fair value of a reporting unit is greater than its carrying amount, then performing the currently prescribed
two-step impairment test is unnecessary. In developing a qualitative assessment to meet the “more-likely-than-not”
threshold, each reporting unit with goodwill is assessed separately and different relevant events and circumstances
are evaluated for each unit. We have the option to bypass the qualitative assessment for any reporting unit in any
period and proceed directly to performing the first step of the two-step goodwill impairment test.
In 2014, we chose to bypass the qualitative assessment and proceed directly to the first step of the impairment
test. In performing the two-step impairment test, we compare each reporting unit’s carrying amount, including
goodwill, to the IFV of the reporting unit. Because none of our reporting units has a publically quoted market price,
we must determine the value that willing buyers and sellers would place on the reporting unit through a routine sale
process (a Level 3 fair value measurement). In our analysis, we target an IFV that represents the value that would be
placed on the reporting unit by market participants, and value the reporting unit based on historical and projected
results throughout a cycle, not the value of the reporting unit based on trough or peak earnings. The IFV of the
reporting unit is estimated using a combination of (i) an analysis of trading multiples of comparable companies
(Market Approach) and (ii) discounted projected cash flows (Income Approach). We also use acquisition multiples
analyses in certain circumstances. The relative weighting of each approach varies by reporting unit, based on
management’s judgment.
Market Approach - This valuation approach utilizes publicly traded comparable companies’ enterprise values,
as compared to their recent and forecasted earnings before interest, taxes and depreciation (EBITDA) information.
We have historically used an average EBITDA multiple ranging from approximately 6.5x to approximately 9.5x
depending on the reporting unit. We use EBITDA because it is a widely used key indicator of the cash generating
capacity of companies in our industry.
Income Approach - This valuation approach derives a present value of the reporting unit’s projected future
annual cash flows over the next five years. We use a variety of underlying assumptions to estimate these future cash
flows, including assumptions relating to future economic market conditions, rates, occupancy levels, costs and
expenses and capital expenditures. These assumptions vary by each reporting unit depending on market conditions.
74
In addition, a terminal value is estimated, using a Gordon Growth methodology with a long-term growth rate of 3%.
We discount our projected cash flows using a long-term weighted average cost of capital based on our estimate of
investment returns that would be required by a market participant.
The IFV of our reporting units is affected by future oil, coal and natural gas prices, anticipated spending by our
customers and the cost of capital. Our estimate of IFV requires us to use significant unobservable inputs,
representative of Level 3 fair value measurements, including numerous assumptions with respect to future
circumstances, such as industry and/or local market conditions that might directly impact each reporting unit’s
operations in the future, and are therefore uncertain. We selected these valuation approaches because we believe the
combination of these approaches and our best judgment regarding underlying assumptions and estimates provides us
with the best estimate of fair value for each of our reporting units. We believe these valuation approaches are proven
valuation techniques and methodologies for our industry and widely accepted by investors. The IFV of each
reporting unit would change if our assumptions under these valuation approaches, or relative weighting of the
valuation approaches, were materially modified.
Definite-Lived Tangible and Intangible Assets. The recoverability of the carrying values of tangible and
intangible assets is assessed at an asset group level which represents the lowest level for which identifiable cash
flows are largely independent of the cash flows of other assets and liabilities. Whenever, in management’s judgment,
events or changes in circumstances indicate that the carrying value of such asset groups may not be recoverable
based on estimated future cash flows, an asset impairment evaluation is performed. Indicators of impairment might
include persistent negative economic trends affecting the markets we serve, recurring losses or lowered expectations
of future cash flows expected to be generated by our assets.
In performing this analysis, the first step is to compare each asset group’s carrying value to estimates of
undiscounted future cash flows. We use a variety of underlying assumptions to estimate these future cash flows,
including assumptions relating to future economic market conditions, rates, occupancy levels, costs and expenses
and capital expenditures. The estimates are consistent with those used for purposes of our goodwill impairment test,
as further discussed in Goodwill, above.
If, based on the assessment, the carrying values of any of our asset groups are determined to not be recoverable,
we proceed to the second step. In this step, we compare the fair value of the respective asset group to its carrying
value. Our estimate of the fair value requires us to use significant unobservable inputs, representative of Level 3 fair
value measurements, including numerous assumptions with respect to future circumstances, such as industry and/or
local market conditions that might directly impact each of the asset groups’ operations in the future, and are
therefore uncertain.
Our industry is cyclical and our estimates of the period over which future cash flows will be generated, as well
as the predictability of these cash flows and our determination of whether a decline in value of our investment has
occurred, can have a significant impact on the carrying value of these assets and, in periods of prolonged down
cycles, may result in impairment losses. If this assessment indicates that the carrying values will not be recoverable,
an impairment loss is recognized equal to the excess of the carrying value over the fair value of the asset group. The
fair value of the asset group is based on prices of similar assets, if available, or discounted cash flows.
During the third quarter of 2016, we identified an indicator that certain asset groups used, or expected to be
used, in conjunction with potential LNG projects in British Columbia may be impaired as a result of recent market
developments, including the delay in FID discussed above. As a result, we assessed the carrying values of each of
the asset groups to determine if they continued to be recoverable based on their estimated future cash flows. Based
on the assessment, the carrying values of our mobile camp assets and certain undeveloped land positions in British
Columbia were determined to not be recoverable, and an impairment charge totaling $37.7 million was recorded in
the third quarter of 2016.
In estimating future cash flows, we made numerous assumptions with respect to future circumstances that might
directly impact each of the asset groups’ operations in the future and are therefore uncertain. These assumptions
with respect to future circumstances included future oil, coal and natural gas prices, anticipated customer spending,
and industry and/or local market conditions. These assumptions represented our best judgment based on the current
facts and circumstances. However, different assumptions could result in a determination that the carrying values of
75
additional asset groups are no longer recoverable based on estimated future cash flows. If estimates of future cash
flows for certain of our assets included in this assessment that were not impaired were reduced by 10%, an
additional impairment of between $25 million and $35 million could be indicated. Our estimate of fair value was
primarily calculated using the Income Approach, which derives a present value of the asset group based on the asset
groups’ estimated future cash flows. We discounted our estimated future cash flows using a long-term weighted
average cost of capital based on our estimate of investment returns required by a market participant.
Please see Note 3 – Impairment Charges to the notes to consolidated financial statements in Item 8 of this report
for further discussion of impairments of definite-lived tangible and intangible assets recorded in the years ended
December 31, 2016, 2015 and 2014.
Indefinite-Lived Intangible Assets. We are required to evaluate our indefinite-lived intangible assets for
impairment annually and when an event occurs or circumstances change to suggest the carrying amount may not be
recoverable. In performing the impairment test, we compare the fair value of the indefinite-lived intangible asset
with its carrying amount. The measurement of the impairment is calculated based on the excess of the carrying
value over its fair value.
Please see Note 3 – Impairment Charges to the notes to consolidated financial statements in Item 8 of this report
for further discussion of impairments of indefinite-lived intangible assets recorded in the years ended December 31,
2015 and 2014.
Revenue and Cost Recognition
Revenues are recognized based on a periodic (usually daily) room rate or when the services are rendered.
Revenues are recognized in the period in which services are provided pursuant to the terms of our contractual
relationships with our customers. In some contracts, the rate or committed room numbers may vary over the contract
term. In these cases, revenue may be deferred and recognized on a straight-line basis over the contract term.
Revenue from the sale of products, not accounted for utilizing the percentage-of-completion method, is recognized
when delivery to and acceptance by the customer has occurred, when title and all significant risks of ownership have
passed to the customer, collectability is probable and pricing is fixed and determinable. Our product sales terms do
not include significant post-delivery obligations.
For significant projects, revenues are recognized under the percentage-of-completion method, measured by the
percentage of costs incurred to date compared to estimated total costs for each contract (cost-to-cost method).
Billings on such contracts in excess of costs incurred and estimated profits are classified as deferred revenue. Costs
incurred and estimated profits in excess of billings on percentage-of-completion contracts are recognized as unbilled
receivables. Our management believes this method is the most appropriate measure of progress on large contracts.
Provisions for estimated losses on uncompleted contracts are made in the period in which such losses are
determined. Changes in job performance, job conditions, estimated profitability, and final contract settlements may
result in revisions to projected costs and revenue and are recognized in the period in which the revisions are
determined. Factors that may affect future project costs and margins include weather, production efficiencies,
availability and costs of labor, materials and subcomponents. These factors can significantly impact the accuracy of
our estimates and materially impact our future reported earnings.
Revenues exclude taxes assessed based on revenues such as sales or value added taxes.
Cost of services includes labor, food, utilities, cleaning supplies and other costs associated with operating the
accommodations facilities. Cost of goods sold includes all direct material and labor costs and those costs related to
contract performance, such as indirect labor, supplies, tools and repairs. Selling, general and administrative costs are
charged to expense as incurred.
Estimation of Useful Lives
The selection of the useful lives of many of our assets requires the judgments of our operating personnel as to
the length of these useful lives. Our judgment in this area is influenced by our historical experience in operating our
assets, technological developments and expectations of future demand for the assets. Should our estimates be too
76
long or short, we might eventually report a disproportionate number of losses or gains upon disposition or retirement
of our long-lived assets. We reevaluate the remaining useful lives and salvage values of our assets when certain
events occur that directly impact the useful lives and salvage values, including changes in operating condition,
functional capability and market and economic factors. We believe our estimates of useful lives are appropriate.
Share-Based Compensation
Our historic share-based compensation is based on participating in Civeo’s 2014 Equity Participation Plan and,
prior to the Spin-Off, the Oil States 2001 Equity Participation Plan (collectively, the Plans). Our disclosures reflect
only our employees’ participation in the Plans. We are required to estimate the fair value of share compensation
made pursuant to awards under the Plans. An initial estimate of the fair value of each option award or restricted
share award determines the amount of share compensation expense we will recognize in the future. For stock option
awards prior to the Spin-Off, to estimate the value of the awards under the Plan, Oil States selected a fair value
calculation model. Oil States chose the Black-Scholes option pricing model to value stock options awarded under
the Plan. Oil States chose this model because option awards were made under straightforward vesting terms, option
prices and option lives. Utilizing the Black-Scholes option pricing model required Oil States to estimate the length
of time options will remain outstanding, a risk free interest rate for the estimated period options are assumed to be
outstanding, forfeiture rates, future dividends and the volatility of our common stock. All of these assumptions affect
the amount and timing of future share-based compensation expense recognition. We have not made any option
awards subsequent to the Spin-Off, but, in the event that we make future awards, we expect to utilize a similar
valuation methodology. We will continually monitor our actual experience and change assumptions for future
awards as we consider appropriate.
We also grant performance awards under the Civeo Plan. Awards granted in 2016 will be earned in amounts
between 0% and 200% of the participant’s target performance share award, based on the payout percentage
associated with Civeo’s relative total shareholder return rank among a peer group of 12 other companies. The fair
value of the 2016 awards was estimated using a Monte Carlo simulation pricing model. We chose this model
because the performance awards contain complex vesting terms. Utilizing the Monte Carlo simulation pricing
model required us to estimate the risk-free interest rate and the expected market price volatility of our common
shares as well as a peer group of companies over a time period equal to the expected term of the award, The
resulting cost is recognized over the period during which an employee is required to provide service in exchange for
the awards, usually the vesting period. For additional details, see Note 15 – Share Based Compensation.
Income Taxes
We follow the liability method of accounting for income taxes in accordance with current accounting standards
regarding the accounting for income taxes. Under this method, deferred income taxes are recorded based upon the
differences between the financial reporting and tax bases of assets and liabilities and are measured using the enacted
tax rates and laws in effect at the time the underlying assets or liabilities are recovered or settled.
When our earnings from foreign subsidiaries are considered to be indefinitely reinvested, no provision for
Canadian income taxes is made for these earnings. If any of the subsidiaries have a distribution of earnings in the
form of dividends or otherwise, we would be subject to both Canadian income taxes (subject to an adjustment for
foreign tax credits) and withholding taxes payable to various foreign countries. During the fourth quarter of 2014,
we reevaluated our intent to indefinitely reinvest earnings of our U.S. foreign subsidiary companies, and recognized
a deferred tax liability of $25.3 million as of December 31, 2014 related to a portion of our undistributed foreign
earnings. During the third quarter of 2015, following our redomiciliation to Canada, we determined that the existing
deferred tax liability recorded was no longer required. We reversed the deferred tax liability and recorded a tax
benefit of approximately $25.3 million during the year ended December 31, 2015. We do not expect to provide
Canadian income taxes on future foreign earnings.
We record a valuation allowance in each reporting period when our management believes that it is more likely
than not that any recorded deferred tax asset will not be realized. Our management will continue to evaluate the
appropriateness of the valuation allowance in the future, based upon our operating results. Please see Note 12 –
Income Taxes to the notes to consolidated financial statements in Item 8 of this report for further discussion.
77
In accounting for income taxes, we are required to estimate a liability for future income taxes for any
uncertainty for potential income tax exposures. The calculation of our tax liabilities involves dealing with
uncertainties in the application of complex tax regulations. We recognize liabilities for anticipated tax audit issues in
the U.S. and other tax jurisdictions based on our estimate of whether, and the extent to which, additional taxes will
be due. If we ultimately determine that payment of these amounts is unnecessary, we reverse the liability and
recognize a tax benefit during the period in which we determine that the liability is no longer necessary. We record
an additional charge in our provision for taxes in the period in which we determine that the recorded tax liability is
less than we expect the ultimate assessment to be.
For periods prior to the Spin-Off, our results were included in the consolidated tax return of Oil States. We have
determined our U.S. income taxes in the combined financial statements by assuming our results are excluded from
the consolidated return and then comparing consolidated taxable income and taxes due with and then without our
results. Canadian and Australian taxes are based on actual tax returns filed by our foreign subsidiaries.
Recent Accounting Pronouncements
From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board
(the FASB), which are adopted by us as of the specified effective date. Unless otherwise discussed, management
believes that the impact of recently issued standards, which are not yet effective, will not have a material impact on
our consolidated financial statements upon adoption. Please see Note 2 – Summary of Significant Accounting
Policies – Recent Accounting Pronouncements to the notes to consolidated financial statements in Item 8 of this
report for further discussion.
78
ITEM 7A. Quantitative and Qualitative Disclosures about Market Risk
Our principal market risks are our exposure to changes in interest rates and foreign currency exchange rates.
Interest Rate Risk
We have credit facilities that are subject to the risk of higher interest charges associated with increases in
interest rates. As of December 31, 2016, we had $357.3 million of outstanding floating-rate obligations under our
credit facilities. These floating-rate obligations expose us to the risk of increased interest expense in the event of
increases in short-term interest rates. If floating interest rates increased by 100 basis points, our consolidated
interest expense would increase by approximately $3.6 million annually, based on our floating-rate debt obligations
as of December 31, 2016.
Foreign Currency Exchange Rate Risk
Our operations are conducted in various countries around the world and we receive revenue and pay expenses
from these operations in a number of different currencies. As such, our earnings are subject to movements in foreign
currency exchange rates when transactions are denominated in (i) currencies other than the U.S. dollar, which is our
functional currency, or (ii) the functional currency of our subsidiaries, which is not necessarily the U.S. dollar.
Excluding intercompany balances, our Canadian dollar and Australian dollar functional currency net assets total
approximately C$0.2 billion and A$0.5 billion, respectively, at December 31, 2016. We use a sensitivity analysis
model to measure the impact of a 10% adverse movement of foreign currency exchange rates against the United
States dollar. A hypothetical 10% adverse change in the value of the Canadian dollar and Australian dollar relative
to the U.S. dollar as of December 31, 2016 would result in translation adjustments of approximately $17.0 million
and $47.0 million, respectively, recorded in other comprehensive loss. Although we do not currently have any
foreign exchange agreements outstanding, in order to reduce our exposure to fluctuations in currency exchange
rates, we may enter into foreign exchange agreements with financial institutions in the future.
ITEM 8. Financial Statements and Supplementary Data
Our Consolidated Financial Statements and supplementary data appear on pages 87 through 127 of this Annual
Report on Form 10-K and are incorporated by reference into this Item 8. Selected quarterly financial data is set
forth in Note 19 – Quarterly Financial Information (Unaudited) to our Consolidated Financial Statements, which is
incorporated herein by reference.
ITEM 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
There were no changes in or disagreements on any matters of accounting principles or financial statement
disclosure between us and our independent auditors during our two most recent fiscal years or any subsequent
interim period.
ITEM 9A. Controls and Procedures
(i) Evaluation of Disclosure Controls and Procedures
As of the end of the period covered by this annual report, we carried out an evaluation, under the supervision
and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of
the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-
15(e) and 15d-15(e) under the Exchange Act). Our disclosure controls and procedures are designed to provide
reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange
Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief
Financial Officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed,
summarized and reported within the time periods specified in the rules and forms of the Commission. Based upon
that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and
procedures were effective as of December 31, 2016 at the reasonable assurance level.
79
(ii) Internal Control Over Financial Reporting
(a) Management's annual report on internal control over financial reporting.
Our management is responsible for establishing and maintaining adequate internal control over financial
reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. Our internal control over financial
reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and
the preparation of consolidated financial statements for external purposes in accordance with GAAP. Our internal
control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records
that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets; (ii) provide
reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in
accordance with GAAP, and that our receipts and expenditures are being made only in accordance with
authorizations of management and our directors, and (iii) provide reasonable assurance regarding prevention or
timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the
consolidated 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. Accordingly, even effective internal control over financial reporting can
only provide reasonable assurance of achieving their control objectives.
Under the supervision and with the participation of our management, including our Chief Executive Officer and
Chief Financial Officer, an assessment of the effectiveness of our internal control over financial reporting as of
December 31, 2016 was conducted. 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 Framework). Based on our assessment we believe that, as of December 31, 2016, the Company's
internal control over financial reporting is effective based on those criteria.
(b) Attestation report of the registered public accounting firm.
The attestation report of Ernst & Young LLP, the Company's independent registered public accounting firm, on
the Company's internal control over financial reporting is set forth in this report on page 89 and is incorporated
herein by reference.
(c) Changes in internal control over financial reporting.
During the three months ended December 31, 2016, there were no changes in our internal control over financial
reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) which have materially affected, or are
reasonably likely to materially affect, our internal control over financial reporting.
ITEM 9B. Other Information
Not applicable.
80
ITEM 10. Directors, Executive Officers and Corporate Governance
PART III
The information required by Item 10 hereby is incorporated by reference to such information as set forth in the
Company's Definitive Proxy Statement for the 2017 Annual General Meeting of Shareholders.
The Board of Directors of the Company (the Board) has documented its governance practices by adopting
several corporate governance policies. These governance policies, including the Company's Corporate Governance
Guidelines, Corporate Code of Business Conduct and Ethics and Financial Code of Ethics for Senior Officers, as
well as the charters for the committees of the Board (Audit Committee, Compensation Committee, Finance and
Investment Committee and Nominating and Corporate Governance Committee) may also be viewed at the
Company's website. The Financial Code of Ethics for Senior Officers applies to our principal executive officer,
principal financial officer, principal accounting officer and certain other senior officers. We intend to disclose any
amendments to or waivers from our Financial Code of Ethics for Senior Officers by posting such information on our
website at www.civeo.com. Copies of such documents will be sent to shareholders free of charge upon written
request to the corporate secretary at the address shown on the cover page of this report.
ITEM 11. Executive Compensation
The information required by Item 11 hereby is incorporated by reference to such information as set forth in the
Company's Definitive Proxy Statement for the 2017 Annual General Meeting of Shareholders.
ITEM 12. Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters
The information required by Item 12 hereby is incorporated by reference to such information as set forth in the
Company's Definitive Proxy Statement for the 2017 Annual General Meeting of Shareholders.
ITEM 13. Certain Relationships and Related Transactions, and Director Independence
The information required by Item 13 hereby is incorporated by reference to such information as set forth in the
Company's Definitive Proxy Statement for the 2017 Annual General Meeting of Shareholders.
ITEM 14. Principal Accounting Fees and Services
The information required by Item 14 hereby is incorporated by reference to such information as set forth in the
Company's Definitive Proxy Statement for the 2017 Annual General Meeting of Shareholders.
81
ITEM 15. Exhibits, Financial Statement Schedules
(a) Index to Financial Statements, Financial Statement Schedules and Exhibits
PART IV
(1) Financial Statements: Reference is made to the index set forth on page 87 of this Annual Report on Form
10-K.
(2) Financial Statement Schedules: No schedules have been included herein because the information required to
be submitted has been included in the Consolidated Financial Statements or the Notes thereto, or the required
information is inapplicable.
(3) Index of Exhibits: See Index of Exhibits, below, for a list of those exhibits filed herewith, which index also
includes and identifies management contracts or compensatory plans or arrangements required to be filed as
exhibits to this Annual Report on Form 10-K by Item 601 of Regulation S-K.
(b)
Index of Exhibits
Exhibit No.
Description
2.1
2.2
3.1
3.2
4.1
10.1
10.2
10.3
10.4
10.5
Agreement and Plan of Merger, dated as of April 6, 2015, among Civeo Corporation, Civeo
Canadian Holdings ULC and Civeo US Merger Co (incorporated by reference to Annex A of
Civeo Corporation’s definitive proxy statement/prospectus on Schedule 14A filed with the SEC on
April 8, 2015).
Separation and Distribution Agreement by and between Oil States International, Inc. and Civeo
Corporation, dated May 27, 2014 (incorporated herein by reference to Exhibit 2.1 to the Current
Report on Form 8-K (File No. 001-36246) filed on June 2, 2014).
Notice of Articles of Civeo Corporation (incorporated herein by reference to Exhibit 3.1 to the
Current Report on Form 8-K12B (File No. 001-36246) filed on July 17, 2015).
Amended and Restated Articles of Civeo Corporation (incorporated herein by reference to Exhibit
3.1 to the Current Report on Form 8-K (File No. 001-36246) filed on May 13, 2016).
Form of Common Share Certificate (incorporated herein by reference to Exhibit 4.1 to the Current
Report on Form 8-K12B (File No. 001-36246) filed on July 17, 2015).
Indemnification and Release Agreement by and between Oil States International, Inc. and Civeo
Corporation, dated May 27, 2014 (incorporated herein by reference to Exhibit 10.1 to the Current
Report on Form 8-K (File No. 001-36246) filed on June 2, 2014).
Tax Sharing Agreement by and between Oil States International, Inc. and Civeo Corporation,
dated May 27, 2014 (incorporated herein by reference to Exhibit 10.2 to the Current Report on
Form 8-K (File No. 001-36246) filed on June 2, 2014).
Employee Matters Agreement by and between Oil States International, Inc. and Civeo
Corporation, dated May 27, 2014 (incorporated herein by reference to Exhibit 10.3 to the Current
Report on Form 8-K (File No. 001-36246) filed on June 2, 2014).
Transition Services Agreement by and between Oil States International, Inc. and Civeo
Corporation, dated May 27, 2014 (incorporated herein by reference to Exhibit 10.4 to the Current
Report on Form 8-K (File No. 001-36246) filed on June 2, 2014).
Syndicated Facility Agreement, dated as of May 28, 2014, among Civeo Corporation, Civeo
Canada Inc., Civeo Premium Camp Services Ltd. And Civeo Australia Pty Limited, as Borrowers,
the Lenders named therein, Royal Bank of Canada, as Administrative Agent, U.S. Collateral
Agent, Canadian Administrative Agent, Canadian Collateral Agent and an Issuing Bank, and RBC
82
10.6†
10.7†
10.8†
10.9†
10.10†
10.11†
10.12†
10.13†
10.14†
10.15†
10.16†
10.17†
10.18†
10.19†
10.20†
Europe Limited, as Australian Administrative Agent, Australian Collateral Agent and an Issuing
Bank (incorporated herein by reference to Exhibit 10.5 to the Current Report on Form 8-K (File
No. 001-36246) filed on June 2, 2014).
Form of Indemnification Agreement (incorporated herein by reference to Exhibit 10.1 to the
Current Report on Form 8-K12B (File No. 001-36246) filed on July 17, 2015).
Settlement Agreement and Release, dated as of June 26, 2014, by and between Civeo Corporation
and Ronald Green (incorporated herein by reference to Exhibit 10.7 to the Quarterly Report on
Form 10-Q (File No. 001-36246) filed on August 13, 2014).
Amended and Restated 2014 Equity Participation Plan of Civeo Corporation (incorporated herein
by reference to Annex B of Civeo Corporation’s definitive proxy statement on Schedule 14A (File
No. 001-36246) filed on April 11, 2016).
Performance Share Award Program under the 2014 Equity Participation Plan (incorporated by
reference to Exhibit 10.2 to the Quarterly Report on Form 10-Q (File No. 001-36246) filed on
April 28, 2016).
Form of Performance Share Award Agreement under the 2014 Equity Participation Plan
(incorporated by reference to Exhibit 10.3 to the Quarterly Report on Form 10-Q (File No. 001-
36246) filed on April 28, 2016).
Form of Civeo Corporation Annual Incentive Compensation Plan (incorporated herein by
reference to Exhibit 10.7 to the Registration Statement on Form 10 (File No. 001-36246) filed on
April 22, 2014).
Form of Canadian Long-Term Incentive Plan (incorporated herein by reference to Exhibit 10.8 to
the Registration Statement on Form 10 (File No. 001-36246) filed on April 22, 2014).
Form of Employee Non-Qualified Stock Option Agreement under the 2014 Equity Participation
Plan of Civeo Corporation (incorporated herein by reference to Exhibit 10.9 to the Registration
Statement on Form 10 (File No. 001-36246) filed on April 22, 2014).
Form of Restricted Stock Agreement under the 2014 Equity Participation Plan of Civeo
Corporation (incorporated herein by reference to Exhibit 10.10 to the Registration Statement on
Form 10 (File No. 001-36246) filed on April 22, 2014).
Form of Non-Employee Director Restricted Stock Agreement (incorporated herein by reference to
Exhibit 10.11 to the Registration Statement on Form 10 (File No. 001-36246) filed on April 22,
2014).
Form of Deferred Stock Agreement (Australia) (incorporated herein by reference to Exhibit 10.12
to the Registration Statement on Form 10 (File No. 001-36246) filed on April 22, 2014).
Form of Deferred Stock Agreement (Canada) (incorporated herein by reference to Exhibit 10.13 to
the Registration Statement on Form 10 (File No. 001-36246) filed on April 22, 2014).
Form of Executive Agreement of Bradley J. Dodson (incorporated herein by reference to Exhibit
10.14 to the Registration Statement on Form 10 (File No. 001-36246) filed on April 22, 2014).
Form of Phantom Unit Agreement under the 2014 Equity Participation Plan of Civeo Corporation
(incorporated herein by reference to Exhibit 10.17 to the Annual Report on Form 10-K (File No.
001-36246) filed on March 13, 2015).
Executive Agreement between Civeo Corporation and Frank C. Steininger, dated May 4, 2015
(incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K (File No.
001-36246) filed on May 7, 2015).
10.21†
Executive Services Agreement, dated May 30, 2012, between Peter McCann and The Mac
83
10.22†
10.23†
10.24†
10.25†
10.26†
10.27†
10.28†
10.29†
10.30†
10.31
10.32
Services Group Pty Ltd. (incorporated herein by reference to Exhibit 10.3 to the Current Report on
Form 8-K12B (File No. 001-36246) filed on July 17, 2015).
Dual Employment Agreement of Bradley J. Dodson (incorporated herein by reference to Exhibit
10.4 to the Current Report on Form 8-K12B (File No. 001-36246) filed on July 17, 2015).
Dual Employment Agreement of Frank C. Steininger (incorporated herein by reference to Exhibit
10.5 to the Current Report on Form 8-K12B (File No. 001-36246) filed on July 17, 2015).
Executive Agreement between Civeo Corporation and Peter McCann, dated August 17, 2015
(incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K (File No.
001-36246) filed on August 27, 2015).
Variation to Executive Services Agreement between Civeo Pty Ltd and Peter McCann, dated
August 17, 2015 (incorporated herein by reference to Exhibit 10.2 to the Current Report on Form
8-K (File No. 001-36246) filed on August 27, 2015).
Dual Employment Agreement (Canada) of Allan Schoening, dated July 16, 2015 (incorporated
herein by reference to Exhibit 10.8 to the Quarterly Report on Form 10-Q (File No. 001-36246)
filed on November 3, 2015).
Dual Employment Agreement (United States) of Allan Schoening, dated July 16, 2015
(incorporated herein by reference to Exhibit 10.9 to the Quarterly Report on Form 10-Q (File No.
001-36246) filed on November 3, 2015).
Executive Agreement between Civeo Corporation and Mike Ridley, effective May 4, 2015
(incorporated herein by reference to Exhibit 10.10 to the Quarterly Report on Form 10-Q (File No.
001-36246) filed on November 3, 2015).
Executive Change of Control Severance Agreement between Civeo Corporation and Allan
Schoening, dated July 13, 2015 (incorporated herein by reference to Exhibit 10.11 to the Quarterly
Report on Form 10-Q (File No. 001-36246) filed on November 3, 2015).
Executive Agreement between Civeo Corporation and Allan Schoening, dated December 15, 2014
(incorporated herein by reference to Exhibit 10.12 to the Quarterly Report on Form 10-Q (File No.
001-36246) filed on November 3, 2015).
First Amendment to Syndicated Facility Agreement, dated as of May 13, 2015, by and among
Civeo Corporation, Civeo Canadian Holdings ULC, Civeo Canada Inc., Civeo Premium Camp
Services Ltd., and Civeo PTY Limited as Borrowers, the Lenders named therein, Royal Bank of
Canada, as Administrative Agent, U.S. Collateral Agent, Canadian Administrative Agent,
Canadian Collateral Agent and an Issuing Bank and RBC Europe Limited, as Australian
Administrative Agent, Australian Collateral Agent and an Issuing Bank (incorporated herein by
reference to Exhibit 10.1 to the Current Report on Form 8-K (File No. 001-36246) filed on May
19, 2015).
Second Amendment to Syndicated Facility Agreement, dated as of February 18, 2016, by and
among Civeo Corporation, Civeo U.S. Holdings LLC, Civeo Management LLC, Civeo Canada
Inc., Civeo Premium Camp Services Ltd., and Civeo PTY Limited as Borrowers, the Lenders
named therein, Royal Bank of Canada, as Administrative Agent, U.S. Collateral Agent, Canadian
Administrative Agent, Canadian Collateral Agent and an Issuing Bank and RBC Europe Limited,
as Australian Administrative Agent, Australian Collateral Agent and an Issuing Bank
(incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K (File No.
001-36246) filed on February 24, 2016).
10.33†*
Amendment to Civeo Corporation 2014 Equity Participation Plan.
21.1*
23.1*
List of Significant Subsidiaries of Civeo Corporation.
Consent of Ernst & Young LLP.
84
31.1*
— Certification of Chief Executive Officer of Civeo Corporation pursuant to Rules 13a-14(a) or 15d-
14(a) under the Securities Exchange Act of 1934.
31.2*
— Certification of Chief Financial Officer of Civeo Corporation pursuant to Rules 13a-14(a) or 15d-
14(a) under the Securities Exchange Act of 1934.
32.1**
— Certification of Chief Executive Officer of Civeo Corporation pursuant to Rules 13a-14(b) or 15d-
14(b) under the Securities Exchange Act of 1934.
32.2**
— Certification of Chief Financial Officer of Civeo Corporation pursuant to Rules 13a-14(b) or 15d-
14(b) under the Securities Exchange Act of 1934.
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
*
†
**
Filed herewith.
Management contracts and compensatory plans and arrangements.
Furnished herewith.
PLEASE NOTE: Pursuant to the rules and regulations of the Securities and Exchange Commission, we have filed or
incorporated by reference the agreements referenced above as exhibits to this Annual Report on Form 10-K. The
agreements have been filed to provide investors with information regarding their respective terms. The agreements
are not intended to provide any other factual information about Civeo or its business or operations. In particular, the
assertions embodied in any representations, warranties and covenants contained in the agreements may be subject to
qualifications with respect to knowledge and materiality different from those applicable to investors and may be
qualified by information in confidential disclosure schedules not included with the exhibits. These disclosure
schedules may contain information that modifies, qualifies and creates exceptions to the representations, warranties
and covenants set forth in the agreements. Moreover, certain representations, warranties and covenants in the
agreements may have been used for the purpose of allocating risk between the parties, rather than establishing
matters as facts. In addition, information concerning the subject matter of the representations, warranties and
covenants may have changed after the date of the respective agreement, which subsequent information may or may
not be fully reflected in our public disclosures. Accordingly, investors should not rely on the representations,
warranties and covenants in the agreements as characterizations of the actual state of facts about Civeo or its
business or operations on the date hereof.
85
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 on February 23,
2017.
CIVEO CORPORATION
By /s/ FRANK C. STEININGER
Frank C. Steininger
Senior Vice President, Chief Financial
Officer and Treasurer
Signature
Title
/s/ DOUGLAS E. SWANSON
Douglas E. Swanson
Chairman of the Board
/s/ BRADLEY J. DODSON
Bradley J. Dodson
Director, President & Chief Executive Officer
(Principal Executive Officer)
/s/ FRANK C. STEININGER
Frank C. Steininger
Senior Vice President, Chief Financial Officer
and Treasurer
(Principal Financial Officer and Accounting Officer)
/s/ C. RONALD BLANKENSHIP
Director
C. Ronald Blankenship
/s/ MARTIN A. LAMBERT
Director
Martin A. Lambert
/s/ CONSTANCE B. MOORE
Director
Constance B. Moore
/s/ RICHARD A. NAVARRE
Richard A. Navarre
Director
/s/ CHARLES SZALKOWSKI
Director
Charles Szalkowski
86
CIVEO CORPORATION
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
Report of Independent Registered Public Accounting Firm on Consolidated Financial Statements .......................
Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting ...........
Consolidated Statements of Operations for the Years Ended December 31, 2016, 2015 and 2014 .........................
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2016, 2015 and
2014 ......................................................................................................................................................................
Consolidated Balance Sheets at December 31, 2016 and 2015................................................................................
Consolidated Statements of Changes in Shareholders’ Equity / Net Investment for the Years Ended December
Page
No.
88
89
90
91
92
93
31, 2016, 2015 and 2014 ......................................................................................................................................
Consolidated Statements of Cash Flows for the Years Ended December 31, 2016, 2015 and 2014 .......................
94
Notes to Consolidated Financial Statements ............................................................................................................ 95 -127
87
CIVEO CORPORATION
Report of Independent Registered Public Accounting Firm on Consolidated Financial Statements
To the Board of Directors and Shareholders of Civeo Corporation:
We have audited the accompanying consolidated balance sheets of Civeo Corporation (the “Company”) as of December 31,
2016 and 2015, and the related consolidated statements of operations, comprehensive income (loss), changes in shareholders’
equity/net investment and cash flows for each of the three years in the period ended December 31, 2016. These financial
statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial
statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United
States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts
and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits
provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated
financial position of Civeo Corporation at December 31, 2016 and 2015, and the consolidated results of its operations and its
cash flows for each of the three years in the period ended December 31, 2016, in conformity with U.S. generally accepted
accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States),
Civeo Corporation internal control over financial reporting as of December 31, 2016, based on criteria established in Internal
Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013
framework) and our report dated February 23, 2017 expressed an unqualified opinion thereon.
/s/ Ernst & Young LLP
Houston, Texas
February 23, 2017
88
Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting
CIVEO CORPORATION
To the Board of Directors and Shareholders of Civeo Corporation:
We have audited Civeo Corporation’s (the “Company”) internal control over financial reporting as of December 31, 2016,
based on criteria established in Internal Control – Integrated Framework issued by the Committee of Sponsoring
Organizations of the Treadway Commission (2013 framework) (the COSO criteria). Civeo Corporation’s management is
responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of
internal control over financial reporting included in the accompanying Management’s annual report on internal control over
financial reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting
based on our audit.
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United
States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective
internal control over financial reporting was maintained in all material respects. Our audit included obtaining an
understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and
evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other
procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our
opinion.
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally
accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures
that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and
dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to
permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and
expenditures of the company are being made only in accordance with authorizations of management and directors of the
company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or
disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also,
projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate
because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
In our opinion, Civeo Corporation maintained, in all material respects, effective internal control over financial reporting as of
December 31, 2016, based on the COSO criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States),
the consolidated balance sheets of Civeo Corporation as of December 31, 2016 and 2015, and the related consolidated
statements of operations, comprehensive income (loss), shareholders’ equity/net investment and cash flows for each of the
three years in the period ended December 31, 2016 and our report dated February 23, 2017 expressed an unqualified opinion
thereon.
/s/ Ernst & Young LLP
Houston, Texas
February 23, 2017
89
CIVEO CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
(In Thousands, Except Per Share Amounts)
Revenues:
Service and other .......................................................................
Product ......................................................................................
Costs and expenses:
Service and other costs ..............................................................
Product costs ..............................................................................
Selling, general and administrative expenses.............................
Spin-off and formation costs......................................................
Depreciation and amortization expense .....................................
Impairment expense ...................................................................
Other operating expense (income) ............................................
Operating loss ..................................................................................
Interest expense to affiliates ............................................................
Interest expense to third-parties, net of capitalized interest .............
Loss on extinguishment of debt .......................................................
Interest income ................................................................................
Other income ...................................................................................
Loss before income taxes ...........................................................
Income tax benefit (provision) .........................................................
Net loss ............................................................................................
Less: Net income attributable to noncontrolling interest ..........
Net loss attributable to Civeo Corporation. .....................................
YEAR ENDED DECEMBER 31,
2015
2014
2016
$ 378,585
18,645
397,230
$ 489,788
28,175
517,963
$
908,061
34,830
942,891
238,037
21,613
55,297
--
131,302
46,129
612
492,990
(95,760)
--
(22,667)
(302)
152
2,645
300,888
26,725
68,441
--
152,990
122,926
(9,004)
662,966
(145,003)
--
(22,585)
(1,474)
2,033
3,276
(115,932)
20,105
(95,827)
561
$ (96,388)
(163,753)
33,089
(130,664)
1,095
$ (131,759)
513,087
31,834
70,345
4,350
174,970
290,508
688
1,085,782
(142,891)
(6,980)
(14,396)
(3,455)
3,915
7,524
(156,283)
(31,379)
(187,662)
1,381
$ (189,043)
Per Share Data (see Note 6)
Basic net loss per share attributable to Civeo Corporation common
shareholders ....................................................................................
$
(0.90)
$
(1.24)
$
(1.77)
Diluted net loss per share attributable to Civeo Corporation
common shareholders. .....................................................................
$
(0.90)
$
(1.24)
$
(1.77)
Weighted average number of common shares outstanding:
Basic ..........................................................................................
Diluted. ......................................................................................
107,024
107,024
106,604
106,604
106,306
106,306
Dividends per common share ..........................................................
$
--
$
--
$
0.26
The accompanying notes are an integral part of these financial statements.
90
CIVEO CORPORATION
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(In Thousands)
YEAR ENDED DECEMBER 31,
2015
2014
2016
Net loss...........................................................................................................
$ (95,827)
$ (130,664)
$ (187,662)
Other comprehensive income (loss), net of tax:
Foreign currency translation adjustment, net of tax of zero, $1.9
million and $771, respectively .................................................................
Total other comprehensive income (loss), net of tax ......................................
3,389
(168,363)
3,389
(168,363)
(138,692)
(138,692)
Comprehensive loss .......................................................................................
Comprehensive income attributable to noncontrolling interest ................
Comprehensive loss attributable to Civeo Corporation. .................................
(92,438)
(571)
$ (93,009)
(299,027)
(550)
$ (299,577)
(326,354)
(1,201)
$ (327,555)
The accompanying notes are an integral part of these financial statements.
91
CIVEO CORPORATION
CONSOLIDATED BALANCE SHEETS
(In Thousands)
ASSETS
2016
2015
DECEMBER 31,
Current assets:
Cash and cash equivalents ....................................................................................
Accounts receivable, net .......................................................................................
Inventories .............................................................................................................
Prepaid expenses ...................................................................................................
Other current assets ..............................................................................................
Total current assets ...........................................................................................
Property, plant and equipment, net ............................................................................
Other intangible assets, net ........................................................................................
Other noncurrent assets .............................................................................................
Total assets ...........................................................................................................
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Accounts payable ..................................................................................................
Accrued liabilities .................................................................................................
Income taxes .........................................................................................................
Current portion of long-term debt .........................................................................
Deferred revenue ..................................................................................................
Other current liabilities .........................................................................................
Total current liabilities ......................................................................................
Long-term debt, less current maturities ......................................................................
Deferred income taxes ...............................................................................................
Other noncurrent liabilities ........................................................................................
Total liabilities ......................................................................................................
Commitments and contingencies (Note 13)
Shareholders’ Equity:
Common shares (no par value; 550,000,000 shares authorized, 108,171,329
shares and 107,470,861 shares issued, respectively, and 108,103,048 shares and
107,470,861 shares outstanding, respectively) ......................................................
Additional paid-in capital ......................................................................................
Accumulated deficit ...............................................................................................
Common shares held in treasury at cost, 68,281 and zero shares, respectively .....
Accumulated other comprehensive loss ................................................................
Total Civeo Corporation shareholders’ equity ..................................................
Noncontrolling interest ..............................................................................................
Total shareholders’ equity ....................................................................................
Total liabilities and shareholders’ equity ..........................................................
$
$
$
1,785
56,302
3,112
15,431
5,938
82,568
789,710
28,039
10,129
910,446
21,119
14,378
111
15,471
6,792
2,572
60,443
337,800
9,194
27,019
434,456
$
7,837
61,467
5,631
11,712
3,312
89,959
931,914
35,309
9,347
$ 1,066,529
$
24,609
14,834
1,104
17,461
7,747
493
66,248
379,416
25,391
31,704
502,759
--
1,311,226
(472,764)
(65)
(362,930)
475,467
523
475,990
910,446
$
--
1,305,930
(376,376)
--
(366,309)
563,245
525
563,770
$ 1,066,529
The accompanying notes are an integral part of these financial statements.
92
CIVEO CORPORATION
CONSOLIDATED STATEMENTS OF CHANGES IN
SHAREHOLDERS’ EQUITY / NET INVESTMENT
(In Thousands)
Common Shares
Par Value
Additional
Paid-in
Capital
Accumulated
Deficit
Treasury
Stock
Oil States Net
Investment
Accumulated
Other
Comprehensive
Income (Loss)
Noncontrolling
Interest
Attributable to Civeo
$
--
--
$
--
(230,724)
$
--
(13,897)
--
(13,893)
--
--
1,311,913
(1,066)
3,220
(128)
$ 1,300,042
--
--
--
929
5,102
(143)
$ 1,305,930
--
--
--
5,296
--
$ 1,311,226
--
--
--
--
--
--
(244,617)
(131,759)
--
--
--
--
--
(376,376)
(96,388)
--
--
--
--
(472,764)
$
$
$
$
$
$
--
--
--
--
--
--
--
--
--
--
--
--
--
--
146
(146)
--
--
--
--
--
(65)
--
(65)
$ 1,651,013
41,681
$
(59,979)
--
$
--
--
(138,512)
--
369,219
(750,000)
(1,311,913)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
$
$
$
--
--
--
--
--
--
$ (198,491)
--
(167,818)
--
--
--
--
$ (366,309)
--
3,379
--
--
--
$ (362,930)
$
$
$
1,711
1,381
(180)
(804)
--
--
--
--
--
--
2,108
1,095
(545)
(2,133)
--
--
--
525
561
10
(573)
--
--
523
Balance, December 31, 2013 ...... $
Net income (loss) .........................
Currency translation
adjustment. ...............................
Dividends paid .............................
Net transfers from Oil States
International, Inc ......................
Distribution to Oil States
International, Inc. .....................
Reclassification of Oil States
International, Inc. Net
Investment to Additional
Paid-in Capital .........................
Issuance of common stock at
the Spin-Off ...........................
Stock-based compensation ...........
Other. ...........................................
Balance, December 31, 2014 ...... $
Net income (loss) ........................
Currency translation
adjustment. ...................................
Dividends paid .............................
Redomicile Transaction ................
Share-based compensation. ..........
Other. ...........................................
Balance, December 31, 2015 ...... $
Net income (loss) ........................
Currency translation
adjustment. ...................................
Dividends paid .............................
Share-based compensation. ..........
Other. ...........................................
Balance, December 31, 2016 ...... $
--
--
--
--
--
--
--
1,066
1
--
1,067
--
--
--
(1,075)
8
--
--
--
--
--
--
--
--
Balance, December 31, 2013 ......
Issuance of common stock at
the Spin-Off .............................
Stock-based compensation. ..........
Balance, December 31, 2014 ......
Share-based compensation. ..........
Balance, December 31, 2015 ......
Share-based compensation. ..........
Balance, December 31, 2016 ......
Common
Stock (in
thousands)
--
106,538
183
106,721
750
107,471
632
108,103
Total
Shareholders’
Equity / Net
Investment
$
1,592,745
(187,662)
(138,692)
(28,594)
369,219
(750,000)
--
--
3,221
(128)
860,109
(130,664)
(168,363)
(2,133)
--
4,964
(143)
563,770
(95,827)
3,389
(573)
5,231
--
475,990
$
$
$
The accompanying notes are an integral part of these financial statements.
93
CIVEO CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In Thousands)
Cash flows from operating activities:
Net loss ............................................................................................................................
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization .....................................................................................
Impairment charges .....................................................................................................
Inventory write-down ..................................................................................................
Loss on extinguishment of debt ...................................................................................
Deferred income tax provision (benefit) ......................................................................
Non-cash compensation charge ...................................................................................
Gains on disposals of assets .........................................................................................
Provision (benefit) for loss on receivables, net of recoveries .......................................
Other, net .....................................................................................................................
Changes in operating assets and liabilities:
Accounts receivable .................................................................................................
Inventories ...............................................................................................................
Accounts payable and accrued liabilities ..................................................................
Taxes payable...........................................................................................................
Other current assets and liabilities, net .....................................................................
Net cash flows provided by operating activities ...............................................................
Cash flows from investing activities:
Capital expenditures, including capitalized interest .....................................................
Proceeds from disposition of property, plant and equipment .......................................
Other, net .....................................................................................................................
Net cash flows used in investing activities ...............................................................
Cash flows from financing activities:
Proceeds from issuance of common shares ..................................................................
Revolving credit borrowings .......................................................................................
Revolving credit repayments .......................................................................................
Term loan borrowings ..................................................................................................
Term loan repayments ..................................................................................................
Debt issuance costs ......................................................................................................
Dividends paid .............................................................................................................
Distributions to Oil States ............................................................................................
Contributions from Oil States ......................................................................................
Net cash flows provided by (used in) financing activities ........................................
Effect of exchange rate changes on cash ..........................................................................
Net change in cash and cash equivalents ..........................................................................
Cash and cash equivalents, beginning of period ...............................................................
Cash and cash equivalents, end of period .........................................................................
$
YEAR ENDED DECEMBER 31,
2015
2016
2014
$
(95,827)
$
(130,664)
$
(187,662)
131,302
46,129
850
302
(13,208)
5,296
29
(54)
868
6,680
1,773
(4,463)
(10,239)
(7,334)
62,104
(19,779)
5,775
1,315
(12,689)
--
310,539
(325,738)
--
(41,023)
(2,062)
--
--
--
(58,284)
2,817
(6,052)
7,837
1,785
152,990
122,926
1,015
1,474
(34,175)
4,614
(1,826)
1,205
1,424
80,347
5,406
(12,885)
6,204
(11,924)
186,131
(62,451)
12,683
--
(49,768)
500
299,427
(240,284)
325,000
(729,425)
(4,833)
--
--
--
(349,615)
(42,225)
(255,477)
263,314
174,970
290,508
--
3,455
4,333
6,283
(5,877)
(1,276)
1,096
4,840
15,174
(167)
(16,738)
2,114
291,053
(251,158)
12,086
--
(239,072)
--
--
--
775,000
--
(9,235)
(27,790)
(750,000)
28,257
16,232
(29,027)
39,186
224,128
$
7,837
$
263,314
The accompanying notes are an integral part of these financial statements.
94
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION
Description of the Business
We are one of the largest integrated providers of workforce accommodations, logistics and facility management
services to the natural resource industry. Our scalable modular facilities provide long-term and temporary
accommodations where traditional accommodations and related infrastructure is insufficient, inaccessible or not cost
effective. Once facilities are deployed in the field, we also provide catering and food services, housekeeping,
laundry, facility management, water and wastewater treatment, power generation, communications and
redeployment logistics. Our accommodations support our customers’ employees and contractors in the Canadian oil
sands and in a variety of oil and natural gas drilling, mining and related natural resource applications as well as
disaster relief efforts, primarily in Canada, Australia and the United States. We operate in three principal reportable
business segments – Canada, Australia and U.S.
On May 30, 2014, Oil States International, Inc. (Oil States) spun-off its Accommodations Segment
(Accommodations) into a standalone, publicly traded Delaware corporation (Civeo US). In accordance with the
Separation and Distribution Agreement, the two companies were separated by Oil States distributing to its
stockholders all 106,538,044 shares of common stock of Civeo US it held after the market closed on May 30, 2014
(the Spin-Off). In connection with the Spin-Off, on May 28, 2014, we made a special cash distribution to Oil States
of $750 million. Following the Spin-Off, Oil States retained no ownership interest in Civeo US, and each company
now has separate public ownership, boards of directors and management.
On July 17, 2015, we changed our place of incorporation from Delaware to British Columbia, Canada, and
Civeo Corporation, a British Columbia, Canada limited company formerly named Civeo Canadian Holdings ULC
(Civeo Canada), became the publicly traded parent company of the Civeo group of companies (the Redomicile
Transaction). The Civeo Canada common shares are listed on the NYSE under the symbol “CVEO,” the same
symbol under which the Civeo US common stock traded prior to the effective time of the Redomicile Transaction.
The Redomicile Transaction qualified as a “self-directed redomiciling” of the Company as permitted under the
U.S. Internal Revenue Code. U.S. federal income tax laws permit a company to change its domicile to a foreign
jurisdiction without corporate-level U.S. federal income taxes provided that such company has “substantial business
activity” in the relevant jurisdiction. “Substantial business activity” is defined as foreign operations consisting of
over 25% of the company’s total (i) revenues, (ii) assets, (iii) employees and (iv) employee compensation. With
approximately 50% or more of our operations in Canada based on these metrics, we qualified for a self-directed
redomiciling.
In connection with the Spin-Off, on May 28, 2014, we entered into a $650.0 million, 5-year revolving credit
facility and a 5-year U.S. term loan facility totaling $775.0 million (collectively, the Credit Facility) for an aggregate
borrowing capacity of $1.4 billion. On July 17, 2015, the First Amendment to the Credit Facility became effective.
On February 18, 2016, the Second Amendment to the Credit Facility became effective. On February 17, 2017, the
Third Amendment to the Credit Facility (together with all amendments, the Amended Credit Facility) became
effective. For further information, please see Note 9 – Debt for further discussion.
We incurred costs related to the Redomicile Transaction totaling $1.3 million, $7.0 million and $2.6 million for
the years ended December 31, 2016, 2015 and 2014, respectively. During the year ended December 31, 2016, we
incurred costs related to the Amended Credit Facility totaling $2.1 million. $2.0 million has been capitalized as debt
issuance costs, and the remaining $0.1 million is included in interest expense. As a result of the Second Amendment
to the Credit Facility, we recognized a loss during the first quarter of 2016 of approximately $0.3 million related to
unamortized debt issuance costs, which is included in “Loss on extinguishment of debt” on the accompanying
consolidated statements of operations. During the year ended December 31, 2015, we incurred costs related to the
Amended Credit Facility totaling $5.5 million. $4.8 million has been capitalized as debt issuance costs and the
remaining $0.7 million is included in interest expense. As a result of the First Amendment to the Credit Facility, we
also recognized a loss during the third quarter 2015 of approximately $1.5 million related to unamortized debt
issuance costs, which is included in “Loss on extinguishment of debt” on the accompanying consolidated statements
of operations.
95
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
As a result of the Spin-Off, we incurred certain costs during the year ended December 31, 2014. We recognized
a loss on the termination of debt of approximately $3.5 million in the second quarter 2014, related to unamortized
debt issuance costs, which is included in Loss on extinguishment of debt on the accompanying consolidated
statements of operations. We recorded transition and formation costs associated with the Spin-Off of approximately
$4.3 million for the year ended December 31, 2014, which are included in Spin-off and formation costs on the
accompanying consolidated statements of operations. In the second quarter 2014, we recognized a $9.0 million
impairment of an intangible asset in Australia, which is included in Impairment expense on the accompanying
consolidated statements of operations. Due to the Spin-Off, and the resulting rebranding of our Australian
operations from The MAC to Civeo, it was determined that the fair value of an intangible asset associated with The
MAC brand had been reduced to nil.
Basis of Presentation
Unless otherwise stated or the context otherwise indicates, all references in these consolidated financial
statements to “Civeo,” “the Company,” “us,” “our” or “we” for the time period prior to the Spin-Off mean the
Accommodations business of Oil States. For time periods after the Spin-Off, but prior to July 17, 2015, these terms
refer to Civeo US and its consolidated subsidiaries. For time periods after July 17, 2015, these terms refer to Civeo
Canada and its consolidated subsidiaries.
Prior to the Spin-Off, our financial position, results of operations and cash flows consisted of the Oil States’
Accommodations business and an allocable portion of its corporate costs, which represented a combined reporting
entity. The combined financial statements for periods prior to the Spin-Off have been prepared on a stand-alone
basis and are derived from the consolidated financial statements and accounting records of Oil States. The combined
financial statements reflect our historical financial position, results of operations and cash flows as we were
historically managed, in conformity with accounting principles generally accepted in the United States of America
(U.S. GAAP). The combined financial statements include certain assets and liabilities that have historically been
held at the Oil States corporate level, but are specifically identifiable or otherwise attributable to us.
All financial information presented after the Spin-Off represents the consolidated results of operations, financial
position and cash flows of Civeo. Accordingly:
(cid:2) Our consolidated statements of operations, comprehensive income (loss), cash flows and changes in
shareholders’ equity / net investment for the years ended December 31, 2016 and 2015 consist entirely
of the consolidated results of Civeo.
(cid:2) Our consolidated statements of operations, comprehensive income (loss), cash flows and changes in
shareholders’ equity / net investment for the year ended December 31, 2014 consist of (i) the combined
results of the Oil States’ Accommodations business for the five months ended May 30, 2014 and (ii)
the consolidated results of Civeo for the seven months ended December 31, 2014.
(cid:2) Our consolidated balance sheets at December 31, 2016 and December 31, 2015 consist entirely of the
consolidated balances of Civeo.
The assets and liabilities in our consolidated financial statements have been reflected on a historical basis, as
immediately prior to the Spin-Off all of the assets and liabilities presented were wholly owned by Oil States and
were transferred within the Oil States consolidated group. All intercompany transactions and accounts have been
eliminated. All affiliate transactions between Civeo and Oil States have been included in these consolidated
financial statements.
The consolidated financial statements for periods prior to the Spin-Off included expense allocations for: (1)
certain corporate functions historically provided by Oil States, including, but not limited to finance, legal, risk
management, tax, treasury, information technology, human resources, and certain other shared services; (2) certain
employee benefits and incentives; and (3) equity-based compensation. These expenses were allocated to us on the
basis of direct usage when identifiable, with the remainder allocated based on estimated time spent by Oil States
personnel, a pro-rata basis of headcount or other relevant measures of Oil States and its subsidiaries. We consider
96
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
the basis on which the expenses were allocated to be a reasonable reflection of the utilization of services provided to
or the benefit received by us during the periods presented. The allocations may not, however, reflect the expense we
would have incurred as an independent, publicly traded company for the periods presented. Actual costs that may
have been incurred if we had been a stand-alone company would depend on a number of factors, including the
chosen organizational structure, which functions were outsourced or performed by employees and strategic
decisions made in areas such as information technology and infrastructure. Following the Spin-Off, we perform
these functions using our own resources or purchase services. Until February 28, 2015, however, some of these
functions were provided by Oil States under a transition services agreement. See Note 17 – Related Party
Transactions.
Oil States used a centralized approach to the cash management and financing of its U.S. operations. Prior to
February 2014, cash from our U.S. operations was transferred to Oil States daily and Oil States funded our U.S.
operating and investing activities as needed. Accordingly, the cash and cash equivalents held by Oil States at the
corporate level were not allocated to us for any of the periods presented prior to February 2014. We reflected the
transfer of cash to and from Oil States as a component of “Net Investment of Oil States International, Inc.” on our
consolidated balance sheet. We have not included interest expense for intercompany cash advances from Oil States,
since historically Oil States has not allocated interest expense related to intercompany advances to any of its
businesses. Beginning in February 2014, we established Civeo cash accounts and funded a portion of our U.S.
operating and investing activities.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Cash
We consider all highly liquid investments purchased with an original maturity of three months or less to be cash
equivalents.
Allowances for Doubtful Accounts
We maintain allowances for doubtful accounts for estimated losses resulting from the inability of our customers
to make required payments. If a trade receivable is deemed to be uncollectible, such receivable is charged-off
against the allowance for doubtful accounts. We consider the following factors when determining if collection of
revenue is reasonably assured: customer credit-worthiness, past transaction history with the customer, current
economic industry trends, customer solvency and changes in customer payment terms. If we have no previous
experience with the customer, we typically obtain reports from various credit organizations to ensure that the
customer has a history of paying its creditors. We may also request financial information, including combined
financial statements or other documents, to ensure that the customer has the means of making payment. If these
factors do not indicate collection is reasonably assured, we generally would require a prepayment or other
arrangement to support revenue recognition and recording of a trade receivable. If the financial condition of our
customers were to deteriorate, adversely affecting their ability to make payments, additional allowances would be
required.
Inventories
Inventories consist of work in process, raw materials and supplies and materials for the construction and
operation of remote accommodation facilities. Inventories also include food, raw materials, labor, subcontractor
charges, manufacturing overhead and catering and other supplies needed for operation of our facilities. Inventories
are carried at the lower of cost or market. The cost of inventories is determined on an average cost or specific-
identification method.
Property, Plant, and Equipment
Property, plant, and equipment are stated at cost or at estimated fair market value at acquisition date if acquired
in a business combination, and depreciation is computed, for assets owned or recorded under capital lease, using the
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(Continued)
straight-line method, after allowing for salvage value where applicable, over the estimated useful lives of the assets.
Leasehold improvements are capitalized and amortized over the lesser of the life of the lease or the estimated useful
life of the asset.
We record the fair value of a liability, which reflects the estimated present value of the amount of asset removal
and site reclamation costs related to the retirement of our assets, for an asset retirement obligation (ARO) when it is
incurred (typically when the asset is installed). When the liability is initially recorded, we capitalize the associated
asset retirement cost by increasing the carrying amount of the related property, plant and equipment. Please see
Asset Retirement Obligations, below, for further discussion.
Expenditures for repairs and maintenance are charged to expense when incurred. Expenditures for major
renewals and betterments, which extend the useful lives of existing equipment, are capitalized and depreciated.
Upon retirement or disposition of property and equipment, the cost and related accumulated depreciation are
removed from the accounts and any resulting gain or loss is recognized in the consolidated statements of operations.
Interest Capitalization
Interest costs for the construction of certain long-term assets are capitalized and amortized over the related
assets’ estimated useful lives. For the years ended December 31, 2016, 2015 and 2014, zero, $1.6 million and $2.3
million were capitalized, respectively.
Impairment of Long-Lived Assets
The recoverability of the carrying values of long-lived assets, including amortizable intangible assets, is
assessed whenever, in management’s judgment, events or changes in circumstances indicate that the carrying value
of such asset groups may not be recoverable based on estimated future cash flows. If this assessment indicates that
the carrying values will not be recoverable, as determined based on undiscounted cash flows over the remaining
useful lives, an impairment loss is recognized. The impairment loss equals the excess of the carrying value over the
fair value of the asset group. The fair value of the asset group is based on prices of similar assets, if available, or
discounted cash flows.
In performing this analysis, the first step is to review asset groups at the lowest level for which identifiable cash
flows are largely independent of the cash flows of other assets and liabilities. For each asset group, we compare its
carrying value to estimates of undiscounted future cash flows. We use a variety of underlying assumptions to
estimate these future cash flows, including assumptions relating to future economic market conditions, rates,
occupancy levels, costs and expenses and capital expenditures. The estimates are consistent with those used for
purposes of our goodwill impairment test, as further discussed in Goodwill and Other Intangible Assets, below.
Based on the assessment, if the carrying values of certain of our asset groups are determined to not be recoverable,
we proceed to the second step. In this step, we compare the fair value of the respective asset group to its carrying
value. The fair value of the asset groups are based on prices of similar assets, as applicable, or discounted cash
flows. Our estimate of the fair value requires us to use significant unobservable inputs, representative of Level 3 fair
value measurements, including numerous assumptions with respect to future circumstances, such as industry and/or
local market conditions that might directly impact each of the asset groups’ operations in the future, and are
therefore uncertain.
Please see Note 3 – Impairment Charges for a discussion of impairment charges we recognized in 2016, 2015
and 2014 related to our long-lived assets.
Goodwill and Other Intangible Assets
Goodwill. Goodwill represents the excess of the purchase price paid for acquired businesses over the allocated
fair value of the related net assets after impairments, if applicable.
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(Continued)
We do not amortize goodwill. We evaluate goodwill for impairment, at the reporting unit level, annually and
when an event occurs or circumstances change to suggest that the carrying amount may not be recoverable. We
conduct our annual impairment test as of November 30 of each year. Our goodwill balance was fully impaired at
September 30, 2015.
A reporting unit is the operating segment, or a business one level below that operating segment (the
“component” level) if discrete financial information is prepared and regularly reviewed by management at the
component level. Each segment of our business represents a separate reporting unit, and all three of our reporting
units previously had goodwill. We recognize an impairment loss for any amount by which the carrying amount of a
reporting unit’s goodwill exceeds the reporting unit’s implied fair value (IFV) of goodwill.
Our assessment consisted of a two-step impairment test. In the first step, we compare each reporting unit’s
carrying amount, including goodwill, to the IFV of the reporting unit. If the carrying amount of the reporting unit
exceeds its fair value, goodwill is potentially impaired, and a second step is performed to determine the amount of
impairment, if any. Future impairment tests will be impacted by new accounting guidance which eliminates the
second step of the goodwill impairment test.
We are given the option to test for impairment of our goodwill by first performing a qualitative assessment to
determine whether it is more likely than not (that is, likelihood of more than 50 percent) that the fair value of a
reporting unit is less than its carrying amount, including goodwill. If it is determined that it is more likely than not
that the fair value of a reporting unit is greater than its carrying amount, then performing the currently prescribed
two-step impairment test is unnecessary. In developing a qualitative assessment to meet the “more-likely-than-not”
threshold, each reporting unit with goodwill is assessed separately and different relevant events and circumstances
are evaluated for each unit. We have the option to bypass the qualitative assessment for any reporting unit in any
period and proceed directly to performing the first step of the two-step goodwill impairment test.
In performing the two-step impairment test, we compare each reporting unit’s carrying amount, including
goodwill, to the IFV of the reporting unit. Because none of our reporting units has a publically quoted market price,
we must determine the value that willing buyers and sellers would place on the reporting unit through a routine sale
process (a Level 3 fair value measurement). In our analysis, we target an IFV that represents the value that would be
placed on the reporting unit by market participants, and value the reporting unit based on historical and projected
results throughout a cycle, not the value of the reporting unit based on trough or peak earnings. The IFV of the
reporting unit is estimated using a combination of (i) an analysis of trading multiples of comparable companies
(Market Approach) and (ii) discounted projected cash flows (Income Approach). We also use acquisition multiples
analyses in certain circumstances. The relative weighting of each approach varies by reporting unit, based on
management’s judgment.
Market Approach - This valuation approach utilizes publicly traded comparable companies’ enterprise values,
as compared to their recent and forecasted earnings before interest, taxes and depreciation (EBITDA) information.
We have historically used an average EBITDA multiple ranging from approximately 6.5x to approximately 9.5x
depending on the reporting unit. We use EBITDA because it is a widely used key indicator of the cash generating
capacity of companies in our industry.
Income Approach - This valuation approach derives a present value of the reporting unit’s projected future
annual cash flows over the next five years. We use a variety of underlying assumptions to estimate these future cash
flows, including assumptions relating to future economic market conditions, rates, occupancy levels, costs and
expenses and capital expenditures. These assumptions vary by each reporting unit depending on market conditions.
In addition, a terminal value is estimated, using a Gordon Growth methodology with a long-term growth rate of 3%.
We discount our projected cash flows using a long-term weighted average cost of capital based on our estimate of
investment returns that would be required by a market participant.
The IFV of our reporting units is affected by future oil, coal and natural gas prices, anticipated spending by our
customers, and the cost of capital. Our estimate of IFV requires us to use significant unobservable inputs,
representative of Level 3 fair value measurements, including numerous assumptions with respect to future
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(Continued)
circumstances, such as industry and/or local market conditions that might directly impact each of the reporting units’
operations in the future, and are therefore uncertain. We selected these valuation approaches because we believe the
combination of these approaches and our best judgment regarding underlying assumptions and estimates provides us
with the best estimate of fair value for each of our reporting units. We believe these valuation approaches are proven
valuation techniques and methodologies for our industry and widely accepted by investors. The IFV of each
reporting unit would change if our assumptions under these valuation approaches, or relative weighting of the
valuation approaches, were materially modified.
Please see Note 3 – Impairment Charges for a discussion of impairment charges we recognized in 2015 and
2014 related to our goodwill.
Other Intangible Assets. We amortize the cost of other intangible assets using the straight-line method over
their estimated useful lives unless such lives are deemed indefinite. For intangible assets that we amortize, we
review the useful life of the intangible asset and evaluate each reporting period whether events and circumstances
warrant a revision to the remaining useful life. We evaluate the remaining useful life of an intangible asset that is not
being amortized each reporting period to determine whether events and circumstances continue to support an
indefinite useful life.
We are required to evaluate our indefinite-lived intangible assets for impairment annually and when an event
occurs or circumstances change to suggest the carrying amount may not be recoverable. In performing the
impairment test, we compare the fair value of the indefinite-lived intangible asset with its carrying amount. The
measurement of the impairment is calculated based on the excess of the carrying value over its fair value.
Please see Note 3 – Impairment Charges for a discussion of impairment charges we recognized in 2015 and
2014 related to our intangible assets.
Foreign Currency and Other Comprehensive Income
Gains and losses resulting from consolidated balance sheet translation of foreign operations where a foreign
currency is the functional currency are included as a separate component of accumulated other comprehensive
income within shareholders’ equity representing substantially all of the balances within accumulated other
comprehensive income. Remeasurements of intercompany loans denominated in a different currency than the
functional currency of the entity that are of a long-term investment nature are recognized as other comprehensive
income within shareholders’ equity. Gains and losses resulting from consolidated balance sheet remeasurements of
assets and liabilities denominated in a different currency than the functional currency, other than intercompany loans
that are of a long-term investment nature, are included in the consolidated statements of operations as incurred. For
the years ended December 31, 2016, 2015, and 2014, we recognized approximately $(0.6) million, $9.0 million and
$0.2 million in foreign currency gains (losses), respectively.
Foreign Exchange Risk
A significant portion of revenues, earnings and net investments in foreign affiliates are exposed to changes in
foreign currency exchange rates. We seek to manage our foreign exchange risk in part through operational means,
including managing expected local currency revenues in relation to local currency costs and local currency assets in
relation to local currency liabilities. We have not entered into any foreign currency forward contracts.
Revenue and Cost Recognition
We derive the majority of our revenue from lodging and related ancillary services. In each of our operating
segments, revenue is recognized in the period in which services are provided pursuant to the terms of contractual
relationships with our customers. In some contracts, rates may vary over the contract term. In these cases, revenue
may be deferred and recognized on a straight-line basis over the contract term. Revenue from the sale of products,
not accounted for utilizing the percentage-of-completion method, is recognized when delivery to and acceptance by
the customer has occurred, when title and all significant risks of ownership have passed to the customer,
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(Continued)
collectability is reasonably assured and pricing is fixed and determinable. Our product sales terms do not include
significant post-delivery obligations.
For significant projects, revenues are recognized under the percentage-of-completion method, measured by the
percentage of costs incurred to date compared to estimated total costs for each contract (cost-to-cost method).
Billings on such contracts in excess of costs incurred and estimated profits are classified as deferred revenue. Costs
incurred and estimated profits in excess of billings on percentage-of-completion contracts are recognized as unbilled
receivables. Management believes this method is the most appropriate measure of progress on large contracts.
Provisions for estimated losses on uncompleted contracts are made in the period in which such losses are
determined. Changes in job performance, job conditions, estimated profitability, and final contract
settlements may result in revisions to projected costs and revenue and are recognized in the period in which the
revisions are determined. Factors that may affect future project costs and margins include weather, production
efficiencies, availability and costs of labor, materials and subcomponents. These factors can significantly impact the
accuracy of our estimates and materially impact our future reported earnings.
Revenues exclude taxes assessed based on revenues such as sales or value added taxes.
Cost of services includes labor, food, utility costs, cleaning supplies, and other costs of operating our
accommodations facilities. Cost of goods sold includes all direct material and labor costs and those costs related to
contract performance, such as indirect labor, supplies, tools and repairs. Selling, general and administrative costs are
charged to expense as incurred.
Income Taxes
Our operations are subject to Canadian federal and provincial income taxes, as well as foreign income taxes.
We determine the provision for income taxes using the asset and liability approach. Under this approach, deferred
income taxes represent the expected future tax consequences of temporary differences between the carrying amounts
and tax bases of assets and liabilities.
Valuation allowances are established when necessary to reduce deferred tax assets to the amounts expected to
be realized. In assessing the need for a valuation allowance, we look to the future reversal of existing taxable
temporary differences, taxable income in carryback years, the feasibility of tax planning strategies and estimated
future taxable income. The valuation allowance can be affected by changes to tax laws, changes to statutory tax rates
and changes to future taxable income estimates.
We recognize tax benefits from uncertain tax positions only if it is more likely than not that the tax position will
be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits
recognized in the consolidated financial statements from such positions are measured based on the largest benefit
that has a greater than 50% likelihood of being realized upon ultimate settlement.
In the U.S., prior to the Spin-Off, our operations were included in Oil States’ income tax returns. In preparing
our consolidated financial statements, we determined our tax provision on a separate return, stand-alone basis.
Pursuant to the Tax Sharing Agreement with Oil States, with respect to any periods (or portions thereof) ending
prior to the Spin-Off, we are obligated to reimburse Oil States an amount equal to the amount of U.S. federal, state
or local income tax we would have paid had we had filed a separate consolidated U.S. federal, state or local income
tax return, subject to certain adjustments. We do not consider these amounts to be material.
Prior to the Spin-Off, because portions of our operations were included in Oil States’ tax returns, payments to
certain tax authorities were historically made by Oil States, and not by us. With the exception of certain dedicated
foreign entities, we did not maintain taxes payable to/from Oil States and we were deemed to settle the annual
current tax balances immediately with the legal tax-paying entities in the respective jurisdictions. These settlements
are reflected as changes in the Oil States International, Inc. net investment account.
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(Continued)
Receivables and Concentration of Credit Risk
Based on the nature of our customer base, we do not believe that we have any significant concentrations of
credit risk other than our concentration in the Canadian oil sands and Australian mining industries. We evaluate the
credit-worthiness of our significant, new and existing customers’ financial condition and, generally, we do not
require collateral from our customers. For the year ended December 31, 2016, each of Imperial Oil and Fort Hills
Energy LP accounted for more than 10% of our revenues. For the year ended December 31, 2015, each of Imperial
Oil, Fort Hills Energy LP and BM Alliance Coal Operations Pty Ltd accounted for more than 10% of our revenues.
For the year ended December 31, 2014, Imperial Oil accounted for more than 10% of our revenues.
Asset Retirement Obligations
We record the fair value of a liability, which reflects the estimated present value of the amount of asset removal
and site reclamation costs related to the retirement of our assets, for an ARO when it is incurred (typically when the
asset is installed). When the liability is initially recorded, we capitalize the associated asset retirement cost by
increasing the carrying amount of the related property, plant and equipment. Over time, the liability increases for
the change in its present value, while the capitalized cost depreciates over the useful life of the related asset.
Accretion expense is recognized over the estimated productive life of the related assets. If the fair value of the
estimated ARO changes, an adjustment is recorded to both the ARO and the capitalized asset retirement cost.
Revisions in estimated liabilities can result from changes in estimated inflation rates, changes in service and
equipment costs and changes in the estimated timing of settling the ARO. We utilize current retirement costs to
estimate the expected cash outflows for retirement obligations. We estimate the ultimate productive life of the
properties and a risk-adjusted discount rate in order to determine the current present value of the obligation.
We relieve ARO liabilities when the related obligations are settled. We have AROs that we are required to
perform under law or contract once an asset is permanently taken out of service. Most of these obligations are not
expected to be paid until several years in the future and will be funded from general company resources at the time
of removal. Please see Note 11 – Asset Retirement Obligations for further discussion.
Share-Based Compensation
We, and, prior to the Spin-Off, Oil States, sponsor an equity participation plan in which certain of our
employees participate. We measure the cost of employee services received in exchange for an award of equity
instruments (typically option awards) based on the grant-date fair value of the award. The fair value is estimated
using option-pricing models. The resulting cost is recognized over the period during which an employee is required
to provide service in exchange for the awards, usually the vesting period.
We, and, prior to the Spin-Off, Oil States, also grant phantom shares under the Canadian Long-Term Incentive
Plan, which provides for the granting of units of phantom shares to key Canadian employees. We also grant
phantom shares under the 2014 Equity Participation Plan, which provides for the granting of units of phantom shares
to key U.S. employees. All of the awards vest in equal annual installments and are accounted for as a liability based
on the fair value of our share price. Participants granted units of phantom shares are entitled to a lump sum cash
payment equal to the fair market value of a common share on the vesting date.
We also grant performance awards under the Civeo Plan. These awards will be earned in amounts between 0%
and 200% of the participant’s target performance share award, based on the payout percentage associated with
Civeo’s relative total shareholder return rank among a peer group of 12 other companies. The fair value is estimated
using option-pricing models. The resulting cost is recognized over the period during which an employee is required
to provide service in exchange for the awards, usually the vesting period.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Guarantees
Substantially all of our Canadian and U.S. subsidiaries are guarantors under our Credit Facility. See Note 9 -
Debt.
During the ordinary course of business, we also provide standby letters of credit or other guarantee instruments
to certain parties as required for certain transactions initiated by us or our subsidiaries. As of December 31, 2016,
the maximum potential amount of future payments that we could be required to make under these guarantee
agreements (letters of credit) was approximately $2.1 million. We have not recorded any liability in connection with
these guarantee arrangements. We do not believe, based on historical experience and information currently
available, that it is likely that any amounts will be required to be paid under these guarantee arrangements.
Use of Estimates
The preparation of consolidated financial statements in conformity with U.S. GAAP requires the use of
estimates and assumptions by management in determining the reported amounts of assets and liabilities and
disclosures of contingent assets and liabilities at the date of the consolidated financial statements and the reported
amounts of revenues and expenses during the reporting period. Examples of a few such estimates include revenue
and income recognized on the percentage-of-completion method, estimates of the amount and timing of costs to be
incurred for asset retirement obligations, any valuation allowance recorded on net deferred tax assets, warranty,
long-lived asset impairments and allowance for doubtful accounts. Actual results could materially differ from those
estimates.
Accounting for Contingencies
We have contingent liabilities and future claims for which we have made estimates of the amount of the
eventual cost to liquidate these liabilities or claims. These liabilities and claims sometimes involve threatened or
actual litigation where damages have been quantified and we have made an assessment of our exposure and recorded
a provision in our accounts to cover an expected loss. Other claims or liabilities have been estimated based on their
fair value or our experience in these matters and, when appropriate, the advice of outside counsel or other outside
experts. Upon the ultimate resolution of these uncertainties, our future reported financial results will be impacted by
the difference between our estimates and the actual amounts paid to settle a liability. Examples of areas where we
have made important estimates of future liabilities include litigation, taxes, interest, insurance claims, warranty
claims and contract claims and obligations.
Recent Accounting Pronouncements
From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board
(the FASB), which are adopted by us as of the specified effective date. Unless otherwise discussed, management
believes that the impact of recently issued standards, which are not yet effective, will not have a material impact on
our consolidated financial statements upon adoption.
In June 2016, the FASB issued Accounting Standards Update (ASU) 2016-13, “Financial Instruments – Credit
Losses” (ASU 2016-13). This new standard changes how companies will measure credit losses for most financial
assets and certain other instruments that are not measured at fair value through net income. ASU 2016-13 is
effective for financial statements issued for reporting periods beginning after December 15, 2019 and interim
periods within the reporting periods. We are currently evaluating the impact of this new standard on our
consolidated financial statements.
In March 2016, the FASB issued ASU 2016-09, “Improvements to Employee Share-Based Payment
Accounting” (ASU 2016-09). This new standard requires companies to recognize the income tax effects of awards
in the income statement when the awards vest or are settled. ASU 2016-09 is effective for financial statements
issued for reporting periods beginning after December 15, 2016 and interim periods within the reporting periods. We
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(Continued)
expect to recognize a cumulative effect of change in accounting principle benefit of less than $1 million in the first
quarter 2017 as a result of implementing this standard.
In February 2016, the FASB issued ASU 2016-02, “Leases” (Topic 842), which replaces the existing guidance
for lease accounting, Leases (Topic 840). ASU 2016-02 requires lessees to recognize a lease liability and a right-of-
use asset for all leases with terms longer than 12 months. The guidance is effective for financial statements issued
for reporting periods beginning after December 15, 2018 and interim periods within the reporting periods. An entity
will be required to recognize and measure leases at the beginning of the earliest period presented using a modified
retrospective approach. We are currently evaluating the impact of this new standard on our consolidated financial
statements.
In April 2015, the FASB issued ASU 2015-03 “Interest - Imputation of Interest: Simplifying the Presentation of
Debt Issuance Costs” (ASU 2015-03). ASU 2015-03 simplifies the presentation of debt issuance costs by requiring
that such costs be presented as a deduction from the corresponding debt liability. Effective with our quarterly report
on Form 10-Q for the quarter ended March 31, 2016, we have adopted the provisions of ASU 2015-03. At
December 31, 2015, as a result of our adoption of ASU 2015-03, we reclassified $4.7 million of debt issuance costs
to reduce our recognized debt liabilities from other current assets ($1.3 million) and other non-current assets ($3.4
million) on the accompanying consolidated balance sheet. A portion of our debt issuance costs relate to revolving
lines of credit and will accordingly continue to be included in “Other current assets” or “Other non-current assets”.
In May 2014, the FASB issued ASU 2014-09 establishing Accounting Standards Codification (ASC) Topic
606, “Revenue from Contracts with Customers” (ASC 606). ASC 606 establishes a comprehensive new revenue
recognition model designed to depict the transfer of goods or services to a customer in an amount that reflects the
consideration the entity expects to be entitled to receive in exchange for those goods or services and requires
significantly enhanced revenue disclosures. The standard is effective for annual reporting periods beginning after
December 15, 2017. Accordingly, we plan to adopt this standard in the first quarter of 2018. ASC 606 allows either
full retrospective or modified retrospective transition, and we currently plan to use the modified retrospective
method of adoption.
We continue to evaluate the impact of this new standard on our consolidated financial statements upon
adoption. Our approach includes performing a detailed review of key contracts representative of our different
businesses and comparing historical accounting policies and practices to the new standard.
3. IMPAIRMENT CHARGES
2016 Impairment Charges
The following summarizes pre-tax impairment charges recorded during 2016, which are included in Impairment
expense in our consolidated statements of operations (in thousands):
Quarter ended March 31, 2016
Long-lived assets ........................................
$
--
Quarter ended September 30, 2016
Long-lived assets ........................................
Total .................................................................
$
37,729
37,729
$
$
--
--
--
$
8,400
--
8,400
$
$
$
8,400
37,729
46,129
Canada
Australia
U.S.
Total
Quarter ended March 31, 2016. During the first quarter of 2016, we recorded an impairment expense of $8.4
million, resulting from the impairment of fixed assets in our U.S. segment, due to a continued reduction of U.S.
drilling activity in the Bakken Shale region. These fixed assets were written down to their fair value of $3.8 million.
We assessed the carrying values of the asset groups to determine if they continued to be recoverable based on
estimated future cash flows. Based on the assessment, the carrying values were determined to not be recoverable,
and we proceeded to compare the fair value of those assets groups to their respective carrying values.
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(Continued)
Quarter ended September 30, 2016. During the third quarter of 2016, we identified an indicator that certain
asset groups used, or expected to be used, in conjunction with potential LNG projects in British Columbia may be
impaired due to market developments occurring in the third quarter of 2016, including the delay in the final
investment decision regarding an LNG project in British Columbia. We assessed the carrying value of each of the
asset groups to determine if they continued to be recoverable based on their estimated future cash flows. Based on
the assessment, the carrying values of the mobile camp assets and certain undeveloped land positions in British
Columbia were determined to not be fully recoverable, and we proceeded to compare the estimated fair value of
those assets groups to their respective carrying values. Accordingly, the mobile camp assets and undeveloped land
positions were written down to their estimated fair values of $26.6 million and $5.6 million, respectively, and we
recorded an associated impairment expense of $37.7 million.
2015 Impairment Charges
The following summarizes pre-tax impairment charges recorded during 2015, which are included in Impairment
expense in our consolidated statements of operations (in thousands):
Canada
Australia
U.S. and
Other
Total
Quarter ended March 31, 2015
Long-lived assets ........................................
$
Quarter ended June 30, 2015
Long-lived assets ........................................
Quarter ended September 30, 2015
Goodwill ....................................................
Long-lived assets ........................................
Intangible assets .........................................
Total .................................................................
$
--
--
43,194
23,041
--
66,235
$
--
$
2,738
$
2,738
9,473
--
23,980
--
33,453
$
--
--
18,040
2,460
23,238
$
9,473
43,194
65,061
2,460
122,926
$
Quarter ended March 31, 2015. During the first quarter of 2015, we made the decision to dispose of our
manufacturing facility in Johnstown, Colorado. Accordingly, the facility met the criteria of held for sale, and its
carrying value was adjusted downward to $8.7 million, which represents its estimated fair value less the cost to sell.
Accordingly, we recorded a pre-tax impairment expense of $2.7 million and an additional $1.1 million write-down
of our inventory. During the fourth quarter of 2015, we completed the sale of the facility.
Quarter ended June 30, 2015. During the second quarter of 2015, we recorded an impairment expense of $9.5
million, resulting from the impairment of fixed assets in a village located in Western Australia, due to the continued
downturn in gold mining activity and lack of contract renewals. These fixed assets were written down to their fair
value of $0.1 million. We assessed the carrying value of the asset group to determine if it continued to be
recoverable based on estimated future cash flows. Based on the assessment, the carrying value was determined to
not be recoverable.
Quarter ended September 30, 2015. During the third quarter of 2015, we recorded impairment expense related
to goodwill, long-lived assets and intangible assets.
Due to the sustained reduction of our share price throughout 2015, our market capitalization implied an
enterprise value which was significantly less than the sum of the estimated fair values of our reporting units. As a
result of our market capitalization at September 30, 2015, coupled with (1) the continued depression of worldwide
oil prices, including the substantial declines experienced in the third quarter of 2015, and (2) continued weakness in
the Canadian dollar in the third quarter of 2015, we determined that an indicator of a goodwill impairment was
present as of September 30, 2015. Accordingly, as a result of then-current macroeconomic conditions, we
performed an interim goodwill impairment test as of September 30, 2015, and we reduced the value of our goodwill
in our Canadian reporting unit to zero. This resulted in a $43.2 million impairment charge in the third quarter of
2015.
Furthermore, due to the goodwill impairment in our Canadian segment, we determined all asset groups within
this segment had experienced a triggering event indicating that the carrying values might not be recoverable.
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Accordingly, we compared the carrying value of each asset group to estimates of the undiscounted cash flows for
such asset group. Based on the assessment, carrying values of certain asset groups were determined to be
unrecoverable, and we proceeded to compare the fair value of those asset groups to their respective carrying values.
Accordingly, we recorded an impairment loss of $11.1 million related to long-lived assets in our Canadian segment.
These fixed assets were written down to their fair value of $12.6 million.
Also due to the sustained reduction of our share price throughout 2015, we reviewed the long-lived assets in our
U.S. and Australia reportable segments to determine if an indicator of impairment had occurred that would indicate
that the carrying values of the asset groups in these segments might not be recoverable. We determined that certain
asset groups within the U.S. and Australia segments had experienced an indicator of impairment, and thus compared
the carrying value of the respective asset group to estimates of the undiscounted future cash flows for such asset
group. Based on the assessment, the carrying values of three of our asset groups were determined to not be
recoverable, and we proceeded to compare the fair values of the asset groups to their carrying values. Accordingly,
we recorded an impairment loss of $20.5 million related to our U.S. segment. Of the $20.5 million impairment,
$18.0 million reduced the value of our fixed assets and $2.5 million reduced the value of our amortizable intangible
assets. These fixed assets were written down to their fair value of $9.5 million. In addition, we recorded an
impairment loss of $24.0 million related to our Australian segment that reduced the value of our fixed assets. These
fixed assets were written down to their fair value of $10.3 million.
Finally, during the third quarter of 2015, we identified assets in our Canadian segment that should have been
impaired in the fourth quarter of 2014. We determined that the error was not material to our financial statements for
the year ended December 31, 2014 and therefore corrected the error in the third quarter of 2015. This resulted in an
additional impairment expense of $11.9 million.
2014 Impairment Charges
The following summarizes pre-tax impairment charges recorded during 2014 which are included in Impairment
expense in our consolidated statements of operations (in thousands):
Canada
Australia
Quarter ended June 30, 2014
Long-lived assets ........................................
Intangible assets .........................................
$
--
--
$
--
8,989
Quarter ended December 31, 2014
Goodwill ....................................................
Long-lived assets ........................................
Intangible assets .........................................
Total .................................................................
--
17,197
--
17,197
$
186,097
--
--
$ 195,086
U.S. and
Other
$
$
2,621
--
16,632
55,776
3,196
78,225
Total
$
$
2,621
8,989
202,729
72,973
3,196
290,508
Quarter ended June 30, 2014. We recognized a $9.0 million impairment of an indefinite-lived intangible asset
in Australia. Due to the Spin-Off, and the resulting rebranding of our Australian operations from The MAC to
Civeo, it was determined that the fair value of an intangible asset associated with The MAC brand had been reduced
to zero.
Additionally, in the second quarter 2014, we recognized an impairment totaling $2.6 million on assets in the
custody of a non-paying client in Mexico and for which the return or reimbursement was uncertain.
Quarter ended December 31, 2014. During the fourth quarter of 2014, we recorded impairment expense
related to goodwill, long-lived assets and intangible assets.
In performing step one of our annual goodwill impairment test as of November 30, 2014, the carrying amounts
of our U.S. and Australia reporting units exceeded the respective reporting unit’s IFV. Accordingly, we proceeded
to the second step for those reporting units. This second step compared the IFV of each reporting unit’s goodwill
with the carrying amount of such goodwill. We performed a hypothetical allocation of the fair value of the reporting
units determined in step one to all of the assets and liabilities of the unit, including any unrecognized intangible
106
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
assets. After making these hypothetical allocations, we determined zero residual value remained that could be
allocated to goodwill within our U.S. and Australian reporting units, respectively. As a result, we recorded
impairment charges totaling $16.6 million and $186.1 million to goodwill for our U.S. and Australian reporting
units, respectively.
Also during the fourth quarter 2014, as a result of the decline in global crude oil prices and forecasts for a
potentially protracted period of lower prices, management assessed the carrying value of all of our long-lived asset
groups to determine if they continued to be recoverable based on estimated future cash flows. Based on the
assessment, the carrying values of certain of our asset groups were determined to not be recoverable. We recorded
impairment losses of $76.2 million during 2014 as a result, of which $59.0 million related to our U.S. segment and
$17.2 million related to our Canadian segment. Of the $59.0 million impairment related to our U.S. segment, $55.8
million reduced the value of our fixed assets and $3.2 million was recorded on our amortizable intangible assets.
These fixed assets were written down to their fair value of $51.7 million in our U.S. segment and $4.6 million in our
Canadian segment.
4. FAIR VALUE MEASUREMENTS
Our financial instruments consist of cash and cash equivalents, receivables, payables and debt instruments. We
believe that the carrying values of these instruments on the accompanying consolidated balance sheets approximate
their fair values.
As of December 31, 2016 and December 31, 2015, we believe the carrying value of our floating-rate debt
outstanding under our term loans and revolving credit facilities approximates their fair values because their terms
include short-term interest rates and exclude penalties for prepayment. We estimated the fair value of our floating-
rate term loan and revolving credit facilities using significant other observable inputs, representative of a Level 2
fair value measurement, including terms and credit spreads for these loans.
During 2016, 2015 and 2014, we wrote down certain long-lived assets to their fair values. Our estimates of fair
value required us to use significant unobservable inputs, representative of Level 3 fair value measurements,
including numerous assumptions with respect to future circumstances that might directly impact each of the asset
groups’ operations in the future and are therefore uncertain. These assumptions with respect to future circumstances
included future oil, coal and natural gas prices, anticipated spending by our customers, the cost of capital, and
industry and/or local market conditions. During the third quarter of 2016, our estimates of fair value of certain
undeveloped land positions in British Columbia were based on appraisals from third parties. Please see Note 2 –
Summary of Significant Accounting Policies – Impairment of Long-Lived Assets for further discussion of the
significant judgments and assumptions used in calculating their fair value.
During 2015 and 2014, we also wrote down our goodwill to its implied fair value (IFV). Our estimate of IFV
required us to use significant unobservable inputs, representative of Level 3 fair value measurements, including
numerous assumptions with respect to future circumstances, such as industry and/or local market conditions that
might directly impact each of the reporting units’ operations in the future, and are therefore uncertain. Please see
Note 2 – Summary of Significant Accounting Policies – Goodwill and Other Intangible Assets for further discussion
of the significant judgments and assumptions used in calculating their fair value.
107
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
5. DETAILS OF SELECTED BALANCE SHEET ACCOUNTS
Additional information regarding selected balance sheet accounts at December 31, 2016 and 2015 is presented
below (in thousands):
December 31,
2016
December 31,
2015
Accounts receivable, net:
Trade ...............................................................................................
Unbilled revenue .............................................................................
Other ...............................................................................................
Total accounts receivable ...........................................................
Allowance for doubtful accounts ....................................................
Total accounts receivable, net .........................................................
$
$
39,442
16,063
1,435
56,940
(638)
56,302
$
$
44,650
16,649
1,289
62,588
(1,121)
61,467
Inventories:
Finished goods and purchased products .......................................
Work in process ...........................................................................
Raw materials ..............................................................................
Total inventories ...........................................................................
December 31,
2016
December 31,
2015
$
1,700
3
1,409
3,112
$
$
$
1,854
1,260
2,517
5,631
During 2016, we recorded a $0.9 million write-down of inventory at our modular construction and
manufacturing plant in Canada, which is included in Cost of sales in our accompanying consolidated statements of
operations.
Estimated
Useful Life
(in years)
December 31,
2016
December 31,
2015
Property, plant and equipment, net:
Land .........................................................
Accommodations assets ............................
Buildings and leasehold improvements ....
Machinery and equipment ........................
Office furniture and equipment ................
Vehicles ....................................................
Construction in progress ...........................
Total property, plant and equipment .....
Accumulated depreciation ........................
Total property, plant and equipment, net ..
3-15
5-20
4-15
3-7
3-5
Accrued liabilities:
Accrued compensation ......................................................................
Accrued taxes, other than income taxes ............................................
Accrued interest ................................................................................
Other .................................................................................................
Total accrued liabilities ......................................................................
$
$
41,122
1,542,806
28,104
9,667
29,948
14,725
35,196
1,701,568
(911,858)
789,710
$
$
47,825
1,482,842
29,099
9,183
29,172
15,412
52,558
1,666,091
(734,177)
931,914
December 31,
2016
December 31,
2015
$
$
11,879
727
194
1,578
14,378
$
$
11,726
963
12
2,133
14,834
108
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
6. EARNINGS PER SHARE
On May 30, 2014, 106,538,044 of our common shares were distributed to Oil States stockholders in connection
with the Spin-Off. For comparative purposes, and to provide a more meaningful calculation of weighted-average
shares outstanding, we have assumed these shares to be outstanding as of the beginning of each period prior to the
separation presented in the calculation of weighted-average shares. In addition, we have assumed the dilutive
securities outstanding at May 30, 2014 were also outstanding for each of the periods prior to the Spin-Off presented.
The calculation of earnings per share attributable to the Company is presented below for the periods indicated
(in thousands, except per share amounts):
Basic Loss per Share
Net loss attributable to Civeo .........................................................................
Less: undistributed net income to participating securities ..............................
Net loss attributable to Civeo’s common shareholders - basic .......................
$
$
(96,388)
--
(96,388)
$ (131,759)
--
$ (131,759)
$
$
(189,043)
921
(188,122)
2016
2015
2014
Weighted average common shares outstanding - basic ..................................
107,024
106,604
Basic loss per share ....................................................................................... $
(0.90)
$
(1.24)
Diluted Loss per Share
Net loss attributable to Civeo’s common shareholders – basic ......................
Less: undistributed net income to participating securities ..............................
Net loss attributable to Civeo’s common shareholders - diluted ....................
$
$
(96,388)
--
(96,388)
$ (131,759)
--
$ (131,759)
Weighted average common shares outstanding - basic ..................................
Effect of dilutive securities (1) ........................................................................
Weighted average common shares outstanding - diluted ...............................
107,024
--
107,024
106,604
--
106,604
$
$
$
106,306
(1.77)
(188,122)
--
(188,122)
106,306
--
106,306
Diluted loss per share .................................................................................... $
(0.90)
$
(1.24)
$
(1.77)
(1) When an entity has a net loss from continuing operations, it is prohibited from including potential common
shares in the computation of diluted per share amounts. Accordingly, we have utilized the basic shares
outstanding amount to calculate both basic and diluted loss per share for the years ended December 31, 2016,
2015 and 2014. In the years ended December 31, 2016, 2015 and 2014, we excluded from the calculation 1.3
million, 1.3 million and 0.7 million share based awards, respectively, since the effect would have been anti-
dilutive.
7. SUPPLEMENTAL CASH FLOW INFORMATION
Cash paid during the years ended December 31, 2016, 2015 and 2014 for interest and income taxes was as
follows (in thousands):
Interest (net of amounts capitalized) .................................................
Income taxes paid, net of refunds ......................................................
$
18,927
3,404
$
21,385
(5,169)
$
14,444
43,237
2016
2015
2014
In accordance with the Separation and Distribution Agreement, our affiliate debt with Oil States, which totaled
approximately $336.8 million as of May 30, 2014, including accrued interest, was settled through a non-cash capital
contribution. For further discussion, please see Note 17 – Related Party Transactions.
109
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
8. GOODWILL AND OTHER INTANGIBLE ASSETS
Changes in the carrying amount of goodwill for the years ended December 31, 2016 and 2015 are as follows (in
thousands):
Balance as of December 31, 2014 ............................
Foreign currency translation ..................................
Goodwill impairment .............................................
Balance as of December 31, 2015 and 2016 ..............
Canada
$
$
45,260
(2,066)
(43,194)
--
Australia
--
$
--
--
--
$
U.S.
$
$
--
--
--
--
Total
45,260
(2,066)
(43,194)
--
$
$
Please see Note 3 – Impairment Charges for a discussion of impairment charges we recognized in 2015 and
2014 related to our goodwill.
The following table presents the total amount of other intangible assets and the related accumulated
amortization for major intangible asset classes as of December 31, 2016 and 2015 (in thousands):
AS OF DECEMBER 31,
2016
2015
Gross
Carrying
Amount
Accumulated
Amortization
Gross
Carrying
Amount
Amortizable Intangible Assets
Customer relationships .............................................................
Contracts / agreements .............................................................
Noncompete agreements ..........................................................
Total amortizable intangible assets .................................
$
$
Indefinite-Lived Intangible Assets Not Subject to Amortization
Licenses ...................................................................................
Total indefinite-lived intangible assets ............................
Total intangible assets ............................................
$
42,614
35,499
749
78,862
30
30
78,892
$
$
$
(28,804)
(21,300)
(749)
(50,853)
$
$
--
--
(50,853)
$
43,668
35,769
795
80,232
30
30
80,262
Accumulated
Amortization
$
$
$
(26,278)
(17,885)
(790)
(44,953)
--
--
(44,953)
Please see Note 3 – Impairment Charges for a discussion of impairment charges we recognized in 2015 and
2014 related to our intangible assets.
The weighted average remaining amortization period for all intangible assets, other than indefinite-lived
intangibles, was 4.1 years as of December 31, 2016 and 5.1 years as of December 31, 2015. Total amortization
expense is expected to be $6.9 million in 2017 through 2020 and $0.2 million in 2021. Amortization expense was
$7.2 million, $7.6 million and $9.6 million in the years ended December 31, 2016, 2015 and 2014, respectively.
110
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
9. DEBT
As of December 31, 2016 and 2015, long-term debt consisted of the following (in thousands):
December 31,
2016
December 31,
2015
U.S. term loan, which matures on May 28, 2019; weighted average interest rate of 3.8%
for the twelve month period ended December 31, 2016 .......................................................
$
24,375
$
49,375
Canadian term loan, which matures on May 28, 2019; 1.25% of aggregate principal
repayable per quarter beginning December 31, 2015; weighted average interest rate of
4.1% for the twelve month period ended December 31, 2016 ..............................................
293,763
300,165
U.S. revolving credit facility, which matures on May 28, 2019, weighted average
interest rate of 5.7% for the twelve month period ended December 31, 2016 .......................
--
--
Canadian revolving credit facility, which matures on May 28, 2019, weighted average
interest rate of 4.3% for the twelve month period ended December 31, 2016 .......................
23,089
52,020
Canadian revolving credit facility, which matures on May 28, 2019, weighted average
interest rate of 4.9% for the twelve month period ended December 31, 2016 .......................
9,533
--
Australian revolving credit facility, which matures on May 28, 2019, weighted average
interest rate of 5.2% for the twelve month period ended December 31, 2016 ......................
Less: Unamortized debt issuance costs .................................................................................
Total debt ........................................................................................................................
Less: Current portion of long-term debt, including unamortized debt issuance costs, net ....
Long-term debt, less current maturities ...........................................................................
6,507
357,267
3,996
353,271
15,471
337,800
$
--
401,560
4,683
396,877
17,461
379,416
$
Scheduled maturities of long-term debt as of December 31, 2016 are as follows (in thousands):
2017 .............................................................................
2018 .............................................................................
2019 .............................................................................
$
$
15,667
15,667
325,933
357,267
Amended Credit Facility
As of December 31, 2016, our revolving credit facility consisted of (i) a $350.0 million, revolving credit facility
scheduled to mature on May 28, 2019, allocated as follows: (A) a $50.0 million senior secured revolving credit
facility in favor of certain of our U.S. subsidiaries, as borrower, (B) a $100.0 million senior secured revolving credit
facility in favor of Civeo and certain of our Canadian subsidiaries, as borrower, (C) a $100.0 million senior secured
revolving credit facility in favor of Civeo, as borrower, and (D) a $100.0 million senior secured revolving credit
facility in favor of one of our Australian subsidiaries, as borrower, and (ii) a $350.0 million, term loan facility
scheduled to mature on May 28, 2019 in favor of Civeo (collectively, the Amended Credit Facility).
On February 17, 2017, the third amendment to the Amended Credit Facility became effective, which:
(cid:2) Provided for the reduction by US$75 million of the aggregate revolving loan commitments under the
Amended Credit Facility, to a maximum principal amount of $275 million. Accordingly, after the
reduction, the revolving credit facility consists of (A) a $40.0 million senior secured revolving credit
facility in favor of certain of our U.S. subsidiaries, as borrower, (B) a $90.0 million senior secured
revolving credit facility in favor of Civeo and certain of our Canadian subsidiaries, as borrowers, (C) a
$60.0 million senior secured revolving credit facility in favor of Civeo, as borrower, and (D) a $85.0
million senior secured revolving credit facility in favor of one of our Australian subsidiaries, as borrower;
(cid:2)
(i) Established one additional level to the total leverage-based grid such that the interest rates for the loans
111
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
range from LIBOR +2.25% to LIBOR +5.50% and (ii) increased the undrawn commitment fee from a
range of 0.51% to 1.13% to a range of 0.51% to 1.24% based on total leverage;
(cid:2) Adjusted the maximum leverage ratio financial covenant, as follows; and
Maximum Leverage Ratio
Period Ended
December 31, 2016 (no change) .................
March 31, 2017 (no change) .......................
June 30, 2017 (no change) ..........................
September 30, 2017 ....................................
December 31, 2017 .....................................
March 31, 2018 ...........................................
June 30, 2018 ..............................................
September 30, 2018 ....................................
December 31, 2018 .....................................
March 31, 2019 & thereafter .......................
5.50 : 1.00
5.25 : 1.00
5.25 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.85 : 1.00
5.50 : 1.00
5.25 : 1.00
(cid:2) Provided for other technical changes and amendments to the Amended Credit Facility.
U.S. dollar amounts outstanding under the Amended Credit Facility bear interest at a variable rate equal to
LIBOR plus a margin of 2.25% to 5.50%, or a base rate plus 1.25% to 4.50%, in each case based on a ratio of our
total leverage to EBITDA (as defined in the Amended Credit Facility). Canadian dollar amounts outstanding under
the Amended Credit Facility bear interest at a variable rate equal to CDOR plus a margin of 2.25% to 5.50%, or a
base rate plus a margin of 1.25% to 4.50%, in each case based on a ratio of our consolidated total leverage to
EBITDA (as defined in the Amended Credit Facility). Australian dollar amounts outstanding under the Amended
Credit Facility bear interest at a variable rate equal to BBSY plus a margin of 2.25% to 5.50%, based on a ratio of
our consolidated total leverage to EBITDA (as defined in the Amended Credit Facility).
The Amended Credit Facility contains customary affirmative and negative covenants that, among other things,
limit or restrict (i) subsidiary indebtedness, liens and fundamental changes, (ii) asset sales, (iii) margin stock, (iv)
specified acquisitions, (v) restrictive agreements, (vi) transactions with affiliates and (vii) investments and other
restricted payments, including dividends and other distributions. Specifically, we must maintain an interest coverage
ratio, defined as the ratio of consolidated EBITDA (as defined in the Amended Credit Facility) to consolidated
interest expense, of at least 3.0 to 1.0 and our maximum leverage ratio, defined as the ratio of total debt to
consolidated EBITDA, of no greater than 5.50 to 1.0 (as of December 31, 2016). As noted above, the permitted
maximum leverage ratio changes over time. Each of the factors considered in the calculations of these ratios are
defined in the Amended Credit Facility. EBITDA and consolidated interest, as defined, exclude goodwill and asset
impairments, debt discount amortization and other non-cash charges. We were in compliance with these covenants
as of December 31, 2016.
As of December 31, 2016, we have 15 lenders in our Amended Credit Facility with commitments ranging from
$1.2 million to $135.7 million. As of December 31, 2016, we had outstanding letters of credit of $0.4 million under
the U.S facility, $0.6 million under the Australian facility and $0.6 million under the Canadian facility.
Borrowings under the Amended Credit Facility are secured by a pledge of substantially all of our assets and the
assets of our subsidiaries. Obligations under the Amended Credit Facility are guaranteed by our significant
subsidiaries.
In addition to the Amended Credit Facility, we have an A$2.0 million bank guarantee facility, which matures
March 31, 2017. There were bank guarantees of A$0.8 million under this facility outstanding as of December 31,
2016.
112
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
10. RETIREMENT PLANS
We sponsor defined contribution plans. Participation in these plans is available to substantially all employees.
We recognized expense of $6.4 million, $9.6 million and $16.3 million, respectively, related to matching
contributions under our various defined contribution plans during the years ended December 31, 2016, 2015 and
2014, respectively. A defined contribution plan is a post-employment benefit plan under which an entity pays fixed
contributions into a separate entity and will generally have no legal or constructive obligation to pay further
amounts. Obligations for contributions to defined contribution plans are recognized as an employee benefit expense
in profit or loss in the periods during which services are rendered by employees.
Canadian Retirement Savings Plan
We offer a defined contribution retirement plan to our Canadian employees. In Canada, we contribute, on a
matched basis, an amount up to 5% of each Canadian based, salaried employee’s earnings (base salary plus annual
incentive compensation) to the legislated maximum for a Deferred Profit Sharing Plan (DPSP – Maximum for 2016
- $13,005). DPSP is a form of defined contribution retirement savings plan governed by Canadian Federal Tax
legislation which provides for deferral of tax on deposit and investment return until removed from the plan to
support retirement income. Employer contributions vest upon the completion of two years of service. Employee
contributions are required in order to be eligible for the DPSP employer matching. Maximum employer matching
(5% noted above) is attained with (6%) employee contribution which would go into a Group Registered Retirement
Savings Plan (GRRSP). The two plans work in tandem. Contributions to the “Retirement Savings Plan” for
Canadian employees are subject to the annual maximum total registered savings limit of $25,370 in 2016 as set out
in the Canadian Tax Act.
Australian Retirement Savings Plan
Our Australian subsidiary contributes to various defined contribution plans for its employees in accordance with
legislation governing the calculation of the Superannuation Guarantee Surcharge (SGC). SGC is contributed by the
employer at a rate of 9.5% of the base salary of an employee, capped at the legislated maximum contribution base
which is indexed annually.
Our Australian subsidiary makes no investment decisions on behalf of the employee and has no obligations
other than to remit the defined contributions to the plan selected by each individual employee.
U.S. Retirement Savings Plan
We offer a defined contribution 401(k) retirement plan to substantially all of our U.S. employees. Participants
may contribute from 1% to 75% of their base and cash incentive compensation (subject to Internal Revenue Service
limitations), and we make matching contributions under this plan on the first 6% of the participant’s compensation
(100% match of the first 4% employee contribution and 50% match on the next 2% contribution). Our matching
contributions vest at a rate of 20% per year for each of the employee’s first five years of service and then are fully
vested thereafter.
113
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
11. ASSET RETIREMENT OBLIGATIONS
AROs at December 31, 2016 and 2015 were (in thousands):
2016
2015
Asset retirement obligations ...........................................................
Less: Asset retirement obligations due within one year* ...............
Long-term asset retirement obligations ..........................................
$
$
17,584
2,374
15,210
$
$
17,299
--
17,299
* Classified as a current liability on the consolidated balance sheets, under the caption “Other current
liabilities.” Related to remediation work planned for 2017.
Total expense related to the ARO was $1.4 million, $1.3 million and $0.3 million in 2016, 2015 and 2014,
respectively.
During the years ended December 31, 2016, 2015 and 2014, our ARO changed as follows (in thousands):
Balance as of January 1........................................ $
Accretion of discount ...........................................
New obligations ...................................................
Change in estimates of existing obligations ........
Settlement of obligations .....................................
Foreign currency translation ...............................
Balance as of December 31 ..................................
$
2016
17,299
1,351
--
(1,182)
(376)
492
17,584
2015
21,610
1,292
81
(2,366)
(132)
(3,186)
17,299
$
$
2014
$
6,095
336
797
14,838
--
(456)
$ 21,610
During 2014, our estimates of existing obligations increased by $14.8 million. The change in estimate was the
result of acceleration of the timing of estimated expenditures, due to new information received during 2014 and
higher expected expenditures for remediation, as a result of current estimates of costs expected to be incurred.
12. INCOME TAXES
The Company’s operations are conducted through its various subsidiaries in a number of countries throughout
the world. The Company has provided for income taxes based upon the tax laws and rates in the countries in which
operations are conducted and income is earned. For the years ended December 31, 2016 and 2015, Civeo Canada is
the public parent registered under the laws of British Columbia, Canada. For the year ended December 31, 2014,
Civeo US, a Delaware corporation, was the public parent registered in the U.S.
Income tax provision (benefit). Pre-tax income (loss) for the years ended December 31, 2016, 2015 and 2014
consisted of the following (in thousands):
Canada operations .....
Foreign operations ....
Total .....................
2016
$ (87,234)
(28,698)
$ (115,932)
$
2015
(73,691)
(90,062)
$ (163,753)
2014
$ 119,509
(275,792)
$ (156,283)
114
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
The components of the income tax provision (benefit) for the years ended December 31, 2016, 2015 and 2014
consisted of the following (in thousands):
2016
2015
2014
Current:
Canada ........................................ $
Foreign........................................
Total ........................................
$
(8,646)
1,749
(6,897)
Deferred:
Canada ........................................ $
Foreign........................................
Total ........................................
$
(12,169)
(1,039)
(13,208)
Total Provision (Benefit) ...............
$
(20,105)
$
$
$
$
$
(820)
1,906
1,086
$ 27,046
--
$ 27,046
(2,707)
(31,468)
(34,175)
$
$
23
4,310
4,333
(33,089)
$ 31,379
The income tax provision (benefit) differs from an amount computed at Canadian statutory rates for the years
ended December 31, 2016 and 2015 and at U.S. statutory rates for the years ended December 31, 2014 (in
thousands) was as follows:
Federal tax provision (benefit) at statutory rates .... $
Effect of foreign income tax, net ............................
Goodwill impairment .............................................
Valuation allowance ...............................................
Tax on future unremitted earnings .........................
Tax effects of restructuring ....................................
Deemed income from foreign subsidiaries .............
Enacted tax rate change ..........................................
Other, net ...............................................................
Net income tax provision (benefit) .................... $
2016
(31,302) 27.0%
5.7%
--
(13.0%)
--
(2.6%)
(1.0%)
(0.6%)
1.8%
(20,105) 17.3%
(6,593)
--
15,051
--
3,038
1,108
712
(2,119)
2015
$ (44,213)
(15,088)
11,533
11,189
(25,306)
17,600
4,190
3,332
3,674
$ (33,089)
27.0%
9.2%
(7.0%)
(6.8%)
15.4%
(10.8%)
(2.6%)
(2.0%)
(2.2%)
20.2%
2014
$ (54,699) 35.0%
(10,599)
19,798
51,369
26,077
--
--
--
(567)
$ 31,379
6.8%
(12.7%)
(32.9%)
(16.7%)
--
--
--
0.4%
(20.1%)
Deferred Tax Liabilities and Assets. The significant items giving rise to the deferred tax assets and liabilities
as of December 31, 2016 and 2015 are as follows (in thousands):
2016
2015
Deferred tax assets:
Net operating loss .............................................
Foreign tax credits ............................................
Allowance for doubtful accounts ......................
Employee benefits ............................................
Deductible goodwill and other intangibles........
Other reserves ...................................................
Unearned revenue .............................................
Other .................................................................
Deferred tax assets ............................................
Valuation allowance ........................................
Deferred tax assets, net .....................................
Deferred tax liabilities:
Depreciation ....................................................
Investment .......................................................
Deferred tax liabilities .....................................
$
$
$
49,810
--
--
6,952
45,262
4,773
1,776
1,588
110,161
(76,157)
34,004
(42,701)
(497)
(43,198)
$
$
$
12,528
58,906
--
5,326
43,857
6,342
2,894
1,893
131,746
(115,087)
16,659
(41,312)
(738)
(42,050)
Net deferred tax liability ...............................
$
(9,194)
$
(25,391)
115
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
NOL and Tax Credit Carryforwards. The following table summarizes net operating loss (NOL) and tax credit
carryforwards at December 31, 2016 (in thousands):
Net operating loss carryforwards:
Canada .......................................................
Australia ....................................................
U.S. – Federal ...........................................
U.S. – State ................................................
Amount
$ 80,307
51,286
21,138
111,242
Expiration Period
Begins to expire in 2035
Does not expire
Expires in 2036
Begins to expire in 2020
Change in Valuation Allowance. Realization of our deferred tax assets is dependent upon, among other things,
our ability to generate taxable income of the appropriate character in the future.
Changes in our valuation allowance for the years ended December 31, 2016 and 2015 are as follows (in
thousands):
Foreign Tax
Credits
Balance as of December 31, 2014 ......
Change in income tax provision ......
Tax effects of restructuring .............
Other change ...................................
Foreign currency translation ...........
Balance as of December 31, 2015 ......
Change in income tax provision ......
Write-off of U.S. foreign tax credits
Other change ...................................
Foreign currency translation ...........
Balance as of December 31, 2016 .......
$
$
--
--
(58,906)
--
--
(58,906)
--
58,906
--
--
--
Deferred
Tax Assets
(49,523)
$
(9,834)
--
(309)
5,367
(54,299)
(6,834)
--
(285)
2
(61,416)
$
Other
$
---
(1,355)
--
(545)
18
(1,882)
(8,217)
--
(4,969)
327
$ (14,741)
Total
(49,523)
(11,189)
(58,906)
(854)
5,385
(115,087)
(15,051)
58,906
(5,254)
329
(76,157)
$
$
As a result of the internal restructuring, a full valuation allowance was placed against excess foreign tax credits
totaling $58.9 million in 2015. The excess foreign tax credits were written-off against the valuation allowance in
2016 because of the remote likelihood that the foreign tax credits will be utilized.
Indefinite Reinvestment of Earnings. During the fourth quarter of 2014, we reevaluated our intent to
indefinitely reinvest earnings of subsidiary companies foreign to the US. Due to our expectations of utilizing our
existing and future cash balances to reduce our aggregate debt balances during 2015, we recognized a deferred tax
liability of $25.3 million related to a portion of our undistributed foreign earnings. During 2015, due to a change in
expectations and legal entity structure, we reversed the deferred tax liability.
At December 31, 2015 and 2016, due to the internal restructuring in connection with the Redomicile
Transaction, we have no undistributed earnings of foreign subsidiaries subject to income tax in Canada.
Unrecognized Tax Benefits. We file tax returns in the jurisdictions in which they are required. All of these
returns are subject to examination or audit and possible adjustment as a result of assessments by taxing authorities.
We believe that we have recorded sufficient tax liabilities and do not expect the resolution of any examination or
audit of our tax returns to have a material adverse effect on our operating results, financial condition or liquidity.
Our Canadian federal tax returns subsequent to 2009 are subject to audit by the Canada Revenue Agency. Our
Australian subsidiary’s federal income tax returns subsequent to 2012 are open for review by the Australian
Taxation Office. Our US subsidiary’s federal tax returns from 2014 are subject to audit by the US Internal Revenue
Service.
The total amount of unrecognized tax benefits as of December 31, 2016 and 2015 was zero and $0.7 million,
respectively. The unrecognized tax benefits, if recognized, would affect the effective tax rate. We accrue interest
and penalties related to unrecognized tax benefits as a component of our provision for income taxes. As of
December 31, 2016 and 2015, we had accrued zero and $0.3 million, respectively, of interest expense and penalties.
116
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows (in thousands):
2016
2015
2014
Balance as of January 1........................................ $
Additions for tax positions of prior years .............
Reductions for tax positions of prior years ...........
Reductions for settlements ...................................
Lapse of the applicable statute of limitations ......
Balance as of December 31 ..................................
$
679
--
--
--
(679)
--
$
$
679
--
--
--
--
679
$
$
679
--
--
--
--
679
During the third quarter of 2015, management determined that, based upon ongoing communications with the
Australian taxing authority and status of the current examination, an uncertain tax liability of approximately $8.1
million related to tax positions taken on previously filed Australian returns should be recorded. In the fourth quarter
of 2015, the examination was concluded in our favor. As a result, in the fourth quarter 2015, we reversed the
uncertain tax liability.
During 2016, management determined that, based upon the status of current examinations, an uncertain tax
liability of $0.7 million was reversed.
13. COMMITMENTS AND CONTINGENCIES
We lease a portion of our equipment, office space, computer equipment, automobiles and trucks under leases
which expire at various dates.
Minimum future operating lease obligations in effect at December 31, 2016, were as follows (in thousands):
2017 .............................................................................
2018 .............................................................................
2019 .............................................................................
2020 .............................................................................
2021 .............................................................................
Thereafter .....................................................................
Total ......................................................................
$
$
4,260
3,467
3,065
2,835
1,822
7,920
23,369
Rental expense under operating leases was $6.0 million, $7.6 million and $8.4 million for the years ended
December 31, 2016, 2015 and 2014, respectively.
We are a party to various pending or threatened claims, lawsuits and administrative proceedings seeking
damages or other remedies concerning our commercial operations, products, employees and other matters, including
warranty and product liability claims as a result of our products or operations. Although we can give no assurance
about the outcome of pending legal and administrative proceedings and the effect such outcomes may have on us,
management believes that any ultimate liability resulting from the outcome of such proceedings, to the extent not
otherwise provided for or covered by insurance, will not have a material adverse effect on our consolidated financial
position, results of operations or liquidity.
In conjunction with, and effective as of, the Spin-Off, we entered into an Indemnification and Release
Agreement with Oil States. This agreement governs the treatment between Oil States and us of all aspects relating
to indemnification, insurance, litigation responsibility and management, and litigation document sharing and
cooperation arising in connection with the Spin-Off. Generally, the agreement provides for cross-indemnities
principally designed to place financial responsibility for the obligations and liabilities of our business with us and
financial responsibility for the obligations and liabilities of Oil States’ business with Oil States. The agreement also
establishes procedures for handling claims subject to indemnification and related matters. Pursuant to the
Indemnification and Release Agreement, we and Oil States will generally release the other party from all claims
arising prior to the Spin-Off other than claims arising under the transaction agreements, including the
117
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
indemnification provisions described above. We evaluated the impact of the indemnifications given and the Civeo
indemnifications received as of the Spin-Off date and concluded those fair values were immaterial.
14. ACCUMULATED OTHER COMPREHENSIVE LOSS
Our accumulated other comprehensive loss decreased $3.4 million from $366.3 million at December 31, 2015
to $362.9 million at December 31, 2016, as a result of foreign currency exchange rate fluctuations. Changes in other
comprehensive loss during 2016 were primarily driven by the Canadian dollar increasing in value compared to the
U.S. dollar and the Australian dollar decreasing in value compared to the U.S. dollar. Excluding intercompany
balances, our Canadian dollar and Australian dollar functional currency net assets totaled approximately C$0.2
billion and A$0.5 billion, respectively, at December 31, 2016.
15. SHARE BASED COMPENSATION
Prior to the Spin-Off, certain employees of Civeo participated in Oil States’ Equity Participation Plan (the Oil
States Plan). The expense associated with these employees is reflected in the accompanying consolidated statements
of operations. Our employees and non-employee directors participate in the Amended and Restated 2014 Equity
Participation Plan of Civeo Corporation (the Civeo Plan). The Civeo Plan authorizes the Board of Directors to grant
options, awards of restricted shares, performance awards, dividend equivalents, awards of deferred shares, and share
payments to our employees and non-employee directors. No more than 14.0 million Civeo common shares may be
awarded under the Civeo Plan.
In connection with the Spin-Off, stock based compensation awards granted under the Oil States Plan and held
by Civeo grantees as of May 30, 2014 were replaced with substitute Civeo awards. Stock options were replaced with
options to purchase Civeo common shares. Unvested restricted stock awards were replaced with substitute Civeo
restricted share awards. Unvested deferred stock awards were replaced with substitute Civeo deferred share awards.
Additionally, phantom shares granted under the Canadian Long-Term Incentive Plan were converted to units that
entitle the recipient to a lump sum cash payment equal to the fair market value of a Civeo common share on the
respective vesting date. These replacements were intended to preserve the intrinsic value of the awards as of May
30, 2014. The substitution of these awards did not cause us to recognize incremental compensation expense as an
equitable adjustment was required to be made as a result of the Spin-Off.
Upon effectiveness of the Redomicile Transaction, Civeo Canada assumed the Civeo US employee equity plans
and related award agreements, including all options and awards issued or granted under such plans, as well as
certain Civeo US benefit plans and agreements.
In connection with the assumption of these plans, each plan was amended or deemed amended to provide that,
as of the effectiveness of the Redomicile Transaction, the plans would include provisions, as applicable, reflecting
the Redomicile Transaction and its effects, including changes made to reflect the fact that Civeo Canada common
shares will be issued to satisfy awards issued or granted under such plan. Additionally, the Civeo Plan was further
amended to comply with applicable Canadian law, including with respect to grants to Canadian employees.
Share-based compensation expense recognized in the years ended December 31, 2016, 2015 and 2014 totaled
$9.9 million, $5.6 million and $8.9 million, respectively. Share-based compensation expense is reflected in Selling,
general and administrative (SG&A) expense in our consolidated statements of operations. The total income tax
benefit recognized in the consolidated statements of operations for share based compensation arrangements was
approximately $0.6 million , $0.3 million and $2.2 million for the years ended December 31, 2016, 2015 and 2014,
respectively.
118
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Options to Purchase Common Shares
The fair value of each option grant is estimated on the date of grant using a Black-Scholes option pricing model
that uses the assumptions noted in the following table. The risk-free interest rate is based on the U.S. Treasury yield
curve in effect for the expected term of the option at the time of grant. The dividend yield on Oil States’ common
stock was assumed to be zero since they did not pay dividends and had no plans to do so prior to the Spin-Off. The
expected market price volatility of Oil States’ common stock was based on an estimate made by them that considers
the historical and implied volatility of its common stock as well as a peer group of companies over a time period
equal to the expected term of the option. The expected life of the options awarded in 2014 was based on a formula
considering the vesting period, term of the options awarded and past experience. No options were awarded in 2016
or 2015. Information for periods prior to the Spin-Off is based on stock option awards for Oil States’ common
stock.
Risk-free weighted interest rate ...........................
Expected life (in years) ........................................
Expected volatility ..............................................
2014 (prior
to Spin-Off)
1.27%
4.1
38%
A total of 120,799 Oil States stock options were converted to 554,738 Civeo stock options at May 30, 2014, in
connection with the Spin-Off. As such, no grant, exercise or cancellation activity occurred on Civeo stock option
awards prior to May 30, 2014. The following table presents the changes in stock options outstanding and related
information for our employees during the years ended December 31, 2016, 2015 and 2014:
Outstanding Options at May 30, 2014 ..........................
Granted .................................................................
Exercised ..............................................................
Forfeited / Expired ................................................
Outstanding Options at December 31, 2014 .................
Granted .................................................................
Exercised ..............................................................
Forfeited / Expired ................................................
Outstanding Options at December 31, 2015 .................
Granted ...................................................................
Exercised ................................................................
Forfeited / Expired..................................................
Outstanding Options at December 31, 2016 .................
Options
554,738
--
(12,628)
(9,184)
532,926
--
(137,771)
(4,821)
390,334
--
--
(224,448)
165,886
Exercisable Options at December 31, 2015 ..................
Exercisable Options at December 31, 2016 ..................
327,201
145,804
Weighted
Average
Exercise
Price Per
Share
Weighted
Average
Contractual
Life (Years)
Intrinsic
Value
(Thousands)
$
$
$
$
$
$
11.14
--
11.95
16.43
11.03
--
3.63
16.43
13.58
--
--
10.33
17.98
12.43
17.67
3.4
$ 66,130
3.5
$
--
4.6
2.8
4.4
$
$
$
--
--
--
The total intrinsic value of options exercised by our employees during 2016, 2015 and 2014 for periods
subsequent to the Spin-Off was zero, less than $100,000 and $0.2 million, respectively. The total intrinsic value of
options exercised by our employees during 2014 for periods prior to the Spin-Off was $5.0 million. Oil States
received all cash from option exercises during 2014 for periods prior to the Spin-Off. The tax benefits realized for
the tax deduction from options exercised during 2016, 2015 and 2014 for periods subsequent to the Spin-Off totaled
zero, less than $100,000 and zero, respectively. The tax benefits realized by Oil States for the tax deduction from
stock options exercised during 2014 for periods prior to the Spin-Off totaled $0.2 million.
At December 31, 2016, unrecognized compensation cost related to options was less than $100,000, which is
expected to be recognized over a weighted average period of 1 year.
119
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
The following table summarizes information for outstanding options of our employees at December 31, 2016:
Options Outstanding
Options Exercisable
Number
Outstanding as
of December 31,
2016
Weighted
Average
Remaining
Contractual
Life
67,155
36,737
34,441
27,553
165,886
3.90
5.04
4.15
6.56
4.64
Weighted
Average
Exercise
Price
$
$
$
$
$
16.43
17.48
18.43
21.87
17.98
Number
Exercisable
as of
December 31,
2016
67,155
29,275
34,441
14,933
145,804
Weighted
Average
Exercise
Price
$
$
$
$
$
16.43
17.48
18.43
21.87
17.67
Range of Exercise
Prices
$16.43 ...............................
$17.48 ...............................
$18.43 ...............................
$21.87 ...............................
$16.43 - $21.87 .................
Restricted Share Awards / Deferred Share Awards
A total of 94,936 unvested Oil States restricted stock and deferred stock awards were converted to 435,999
unvested Civeo restricted stock awards at May 30, 2014, in connection with the Spin-Off. As such, no grant,
exercise or cancellation activity occurred on Civeo restricted stock awards prior to May 30, 2014. Included in this
total were 20,000 Oil States performance based restricted stock awards, which vested in an amount that depended on
Oil States’ achievement of specified performance objectives. In conjunction with the Spin-Off transaction, the
awards were cancelled and the holder was granted 91,848 unvested Civeo restricted share awards, of which half
vested in February 2015 and the other half vested in February 2016.
The following table presents the changes in restricted share and deferred share awards outstanding and related
information for our employees during the years ended December 31, 2016, 2015 and 2014:
Nonvested shares at May 30, 2014 ..........................................
Granted ...........................................................................
Vested .............................................................................
Forfeited..........................................................................
Nonvested shares at December 31, 2014 .................................
Granted ...........................................................................
Vested .............................................................................
Forfeited..........................................................................
Nonvested shares at December 31, 2015 .................................
Granted .............................................................................
Vested ...............................................................................
Forfeited ...........................................................................
Nonvested shares at December 31, 2016 .................................
Number of
Awards
435,999
188,005
(19,358)
(27,764)
576,882
1,208,642
(248,215)
(223,745)
1,313,564
584,283
(526,628)
(72,847)
1,298,372
$
$
Weighted
Average Grant
Date Fair Value
Per Share
18.87
21.14
13.87
18.75
19.78
3.61
18.17
7.54
7.29
1.64
8.15
7.04
4.41
$
$
The weighted average grant date fair value per share for restricted share and deferred share awards granted
during 2016, 2015 and during 2014 subsequent to the Spin-Off was $1.64, $3.61 and $21.14, respectively. The
weighted average grant date fair value per share for restricted stock and deferred stock awards granted in 2014 for
periods prior to the Spin-Off $100.43. The total fair value of restricted share and deferred share awards vested
during 2016, 2015 and 2014 for periods subsequent to the Spin-Off was $0.6 million, $0.9 million and $0.4 million,
respectively. The total fair value of restricted stock and deferred stock awards vested during 2014 for periods prior
to the Spin-Off was $2.7 million. At December 31, 2016, unrecognized compensation cost related to restricted share
and deferred share awards was $4.2 million, which is expected to be recognized over a weighted average period of
1.6 years.
120
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Phantom Share Awards
Each phantom share award is equal in value to one common share. Upon vesting, each recipient will receive a
lump sum cash payment equal to the fair market value of a common share on the respective vesting date. These
awards are accounted for as a liability that is remeasured at each reporting date until paid.
The following table presents the changes in phantom share awards outstanding and related information for our
employees during the years ended December 31, 2016, 2015 and 2014:
Awards Granted
under the Civeo
Plan
Awards Granted
under the
Canadian Long-
Term Incentive
Plan
Nonvested shares at May 30, 2014 ..........................................
Granted ...........................................................................
Vested .............................................................................
Forfeited .........................................................................
Nonvested shares at December 31, 2014 .................................
Granted ...........................................................................
Vested .............................................................................
Forfeited .........................................................................
Nonvested shares at December 31, 2015 .................................
Granted .............................................................................
Vested ...............................................................................
Forfeited ...........................................................................
Nonvested shares at December 31, 2016 .................................
--
--
--
--
--
517,145
--
(48,823)
468,322
3,732,763
(117,081)
(253,309)
3,830,695
565,706
10,077
(109,455)
(33,447)
432,881
1,403,306
(202,284)
(304,025)
1,329,878
3,099,194
(491,149)
(1,498,654)
2,439,269
At December 31, 2016, the balance of the liability for the phantom share awards was $4.1 million. For the
years ended December 31, 2016, 2015 and 2014, we made phantom share cash payments of $0.5 million, $0.8
million and $3.9 million, respectively. At December 31, 2016, unrecognized compensation cost related to phantom
shares was $9.7 million, as remeasured at December 31, 2016, which is expected to be recognized over a weighted
average period of 2.1 years. The weighted average grant date fair value of phantom shares granted during the years
ended December 31, 2016 and 2015 and the period from May 30, 2014 to December 31, 2014 was $0.91, $3.68 and
$23.17, respectively.
Performance Share Awards
On February 23, 2016, we granted 2,400,606 performance awards under the Civeo Plan, which cliff vest in
three years on February 23, 2019. These awards will be earned in amounts between 0% and 200% of the
participant’s target performance share award, based on the payout percentage associated with Civeo’s relative total
shareholder return (TSR) rank among a peer group of 12 other companies. Shareholder approval to grant these
awards as equity awards to be settled in shares was obtained on May 12, 2016. Accordingly, the awards are being
accounted for as equity awards, with a fair value of $3.18 calculated as of May 12, 2016.
The fair value of each performance award was estimated on the date of shareholder approval using a Monte
Carlo simulation pricing model that uses the assumptions noted in the following table. The risk-free interest rate is
based on the U.S. Treasury yield curve in effect for the expected term of the performance share at the time of grant.
The dividend yield on our common shares was assumed to be zero since we do not currently pay dividends. The
expected market price volatility of our common shares was based on an estimate that considers the historical and
implied volatility of our common shares as well as a peer group of companies over a time period equal to the
expected term of the option. The initial TSR performance was based on historical performance of our common
shares and the peer group’s common shares.
121
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Risk-free weighted interest rate ...........................
Expected volatility ..............................................
Initial TSR ...........................................................
0.92%
90.0%
93.7%
The following table presents the changes in performance awards outstanding and related information for our
employees during the year ended December 31, 2016:
Nonvested shares at December 31, 2015 .................................
Granted .............................................................................
Vested ...............................................................................
Forfeited ...........................................................................
Nonvested shares at December 31, 2016 .................................
Number of
Awards
--
2,400,606
--
(448,922)
1,951,684
$
Weighted
Average Grant
Date Fair Value
Per Share
--
3.18
--
3.18
3.18
$
During the year ended December 31 2016, we recognized compensation expense associated with performance
awards totaling $1.9 million. At December 31, 2016, unrecognized compensation cost related to performance
awards was $4.3 million, which is expected to be recognized over a weighted average period of 2.2 years.
16. SEGMENT AND RELATED INFORMATION
In accordance with current accounting standards regarding disclosures about segments of an enterprise and
related information, we have identified the following reportable segments: Canadian, Australian and U.S., which
represent our strategic focus on work force accommodations.
Financial information by business segment for each of the three years ended December 31, 2016, 2015 and
2014 is summarized in the following table (in thousands):
Total
Revenues
Less:
Intersegment
Revenues
Depreciation
and
amortization
2016
Canada ................................. $ 278,464
106,815
Australia ..............................
United States........................
11,951
Corporate, stand-alone
adjustments and
--
eliminations ...................
Total .............................. $ 397,230
2015
Canada ................................. $ 344,249
135,964
Australia ..............................
40,146
United States........................
Corporate, stand-alone
adjustments and
eliminations ...................
(2,396)
Total .............................. $ 517,963
2014
Canada ................................. $ 661,721
213,279
Australia ..............................
United States........................
123,328
Corporate, stand-alone
adjustments and
(55,437)
eliminations ...................
Total .............................. $ 942,891
$
$
$
$
$
$
Revenues
from
unaffiliated
customers
$ 278,464
106,815
11,951
--
$ 397,230
--
--
--
--
--
--
--
(2,396)
$ 344,249
135,964
37,750
2,396
--
--
$ 517,963
(305)
--
(55,132)
$ 661,416
213,279
68,196
55,437
--
--
$ 942,891
122
Operating
income
(loss)
$
(59,351)
(6,853)
(24,616)
$
$
(4,940)
(95,760)
(73,215)
(24,817)
(40,083)
80,837
45,883
5,433
(851)
131,302
89,269
51,392
11,833
496
152,990
(6,888)
$ (145,003)
91,893
62,924
20,281
$ 106,580
(155,851)
(86,959)
Capital
expenditures
Total
assets
$
$
$
$
$
3,773
5,682
6
$ 548,786
376,008
29,799
10,318
19,779
(44,147)
$ 910,446
41,446
12,160
2,170
6,675
62,451
$ 579,816
424,731
71,710
(9,728)
$ 1,066,529
218,620
24,907
10,901
$ 1,024,990
669,789
135,681
(128)
174,970
(6,661)
$ (142,891)
(3,270)
251,158
$
(1,299)
$ 1,829,161
$
$
$
$
$
$
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Financial information by geographic segment for each of the three years ended December 31, 2016, 2015 and
2014, is summarized below (in thousands). Revenues in the U.S. include export sales. Revenues are attributable to
countries based on the location of the entity selling the products or performing the services. Long-lived assets are
attributable to countries based on the physical location of the entity and its operating assets and do not include
intercompany balances.
2016
Revenues from unaffiliated customers ..............
Long-lived assets ..............................................
2015
Revenues from unaffiliated customers ..............
Long-lived assets ..............................................
2014
Revenues from unaffiliated customers ..............
Long-lived assets ..............................................
$
$
$
Canada
Australia
278,464
431,477
$ 106,815
348,293
344,249
532,419
$ 135,964
390,623
661,416
746,983
$ 213,279
519,777
17. RELATED PARTY TRANSACTIONS
U.S. and
Other
11,951
46,995
37,750
56,935
$
$
$
Total
$
$
397,230
826,765
517,963
979,977
68,196
96,120
$
942,891
1,362,880
Our related parties included Oil States until May 30, 2014, the effective date of the Spin-Off.
On May 27, 2014, in connection with the Spin-off, we entered into several agreements with Oil States that
govern the Spin-Off and the relationship of the parties following the Spin-Off. Because the terms of these
agreements were entered into in the context of a related party transaction, the terms may not be comparable to terms
that would be obtained in a transaction between unaffiliated parties.
The Separation and Distribution Agreement between us and Oil States contains the key provisions relating to
the separation of our business from Oil States and the distribution of our common stock to Oil States stockholders.
The Separation and Distribution Agreement identifies the assets that were transferred or sold, liabilities that were
assumed or sold and contracts that were assigned to us by Oil States or by us to Oil States in the Spin-Off and
describes how these transfers, sales, assumptions and assignments occurred. Pursuant to the Separation and
Distribution Agreement, on May 28, 2014, we made a cash distribution to Oil States of $750 million.
The Indemnification and Release Agreement governs the treatment of all aspects relating to indemnification,
insurance, litigation responsibility and management, and litigation document sharing and cooperation. Generally, the
Indemnification and Release Agreement provides for cross-indemnities principally designed to place financial
responsibility for the obligations and liabilities of our business with us and financial responsibility for the
obligations and liabilities of Oil States’ business with Oil States. The Indemnification and Release Agreement also
establishes procedures for handling claims subject to indemnification and related matters. Pursuant to the
Indemnification and Release Agreement, we and Oil States will generally release the other party from all claims
arising prior to the Spin-Off other than claims arising under the transaction agreements, including the
indemnification provisions described above. See Note 13 – Commitments and Contingencies.
The Tax Sharing Agreement governs the respective rights, responsibilities and obligations of Oil States and us
with respect to taxes and tax benefits, the filing of tax returns, the control of audits, restrictions on us to preserve the
tax-free status of the Spin-Off and other tax matters.
The Employee Matters Agreement provides that each company has responsibility for its own employees and
compensation plans. The agreement also contains provisions regarding share-based compensation. See Note 15 –
Share Based Compensation.
The Transition Services Agreement sets forth the terms on which Oil States provided to us, and we provided to
Oil States, on a temporary basis, certain services or functions that the companies historically have shared. Transition
123
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
services provided to us by Oil States included administrative, payroll, legal, human resources, data
processing, financial audit support, financial transaction support, and other support services, information technology
systems and various other corporate services. Transition services provided to Oil States by us included information
technology systems, financial audit support, tax support and other corporate services. The agreement provided for
the provision of specified transition services, generally for a period of up to nine months from the date of the Spin-
Off, with a possible extension of 1 month (an aggregate of 10 months) at a predetermined fee based on estimated
cost to Oil States. The Transition Services Agreement expired under the terms of the agreement on February 28,
2015. We incurred costs under the Transition Services Agreement totaling $0.3 million and $1.3 million during the
years ended December 31, 2015 and 2014, respectively.
Parent Company Services Provided and Corporate Allocations
Prior to the Spin-Off, Oil States provided services to and funded certain expenditures of Civeo. The most
significant of these services and expenditures were: (1) funding expenditures to settle domestic accounts payable; (2)
funding and processing of domestic payroll; (3) share-based compensation; and (4) certain transaction-related
expenditures. The consolidated financial statements of Civeo reflect these expenditures. During the year ended
December 31, 2014 $41.7 million of expenditures for services received from Oil States or funding for expenditures
provided by Oil States were included in the consolidated financial statements.
Prior to the Spin-Off, the consolidated statements of operations also include general corporate expense
allocations, which include costs incurred by Oil States for certain corporate functions such as executive
management, finance, information technology, tax, internal audit, risk management, legal, human resources and
treasury. During the year ended December 31, 2014 we were allocated $2.8 million, in respect of these corporate
expenses which are included within selling, general and administrative expenses in the accompanying consolidated
statements of operations.
Oil States Net Investment
Net transfers to Oil States are included within Oil States net investment on the consolidated balance sheets. The
components of the change in Oil States net investment for the year ended December 31, 2014 are as follows (in
thousands):
Cash transfers and general financing activities ........................
Services received or funding for expenditures ........................
Corporate allocations, including income tax provision (1) ......
Net increase in Oil States net investment .................................
$
$
2014
(13,255)
41,725
3,950
32,420
(1) Corporate allocations includes the general corporate expense allocations of $2.8 million for the year ended
December 31, 2014, the impact of the income tax provision, the allocation of corporate insurance premiums,
and the attribution of certain assets and liabilities that have historically been held at the Oil States corporate
level, but which are specifically identifiable or otherwise allocable to us. The attributed assets and liabilities are
included in Civeo’s consolidated balance sheets.
Supplemental Cash Flow Information
In accordance with the Separation and Distribution Agreement, our affiliate debt with Oil States, which totaled
approximately $336.8 million as of May 30, 2014, including accrued interest, was settled through a non-cash capital
contribution.
124
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
18. VALUATION ACCOUNTS
Activity in the valuation accounts was as follows (in thousands):
Balance at
Beginning
of Period
Charged to
Costs and
Expenses
Deductions
(Net of
Recoveries)
Translation
and Other,
Net
Balance
at End of
Period
Year Ended December 31, 2016:
Allowance for doubtful accounts
receivable ...........................................
$
1,121
$
(110)
$
(377)
$
4
$
638
Valuation allowance for deferred tax
assets..................................................
Year Ended December 31, 2015:
Allowance for doubtful accounts
115,087
15,051
(53,652)
(329)
76,157
receivable .....................................
$
4,043
$
1,004
$
(3,844)
$
(82)
$
1,121
Valuation allowance for deferred
tax assets ......................................
Year Ended December 31, 2014:
Allowance for doubtful accounts
49,523
70,095
--
(4,531)
115,087
receivable .....................................
$
3,656
$
503
$
(51)
$
(65)
$
4,043
Valuation allowance for deferred
tax assets ......................................
--
49,523
--
--
49,523
19. QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
The following table summarizes quarterly financial information for 2016 and 2015 (in thousands, except per
share amounts):
First
Quarter(2)
Second
Quarter(3)
Third
Quarter(4)
Fourth
Quarter(5)
2016
Revenues ............................................................ $
Gross profit(1) .....................................................
Net income (loss) attributable to Civeo ..............
Basic earnings (loss) per share ...........................
Diluted earnings (loss) per share ........................
95,036
29,093
(26,822)
(0.25)
(0.25)
2015
Revenues .............................
Gross profit(1) ......................
Net income attributable to Civeo ........................
Basic earnings per share ......
Diluted earnings per share ...
$ 170,987
68,076
(16)
0.00
0.00
$ 107,035
42,449
(11,486)
(0.11)
(0.11)
$ 143,147
53,723
(13,461)
(0.13)
(0.13)
$ 104,238
36,274
(42,131)
(0.39)
(0.39)
$ 106,544
36,793
(107,685)
(1.01)
(1.01)
$ 90,921
29,764
(15,949)
(0.15)
(0.15)
$ 97,285
31,758
(10,597)
(0.10)
(0.10)
(1) Represents "revenues" less "product costs" and "service and other costs" included in our consolidated
statements of operations.
(2)
In the first quarter of 2016, we recognized the following items:
(cid:2) Costs associated with our planned migration to Canada of $1.0 million ($0.7 million after-tax, or
$0.01 per diluted share), included in Selling, general and administrative expenses on the
accompanying consolidated statements of operations.
(cid:2) A charge of $8.4 million ($8.4 million after-tax, or $0.05 per diluted share), related to the
impairment of certain fixed assets which carrying value we determined not to be recoverable. The
charge, which is related to our U.S. segment, is included in Impairment expense on the
accompanying consolidated statements of operations.
125
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
In the first quarter of 2015, we recognized the following items:
(cid:2) Costs associated with our planned migration to Canada of $1.1 million ($0.8 million after-tax, or
$0.01 per diluted share), included in Selling, general and administrative expenses on the
consolidated statements of operations.
(cid:2) A loss of $3.8 million ($2.4 million after-tax, or $0.02 per diluted share) of which $1.1 million is
included in cost of sales and services and $2.7 million is included in impairment expense. This
charge relates to the decision to close a manufacturing facility in the United States. As a result, the
related assets were written down to their estimated sales proceeds, less costs to sell.
(3)
In the second quarter of 2016, we recognized the following items:
(cid:2) Costs associated with our migration to Canada of $0.2 million ($0.2 million after-tax, or $0.00 per
diluted share), included in Selling, general and administrative expenses on the accompanying
consolidated statements of operations.
In the second quarter of 2015, we recognized the following items:
(cid:2) A charge of $9.5 million ($6.6 million after-tax, or $0.06 per diluted share), related to the
impairment of certain fixed assets which carrying value we determined not to be recoverable. The
charge, which is related to our Australia segment, is included in Impairment expense on the
accompanying consolidated statements of operations.
(cid:2) Costs associated with our migration to Canada of $2.4 million ($1.6 million after-tax, or $0.02 per
diluted share), included in Selling, general and administrative expenses on the accompanying
consolidated statements of operations.
(4)
In the third quarter of 2016, we recognized the following items:
(cid:2) A charge of $37.7 million ($27.5 million after-tax, or $0.26 per diluted share), related to mobile
camp assets and certain undeveloped land positions in the British Columbia LNG market which
carrying value we determined not to be recoverable. The charge, which is related to our Canadian
segment, is included in Impairment expense on the accompanying consolidated statements of
operations.
In the third quarter of 2015, we recognized the following items:
(cid:2) Goodwill impairment losses of $43.2 million ($43.2 million after-tax, or $0.40 per diluted share),
which are related to our Canadian segment, and are included in Impairment expense on the
accompanying consolidated statements of operations.
(cid:2) Fixed asset and intangible asset impairment losses of $67.5 million ($46.9 million after-tax, or
$0.44 per diluted share), of which $20.5 million related to our U.S. segment, $24.0 million related
to our Australian segment and $23.0 million related to our Canadian segment, and is included in
Impairment expense on the accompanying consolidated statements of operations. The Canadian
segment included $11.9 million related to assets that should have been impaired in the fourth
quarter of 2014. We determined that the error was not material to our financial statements for the
year ended December 31, 2014 and therefore corrected the error in the third quarter of 2015.
(cid:2) Costs associated with our migration to Canada of $1.5 million ($1.0 million after-tax, or $0.01 per
diluted share), included in Selling, general and administrative expenses on the accompanying
consolidated statements of operations.
$1.5 million, or $0.01 per diluted share, of losses incurred on extinguishment of debt.
(cid:2)
(5)
In the fourth quarter of 2016, there were no significant items recognized.
In the fourth quarter of 2015, we recognized the following items:
(cid:2) Costs associated with our migration to Canada of $1.9 million ($1.2 million after-tax, or $0.01 per
diluted share), included in Selling, general and administrative expenses on the accompanying
consolidated statements of operations.
126
CIVEO CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
(cid:2) A foreign currency gain of $3.6 million that should have been recorded in the third quarter of
2015. We determined that the error was not material to our financial statements for the period
ended September 30, 2015 and therefore corrected the error in the fourth quarter of 2015.
Amounts are calculated independently for each of the quarters presented. Therefore, the sum of the quarterly
amounts may not equal the total calculated for the year.
20. SUBSEQUENT EVENTS
On February 7, 2017, we closed a public offering of 23,000,000 common shares at $3.00 per share. We expect to
use the net proceeds of $64.9 million from the offering to repay amounts outstanding under our revolving credit
facilities and for general corporate purposes.
On February 17, 2017, we amended our Amended Credit Facility. Please see Note 9 – Debt for further
information.
127
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Directors and Officers
Board of Directors
Executive Officers
Bradley J. Dodson
President and Chief Executive Officer
Frank C. Steininger
Senior Vice President,
Chief Financial Officer and Treasurer
Peter McCann
Senior Vice President, Australia
Allan D. Schoening
Senior Vice President, Human Resources
and Health, Safety and Environment
Douglas E. Swanson
Chairman of the Board
C. Ronald Blankenship
Director
Bradley J. Dodson
President and Chief Executive Officer
Martin A. Lambert
Director
Constance B. Moore
Director
Richard A. Navarre
Director
Charles Szalkowski
Director
Timothy O. Wall
Director
General Information
Auditors
Ernst & Young LLP
Houston, Texas
Transfer Agent
Computershare Investor Services Inc.
3rd Floor, 510 Burrard Street
Vancouver, BC V6C 3B9
800.564.6253 (North America)
514.982.7555 (International)
service@computershare.com
Legal Counsel
Baker Botts L.L.P.
Houston, Texas
Trading Information
New York Stock Exchange
Ticker Symbol: CVEO
Headquarters
333 Clay Street
Suite 4980
Houston, Texas 77002
Tel: 713.510.2400
Fax: 713.510.2499
www.civeo.com
Forward-looking Statements
The foregoing contains forward-looking statements within the meaning of the
Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934.
Forward-looking statements are those that do not state historical facts and are,
therefore, inherently subject to risks and uncertainties. The forward-looking state-
ments included herein include statements about Civeo’s: positioning for a recovery
in oil and gas and mining activity and a return to growth; hope that improved met
coal economics will precipitate mining activity and spending in the second half of
2017; characterization of the new LNG market in British Columbia as a significant
opportunity for accommodations; plan to install its EDI systems at its Wapasu
Creek location in 2017; and statements above under the heading “Looking Ahead.”
Those forward-looking statements are based on then current expectations and
entail various risks and uncertainties that could cause actual results to differ materially
from those expressed or implied by these forward-looking statements. Such risks
and uncertainties include, among other things, risks associated with the general
nature of the accommodations industry, risks associated with the level of supply
and demand for oil, coal, natural gas, iron ore and other minerals, including the
level of activity and developments in the Canadian oil sands, the level of demand
for coal and other natural resources from Australia, and fluctuations in the current
and future prices of oil, coal, natural gas, iron ore and other minerals, risks associated
with the Company’s migration to Canada, including, among other things, risks
associated with changes in tax laws or their interpretations, the ability to realize
the anticipated benefits thereof, the impact thereof on our relationships, including
with employees, customers, competitors, investors and other factors discussed
in the “Business” and “Risk Factors” sections of the Company’s annual report on
Form 10-K for the year ended December 31, 2016 and other reports the Company
may file from time to time with the Securities and Exchange Commission. Each
forward-looking statement contained herein speaks only as of the date of this
release. Except as required by law, the Company expressly disclaims any intention
or obligation to revise or update any forward-looking statements whether as a
result of new information, future events or otherwise.
Design: Savage Brands, Houston TX
333 Clay Street
Suite 4980
Houston, TX 77002
www.civeo.com