2016 Annual Report
OCEANEERING
AT A GLANCE
Oceaneering is a global provider of engineered
services and products, primarily to the offshore
oil and gas industry, with a focus on deepwater
applications. Through the use of its applied
technology expertise, Oceaneering also serves
the defense, aerospace and commercial theme
park industries. At the end of 2016, Oceaneering
employed approximately 9,300 people.
Remotely Operated
Vehicles
ROVs are submersible
vehicles teleoperated
by technicians from a
control van onboard
an offshore rig or
vessel. They are piloted
by microprocessor-
based control systems
through armored
electrical fiber-
optic umbilicals.
ROVs are the key
technology enabling
the performance of
critical oilfield tasks
in deepwater. These
tasks include drill
support, subsea
hardware installation
and construction,
subsea infrastructure
inspections and
surveys, and subsea
production facility
operation and
maintenance.
At the end of 2016,
we owned 280 ROVs,
and we estimate that
this represented
approximately 28% of
the industry’s work
class vehicles. We were
the primary provider
of these vehicles to
perform drill support
service, with an
estimated market
share of 53%.
Subsea
Products
Subsea
Projects
Asset
Integrity
Advanced
Technologies
We provide asset
integrity management,
corrosion management,
inspection and non-
destructive testing
services, principally
to the oil and gas,
power generation,
and petrochemical
industries. These
services are performed
on facilities onshore
and offshore, both
topside and subsea.
We provide engineering
services and related
manufacturing,
principally to the U.S.
Department of Defense,
NASA and its prime
contractors, and the
commercial theme
park industry. The U.S.
Navy is our largest
non-oilfield customer,
for whom we perform
work predominantly
on surface ships and
submarines.
We provide project
management, survey,
subsea installation
and inspection,
maintenance, and
repair services,
principally in the U.S.
Gulf of Mexico and
offshore Angola and
India. We service
deepwater projects
with dynamically
positioned vessels
that have our ROVs
onboard, and shallow
water projects with
our manned diving
operations, utilizing
dive support vessels
and saturation diving
systems.
We manufacture a
variety of specialty
subsea oilfield
products. These
encompass production
control umbilicals,
tooling and subsea
work systems,
installation workover
control systems
(“IWOCS”), and subsea
hardware. While
most of our subsea
products are sold, we
also rent tooling and
provide IWOCS and
subsea work systems
as a service, including
hydrate remediation,
well stimulation,
dredging and
decommissioning.
In 2016, we acquired
the assets of Blue
Ocean Technologies,
LLC, a privately
held provider of
riserless light well
intervention (“RLWI”)
services. Subsea well
intervention services
are intended to
maximize production
and increase the
recovery rate from
offshore oil and
gas reservoirs or,
alternatively, prepare
wells to be plugged and
abandoned.
Cover: Riserless light well intervention
being performed on a subsea tree.
Oceaneering International, Inc. 2016 LETTER TO
SHAREHOLDERS
2016 proved to be another challenging year for
Oceaneering and the offshore oilfield services industry.
Our income from operations substantially declined
compared to 2015. This was due to the continuation of
major reductions in activity levels and pricing across
all of our oilfield operating segments resulting from
the prolonged decline in crude oil prices that began in
mid-2014.
During 2016, we remained focused on organizing
more effectively, adjusted our cost structure to remain
profitable within all of our operating segments, and
continued to generate a substantial amount of free cash
flow (defined as cash provided by operating activities
less purchases of property and equipment, or organic
capital expenditures). We ended the year with a strong
balance sheet, which included $450 million in cash.
Additionally, we took steps to strengthen our liquidity as
our bank group extended 90% of our $300 million term
loan and our $500 million undrawn revolving credit
facility, each for an additional year.
In the face of difficult market conditions, we
demonstrated our commitment to deliver value to our
shareholders. In 2016, we continued to pay a quarterly
dividend, returning $94 million to our shareholders.
In 2017, we are likely to face a third consecutive year
of declining offshore activity for the oilfield services
industry. Our outlook is for a continued decline
in customer spending on deepwater drilling, field
development, and inspection, maintenance and
repair activities, due to the current and anticipated
oil price environment. As a result, we expect to be
marginally profitable at the operating income level on
a consolidated basis. At an operating income break-
even level, and anticipated organic capital expenditures
between $90 million and $120 million, we should still
generate a substantial amount of free cash flow in
2017. In response to the industry-wide conditions, we
intend to continue focusing on controlling our costs,
becoming more efficient and winning work to maintain
our market share.
Beyond 2017, with stable and improving oil prices,
we foresee an increase in offshore expenditures and
improving demand for our services and products.
We are leveraged to deepwater and, longer term,
deepwater is still expected to play a critical role in the
global supply growth required to replace depletion and
meet projected demand. Consequently, we intend to
expand our ability to participate in the offshore market
by continuing to invest in our current and adjacent
market niches, with more focus on our customers’
operating expenditures and the production phase of the
offshore oilfield life cycle.
I’d like to thank our employees and management team.
The last two years of this current cycle have been
challenging and stressful. Although we were forced to
make difficult decisions to adjust our business to be
leaner and more appropriately sized for the expected
level of activity, I am proud that our employees have
remained committed to delivering world-class safety
and superior operational performance every day. As we
continue to adapt and prepare for the eventual offshore
market upcycle, the same tenacity and creativity of our
people will enable us to continue delivering the high
levels of performance our customers expect, as well as
developing the services and products they need, all the
while creating the value our shareholders deserve.
This is my last shareholder letter, as I will be retiring as
Oceaneering’s CEO in 2017. I have been privileged to
be part of Oceaneering for the past 38 years and to have
worked with so many dedicated and talented people.
I plan to continue my affiliation with the company as
a member of the Board of Directors. Rod Larson,
who currently serves as Oceaneering’s President, has
been designated to succeed me as CEO. I am highly
confident we can count on Rod’s leadership, supported
by an exceptional management team, to continue to
drive safety and operational excellence, provide a great
place to work for our employees, and deliver value to
our customers and shareholders.
M. Kevin McEvoy
Chief Executive Officer
Annual Report 2016 2016 ANNUAL
REPORT ON
FORM 10-K
ENOVUS ROV installing
a flying lead.
Oceaneering International, Inc. UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2016
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from to
Commission file number 1-10945
____________________________________________
OCEANEERING INTERNATIONAL, INC.
(Exact name of registrant as specified in its charter)
Delaware
(State or other jurisdiction of
incorporation or organization)
11911 FM 529
Houston, Texas
(Address of principal executive offices)
95-2628227
(I.R.S. Employer
Identification No.)
77041
(Zip Code)
Registrant's telephone number, including area code: (713) 329-4500
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Name of each exchange on which registered
Common Stock, $0.25 par value
New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act:
None
____________________________________________
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Yes No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the
Act. Yes No
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required
to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes No
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every
Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter)
during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such
files). Yes No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is
not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. Yes No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a
smaller reporting company. See definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in
Rule 12b-2 of the Exchange Act.
Large accelerated filer
Accelerated filer
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
Aggregate market value of the voting stock held by nonaffiliates of the registrant computed by reference to the closing price of
$29.86 of the Common Stock on the New York Stock Exchange as of June 30, 2016, the last business day of the registrant's
most recently completed second quarter: $2.9 billion
Number of shares of Common Stock outstanding at February 17, 2017: 98,072,195.
Documents Incorporated by Reference:
Portions of the proxy statement relating to the registrant's 2017 annual meeting of shareholders, to be filed on or before
May 1, 2017 pursuant to Regulation 14A of the Securities Exchange Act of 1934, are incorporated by reference to the extent
set forth in Part III, Items 10-14 of this report.
Oceaneering International, Inc.
Form 10-K
Table of Contents
Business
Cautionary Statement Concerning Forward-Looking Statements
Executive Officers of the Registrant
Risk Factors
Unresolved Staff Comments
Properties
Legal Proceedings
Mine Safety Disclosures
Market for Registrant's Common Equity, Related Stockholder Matters and Issuer
Purchases of Equity Securities
Selected Financial Data
Management's Discussion and Analysis of Financial Condition and Results of
Operations
Quantitative and Qualitative Disclosures About Market Risk
Financial Statements and Supplementary Data
Changes in and Disagreements with Accountants on Accounting and Financial
Disclosure
Controls and Procedures
Other Information
Directors, Executive Officers and Corporate Governance
Executive Compensation
Security Ownership of Certain Beneficial Owners and Management and Related
Stockholder Matters
Certain Relationships and Related Transactions, and Director Independence
Principal Accounting Fees and Services
Exhibits, Financial Statement Schedules
Part I
Item 1.
Item 1A.
Item 1B.
Item 2.
Item 3.
Item 4.
Part II
Item 5.
Item 6.
Item 7.
Item 7A.
Item 8.
Item 9.
Item 9A.
Item 9B.
Part III
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
Part IV
Item 15.
Signatures
Index to Financial Statements and Schedules
Report of Independent Registered Public Accounting Firm
Consolidated Balance Sheets
Consolidated Statements of Income
Consolidated Statements of Comprehensive Income
Consolidated Statements of Cash Flows
Consolidated Statements of Shareholders' Equity
Notes to Consolidated Financial Statements
Selected Quarterly Financial Data (unaudited)
1
Item 1. Business.
GENERAL DEVELOPMENT OF BUSINESS
PART I
Oceaneering International, Inc. is a global oilfield provider of engineered services and products,
primarily to the offshore oil and gas industry, with a focus on deepwater applications. Oceaneering
also serves the defense, aerospace and commercial theme park industries. Oceaneering was
organized as a Delaware corporation in 1969 out of the combination of three diving service
companies founded in the early 1960s. Since our establishment, we have concentrated on the
development and marketing of underwater services and products to meet customer needs requiring
the use of advanced deepwater technology. We believe we are one of the world's largest underwater
services contractors. The services and products we provide to the oil and gas industry include
remotely operated vehicles, specialty subsea hardware, engineering and project management,
subsea intervention services, including manned diving, survey and positioning services and asset
integrity and nondestructive testing services. Our foreign operations, principally in the North Sea,
Africa, Brazil, Australia and Asia, accounted for approximately 57% of our revenue, or $1.3 billion,
for the year ended December 31, 2016.
Our business segments are contained within two businesses – services and products provided to the
oil and gas industry ("Oilfield") and all other services and products ("Advanced Technologies"). Our
four business segments within the Oilfield business are Remotely Operated Vehicles ("ROVs"),
Subsea Products, Subsea Projects and Asset Integrity. We report our Advanced Technologies
business as one segment. Unallocated Expenses are expenses not associated with a specific
business segment. These consist of expenses related to our incentive and deferred compensation
plans, including restricted stock and bonuses, as well as other general expenses.
Oilfield. The primary focus of our Oilfield business over the last several years has been toward
increasing our asset base and capabilities for providing services and products for deepwater offshore
operations and subsea completions. In more recent years we have focused on increasing our service
and product offerings toward our customers' operating expenses.
During the past ten years, we have acquired businesses to expand and complement our service and
product offerings. These include:
• a Canadian manufacturer of clamp connectors, check valves and universal ball joints;
• a Norwegian-based provider of inspection, maintenance, subsea engineering and field
operations services, principally to the oil and gas industry
• a Norwegian rental provider of specialized subsea dredging equipment, including ROV-
deployed units, to the offshore oil and gas industry;
• a Norwegian oilfield technology company specializing in providing subsea tooling services and
plugging, abandonment and decommissioning of offshore oil and gas production platforms
and subsea wellheads;
• a Norwegian design and fabrication company specializing in subsea tools for the offshore oil
and gas industry;
• a U.S.-based international provider of survey and positioning services;
• a business that uses ROVs to perform surveys on mobile offshore drilling units and floating
production systems that satisfy the underwater inspection in lieu of drydocking (UWILD)
requirements of all major classification societies; and
• the assets of a provider of riserless light well intervention services.
ROVs. We provide ROVs, which are tethered submersible vehicles remotely operated from the
surface, to customers in the oil and gas industry for drilling support and vessel-based services,
including subsea hardware installation, construction, pipeline inspection, survey and facilities
inspection, maintenance and repair. We design and build our new ROVs at in-house facilities, the
largest of which is in Morgan City, LA. In 2016, we manufactured and added 6 ROVs to our fleet and
retired 41. Our work-class ROV fleet size was 280 at December 31, 2016, 315 at December 31,
2015 and 336 at December 31, 2014. We have decreased our ROV fleet size over the last two years
as a result of lower market demand.
2
Subsea Products. We manufacture or assemble a variety of specialty subsea oilfield products. These
encompass production control umbilicals, tooling and subsea work systems, installation and
workover control systems ("IWOCS"), and subsea hardware.
While most of our products are sold, we also rent tooling and provide IWOCS and subsea work
systems as a service, including hydrate remediation, well stimulation, dredging and
decommissioning.
To improve operational efficiency, in 2016 we reorganized our Subsea Products segment into two
business units – (1) manufactured products and (2) service and rental. Manufactured products
include production control umbilicals and specialty subsea hardware, while service and rental
includes tooling, subsea work systems and installation and workover control systems, which we
design and build but operate as a service. This internal reorganization does not affect our segment
reporting structure or the historical comparability of our segment results.
We provide various types of subsea umbilicals through our Umbilical Solutions division from plants in
the United States, Scotland and Brazil. Offshore operators use umbilicals to control subsea wellhead
hydrocarbon flow rates, monitor downhole and wellhead conditions and perform chemical injection.
Subsea umbilicals are also used to provide power and fluids to other subsea processing hardware,
including pumps and gas separation equipment. We continue to invest in our plants to meet the
requirements of the deepwater operations of our customers.
Subsea Projects. Our Subsea Projects segment consists of our subsea installation, inspection,
maintenance and repair services, principally in the U.S. Gulf of Mexico and offshore Angola and
India, utilizing a fleet of two owned and three long-term chartered dynamically positioned deepwater
vessels with integrated high-specification work-class ROVs onboard, and four owned shallow water
diving vessels, spot-chartered vessels and other assets. All of our owned vessels are Jones Act-
compliant. The dynamically positioned vessels are equipped with thrusters that allow them to
maintain a constant position at a location without the use of anchors. They are used in the
inspection, maintenance and repair of subsea facilities, pipeline or flowline tie-ins, pipeline crossings
and installations. These vessels can carry and install equipment or umbilicals required to bring
subsea well completions into production (tie-back to production facilities).
Unless indicated otherwise, each of the chartered vessels discussed below is a deepwater
multiservice subsea support vessel outfitted with two of our high-specification work-class ROVs.
Beginning in the third quarter of 2008, we chartered a vessel, the Olympic Intervention IV, for an
initial term of five years. Following extension periods, the charter expired in July 2016, and we
released the vessel to its owner. We had been using the Olympic Intervention IV in the U.S. Gulf of
Mexico.
In 2012, we moved the chartered vessel Ocean Intervention III to Angola and also chartered the
Bourbon Oceanteam 101 to work on a three-year field support vessel services contract for a unit of
BP plc. We had extended the charter of the Bourbon Oceanteam 101 to January 2017. However, in
early 2016, the customer exercised its right, under the field support vessel services contract, to
terminate its use of the Bourbon Oceanteam 101 at the end of May 2016. Under the terms of the
contract, the costs incurred by us associated with the early release and demobilization of the vessel
were reimbursed by the customer. Following the release of the vessel, we redelivered it to the vessel
supplier. Under the field support vessel services contract, which has been extended through
January 2019, we are continuing to supply project management, engineering and the
Ocean Intervention III, which we have under charter on a month-to-month basis through July 2017.
We also provide ROV tooling, asset integrity services and installation and workover control system
services. We also have provided other chartered vessels and barges as requested by the customer.
In March 2013, we commenced a five-year charter for a Jones Act-compliant multi-service support
vessel, the Ocean Alliance, we have been using in the U.S. Gulf of Mexico. In January 2015, we
commenced a two-year contract with a customer for the use of the Ocean Alliance. The contract
expired in January 2017, and we are marketing the vessel for spot market work in the U.S. Gulf of
Mexico.
3
In December 2013, we commenced a three-year charter for the Normand Flower, a multi-service
subsea marine support vessel. We made modifications to the vessel and used the vessel in the U.S.
Gulf of Mexico to perform inspection, maintenance and repair projects and hardware installations. In
December 2016, we declined our option to extend the charter and the vessel was released.
In November 2015, we commenced a two-year charter for the use of the Island Pride, a multi-
service subsea marine support vessel. We are using the vessel under a two-year contract to provide
field support services off the coast of India for an oil and gas customer based in India. We have
options to extend the charter for up to two additional years.
We also charter or lease vessels on a short-term basis as necessary to augment our fleet.
In 2010, we acquired a vessel, which we renamed the Ocean Patriot, and we have converted it to a
dynamically positioned saturation diving and ROV service vessel. We installed a 12-man saturation
("SAT") diving system and one work-class ROV on the vessel, and we placed the vessel into service
in December 2011.
During the third quarter of 2013, we signed an agreement with a shipyard for the construction of a
subsea support vessel, to be named the Ocean Evolution. We expect delivery of that vessel in the
middle of 2017. We intend for the vessel to be U.S.-flagged and documented with a coastwise
endorsement by the U.S. Coast Guard. It is expected to have an overall length of 353 feet, a Class 2
dynamic positioning system, accommodations for 110 personnel, a helideck, a 250-ton active heave-
compensated crane, and a working moonpool. We expect to outfit the vessel with two of our high
specification work-class ROVs. The vessel will also be equipped with a satellite communications
system capable of transmitting streaming video for real-time work observation by shore personnel.
We anticipate the vessel will be used to augment our ability to provide subsea intervention services
in the ultra-deep waters of the U.S. Gulf of Mexico. These services are required to perform
inspection, maintenance and repair projects and hardware installations.
In 2015, we acquired C & C Technologies, Inc. ("C&C") for approximately $224 million. C&C is a
global provider of ocean-bottom mapping services in deepwater utilizing customized autonomous
underwater vehicles and provides marine construction surveys for both surface and subsea assets,
as well as satellite-based positioning services for drilling rigs and seismic and construction vessels.
C&C also provides land and near-shore survey services along the U.S. Gulf Coast and in Mexico, and
performs shallow water conventional geophysical surveys in the U.S. Gulf of Mexico.
In 2016, we acquired the assets of Blue Ocean Technologies, LLC, a privately held provider of
riserless light well intervention ("RLWI") services. Subsea well intervention services are intended to
maximize production and increase the recovery rate from offshore oil and gas reservoirs or,
alternatively, prepare wells to be plugged and abandoned. These RLWI systems have the capability
to perform a wide variety of cost-effective services for well interventions, including well diagnostics,
damaged well remediation and workovers, and well plugging and abandonment.
Asset Integrity. Through our Asset Integrity division, we provide asset integrity management,
corrosion management, inspection, and non-destructive testing services, principally to customers in
the oil and gas, power generation, and petrochemical industries. We perform these services on both
onshore and offshore facilities, both topside and subsea.
In December 2011, we purchased a Norwegian-based provider of inspection, maintenance, subsea
engineering and field operations services, principally to the oil and gas industry.
General. During the last five years, we have also made several small acquisitions to add
complementary technology or niche markets. We intend to continue our strategy of acquiring, as
opportunities arise, additional assets or businesses, to improve our market position or expand into
related service and product lines.
Advanced Technologies. Our Advanced Technologies provides engineering services and related
manufacturing, principally to the U.S. Department of Defense, NASA and its prime contractors, and
the commercial theme park industry.
4
FINANCIAL INFORMATION ABOUT SEGMENTS
For financial information about our business segments, please see the tables in Note 7 of the Notes
to Consolidated Financial Statements in this report, which present revenue, income from operations,
depreciation and amortization expense and capital expenditures for 2016, 2015 and 2014, and
identifiable assets, property and equipment and goodwill by business segment as of December 31,
2016 and 2015.
DESCRIPTION OF BUSINESS
Oilfield
Our Oilfield business consists of ROVs, Subsea Products, Subsea Projects and Asset Integrity.
ROVs. ROVs are tethered submersible vehicles remotely operated from the surface. We use our
ROVs in the offshore oil and gas industry to perform a variety of underwater tasks, including drill
support, vessel-based inspection, maintenance and repair, installation and construction support,
pipeline inspection and surveys, and subsea production facility operation and maintenance. Work-
class ROVs are outfitted with manipulators, sonar and video cameras, and can operate specialized
tooling packages and other equipment or features to facilitate the performance of specific
underwater tasks. At December 31, 2016, we owned 280 work-class ROVs. We believe we operate
the largest fleet of ROVs in the world. We also believe we are the industry leader in providing ROV
services for drill support, with an estimated 53% market share at the end of 2016.
ROV revenue:
2016
2015
2014
Amount
$
(in thousands)
522,121
807,723
1,069,022
Percent of Total
Revenue
23%
27%
29%
Subsea Products. We construct a variety of specialty subsea hardware to ISO 9001 quality
requirements. These products include:
• various types of subsea umbilicals utilizing thermoplastic hoses and steel tubes, along with
termination assemblies;
installation and workover control systems;
• tooling, ROV tooling and subsea work packages;
• production control equipment;
•
• clamp connectors;
• pipeline connector and repair systems;
• subsea and topside control valves; and
• subsea chemical injection valves.
We market these products under the trade names Oceaneering Umbilical Solutions, Oceaneering
Grayloc, Oceaneering Pipeline Connection & Repair Systems (PCRS) and Oceaneering Rotator.
Offshore well operators use subsea umbilicals and production control equipment to control subsea
wellhead hydrocarbon flow, monitor downhole and wellhead conditions and perform chemical
injection. They are also used to provide power and fluids to other subsea processing hardware,
including pumps and gas/oil separation equipment. ROV tooling provides an additional operational
interface between an ROV and permanently installed equipment located on the sea floor. Subsea
work packages facilitate well and associated equipment intervention for the purposes of flow
remediation and well stimulation.
Subsea Products revenue:
2016
2015
2014
Percent of Total
Revenue
30%
31%
34%
Amount
$
(in thousands)
692,030
959,714
1,238,746
5
Subsea Projects. We perform subsea oilfield hardware installation and inspection, maintenance and
repair services. We service deepwater projects with dynamically positioned vessels that typically
have Oceaneering ROVs onboard. We service shallow water projects with our manned diving
operation utilizing dive support vessels and saturation diving systems.
We perform subsea intervention and hardware installation services, principally in the U.S. Gulf of
Mexico, offshore Angola and offshore India from two owned and three chartered multiservice
deepwater vessels that have Oceaneering ROVs onboard. These services include: subsea well tie-
backs; pipeline/flowline tie-ins and repairs; pipeline crossings; umbilical and other subsea equipment
installations; subsea intervention; and inspection, maintenance and repair activities.
We provide ocean-bottom mapping services in deepwater, utilizing customized autonomous
underwater vehicles, as well as vessel-mounted and towed geophysical equipment. We also provide
marine construction surveys for both surface and subsea assets, as well as satellite-based
positioning services for drilling rigs and seismic and construction vessels.
We service oil and gas industry shallow water projects in the U.S. Gulf of Mexico and offshore Angola
with our manned diving operation utilizing the traditional diving techniques of air, mixed gas and
saturation diving, all of which use surface-supplied breathing gas. We supply our diving services
from four owned diving support vessels and other vessels and facilities. We do not use traditional
diving techniques in water depths greater than 1,000 feet.
Subsea Projects revenue:
2016
2015
2014
Amount
$
(in thousands)
472,979
604,484
588,572
Percent of Total
Revenue
21%
20%
16%
Asset Integrity. Through our Asset Integrity division, we offer a wide range of asset integrity services
to customers worldwide to help ensure the safety of their facilities onshore and offshore, while
reducing their unplanned maintenance and repair costs. We also provide third-party inspections to
satisfy contractual structural specifications, internal safety standards or regulatory requirements.
We provide these services principally to customers in the oil and gas, petrochemical and power
generation industries. In the U.K., we provide Independent Inspection Authority services for the oil
and gas industry, which includes first-pass integrity evaluation and assessment and nondestructive
testing services. We use a variety of technologies to perform pipeline inspections, both onshore and
offshore.
Asset Integrity revenue:
2016
2015
2014
Advanced Technologies
Amount
$
(in thousands)
275,397
372,957
500,237
Percent of Total
Revenue
12%
12%
14%
Our Advanced Technologies segment provides engineering services and products principally to the
U.S. Department of Defense, NASA and its contractors, and the commercial theme park industry. We
work with our customers to understand their specialized requirements, identify and mitigate risks,
and provide them value-added, maintainable, safe and certified solutions. The U.S. Navy is our
largest customer in this segment, for whom we perform work primarily on surface ships and
submarines.
We provide support for the U.S. Navy, including underwater operations, data analysis, development
of ocean-related computer software, and the design and development of new underwater tools and
systems. We also install and maintain mechanical systems for the Navy's submarines, surface ships,
offshore structures and moorings. We provide services and products to NASA and aerospace
contractors. Our U.S. Navy and NASA-related activities substantially depend on continued
government funding.
6
Advanced Technologies revenue:
Amount
Percent of Total
Revenue
2016
2015
2014
MARKETING
$
(in thousands)
309,076
317,876
263,047
14%
10%
7%
Oilfield. Oil and gas exploration and development expenditures fluctuate from year to year. In
particular, budgetary approval for more expensive drilling and production in deepwater, an area in
which we have a high degree of focus, may be postponed or suspended during periods when
exploration and production companies reduce their offshore capital spending. In more recent years,
we have focused on increasing our service and product offerings toward our customers' operating
expenses.
We market our ROVs, Subsea Products, Subsea Projects and Asset Integrity services and products to
domestic, international and foreign national oil and gas companies engaged in offshore exploration,
development and production. We also provide services and products as a subcontractor to other
oilfield service companies operating as prime contractors. Customers for these services typically
award contracts on a competitive-bid basis. These contracts are typically less than one year in
duration, although we enter into multi-year contracts from time to time.
In connection with the services we perform in our Oilfield business, we generally seek contracts that
compensate us on a dayrate basis. Under dayrate contracts, the contractor provides the ROV, vessel
or equipment and the required personnel to operate the unit and compensation is based on a rate
per day for each day the unit is used. The typical dayrate depends on market conditions, the nature
of the operations to be performed, the duration of the work, the equipment and services to be
provided, the geographical areas involved and other variables. Dayrate contracts may also contain
an alternate, lower dayrate that applies when a unit is moving to a new site or when operations are
interrupted or restricted by equipment breakdowns, adverse weather or water conditions or other
conditions beyond the contractor's control. Sales contracts for our products are generally for a fixed
price.
Advanced Technologies. We market our marine services and related engineering services to
government agencies, major defense contractors, NASA and NASA contractors, and to theme park
and other commercial customers outside the energy sector.
Major Customers. Our top five customers in 2016, 2015 and 2014 accounted for 43%, 38% and
40%, respectively, of our consolidated revenue. In 2016, four of our top five customers were oil and
gas exploration and production companies served by our Oilfield business segments, with the other
one being the U.S. Navy or other parts of the U.S. Government, which is served by our Advanced
Technologies segment. In 2015 and 2014, all of our top five customers were oil and gas exploration
and production companies served by our Oilfield business segments. During each of 2016, 2015 and
2014, revenue from one customer, BP plc and subsidiaries, accounted for 18% of our total
consolidated annual revenue.
While we do not depend on any one customer, the loss of one of our significant customers could, at
least on a short-term basis, have an adverse effect on our results of operations and cash flows.
RAW MATERIALS
Most of the raw materials we use in our manufacturing operations, such as steel in various forms,
copper, electronic components and plastics, are available from many sources. However, some
components we use to manufacture subsea umbilicals are available from limited sources. With the
exception of certain kinds of steel tube, where we are limited in the number of available suppliers,
we can offer alternative materials or technologies in many cases, which depends on the requisite
approval of our customers. While we have experienced some level of difficulty in obtaining certain
kinds of steel tube in the past due to global demand outstripping capacity, an increase in supplier
7
capacity, coupled with a drop in global demand, has resolved this issue, and we believe the situation
is unlikely to recur in the near future.
COMPETITION
Our businesses operate in highly competitive industry segments.
Oilfield
We are one of several companies that provide underwater services and specialty subsea hardware on
a worldwide basis. We compete for contracts with companies that have worldwide operations, as
well as numerous others operating locally in various areas. We believe that our ability to provide a
wide range of underwater services and products on a worldwide basis enables us to compete
effectively in all phases of the offshore oilfield life cycle. In some cases involving projects that
require less sophisticated equipment, small companies have been able to bid for contracts at prices
uneconomical to us. Additionally, in some jurisdictions we are subject to foreign governmental
regulations favoring or requiring the awarding of contracts to local contractors or requiring foreign
contractors to employ citizens of, or purchase supplies from, a particular jurisdiction. These
regulations may adversely affect our ability to compete.
ROVs. We believe we are the world's largest owner/operator of work-class ROVs employed in oil and
gas related operations. At December 31, 2016, we owned 280 work-class ROVs, and we estimate
that this represented approximately 28% of the work-class ROVs utilized in the oilfield service
industry. We compete with several major companies on a worldwide basis and with numerous others
operating locally in various areas.
Competition for ROV services historically has been based on equipment availability, location of or
ability to deploy the equipment, quality of service and price. The relative importance of these factors
can vary over time based on market conditions. The ability to develop improved equipment and
techniques and to train and retain skilled personnel is also an important competitive factor in our
markets. Demand for ROVs has been decreasing since mid 2014 due to the oil price environment,
and our margins have decreased in recent periods due to lower utilization and pricing pressure, as
price has become a more important factor in the current oil price environment.
Subsea Products. There are many competitors offering specialized products. We are one of several
companies that compete on a worldwide basis for the provision of thermoplastic and steel tube
subsea control umbilicals, and compared to current and forecasted market demand, we are faced
with overcapacity in the umbilical manufacturing market.
Subsea Projects. We perform subsea intervention and hardware installation services, principally in
the U.S. Gulf of Mexico and offshore Angola and India, from two owned and three chartered
multiservice deepwater vessels. We are one of many companies that offer these services. In
general, our competitors can move their vessels to where we operate from other locations with
relative ease. We also have many competitors that supply commercial diving services to the oil and
gas industry in the U.S. Gulf of Mexico. Our survey and positioning services are similarly
competitive.
Asset Integrity. The worldwide asset integrity and inspection markets consist of a wide range of
inspection and certification requirements in many industries. We compete in only selected portions
of this market. We believe that our broad geographic sales and operational coverage, long history of
operations, technical reputation, application of various pipeline inspection technologies and
accreditation to international quality standards enable us to compete effectively in our selected asset
integrity and inspection services market segments.
8
Advanced Technologies
Engineering services is a very broad market with a large number of competitors. We compete in
specialized areas in which we can combine our extensive program management experience,
mechanical engineering expertise and the capability to continue the development of conceptual
project designs into the manufacture of custom equipment for customers.
SEASONALITY AND BACKLOG
We generate a material amount of our consolidated revenue from contracts for services in the U.S.
Gulf of Mexico in our Subsea Projects segment, which is usually more active in the second and third
quarters, as compared to the rest of the year. The European operations of our Asset Integrity
segment are also seasonally more active in the second and third quarters. Revenue in our ROV
segment is subject to seasonal variations in demand, with our first quarter generally being the low
quarter of the year. The level of our ROV seasonality depends on the number of ROVs we have
engaged in vessel-based subsea infrastructure inspection, maintenance, repair and installation,
which is more seasonal than drilling support. Revenue in each of our Subsea Products and Advanced
Technologies segments has generally not been seasonal.
The amounts of backlog orders we believed to be firm as of December 31, 2016 and 2015 were as
follows (in millions):
Oilfield
ROVs
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Total
As of December 31, 2016
As of December 31, 2015
Total
1+ yr*
Total
1+ yr*
$
$
498 $
431
149
280
1,358
195
1,553 $
263 $
91
—
124
478
29
507 $
890 $
652
376
427
2,345
170
2,515 $
459
189
46
211
905
39
944
*
Represents amounts that were not expected to be performed within one year.
No material portion of our business is subject to renegotiation of profits or termination of contracts
by the U.S. government.
PATENTS AND LICENSES
We currently hold numerous of U.S. and foreign patents and pending patent applications. We have
acquired patents and licenses and granted licenses to others when we have considered it
advantageous for us to do so. Although in the aggregate our patents and licenses are important to
us, we do not regard any single patent or license or group of related patents or licenses as critical or
essential to our business as a whole. In general, we depend on our technological capabilities and the
application of know-how rather than patents and licenses in the conduct of our operations.
REGULATION
Our operations are affected from time to time and in varying degrees by foreign and domestic
political developments and foreign, federal and local laws and regulations, including those relating
to:
• operating from and around offshore drilling, production and marine facilities;
• national preference for local equipment and personnel;
9
• marine vessel safety;
• protection of the environment;
• workplace health and safety;
• taxation of earnings;
•
• currency conversion and repatriation.
license requirements for exportation of our equipment and technology; and
In addition, our Oilfield business depends on the demand for our services and products from the oil
and gas industry and, therefore, is affected by changing taxes, price controls and other laws and
regulations relating to the oil and gas industry generally. The adoption of laws and regulations
curtailing offshore exploration and development drilling for oil and gas for economic and other policy
reasons would adversely affect our operations by limiting demand for our services. We cannot
determine the extent to which new legislation, new regulations or changes in existing laws or
regulations may affect our future operations.
Our operations and properties are subject to a wide variety of increasingly complex and stringent
foreign, federal, state and local environmental laws and regulations, including those governing
discharges into the air and water, the handling and disposal of solid and hazardous wastes, the
remediation of soil and groundwater contaminated by hazardous substances and the health and
safety of employees. Sanctions for noncompliance may include revocation of permits, corrective
action orders, administrative or civil penalties and criminal prosecution. Some environmental laws
provide for strict, joint and several liability for remediation of spills and other releases of hazardous
substances, as well as damage to natural resources. In addition, companies may be subject to
claims alleging personal injury or property damage as a result of alleged exposure to hazardous
substances. These laws and regulations may also expose us to liability for the conduct of or
conditions caused by others, or for our acts that were in compliance with all applicable laws at the
time such acts were performed.
Environmental laws and regulations that apply to our operations include the Comprehensive
Environmental Response, Compensation, and Liability Act of 1980, the Clean Air Act, the Clean Water
Act, the Resource Conservation and Recovery Act (each, as amended) and similar laws that provide
for responses to, and liability for, releases of hazardous substances into the environment.
Environmental laws and regulations also include similar foreign, state or local counterparts to the
above-mentioned federal laws, which regulate air emissions, water discharges, hazardous substances
and waste, and require public disclosure related to the use of various hazardous substances. Our
operations are also governed by laws and regulations relating to workplace safety and worker health,
primarily, in the United States, the Occupational Safety and Health Act and regulations promulgated
thereunder.
Compliance with federal, state and local provisions regulating the discharge of materials into the
environment or relating to the protection of the environment has not had a material impact on our
capital expenditures, earnings or competitive position. We cannot predict all of the environmental
requirements or circumstances that will exist in the future but anticipate that environmental control
and protection standards will become increasingly stringent and costly. Based on our experience to
date, we do not currently anticipate any material adverse effect on our business or consolidated
financial position, results of operations or cash flows as a result of future compliance with existing
environmental laws and regulations. However, future events, such as changes in existing laws and
regulations or their interpretation, more vigorous enforcement policies of regulatory agencies, or
stricter or different interpretations of existing laws and regulations, may require additional
expenditures by us, which may be material. Accordingly, there can be no assurance that we will not
incur significant environmental compliance costs in the future.
Our quality management systems are registered as being in conformance with ISO 9001:2000 and
cover:
• all our Oilfield services and products in the United Kingdom and Norway;
• our Remotely Operated Vehicle operations in the U.S. Gulf of Mexico, Brazil, Canada, the
Middle East, Australia and Asia;
• our Asset Integrity operations in the Western Hemisphere, the Middle East, Australia and
Indonesia;
10
• our Subsea Projects operations, except for shallow water diving;
• our Subsea Products segment; and
• the Oceaneering Space Systems, Oceaneering Technologies, Entertainment and Marine
Services units of our Advanced Technologies segment.
ISO 9001 is an internationally recognized system for quality management established by the
International Standards Organization, and the 2000 edition emphasizes customer satisfaction and
continual improvement.
EMPLOYEES
As of December 31, 2016, we had approximately 9,300 employees. Taking into account reductions
in workforce we announced in 2016 to take effect in 2017, we would have approximately 8,800
employees. Our workforce varies seasonally and peaks during the second and third quarters. We
consider our relations with our employees to be satisfactory.
FINANCIAL INFORMATION ABOUT GEOGRAPHIC AREAS
For financial information about our geographic areas of operation, please see the tables in Note 7 of
the Notes to Consolidated Financial Statements in this report, which present revenue for 2016, 2015
and 2014 and long-lived assets as of December 31, 2016 and 2015 attributable to each of our major
geographic areas. For a discussion of risks attendant to our foreign operations, see the discussion in
Item 1A, "Risk Factors" under the heading "Our international operations involve additional risks not
associated with domestic operations."
CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS
We are including the following discussion to inform our existing and potential security holders
generally of some of the risks and uncertainties that can affect our company and to take advantage
of the "safe harbor" protection for forward-looking statements that applicable federal securities law
affords.
From time to time, our management or persons acting on our behalf make forward-looking
statements to inform existing and potential security holders about our company. These statements
may include projections and estimates concerning the timing and success of specific projects and our
future orders, revenue, income and capital spending. Forward-looking statements are generally
accompanied by words such as "estimate," "plan," "project," "predict," "believe," "expect,"
"anticipate," "plan," "forecast," "budget," "goal," "may," "should," or other words that convey the
uncertainty of future events or outcomes. In addition, sometimes we will specifically describe a
statement as being a forward-looking statement and refer to this cautionary statement.
In addition, various statements this report contains, including those that express a belief,
expectation or intention are forward-looking statements. Those forward-looking statements appear
in Part I of this report in Item 1 – "Business," Item 2 – "Properties" and Item 3 – "Legal Proceedings"
and in Part II of this report in Item 7 – "Management's Discussion and Analysis of Financial Condition
and Results of Operations," Item 7A – "Quantitative and Qualitative Disclosures About Market Risk"
and in the Notes to Consolidated Financial Statements incorporated into Item 8 and elsewhere in this
report. These forward-looking statements speak only as of the date of this report, we disclaim any
obligation to update these statements, and we caution you not to rely unduly on them. We have
based these forward-looking statements on our current expectations and assumptions about future
events. While our management considers these expectations and assumptions to be reasonable,
they are inherently subject to significant business, economic, competitive, regulatory and other
risks, contingencies and uncertainties, most of which are difficult to predict and many of which are
beyond our control. These risks, contingencies and uncertainties relate to, among other matters, the
following:
• worldwide demand for and prices of oil and gas;
• changes in, or our ability to comply with, government regulations, including those relating to
the environment;
• the continued availability of qualified personnel;
11
• general economic and business conditions and industry trends;
• the volatility and uncertainties of credit markets;
• the highly competitive nature of our businesses;
• decisions about offshore developments to be made by oil and gas exploration, development
and production companies;
• cancellations of contracts, change orders and other contractual modifications and the
resulting adjustments to our backlog;
• collections from our customers;
• the use of subsea completions and our ability to capture associated market share;
• the strength of the industry segments in which we are involved;
• the levels of oil and gas production to be processed by the Medusa field production spar
platform;
• our future financial performance, including availability, terms and deployment of capital;
• the consequences of significant changes in currency exchange rates;
• changes in tax laws, regulations and interpretation by taxing authorities;
• our ability to obtain raw materials and parts on a timely basis and, in some cases, from
limited sources;
• operating risks normally incident to offshore exploration, development and production
operations;
• hurricanes and other adverse weather and sea conditions;
• cost and time associated with drydocking of our vessels;
• adverse outcomes from legal or regulatory proceedings;
• the risks associated with integrating businesses we acquire;
• rapid technological changes; and
• social, political, military and economic situations in foreign countries where we do business
and the possibilities of civil disturbances, war, other armed conflicts or terrorist attacks.
We believe the items we have outlined above are important factors that could cause our actual
results to differ materially from those expressed in a forward-looking statement made in this report
or elsewhere by us or on our behalf. We have discussed most of these factors in more detail
elsewhere in this report. These factors are not necessarily all the factors that could affect us.
Unpredictable or unanticipated factors we have not discussed in this report could also have material
adverse effects on actual results of matters that are the subject of our forward-looking statements.
We do not intend to update our description of important factors each time a potential important
factor arises. We advise our security holders that they should (1) be aware that important factors
we do not refer to above could affect the accuracy of our forward-looking statements and (2) use
caution and common sense when considering our forward-looking statements.
AVAILABLE INFORMATION
Our Web site address is www.oceaneering.com. We make available through this Web site under
"Investor Relations — SEC Financial Reports," free of charge, our annual reports on Form 10-K,
quarterly reports on Form 10-Q, current reports on Form 8-K, amendments to those reports and
Section 16 filings by our directors and executive officers as soon as reasonably practicable after we,
or our executive officers or directors, as the case may be, electronically file those materials with, or
furnish those materials to, the SEC. You may read and copy any materials we file with the SEC at
the SEC's Public Reference Room at 100 F Street, NE, Washington, DC 20549. You may obtain
information regarding the Public Reference Room by calling the SEC at 1-800-SEC-0330. In addition,
the SEC maintains a Web site, www.sec.gov, which contains reports, proxy and other information
statements, and other information regarding issuers that file electronically with the SEC.
We have adopted, and posted on our Web site: our corporate governance guidelines; a code of ethics
for our Chief Executive Officer and Senior Financial Officers; and charters for the Audit, Nominating
and Corporate Governance and Compensation Committees of our Board of Directors.
12
EXECUTIVE OFFICERS OF THE REGISTRANT
Executive Officers. The following information relates to our executive officers as of February 17,
2017:
NAME
M. Kevin McEvoy
Roderick A. Larson
Clyde W. Hewlett
Alan R. Curtis
W. Cardon Gerner
David K. Lawrence
Stephen P. Barrett
William J. Boyle
John R. Kreider
Martin J. McDonald
AGE POSITION
66 Chief Executive Officer and Director
50 President
62 Chief Operating Officer
51 Senior Vice President and Chief Financial Officer
62 Senior Vice President and Chief Accounting Officer
57 Senior Vice President, General Counsel and Secretary
59 Senior Vice President, Business Development
55 Senior Vice President, Asset Integrity
65 Senior Vice President, Advanced Technologies
53 Senior Vice President, Remotely Operated Vehicles
OFFICER
SINCE
1990
2012
2004
2014
2006
2012
2015
2016
2001
2016
EMPLOYEE
SINCE
1979
2012
1988
1995
2006
2005
2015
2016
1992
1989
Each executive officer serves at the discretion of our Chief Executive Officer and our Board of
Directors and is subject to reelection or reappointment each year after the annual meeting of our
shareholders. We do not know of any arrangement or understanding between any of the above
persons and any other person or persons pursuant to which he was selected or appointed as an
officer.
Business Experience. The following summarizes the business experience of our executive officers.
Except where we otherwise indicate, each of these persons has held his current position with
Oceaneering for at least the past five years.
M. Kevin McEvoy, Chief Executive Officer, joined Oceaneering in 1984 when we acquired Solus Ocean
Systems, Inc. Since 1984, he has held various senior management positions in each of our
operating groups. He was appointed a Vice President in 1990, a Senior Vice President in 1998,
Executive Vice President in 2006 and to the additional office of Chief Operating Officer in
February 2010, and became President and Chief Executive Officer and a director of Oceaneering in
May 2011.
Roderick A. Larson joined Oceaneering in May 2012 as Senior Vice President and Chief Operating
Officer and became President in February 2015. Mr. Larson previously held positions with Baker
Hughes Incorporated from 1990 until he joined Oceaneering, serving most recently as President,
Latin America Region from January 2011. Previously, he served as Vice President of Operations, Gulf
of Mexico Region from 2009 to 2011, Gulf Coast Area Manager from 2007 to 2009, and Special
Projects Leader Technical Training Task from 2006 to 2007.
Clyde W. Hewlett, Chief Operating Officer, has extensive experience in the offshore and subsea
oilfield markets. He joined Oceaneering in 1988 and has held increasingly responsible positions. He
has served as our Vice President of Mobile Offshore Production Systems, Vice President of Subsea
Projects, Senior Vice President of Subsea Projects and Senior Vice President, Subsea Services. He
was promoted to his current position in August 2015.
Alan R. Curtis, Senior Vice President and Chief Financial Officer, joined Oceaneering in 1995 as the
Financial and Operations Controller for our Subsea Products segment, and became Vice President
and Controller of Subsea Products in 2013 and Senior Vice President, Operations Support in 2014.
He was appointed to his current position in August 2015. He is a Certified Public Accountant and
Chartered Global Management Accountant.
W. Cardon Gerner, Senior Vice President and Chief Accounting Officer, joined Oceaneering in 2006 as
Vice President and Chief Accounting Officer, and became a Senior Vice President in August 2011 and
served as our Chief Financial Officer from that date until August 2015. From 1999 to 2006, he held
13
various financial positions with Service Corporation International, a global provider of death-care
services, serving as Vice President Accounting from 2002 to 2006. He also served as Senior Vice
President and Chief Financial Officer of Equity Corporation International from 1995 to 1999. He is a
Certified Public Accountant.
David K. Lawrence, Senior Vice President, General Counsel and Secretary, joined Oceaneering in
2005 as Assistant General Counsel. He was appointed Associate General Counsel effective
January 2011, Vice President, General Counsel and Secretary in January 2012 and to his current
position in February 2014. He has over 20 years experience as in-house counsel in the oilfield
services and products industry and manufacturing.
Stephen P. Barrett, Senior Vice President, Business Development, joined Oceaneering in July 2015 as
Senior Vice President, Subsea Products. He was appointed to his current position in November 2016.
Prior to joining Oceaneering, he served at FMC Technologies beginning in 1982, progressing through
a variety of engineering, sales and marketing, and general management roles. His last three roles at
FMC Technologies were Western Region Subsea General Manager, Global Subsea Products Director
and Global Subsea Services Director.
William J. Boyle, Senior Vice President, Asset Integrity, joined Oceaneering in March 2016. Prior to
joining Oceaneering, Mr. Boyle held the position of Chief Executive Officer with Underwater Integrity
Solutions from November 2014 until December 2015. Previously, Mr. Boyle held senior leadership
positions at Forum Energy Technologies, Inc. from 2013 to 2014, Clough Limited from 2008 to 2012,
Subsea 7 S.A. from 2005 to 2008, John Wood Group PLC from 2003 to 2005 and Technip S.A. from
1991 to 2003.
John R. Kreider, Senior Vice President, Advanced Technologies, joined Oceaneering as a Vice
President in 1992 when we acquired Eastport International, Inc. Since 1992, he has held various
senior management positions in our Advanced Technologies segment. He was appointed Senior Vice
President, Advanced Technologies in October 2001.
Martin J. McDonald, Senior Vice President, Remotely Operated Vehicles, joined Oceaneering in 1989.
He has held a variety of domestic and international positions of increasing responsibility in our ROV
segment and most recently served as Vice President and General Manager for our ROV operations in
the Eastern Hemisphere from 2006 until being appointed to his current position effective
January 2016.
14
Item 1A. Risk Factors.
We are subject to various risks and uncertainties in the course of our business. The following
summarizes significant risks and uncertainties that may materially and adversely affect our business,
financial condition, results of operations or cash flows and the market value of our securities.
Investors in our company should consider these matters, in addition to the other information we
have provided in this report and the documents we incorporate by reference.
We derive most of our revenue from companies in the offshore oil and gas industry, a
historically cyclical industry with levels of activity that are significantly affected by the
levels and volatility of oil and gas prices.
We derive most of our revenue from customers in the offshore oil and gas exploration, development
and production industry. The offshore oil and gas industry is a historically cyclical industry
characterized by significant changes in the levels of exploration and development activities. Oil and
gas prices, and market expectations of potential changes in those prices, significantly affect the
levels of those activities. Worldwide political, economic and military events have contributed to oil
and gas price volatility and are likely to continue to do so in the future. Since the general decline in
the price of oil from mid 2014, many oil and gas companies made significant reductions in their
capital and operating expenditures, which are adversely impacting demand for the services and
products provided by our Oilfield business. Any prolonged reduction in the overall level of offshore
oil and gas exploration and development activities, whether resulting from changes in oil and gas
prices or otherwise, could materially and adversely affect our financial condition and results of
operations in our segments within our Oilfield business. Some factors that have affected and are
likely to continue affecting oil and gas prices and the level of demand for our services and products
include the following:
• worldwide demand for oil and gas;
• general economic and business conditions and industry trends;
• the ability of the Organization of Petroleum Exporting Countries, or OPEC, to set and maintain
production levels;
• the level of production by non-OPEC countries, including U.S. shale oil;
• the ability of oil and gas companies to generate funds for capital expenditures;
• domestic and foreign tax policy;
•
laws and governmental regulations that restrict exploration and development of oil and gas in
various offshore jurisdictions;
• technological changes;
• the political environment of oil-producing regions;
• the price and availability of alternative fuels; and
• overall economic conditions.
Our operations could be adversely impacted by the effects of new regulations.
During 2010, the U.S. government established new regulations relating to the design of wells and
testing of the integrity of wellbores, the use of drilling fluids, the functionality and testing of well
control equipment, including blowout preventers, and other safety and environmental regulations.
The U.S. government is requiring that operators demonstrate their compliance with those regulations
before commencing deepwater drilling operations. Changes in laws or regulations regarding offshore
oil and gas exploration and development activities, the cost or availability of insurance and the
impacts of these factors on decisions by customers or other industry participants could further
reduce demand for our services, which would have a negative impact on our operations.
15
Our international operations involve additional risks not associated with domestic
operations.
A significant portion of our revenue is attributable to operations in foreign countries. These activities
accounted for approximately 57% of our consolidated revenue in 2016. Risks associated with our
operations in foreign areas include risks of:
• regional and global economic downturns;
• disturbances or other risks that may limit or disrupt markets;
• expropriation, confiscation or nationalization of assets;
• renegotiation or nullification of existing contracts;
• foreign exchange restrictions;
• foreign currency fluctuations, particularly in countries highly dependent on oil revenue;
• foreign taxation, including the application and interpretation of tax laws;
• the inability to repatriate earnings or capital;
• changing political conditions;
• changing foreign and domestic monetary policies; and
• social, political, military and economic situations in foreign areas where we do business and
the possibilities of civil disturbances, war, other armed conflict, terrorist attacks or acts of
piracy.
Additionally, in some jurisdictions we are subject to foreign governmental regulations favoring or
requiring the awarding of contracts to local contractors or requiring foreign contractors to employ
citizens of, or purchase supplies from, a particular jurisdiction. These regulations may adversely
affect our ability to compete.
Our exposure to the risks we described above varies from country to country. In recent periods,
economic conditions, political instability and civil unrest in Africa have been our greatest concerns.
There is a risk that a continuation or worsening of these conditions could materially and adversely
impact our future business, operations, financial condition and results of operations. Of our total
consolidated revenue for 2016, we generated approximately 21% from our operations in Africa,
primarily in Angola.
Foreign exchange risks and fluctuations may affect our profitability on certain projects.
We operate on a worldwide basis with substantial operations outside the U.S. that subject us to U.S.
dollar translation and economic risks. In order to manage some of the risks associated with foreign
currency exchange rates, we may enter into foreign currency derivative (hedging) instruments,
especially when there is currency risk exposure that is not naturally mitigated via our contracts.
However, these actions may not always eliminate all currency risk exposure, in particular for our
long-term contracts. A disruption in the foreign currency markets, including the markets with
respect to any particular currencies, could adversely affect our hedging instruments and subject us
to additional currency risk exposure. Based on fluctuations in currency, the U.S. dollar value of our
backlog may from time to time increase or decrease significantly. We do not enter into derivative
instruments for trading or other speculative purposes. Our operational cash flows and cash
balances, though predominately held in U.S. dollars, may consist of different currencies at various
points in time in order to execute our contracts globally. Non-U.S. asset and liability balances are
subject to currency fluctuations when measured period to period for financial reporting purposes in
U.S. dollars.
Our backlog is subject to unexpected adjustments and cancellations and is, therefore, an
uncertain indicator of our future revenues and earnings.
There can be no assurance that the revenues included in our backlog will be realized or, if realized,
will result in profits. Because of project cancellations or potential changes in the scope or schedule
of our customers' projects, we cannot predict with certainty when or if backlog will be realized.
Material delays, suspensions, cancellations or payment defaults could materially affect our financial
condition, results of operations and cash flows. We may be at greater risk of delays, suspensions
and cancellations in the current oil price environment.
16
Reductions in our backlog due to cancellation by a customer or for other reasons would adversely
affect, potentially to a material extent, the revenues and earnings we actually receive from contracts
included in our backlog. Many of our ROV contracts have 30-day notice termination clauses. Some
of the contracts in our backlog provide for cancellation fees in the event customers cancel projects.
These cancellation fees usually provide for reimbursement of our out-of-pocket costs, revenues for
work performed prior to cancellation and a varying percentage of the profits we would have realized
had the contract been completed. We typically have no contractual right upon cancellation to the
total contract revenues as reflected in our backlog. If we experience significant project terminations,
suspensions or scope adjustments to contracts reflected in our backlog, our financial condition,
results of operations and cash flows may be adversely impacted.
A global financial crisis could impact our business and financial condition in ways that we
currently cannot predict.
A recurrence of the credit crisis and related turmoil in the global financial system that occurred in
2008 and 2009 could have an impact on our business and our financial condition. In particular, the
cost of capital increased substantially while the availability of funds from the capital markets
diminished significantly. Although the capital markets have recovered, in a recurrence, our ability to
access the capital markets in the future could be restricted or be available only on terms we do not
consider favorable. Limited access to the capital markets could adversely impact our ability to take
advantage of business opportunities or react to changing economic and business conditions and
could adversely impact our ability to continue our growth strategy. Ultimately, we could be required
to reduce our future capital expenditures substantially. Such a reduction could have a material
adverse effect on our business and our consolidated financial condition, results of operations and
cash flows. A recurrence of such a global financial crisis could have further impacts on our business
that we currently cannot predict or anticipate.
A global financial crisis or economic recession could have an impact on our suppliers and our
customers, causing them to fail to meet their obligations to us, which could have a material adverse
effect on our revenue, income from operations and cash flows.
If one or more of the lenders under our revolving credit facility were to become unable or unwilling
to perform their obligations under that facility, our borrowing capacity could be reduced. Our
inability to borrow under our revolving credit facility could limit our ability to fund our future
operations and growth.
In addition, we maintain our cash balances and short-term investments in accounts held by major
banks and financial institutions located principally in North America, Europe, Africa and Asia, and
some of those accounts hold deposits that exceed available insurance. It is possible that one or
more of the financial institutions in which we hold our cash and investments could become subject to
bankruptcy, receivership or similar proceedings. As a result, we could be at risk of not being able to
access material amounts of our cash, which could result in a temporary liquidity crisis that could
impede our ability to fund operations.
Employee, agent or partner misconduct or our overall failure to comply with laws or
regulations could weaken our ability to win contracts, which could result in reduced revenues
and profits.
Misconduct, fraud, non-compliance with applicable laws and regulations, or other improper activities
by one or more of our employees, agents or partners could have a significant negative impact on our
business and reputation. Such misconduct could include the failure to comply with the U.S. Foreign
Corrupt Practices Act ("FCPA"), which prohibits companies and their intermediaries from making
improper payments to non-U.S. officials, as well as the failure to comply with government
procurement regulations, regulations on lobbying or similar activities, regulations pertaining to the
internal controls over financial reporting and various other applicable laws or regulations, including
the U.K. Bribery Act. We operate in some countries that international corruption monitoring groups
have identified as having high levels of corruption. Our activities create the risk of unauthorized
payments or offers of payments by one of our employees or agents that could be in violation of the
FCPA or other applicable anti-corruption laws. The precautions we take to prevent and detect
misconduct, fraud or non-compliance with applicable laws and regulations may not be effective, and
17
we could face unknown risks or losses. Our failure to comply with applicable laws or regulations or
acts of misconduct could subject us to fines, penalties or other sanctions, which could have a
material adverse effect on our business and our consolidated financial condition, results of operations
and cash flows.
Our business strategy contemplates future acquisitions. Acquisitions of other businesses
or assets present various risks and uncertainties.
We may pursue growth through the acquisition of businesses or assets that will enable us to broaden
our service and product offerings and expand into new markets. We may be unable to implement
this element of our growth strategy if we cannot identify suitable businesses or assets, reach
agreement on potential strategic acquisitions on acceptable terms or for other reasons. Moreover,
acquisitions involve various risks, including:
• difficulties relating to the assimilation of personnel, services and systems of an acquired
business and the assimilation of marketing and other operational capabilities;
• challenges resulting from unanticipated changes in customer and other third-party
relationships subsequent to acquisition;
• additional financial and accounting challenges and complexities in areas such as tax planning,
treasury management, financial reporting and internal controls;
• assumption of liabilities of an acquired business, including liabilities that were unknown at the
time the acquisition transaction was negotiated;
• possible liabilities under the FCPA and other anti-corruption laws;
• diversion of management's attention from day-to-day operations;
• failure to realize anticipated benefits, such as cost savings and revenue enhancements;
• potentially substantial transaction costs associated with acquisitions; and
• potential impairment resulting from the overpayment for an acquisition.
Future acquisitions may require us to obtain additional equity or debt financing, which may not be
available on attractive terms. Moreover, to the extent an acquisition transaction financed by non-
equity consideration results in goodwill, it will reduce our tangible net worth, which might have an
adverse effect on credit availability.
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.
Our business strategy also includes development and commercialization of new
technologies to support our growth. The development and commercialization of new
technologies require capital investment and involve various risks and uncertainties.
Our future growth will depend on our ability to continue to innovate by developing and
commercializing new service and product offerings. Investments in new technologies involve varying
degrees of uncertainties and risk. Commercial success depends on many factors, including the levels
of innovation, the development costs and the availability of capital resources to fund those costs, the
levels of competition from others developing similar or other competing technologies, our ability to
obtain or maintain government permits or certifications, the effectiveness of production, distribution
and marketing efforts, and the costs to customers to deploy and provide support for the new
technologies. We may not achieve significant revenues from new service and product investments
for a number of years, if at all. Moreover, new services and products may not be profitable, and,
even if they are profitable, our operating margins from new services and products may not be as
high as the margins we have experienced historically.
The loss of the services of one or more of our key personnel, or our failure to attract,
assimilate and retain trained personnel in the future, could disrupt our operations and
result in loss of revenues.
Our success depends on the continued active participation of our executive officers and key
operating personnel. The unexpected loss of the services of any one of these persons could
adversely affect our operations.
Our operations require the services of employees having the technical training and experience
necessary to obtain the proper operational results. As a result, if we should suffer any material loss
18
of personnel to competitors or be unable to employ additional or replacement personnel with the
requisite level of training and experience to adequately operate our equipment, our operations could
be adversely affected. A significant increase in the wages paid by other employers could result in a
reduction in our workforce, increases in wage rates, or both.
We may not be able to compete successfully against current and future competitors.
Our businesses operate in highly competitive industry segments. Some of our competitors or
potential competitors have greater financial or other resources than we have. Our operations may
be adversely affected if our current competitors or new market entrants introduce new products or
services with better features, performance, prices or other characteristics than those of our services
and products. This factor is significant to our segments' operations, particularly in the segments
within our Oilfield business, where capital investment is critical to our ability to compete.
We rely on intellectual property law and confidentiality agreements to protect our
intellectual property. We also rely on intellectual property we license from third parties.
Our failure to protect our intellectual property rights, or our inability to obtain or renew
licenses to use intellectual property of third parties, could adversely affect our business.
We rely on a variety of intellectual property rights that we use in our services and products, and our
success depends, in part, on our ability to protect our proprietary information and other intellectual
property. Our intellectual property could be challenged, invalidated, circumvented or rendered
unenforceable. In addition, effective intellectual property protection may be limited or unavailable in
some foreign countries where we operate.
Our failure to protect our intellectual property rights may result in the loss of valuable technologies
or adversely affect our competitive business position. We rely significantly on proprietary
technology, information, processes and know-how that are not subject to patent or copyright
protection. We seek to protect this information through trade secret or confidentiality agreements
with our employees, consultants, subcontractors or other parties, as well as through other security
measures. These agreements and security measures may be inadequate to deter or prevent
misappropriation of our confidential information. In the event of an infringement of our intellectual
property rights, a breach of a confidentiality agreement or divulgence of proprietary information, we
may not have adequate legal remedies to protect our intellectual property.
In some instances, we have augmented our technology base by licensing the proprietary intellectual
property of third parties. However, it is possible that the tools, techniques, methodologies, programs
and components we use to provide our services or products may infringe on the intellectual property
rights of others. In the future, we may not be able to obtain necessary licenses on commercially
reasonable terms. Royalty payments under licenses from third parties, if available, or developing
non-infringing technologies could materially increase our costs. Additionally, if a license or non-
infringing technology were not available, we might not be able to continue providing a particular
service or product, which could materially and adversely affect our financial condition, results of
operations and cash flows.
Litigation to determine the scope of intellectual property rights, even if ultimately successful, could
be costly and could divert management's attention away from other aspects of our business. In
addition, our trade secrets may otherwise become known or be independently developed by
competitors.
Our information technology systems are subject to interruption and cybersecurity risks
that could adversely impact our operations.
We continue to evaluate potential replacements or upgrades of existing key information technology
systems. The implementation of new information technology systems or upgrades to existing
systems subjects us to inherent costs and risks associated with replacing or changing these systems,
including potential disruption of our internal control structure, substantial capital expenditures,
demands on management time and other risks. Our possible new information technology systems
implementations or upgrades may not result in productivity improvements at the levels anticipated,
or at all. In addition, the implementation of new or upgraded information technology systems may
cause disruptions in our business operations. Any such disruption, and any other information
technology system disruptions, if not anticipated and appropriately mitigated, could have a material
adverse effect on our operations.
19
Our operations (both onshore and offshore) are highly dependent on information technology
systems. Threats to our information technology systems associated with cybersecurity risks and
cyber incidents or attacks continue to grow. In addition, breaches to our systems could go unnoticed
for some period of time. Risks associated with these threats include disruptions of certain systems
on our vessels or utilized to operate our ROVs; other impairments of our ability to conduct our
operations; loss of or damage to intellectual property, proprietary information or customer data;
disruption of our customers’ operations; loss or damage to our customer data delivery systems; and
increased costs to prevent, respond to or mitigate cybersecurity incidents. If such a cyber-incident
were to occur, it could have a material adverse effect on our business and our consolidated financial
condition, results of operations and cash flows.
Our offshore oilfield operations involve a variety of operating hazards and risks that could
cause losses.
Our operations are subject to the hazards inherent in the offshore oilfield business. These include
blowouts, explosions, fires, collisions, capsizings and severe weather conditions. These hazards
could result in personal injury and loss of life, severe damage to or destruction of property and
equipment, pollution or environmental damage and suspension of operations. We may incur
substantial liabilities or losses as a result of these hazards. While we maintain insurance protection
against some of these risks, and seek to obtain indemnity agreements from our customers requiring
the customers to hold us harmless from some of these risks, our insurance and contractual
indemnity protection may not be sufficient or effective to protect us under all circumstances or
against all risks. The occurrence of a significant event not fully insured or indemnified against or the
failure of a customer to meet its indemnification obligations to us could materially and adversely
affect our results of operations and financial condition.
Laws and governmental regulations may add to our costs or adversely affect our
operations.
Our business is affected by changes in public policy and by federal, state, local and foreign laws and
regulations relating to the offshore oil and gas industry. Offshore oil and gas exploration and
production operations are affected by tax, environmental, safety and other laws, by changes in those
laws, application or interpretation of existing laws, and changes in related administrative regulations.
It is also possible that these laws and regulations may in the future add significantly to our operating
costs or those of our customers or otherwise directly or indirectly affect our operations.
Environmental laws and regulations can increase our costs, and our failure to comply with
those laws and regulations can expose us to significant liabilities.
Risks of substantial costs and liabilities related to environmental compliance issues are inherent in
our operations. Our operations are subject to extensive federal, state, local and foreign laws and
regulations relating to the generation, storage, handling, emission, transportation and discharge of
materials into the environment. Permits are required for the operation of various facilities, and those
permits are subject to revocation, modification and renewal. Governmental authorities have the
power to enforce compliance with their regulations, and violations are subject to fines, injunctions or
both. In some cases, those governmental requirements can impose liability for the entire cost of
cleanup on any responsible party without regard to negligence or fault and impose liability on us for
the conduct of or conditions others have caused, or for our acts that complied with all applicable
requirements when we performed them. It is possible that other developments, such as stricter
environmental laws and regulations, and claims for damages to property or persons resulting from
our operations, would result in substantial costs and liabilities. Our insurance policies and the
contractual indemnity protection we seek to obtain from our customers may not be sufficient or
effective to protect us under all circumstances or against all risks involving compliance with
environmental laws and regulations.
Our internal controls may not be sufficient to achieve all stated goals and objectives.
Our internal controls and procedures were developed through a process in which our management
applied its judgment in assessing the costs and benefits of such controls and procedures, which, by
their nature, can provide only reasonable assurance regarding the control objectives. The design of
any system of internal controls and procedures is based, in part, on various assumptions about the
likelihood of future events. We cannot assure that any design will succeed in achieving its stated
goals under all potential future conditions, regardless of how remote.
20
The use of estimates could result in future adjustments to our assets, liabilities and
results of operations.
The preparation of financial statements in conformity with accounting principles generally accepted in
the United States requires that our management make estimates and assumptions that affect the
reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenue and expense during the reporting
period. Actual results could differ from those estimates.
We may issue preferred stock whose terms could adversely affect the voting power or
value of our common stock.
Our certificate of incorporation authorizes us to issue, without the approval of our shareholders, one
or more classes or series of preferred stock having such preferences, powers and relative,
participating, optional and other rights, including preferences over our common stock respecting
dividends and distributions, as our board of directors may determine. The terms of one or more
classes or series of preferred stock could adversely impact the voting power or value of our common
stock. For example, we might grant holders of preferred stock the right to elect some number of our
directors in all events or on the happening of specified events or the right to veto specified
transactions. Similarly, the repurchase or redemption rights or liquidation preferences we might
assign to holders of preferred stock could affect the residual value of the common stock.
Provisions in our corporate documents and Delaware law could delay or prevent a change
in control of our company, even if that change would be beneficial to our shareholders.
The existence of some provisions in our corporate documents and Delaware law could delay or
prevent a change in control of our company, even if that change would be beneficial to our
shareholders. Our certificate of incorporation and bylaws contain provisions that may make
acquiring control of our company difficult, including:
• provisions relating to the classification, nomination and removal of our directors;
• provisions regulating the ability of our shareholders to bring matters for action at annual
meetings of our shareholders;
• provisions requiring the approval of the holders of at least 80% of our voting stock for a
broad range of business combination transactions with related persons; and
• the authorization given to our board of directors to issue and set the terms of preferred stock.
In addition, the Delaware General Corporation Law imposes restrictions on mergers and other
business combinations between us and any holder of 15% or more of our outstanding common
stock.
Item 1B. Unresolved Staff Comments.
None.
Item 2. Properties.
We maintain office, shop and yard facilities in various parts of the world to support our operations.
We consider these facilities, which we describe below, to be suitable for their intended use. In these
locations, we typically own or lease office facilities for our administrative and engineering staff, shops
equipped for fabrication, testing, repair and maintenance activities and warehouses and yard areas
for storage and mobilization of equipment to work sites. All sites are available to support any of our
business segments as the need arises. The groupings that follow associate our significant offices
with the primary business segment they serve.
Oilfield. In general, our Oilfield business segments share facilities. Our location in Morgan City,
Louisiana consists of ROV manufacturing and training facilities, vessel docking facilities, open and
covered warehouse space and offices. The Morgan City facilities primarily support operations in the
United States. We have regional support offices for our North Sea, Africa, Brazil and Southeast Asia
operations in: Aberdeen, Scotland; Stavanger and Bergen, Norway; Dubai, U.A.E.; Rio de Janeiro
21
and Macaé, Brazil; Luanda, Angola; Chandigarh, India; Perth, Australia; Kuala Lumpur, Malaysia;
and Singapore. We also have operational bases in various other locations.
We use workshop and office space in Houston, Texas in our Subsea Products, Subsea Projects and
Asset Integrity business segments. Our principal manufacturing facilities for our Subsea Products
segment are located in or near: Houston, Texas; Panama City, Florida; Aberdeen and Rosyth,
Scotland; Nodeland and Stavanger, Norway; Perth, Australia; Luanda, Angola; and Niterói and
Macaé, Brazil. Each of these manufacturing facilities is suitable for its intended purpose and has
sufficient capacity to respond to increases in demand for our subsea products that may be
reasonably anticipated in the foreseeable future.
For a description of the vessels we use in our Subsea Projects operations, see the discussion in Item
1. "Business" under the heading "GENERAL DEVELOPMENT OF BUSINESS – Oilfield – Subsea
Projects."
Advanced Technologies. Our primary facilities for our Advanced Technologies segment are leased
offices and workshops in Hanover, Maryland. We have regional offices in Chesapeake, Virginia;
Bremerton, Washington; Pearl Harbor, Hawaii; and San Diego, California, which support our services
for the U.S. Navy. We also have an office in Orlando, Florida, which supports our commercial theme
park animation activities, facilities in Utrecht, Netherlands, to support robotic activities, and facilities
in Houston, Texas, to support our space industry activities.
Item 3.
Legal Proceedings.
On June 17, 2014, Peter L. Jacobs, a purported shareholder, filed a derivative complaint against all of
the then current members of our board of directors and one of our former directors, as defendants,
and our company, as nominal defendant, in the Court of Chancery of the State of Delaware. Through
the complaint, the plaintiff is asserting, on behalf of our company, actions for breach of fiduciary
duties and unjust enrichment in connection with prior determinations of our board of directors
relating to nonexecutive director compensation. The plaintiff is seeking relief including disgorgement
of payments made to the defendants, an award of unspecified damages and an award for attorneys’
fees and other costs. We and the defendants filed a motion to dismiss the complaint and a
supporting brief on which the Court has not yet ruled. In any event, our company is only a nominal
defendant in this litigation, and we do not expect the resolution of this matter to have a material
adverse effect on our results of operations, cash flows or financial position.
In the ordinary course of business, we are subject to actions for damages alleging personal injury
under the general maritime laws of the United States, including the Jones Act, for alleged
negligence. We report actions for personal injury to our insurance carriers and believe that the
settlement or disposition of those claims will not have a material adverse effect on our consolidated
financial position, results of operations or cash flows.
Various other actions and claims are pending against us, most of which are covered by insurance.
Although we cannot predict the ultimate outcome of these matters, we believe that our ultimate
liability, if any, that may result from these other actions and claims will not materially affect our
results of operations, cash flows or financial position.
Item 4. Mine Safety Disclosures.
Not applicable.
22
Part II
Item 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer
Purchases of Equity Securities.
Our common stock is listed on the New York Stock Exchange under the symbol OII. We submitted to
the New York Stock Exchange during 2016 a certification of our Chief Executive Officer regarding
compliance with the Exchange's corporate governance listing standards. We also included as exhibits
to this annual report on Form 10-K, as filed with the SEC, the certifications of our principal executive
officer and principal financial officer required under Section 302 of the Sarbanes-Oxley Act of 2002.
The following table sets out, for the periods indicated, the high and low sales prices for our common
stock as reported on the New York Stock Exchange (consolidated transaction reporting system):
For the quarter ended:
March 31
June 30
September 30
December 31
2016
2015
High
Low
High
Low
$
39.04 $
25.33 $
36.92
31.55
32.12
28.36
24.33
22.47
59.37 $
59.65
46.86
48.11
48.37
46.05
37.00
36.87
On February 17, 2017, there were 433 holders of record of our common stock. On that date, the
closing sales price, as quoted on the New York Stock Exchange, was $27.20. In 2016, we declared
quarterly cash dividends of $0.27 per share in the first three quarters and $0.15 per share in the
fourth quarter. In 2015, we declared quarterly cash dividends of $0.27 per share in each quarter. It
is our intent to continue to pay a quarterly cash dividend; however, payment of future cash dividends
will be at the discretion of our board of directors in accordance with applicable law, after taking into
account various factors, including our financial condition, earnings, capital requirements, legal
requirements, regulatory constraints, industry practice and any other factors that our board of
directors believes are relevant.
In February 2010, our Board of Directors approved a program to repurchase up to 12 million shares
of our common stock. Through December 31, 2014 under that program, we repurchased the 12
million shares of our common stock for $677 million.
In December 2014, following completion of the February 2010 program, our Board of Directors
approved a new share repurchase program under which we may repurchase up to 10 million shares
of our common stock on a discretionary basis. The December 2014 program calls for the
repurchases to be made in the open market, or in privately negotiated transactions from time to
time, in compliance with applicable laws, rules and regulations, including Rule 10b-18 under the
Securities Exchange Act of 1934, as amended, subject to market and business conditions, levels of
available liquidity, cash requirements for other purposes, applicable legal requirements and other
relevant factors. The timing and amount of any repurchases will be determined by management
based on its evaluation of these factors. We expect that any shares repurchased under the new
program will be held as treasury stock for future use. The new program does not obligate us to
repurchase any particular number of shares. Under the new program, we had repurchased 2.0
million shares of our common stock for $100 million through December 31, 2015. We did not
repurchase any shares during 2016.
23
EQUITY COMPENSATION PLAN INFORMATION
The following presents equity compensation plan information as of December 31, 2016:
Plan Category
Equity compensation plans approved by
security holders
Equity compensation plans not approved by
security holders
Total
Number of
securities to be
issued upon
exercise of
outstanding
options, warrants
and rights
Weighted-average
exercise price of
outstanding options,
warrants and rights
Number of securities
remaining available
for future issuance
under equity
compensation plans
(excluding securities
reflected
in the first column)
—
—
—
N/A
N/A
N/A
1,068,572
—
1,068,572
We had no outstanding options, warrants or rights at December 31, 2016.
At December 31, 2016, there were: (1) no shares of Oceaneering common stock under equity
compensation plans not approved by security holders available for grant; and (2) 1,068,572 shares
of Oceaneering common stock under equity compensation plans approved by security holders
available for grant in the form of stock options, stock appreciation rights or stock awards. We have
not granted any stock options since 2005 and the Compensation Committee of our Board of Directors
has expressed its intention to refrain from using stock options as a component of employee
compensation for our executive officers and other employees for the foreseeable future.
Additionally, our Board of Directors has expressed its intention to refrain from using stock options as
a component of nonemployee director compensation for the foreseeable future. For a description of
the material features of our equity compensation arrangements, see the discussion in Note 8 of
Notes to Consolidated Financial Statements under the heading "Incentive Plan."
24
PERFORMANCE GRAPH
The following graph compares our total shareholder return to the Standard & Poor's 500 Stock Index
("S&P 500") and the PHLX Oil Service Sector Index from December 31, 2011 through
December 31, 2016. The PHLX Oil Service Sector Index is designed to track the performance of a
set of companies involved in the oil services sector.
It is assumed in the graph that: (1) $100 was invested in Oceaneering Common Stock, the S&P 500
and the PHLX Oil Service Sector Index on December 31, 2011; and (2) any Oceaneering dividends
are reinvested. The shareholder return shown is not necessarily indicative of future performance.
25
Item 6.
Selected Financial Data.
The following table sets forth certain selected historical consolidated financial data and should be
read in conjunction with Management's Discussion and Analysis of Financial Condition and Results of
Operation and our Consolidated Financial Statements and Notes included in this report. The
following information may not be indicative of our future operating results.
Results of Operations:
(in thousands, except per share amounts)
Revenue
Cost of services and products
Gross margin
Selling, general and administrative expense
Income from operations
Net income
Cash dividends declared per Share
Diluted earnings per share
Depreciation and amortization
Capital expenditures, including business
acquisitions
Other Financial Data:
(dollars in thousands)
Working capital ratio
Working capital
Total assets
Long-term debt
Shareholders' equity
Year Ended December 31,
2016
2014
$ 2,271,603 $ 3,062,754 $ 3,659,624 $ 3,287,019 $ 2,782,604
2015
2013
2012
1,992,376
2,457,325
279,227
208,463
605,429
231,619
$
$
$
$
$
70,764 $
373,810 $
24,586 $
231,011 $
0.96 $
1.08 $
0.25 $
2.34 $
250,247 $
241,235 $
2,800,423
859,201
230,871
628,330 $
428,329 $
1.03 $
4.00 $
229,779 $
2,521,483
2,154,746
765,536
220,420
627,858
199,261
545,116 $
428,597
371,500 $
289,017
0.84 $
3.42 $
0.69
2.66
202,228 $
176,483
$
142,513 $
423,988 $
426,671
$
393,590 $
309,858
As of December 31,
2016
2.48
2015
2.46
$ 754,231
$ 901,537
$ 3,130,315
$ 3,429,536
$ 793,058
$ 795,836
$ 1,516,643
$ 1,578,734
2014
2013
2.52
1.97
$ 706,187
$ 1,034,413
$ 3,504,940 $ 3,128,500
—
$ 743,469 $
$ 1,657,471 $ 2,043,440
2012
1.95
$ 585,805
$ 2,768,118
$
94,000
$ 1,815,460
Goodwill as a percentage of Shareholders'
equity
29%
27%
20%
17%
20%
26
Item 7. Management's Discussion and Analysis of Financial Condition and Results of
Operations.
Certain statements in this annual report on Form 10-K, including, without limitation, statements
regarding the following matters, are forward-looking statements made pursuant to the safe harbor
provisions of the Private Securities Litigation Reform Act of 1995:
industry conditions;
• our business strategy;
• our plans for future operations;
•
• seasonality;
• our expectations about 2017 earnings per share, items below the operating income line and
segment operating results, and the factors underlying those expectations, including our
expectations about demand and pricing for our deepwater oilfield services and products as a
result of the factors we specify in "Overview" and "Results of Operations" below;
• projections relating to floating rig demand and subsea tree installations;
• the adequacy of our liquidity and capital resources to support our operations and internally
generated growth initiatives;
• our projected capital expenditures for 2017;
• our plans to add ROVs to our fleet;
• our intentions relating to the subsea support vessel scheduled for delivery in 2017;
• our expectations regarding deferred tax assets and our belief that our goodwill will not be
impaired during 2017;
• the adequacy of our accruals for uninsured expected liabilities from workers' compensation,
maritime employer's liability and general liability claims;
• our belief that our total unrecognized tax benefits will not significantly increase or decrease in
the next 12 months;
• our anticipated tax rates and underlying assumptions;
• our anticipation of a discrete tax item in the first quarter of 2017;
• our expectations regarding shares repurchased under our share repurchase plan;
• our backlog; and
• our expectations regarding the effect of inflation in the near future.
These forward-looking statements are subject to various risks, uncertainties and assumptions,
including those we refer to under the headings "CAUTIONARY STATEMENT CONCERNING FORWARD-
LOOKING STATEMENTS" and "Risk Factors" in Part I of this report. Although we believe that the
expectations reflected in such forward-looking statements are reasonable, because of the inherent
limitations in the forecasting process, as well as the relatively volatile nature of the industries in
which we operate, we can give no assurance that those expectations will prove to have been correct.
Accordingly, evaluation of our future prospects must be made with caution when relying on forward-
looking information.
Overview
The table that follows sets out our revenue and operating results for 2016, 2015 and 2014.
(dollars in thousands)
Revenue
Gross Margin
Gross Margin %
Operating Income
Operating Income %
Net Income
2016
$ 2,271,603
279,227
Year Ended December 31,
2015
$ 3,062,754
605,429
$ 3,659,624
859,201
2014
12 %
20 %
23 %
70,764
373,810
628,330
3 %
12 %
17 %
24,586
231,011
428,329
Our business substantially depends on the level of spending on offshore developments by our
customers in the oil and gas industry. During 2016, we generated approximately 86% of our
revenue, and 92% of our operating income before Unallocated Expenses, from services and products
27
we provided to the oil and gas industry. In 2016, our revenue decreased by 26%, with the larger
percentage decreases occurring in our ROV, Subsea Products and Asset Integrity segments, all of
which decreased from lower oilfield activity resulting from the general decline in crude oil prices from
mid 2014. Starting in 2015, we have taken initiatives to align our operations with current and
anticipated declining activity and pricing levels. These initiatives required us to reduce our workforce,
incur unusual expenses, and make certain accounting adjustments.
The $25 million consolidated net income we earned in 2016 was substantially less than the $231
million we earned in 2015, and the $0.25 earnings per diluted share was the lowest we made since
2000. The $206 million decrease from 2015 net income was attributable to lower profit contributions
from all of our oilfield business segments, most notably:
• our ROV segment, which had $167 million less operating income on $286 million less
revenue;
• our Subsea Products segment, which had $100 million less operating income on $268 million
less revenue; and
• our Subsea Projects segment, which had $58 million less operating income on $132 million
less revenue.
In 2016, we invested in the following capital projects:
• additions of capabilities in our Subsea Products segment, including payment of $28 million for
the purchase of the assets of a provider of riserless light well intervention services;
• $13 million related to a new subsea support vessel for our Subsea Projects segment
scheduled for delivery in 2017; and
• additions of and upgrades to our work-class ROVs.
In 2015, we exited the business of manufacturing subsea blow out preventer ("BOP") control
systems.
We expect our 2017 diluted earnings per share to be less than the $0.25 we reported in 2016. With
our limited market visibility resulting from the uncertain energy market, we are not providing
earnings per share guidance for 2017. We anticipate lower global demand for deepwater drilling,
field development, and inspection, maintenance and repair activities due to the current and
anticipated oil price environment, which has led to spending cuts from our customers and pricing
pressure. Compared to 2016, in 2017 we are forecasting that we will be marginally profitable at the
operating income line. Below the operating income line, we expect:
• a loss on our equity investment in Medusa Spar LLC as production continues to decline;
•
increased interest expense from higher interest rates, which affects our floating rate debt and
our swaps to floating rates on $200 million of fixed-rate debt;
in the first quarter, a discrete additional tax expense related to our share-based compensation
plan.
•
We use our ROVs to provide drilling support, vessel-based inspection, maintenance and repair,
subsea hardware installation, construction, and pipeline inspection services to customers in the oil
and gas industry. The largest percentage of our ROVs has historically been used to provide drill
support services. Therefore, the number of floating drilling rigs on hire is a leading market indicator
for this business. The following table shows average floating rigs under contract and our ROV
utilization.
Average number of floating rigs under contract
ROV days on hire (in thousands)
ROV utilization
2016
177
60
53%
2015
241
84
69%
2014
280
98
83%
28
Demand for floating rigs is the primary leading indicator of the strength of the deepwater market.
According to industry data published by IHS Petrodata, at the end of 2016, there were 336 floating
drilling rigs in operation or available for work throughout the world, with 151 of those rigs under
contract. Of the 151 rigs under contract, 91 are contracted through the end of 2017. Recent
industry forecasts of floating rig demand point to an expectation that demand in 2017 will decline by
approximately 25%.
In addition to floating rig demand, the number of subsea tree completions is another leading
indicator, and the primary demand driver for our Subsea Products lines. According to industry data
published by Infield Systems Limited in January 2017, there will be 200 subsea tree installations in
2017, down from 305 in 2016, 308 in 2015 and 349 in 2014. Subsea tree installations are forecast
to increase to 227 in 2018.
Critical Accounting Policies and Estimates
We have based the following discussion and analysis of our financial condition and results of
operations on our consolidated financial statements, which we have prepared in conformity with
accounting principles generally accepted in the United States. These principles require us to make
various estimates, judgments and assumptions that affect the reported amounts of assets and
liabilities at the date of the financial statements and the reported amounts of revenue and expense
during the periods we present. We base our estimates on historical experience, available information
and other assumptions we believe to be reasonable under the circumstances. On an ongoing basis,
we evaluate our estimates; however, our actual results may differ from these estimates under
different assumptions or conditions. The following discussion summarizes the accounting policies we
believe (1) require our management's most difficult, subjective or complex judgments and (2) are
the most critical to our reporting of results of operations and financial position.
Revenue Recognition. We recognize our revenue according to the type of contract involved. On a
daily basis, we recognize revenue under contracts that provide for specific time, material and
equipment charges, which we bill periodically, ranging from weekly to monthly.
We account for significant fixed-price contracts, which we enter into mainly in our Subsea Products
segment, and to a lesser extent in our Subsea Projects and Advanced Technologies segments, using
the percentage-of-completion method. In 2016, we accounted for 16% of our revenue using the
percentage-of-completion method. In determining whether a contract should be accounted for using
the percentage-of-completion method, we consider whether:
• the customer provides specifications for the construction of facilities or production of goods or
for the provision of related services;
• we can reasonably estimate our progress towards completion and our costs;
• the contract includes provisions as to the enforceable rights regarding the goods or services
to be provided, consideration to be received and the manner and terms of payment;
• the customer can be expected to satisfy its obligations under the contract; and
• we can be expected to perform our contractual obligations.
Under the percentage-of-completion method, we generally recognize estimated contract revenue
based on costs incurred to date as a percentage of total estimated costs. Changes in the expected
cost of materials and labor, productivity, scheduling and other factors affect the total estimated
costs. Additionally, external factors, including weather or other factors outside of our control, may
also affect the progress and estimated cost of a project's completion and, therefore, the timing of
income and revenue recognition. We routinely review estimates related to our contracts and reflect
revisions to profitability in earnings immediately. If a current estimate of total contract cost
indicates an ultimate loss on a contract, we recognize the projected loss in full when we determine it.
In prior years, we have recorded adjustments to earnings as a result of revisions to contract
estimates. Although we are continually striving to accurately estimate our contract costs and
profitability, adjustments to overall contract costs could be significant in future periods.
We recognize the remainder of our revenue when persuasive evidence of an arrangement exists,
delivery has occurred or services have been rendered, price is fixed or determinable and collection is
reasonably assured.
29
Property and Equipment and Long-lived Intangible Assets. We periodically and upon the
occurrence of a triggering event review the realizability of our property and equipment and long-
lived intangible assets to determine whether any events or changes in circumstances indicate that
the carrying amount of the asset may not be recoverable. For long-lived assets to be held and used,
we base our evaluation on impairment indicators such as the nature of the assets, the future
economic benefits of the assets, any historical or future profitability measurements and other
external market conditions or factors that may be present. If such impairment indicators are present
or other factors exist that indicate that the carrying amount of an asset may not be recoverable, we
determine whether an impairment has occurred through the use of an undiscounted cash flows
analysis of the asset at the lowest level for which identifiable cash flows exist. If an impairment has
occurred, we recognize a loss for the difference between the carrying amount and the fair value of
the asset. For assets held for sale or disposal, the fair value of the asset is measured using fair
market value less cost to sell. Assets are classified as held-for-sale when we have a plan for disposal
of certain assets and those assets meet the held for sale criteria.
We charge the costs of repair and maintenance of property and equipment to operations as incurred,
while we capitalize the costs of improvements that extend asset lives or functionality.
Goodwill. In our annual evaluation of goodwill for impairment, we first assess qualitative factors to
determine whether the existence of events or circumstances leads to a determination that it is more
likely than not that the fair value of a reporting unit is less than its carrying amount. If, after
assessing the totality of events or circumstances, we determine it is more likely than not that the fair
value of a reporting unit exceeds its carrying amount, performing the two-step impairment test is
unnecessary. However, if we conclude otherwise, then we are required to perform the first step of
the two-step impairment test. We estimate fair value of the reporting units using both an income
approach, which considers a discounted cash flow model, and a market approach. Reductions in
estimates of our future cash flows or adverse changes in market comparable information may result
in goodwill impairments in the future.
For reporting units with goodwill, we do not believe our goodwill will be impaired during 2017.
Income Taxes. Our tax provisions are based on our expected taxable income, statutory rates and
tax-planning opportunities available to us in the various jurisdictions in which we operate.
Determination of taxable income in any jurisdiction requires the interpretation of the related tax
laws. We are at risk that a taxing authority's final determination of our tax liabilities may differ from
our interpretation. Our effective tax rate may fluctuate from year to year as our operations are
conducted in different taxing jurisdictions, the amount of pre-tax income fluctuates, the amounts of
foreign income we anticipate will be repatriated and our estimates regarding the realizability of items
such as foreign tax credits may change. We consider $623 million of unremitted earnings of our
foreign subsidiaries to be indefinitely reinvested. We believe we have the ability to indefinitely
reinvest these foreign earnings based on our expectations of profitability for our U.S. operations over
the long term, our significant U.S. liquidity, and the amount of unremitted earnings of our foreign
subsidiaries not considered indefinitely reinvested, for which we have provided deferred income
taxes.
We account for any applicable interest and penalties on uncertain tax positions as a component of
our provision for income taxes on our financial statements. Current income tax expense represents
either nonresident withholding taxes or the liabilities expected to be reflected on our income tax
returns for the current year, while the net deferred income tax expense or benefit represents the
change in the balance of deferred tax assets or liabilities as reported on our balance sheet.
We establish valuation allowances to reduce deferred tax assets when it is more likely than not that
some portion or all of the deferred tax assets will not be realized in the future. While we have
considered estimated future taxable income and ongoing prudent and feasible tax-planning
strategies in assessing the need for the valuation allowances, changes in these estimates and
assumptions, as well as changes in tax laws, could require us to provide for valuation allowances for
our deferred tax assets. Provisions for valuation allowances impact our income tax provision in the
period in which such adjustments are identified and recorded. We established a deferred tax asset
valuation allowance of $4.2 million in 2016 related to the realizability of loss carryforwards in certain
of our foreign jurisdictions.
30
In March 2016, the FASB issued ASU 2016-09, "Compensation – Stock Compensation Improvements
to Employee Share-Based Payment Accounting." This update requires that all excess tax benefits
and tax deficiencies (including tax benefits of dividends on share-based payment awards) should be
recognized as income tax expense or benefit in the income statement. The tax effects of exercised
or vested awards should be treated as discrete items in the reporting period in which they occur. An
entity also should recognize excess tax benefits regardless of whether the benefit reduces taxes
payable in the current period. Currently, an entity must determine, for each award, whether the
difference between the deduction for tax purposes and the compensation cost recognized for
financial reporting purposes results in either an excess tax benefit or a tax deficiency. The
amendments in this update are effective for us beginning January 1, 2017. Through
December 31, 2016, we recognized excess tax benefits in additional paid-in capital, and tax
deficiencies have been recognized as an offset to accumulated excess tax benefits. In 2017, we
expect a tax deficiency in the first quarter and, under this new standard, we will recognize it as a
discrete item in the income statement rather than in additional paid-in capital. We do not anticipate
that this update will have a material effect on our consolidated financial statements.
For a summary of our major accounting policies and a discussion of recently adopted accounting
standards, please see Note 1 to our Consolidated Financial Statements.
Liquidity and Capital Resources
We consider our liquidity and capital resources adequate to support our operations and growth
initiatives. At December 31, 2016, we had working capital of $754 million, including cash and cash
equivalents of $450 million. Additionally, we had $500 million available through our revolving credit
facility under a credit agreement (as amended, the "Credit Agreement"), which is scheduled to
expire on October 25, 2021.
In October 2014, we entered into the Credit Agreement with a group of banks to replace our prior
principal credit agreement. The Credit Agreement provides for a $300 million three-year term loan
(the "Term Loan Facility") and a $500 million five-year revolving credit facility (the "Revolving Credit
Facility"). Subject to certain conditions, the aggregate commitments under the Revolving Credit
Facility may be increased to up to $800 million at any time upon agreement between us and existing
or additional lenders. Borrowings under the Revolving Credit Facility and the Term Loan Facility may
be used for general corporate purposes. Simultaneously with the execution of the Credit Agreement
and pursuant to its terms, we repaid all amounts outstanding under, and terminated, the prior credit
agreement.
In November 2015, we entered into an Agreement and Amendment No. 1 to Credit Agreement
("Amendment No. 1"). Amendment No. 1 amended the Credit Agreement to (1) replace the
maximum leverage ratio financial covenant with a new financial covenant restricting the maximum
total capitalization ratio (defined in Amendment No. 1 to be the ratio of consolidated debt to total
capitalization) to 55% and (2) extend the maturities of the Term Loan Facility and the Revolving
Credit Facility by one year each, which maturity terms have since been superseded by amendment,
as described below.
In November 2016, we entered into Agreement and Amendment No. 2 to Credit Agreement
("Amendment No. 2"). Amendment No. 2 amended the Credit Agreement to, among other things,
extend the maturities of the Term Loan Facility and the Revolving Credit Facility to October 25, 2019
and October 25, 2021, respectively, with the extending Lenders, which represent 90% of the existing
commitments of the Lenders, such that (a) the total commitments for the Revolving Credit Facility
will be $500 million until October 25, 2020 and thereafter $450 million until October 25, 2021, and
(b) the outstanding term loan maturities pursuant to the Term Loan Facility will be $300 million until
October 27, 2018 and thereafter $270 million until October 25, 2019.
Borrowings under the Credit Agreement bear interest at an Adjusted Base Rate or the Eurodollar
Rate (both as defined in the Credit Agreement), at our option, plus an applicable margin initially
based on our Leverage Ratio (as defined in the Credit Agreement) and, at our election, based on
ratings of our senior unsecured debt by designated ratings services, thereafter to be based on such
debt ratings. The applicable margin varies: (1) in the case of advances bearing interest at the
31
Adjusted Base Rate, from 0.125% to 0.750% for borrowings under the Revolving Credit Facility and
from 0% to 0.500% for borrowings under the Term Loan Facility; and (2) in the case of advances
bearing interest at the Eurodollar Rate, from 1.125% to 1.750% for borrowings under the Revolving
Credit Facility and from 1.000% to 1.500% for borrowings under the Term Loan Facility. The
Adjusted Base Rate is the highest of (1) the per annum rate established by the administrative agent
as its prime rate, (2) the federal funds rate plus 0.50% and (3) the daily one-month LIBOR plus 1%.
We pay a commitment fee ranging from 0.125% to 0.300% on the unused portion of the Revolving
Credit Facility, depending on our Leverage Ratio. The commitment fees are included as interest
expense in our consolidated financial statements.
The Credit Agreement contains various covenants that we believe are customary for agreements of
this nature, including, but not limited to, restrictions on our ability and the ability of each of our
subsidiaries to incur debt, grant liens, make certain investments, make distributions, merge or
consolidate, sell assets, enter into transactions with affiliates and enter into certain restrictive
agreements. We are also subject to a maximum total capitalization ratio of 55%, as noted above.
The Credit Agreement includes customary events of default and associated remedies. As of
December 31, 2016, we were in compliance with all the covenants set forth in the Credit Agreement.
In November 2014, we completed the public offering of $500 million aggregate principal amount of
4.650% Senior Notes due 2024 (the "Senior Notes"). We pay interest on the Senior Notes on
May 15 and November 15 of each year, beginning on May 15, 2015. The Senior Notes are scheduled
to mature on November 15, 2024. We may redeem some or all of the Senior Notes prior to maturity
at specified redemption prices. We used the net proceeds from the offering for general corporate
purposes, including funding the acquisition described below, other capital expenditures and
repurchases of shares of our common stock.
Our maximum outstanding indebtedness during 2016 under the Credit Agreement and Senior Notes
was $800 million, and our total interest costs, including commitment fees, were $29.1 million.
Our capital expenditures, including business acquisitions, for 2016, 2015 and 2014 were $143
million, $424 million and $427 million, respectively. Our capital expenditures in 2016 included $50
million in our ROV segment, $57 million in our Subsea Products segment and $26 million in our
Subsea Projects segment. Our capital expenditures in 2015 included our acquisition of C & C
Technologies, Inc. ("C&C") for approximately $224 million. C&C is a global provider of ocean-bottom
mapping services in deepwater utilizing customized autonomous underwater vehicles and provides
marine construction surveys for both surface and subsea assets, as well as satellite-based
positioning services for drilling rigs and seismic and construction vessels. C&C also provides land and
near-shore survey services along the U.S. Gulf Coast and in Mexico, and performs shallow water
conventional geophysical surveys in the U.S. Gulf of Mexico. In addition to the C&C acquisition, our
capital expenditures in 2015 included: $58 million for upgrading and expanding our ROV fleet; $69
million in our Subsea Products segment, principally for growth of our tooling and installation and
workover control systems capabilities; and $52 million in our Subsea Projects segment, including
$43 million related to a new subsea support vessel scheduled for delivery in 2017. Our capital
expenditures in 2014 included: $189 million for upgrading and expanding our ROV fleet; $113
million in our Subsea Products segment, principally for growth of our tooling and installation and
workover control systems capabilities, expansion of our Houston manufacturing facilities and
establishment of manufacturing capabilities in Angola; and $92 million in our Subsea Projects
segment, including $40 million related to a new subsea support vessel scheduled for delivery in
2017.
For 2017, we expect our capital expenditures to be in the range of $90 million to $120 million,
exclusive of business acquisitions. This estimate includes $25 million in our Subsea Projects
segment to complete the new-build subsea support vessel, the Ocean Evolution, scheduled for
delivery in the middle of 2017. During the third quarter of 2013, we signed an agreement with a
shipyard for the construction of the Ocean Evolution. We intend for the vessel to be U.S.-flagged
and documented with a coastwise endorsement by the U.S. Coast Guard. It is expected to have an
overall length of 353 feet, a Class 2 dynamic positioning system, accommodations for 110 personnel,
a helideck, a 250-ton active heave-compensated crane, and a working moonpool. We expect to
32
outfit the vessel with two of our high specification work-class ROVs. The vessel will also be equipped
with a satellite communications system capable of transmitting streaming video for real-time work
observation by shore personnel. We anticipate the vessel will be used to augment our ability to
provide subsea intervention services in the U.S. Gulf of Mexico. These services are required to
perform inspection, maintenance and repair projects and hardware installations.
Our capital expenditures during 2016, 2015 and 2014 included $50 million, $58 million and $189
million, respectively, in our ROV segment, principally for additions and upgrades to our ROV fleet to
expand the fleet and replace units we retired and for facilities infrastructure to support our growing
ROV fleet size. We currently plan to add new ROVs only to meet contractual commitments. We
added 6, 16 and 49 ROVs to our fleet and retired 41, 36, and 17 units during 2016, 2015 and 2014,
respectively, and transferred one to our Advanced Technologies segment in 2015, resulting in a total
of 280 work-class systems in the fleet at December 31, 2016. Over the past two years, we retired a
greater number of ROVs than we have added due to market conditions and outlook.
Unless indicated otherwise, each of the vessels discussed below is a deepwater multiservice subsea
support vessel outfitted with two of our high-specification work-class ROVs.
Beginning in the third quarter of 2008, we chartered a vessel, the Olympic Intervention IV, for an
initial term of five years. Following extension periods, the charter expired in July 2016, and we
released the vessel to its owner. We had been using the Olympic Intervention IV in the U.S. Gulf of
Mexico.
In 2012, we moved the chartered vessel Ocean Intervention III to Angola and also chartered the
Bourbon Oceanteam 101 to work on a three-year field support vessel services contract for a unit of
BP plc. We had extended the charter of the Bourbon Oceanteam 101 to January 2017. However, in
early 2016, the customer exercised its right, under the field support vessel services contract, to
terminate its use of the Bourbon Oceanteam 101 at the end of May 2016. Under the terms of the
contract, the costs incurred by us associated with the early release and demobilization of the vessel
were reimbursed by the customer. Following the release of the vessel, we redelivered it to the vessel
supplier. Under the field support vessel services contract, which has been extended through
January 2019, we are continuing to supply project management, engineering and the
Ocean Intervention III, which we have under charter on a month-to-month basis through July 2017.
We also provide ROV tooling, asset integrity services and installation and workover control system
services. We also have provided other chartered vessels and barges as requested by the customer.
In March 2013, we commenced a five-year charter for a Jones Act-compliant multi-service support
vessel, the Ocean Alliance, we have been using in the U.S. Gulf of Mexico. In January 2015, we
commenced a two-year contract with a customer for the use of the Ocean Alliance. The contract
expired in January 2017, and we are marketing the vessel for spot market work in the U.S. Gulf of
Mexico.
In December 2013, we commenced a three-year charter for the Normand Flower, a multi-service
subsea marine support vessel. We made modifications to the vessel and used the vessel in the U.S.
Gulf of Mexico to perform inspection, maintenance and repair projects and hardware installations. In
December 2016, we declined our option to extend the charter and the vessel was released.
In November 2015, we commenced a two-year charter for the use of the Island Pride, a multi-
service subsea marine support vessel. We are using the vessel under a two-year contract to provide
field support services off the coast of India for an oil and gas customer based in India. We have
options to extend the charter for up to two additional years.
We also charter or lease vessels on a short-term basis as necessary to augment our fleet.
Our principal source of cash from operating activities is our net income, adjusted for the non-cash
expenses of depreciation and amortization, deferred income taxes and noncash compensation under
our restricted stock plans. Our $341 million, $560 million and $722 million of cash provided from
operating activities in 2016, 2015 and 2014, respectively, were affected by cash
increases/(decreases) of: (1) $123 million, $179 million and $(8) million, respectively, of changes in
accounts receivable; (2) $18 million, $33 million and $66 million, respectively, of changes in
33
inventory; and (3) $(117) million, $(45) million and $(44) million, respectively, of changes in
accounts payable and accrued liabilities. In 2016 and 2015, our accounts receivable, inventory and
accounts payable and accrued liabilities all decreased as a result of lower revenue and activity in
general from each year's preceding year. The 2016 and 2015 decreases in inventory were in
addition to write-downs totaling $30 million and $26 million, respectively, in our ROV and Subsea
Products segments discussed below. In 2014, our inventory decreased as a result of the use of
inventory in progressing and completing projects that had been in our Subsea Products backlog at
December 31, 2013 and our expectation of lower Subsea Products demand in 2015 as compared to
2014.
In 2016, we used a net of $169 million in investing activities, with $143 million used to fund the
capital expenditures described above and $39 million used to purchase Angolan central bank bonds
indexed to the U.S. dollar. In 2015, we used a net of $437 million in investing activities, with $424
million used to fund the capital expenditures and business acquisitions described above. In 2014,
we used a net of $419 million in investing activities, with $427 million used to fund the capital
expenditures and business acquisitions described above.
In 2016, we used $97 million in financing activities, primarily for the $94 million of cash dividends
we paid. In 2015, we used $157 million in financing activities. We borrowed $50 million,
repurchased 2 million shares for $100 million and paid cash dividends of $106 million. In 2014, we
generated $45 million in financing activities. We borrowed $742 million, net of associated expenses
and debt discount, repurchased 8.9 million shares for $590 million and paid cash dividends of $110
million.
In February 2010, our Board of Directors approved a program to repurchase up to 12 million shares
of our common stock. In 2014, we completed the purchase of the shares authorized under that
program by repurchasing the remaining 8.9 million shares for $590 million. The total cost for the
repurchase of the 12 million shares of our common stock was $677 million.
In December 2014, following completion of the February 2010 program, our Board of Directors
approved a new share repurchase program under which we may repurchase up to 10 million shares
of our common stock on a discretionary basis. The December 2014 program calls for the
repurchases to be made in the open market, or in privately negotiated transactions from time to
time, in compliance with applicable laws, rules and regulations, including Rule 10b-18 under the
Securities Exchange Act of 1934, as amended, subject to market and business conditions, levels of
available liquidity, cash requirements for other purposes, applicable legal requirements and other
relevant factors. The timing and amount of any repurchases will be determined by our management
based on its evaluation of these factors. We expect that any shares repurchased under the new
program will be held as treasury stock for future possible use. The new program does not obligate us
to repurchase any particular number of shares. Through December 31, 2015 under the new
program, we repurchased 2 million shares of our common stock for $100 million. We did not
repurchase any shares in 2016.
As of December 31, 2016, we retained 12.8 million of the shares we had repurchased. We expect to
hold the shares repurchased for future use.
Because of our significant foreign operations, we are exposed to currency fluctuations and exchange
rate risks. We generally minimize these risks primarily through matching, to the extent possible,
revenue and expense in the various currencies in which we operate. Cumulative translation
adjustments as of December 31, 2016 relate primarily to our net investments in, including long-term
loans to, our foreign subsidiaries. A stronger U.S. dollar against the U.K. pound sterling, Norwegian
kroner and Brazilian real would result in lower operating income. See Item 7A – "Quantitative and
Qualitative Disclosures About Market Risk."
Results of Operations
Additional information on our business segments is shown in Note 7 of the Notes to Consolidated
Financial Statements included in this report.
Oilfield. The table that follows sets out revenue and profitability for the business segments within
our Oilfield business. In the ROV section of the table that follows, "Days available" includes all days
from the first day that an ROV is placed in service until the ROV is retired. All days in this period are
34
considered available days, including periods when an ROV is undergoing maintenance or repairs.
Our ROVs do not have scheduled maintenance or repair that requires significant time when the ROVs
are not available for utilization.
(dollars in thousands)
Remotely Operated Vehicles
Revenue
Gross Margin
Gross Margin %
Operating Income
Operating Income %
Days available
Days utilized
Utilization %
Subsea Products
Revenue
Gross Margin
Gross Margin %
Operating Income
Operating Income %
Backlog at end of period
Subsea Projects
Revenue
Gross Margin
Gross Margin %
Operating Income
Operating Income %
Asset Integrity
Revenue
Gross Margin
Gross Margin %
Operating Income
Operating Income %
Total Oilfield
Revenue
Gross Margin
Gross Margin %
Operating Income
Operating Income %
Year Ended December 31,
2016
2015
2014
$ 522,121
59,038
11%
25,193
$ 807,723
227,330
$ 1,069,022
361,466
28%
192,514
34%
320,550
5%
24%
30%
112,588
59,963
121,944
83,838
117,882
98,302
53%
69%
83%
692,030
140,275
20%
75,938
11%
431,000
472,979
51,392
11%
34,476
7%
275,397
41,458
15%
7,551
3%
959,714
257,755
27%
175,585
18%
652,000
604,484
114,672
19%
92,034
15%
372,957
47,342
13%
18,235
5%
1,238,746
364,760
29%
281,239
23%
690,000
588,572
124,418
21%
107,852
18%
500,237
87,236
17%
55,469
11%
$ 1,962,527
292,163
$ 2,744,878
647,099
$ 3,396,577
937,880
15%
143,158
24%
478,368
28%
765,110
7%
17%
23%
Historically, we built new ROVs to increase the size of our fleet in response to demand to support
deepwater drilling and vessel-based inspection, maintenance and repair ("IMR") and installation
work. In 2015, as a result of declining market conditions, we began building fewer ROVs, primarily
to meet contractual commitments. These vehicles are designed for use around the world in water
depths of 10,000 feet or more. We added 6, 16 and 49 ROVs in 2016, 2015 and 2014, respectively,
while retiring 94 units over the three-year period and transferring one to our Advanced Technologies
segment over that period. Our ROV fleet size was 280 at December 31, 2016, 315 at December 31,
35
2015 and 336 at December 31, 2014. We have decreased our ROV fleet size over the last two years
as a result of lower market demand.
Our ROV operating income decreased in the year ended December 31, 2016 compared to the prior
year, as a result of lower days on hire and lower average revenue per day-on-hire, as well as
inventory write-downs and fixed asset write-offs totaling $36.0 million in 2016. During 2016, the
leading indicator for deepwater activity, contracted floating rigs, continued to decline as the rate of
rigs being idled, either by contract termination or expiration, continued. This prevailing market
condition required us to reassess the number of ROVs we had in our fleet, as well as the associated
inventory. As a result of our reassessment, in 2016 we recorded $36.0 million of charges consisting
of: (1) $25.2 million for a reserve for excess inventory; and (2) $10.8 million for the retirement of
39 ROVs. During 2016 we also incurred charges related to restructuring expenses of $3.8 million
and bad debt expenses of $1.2 million.
For 2015, our ROV revenue and operating income declined from 2014 from lower demand for drill
support services and a reduction in average revenue per day across all our geographic areas of
operation. ROV days on hire decreased by 15% and revenue per day on hire decreased 11%. In
2015, our ROV cost of services and products included inventory write-downs of $15.7 million,
restructuring expenses of $7.2 million and ROV retirements resulting in write-offs of $2.9 million.
The inventory write downs were due to excess inventory, which we do not anticipate using given
current and forecast market conditions. The restructuring expenses related to severance costs for
incurred and designated future workforce reductions and costs associated with closing excess
facilities. The write-offs were necessitated as a result of our retiring an unusually large number of
ROVs in 2015 due to market prospects for these vehicles.
In our financial statements, the charges incurred in both 2016 and 2015 are reflected in our cost of
services and products, except for the charges related to bad debts, which are reflected in general
and administrative expenses.
We anticipate ROV operating income to decrease in 2017 as a result of decreases in average revenue
per day on hire and the number of days on hire for drilling support services, attributable to the
market conditions described under "Overview" above. We normally expect to retire, on average, 4%
to 5% of our fleet on an annual basis, although we retired a greater number in each of 2016 and
2015 due to market conditions.
To improve operational efficiency, in 2016 we reorganized our Subsea Products segment into two
business units – (1) manufactured products and (2) service and rental. Manufactured products
include production control umbilicals and specialty subsea hardware, while service and rental
includes tooling, subsea work systems and installation and workover control systems. This internal
reorganization does not affect our segment reporting structure or the historical comparability of our
segment results. The following table presents revenue from manufactured products and service and
rental, as their respective percentages of total Subsea Products revenue:
Manufactured Products
Service and Rental
Year Ended December 31,
2016
2015
2014
65%
61%
64%
35%
39%
36%
36
For the year ended December 31, 2016, our Subsea Products revenue and operating income
decreased from the prior year across both business units, but most notably due to lower demand for
and pricing of service and rental. In 2016 we incurred the following charges:
• $8.2 million, predominantly for tools and inventory in our portfolio used to support deepwater
drilling and operations;
• $3.7 of restructuring expenses; and
• $1.9 million of allowances for bad debts.
Subsea Products revenue, operating income and margin were lower in 2015 than in 2014 due to
lower demand and pricing for tooling and subsea hardware and lower umbilical plant throughput.
Due to deteriorating market conditions, we wrote down Subsea Products inventory $10.3 million in
2015, including $9.0 million associated with our decision to cease manufacture of subsea BOP control
systems. In 2015, Subsea Products also incurred the following charges:
• $8.7 million of restructuring expenses;
• $6.6 million of a non-current asset reserve; and
• $4.8 million for an allowance for bad debts.
In our financial statements, the charges incurred in both 2016 and 2015 are reflected in our cost of
services and products, except for the charges related to the allowances for bad debts, which are
reflected in general and administrative expenses. The restructuring expenses related to severance
costs for incurred and designated future workforce reductions and costs associated with closing
excess facilities. The charge for a non-current asset reserve related to prepaid non-income taxes
based on consumption, and the charge amount is based on our estimate of the amount that will
expire due to reduced activity going forward. The allowance for bad debts in 2015 related to a
customer that filed for bankruptcy and was unable to pay for a built umbilical.
We anticipate our Subsea Products segment operating income in 2017 to be lower than in 2016 on a
decline in pricing in current backlog and new orders, and we expect reduced margins in the mid- to
high-single digit range. Our Subsea Products backlog was $431 million at December 31, 2016,
approximately 34% lower than it was at December 31, 2015. The backlog decrease from 2015 was
principally in umbilicals.
For the year ended December 31, 2016, our Subsea Projects revenue and operating income
decreased from that of the prior year, as a result of decreased demand and lower pricing for
deepwater vessel services, including the completion during April 2015 of work associated with the
Bourbon Evolution 803, a vessel we chartered on a short-term basis for use offshore Angola
associated with our field support vessel services contract, and the release in May 2016 of the
Bourbon Oceanteam 101, which was previously deployed under the same contract offshore Angola.
Subsea Projects operating income declined slightly during 2015 from 2014 on slightly higher
revenue. The relatively better performance compared to the other oilfield segments was aided by an
increase in international manned diving operations. The decline in operating income was due to
lower deepwater vessel activity and market pricing offshore Angola and in the U.S. Gulf of Mexico
and from survey operations from reduced demand and lower pricing.
For the year ended December 31, 2016, our Asset Integrity revenue and operating income decreased
from that of the prior year across most of our operating areas, due to decreased demand and
pricing. Our Asset Integrity results in 2016 included bad debt expense of $5.0 million, which is
reflected in selling, general and administrative expense, and $1.4 million of restructuring charges,
which are reflected in our cost of services and products.
In 2015, our Asset Integrity operating income declined precipitously on lower global demand and
pricing for inspection services. Asset Integrity results in 2015 include restructuring charges of
$6.4 million reflected in our cost of services and products.
We anticipate our 2017 operating income for Asset Integrity to be lower than in 2016 on continued
lower global demand and pricing.
37
Advanced Technologies. The table that follows sets out revenue and profitability for this segment.
(dollars in thousands)
Revenue
Gross Margin
Gross Margin %
Operating Income
Operating Income %
Year Ended December 31,
2016
$ 309,076
33,784
2015
$ 317,876
30,034
2014
$ 263,047
32,410
11%
11,809
4%
9%
9,689
3%
12%
13,230
5%
For the year ended December 31, 2016, Advanced Technologies operating income was higher than
that of the corresponding period of 2015, due to improved execution on commercial theme park
projects. Advanced Technologies operating income for 2015 was lower than that of 2014 due to
execution issues on commercial theme park projects. We project an improvement in our Advanced
Technologies operating income in 2017, due to increased activity.
Unallocated Expenses. Our unallocated expenses, i.e., those not associated with a specific
business segment, within gross margin consist of expenses related to our incentive and deferred
compensation plans, including restricted stock and bonuses, as well as other general expenses. Our
unallocated expenses within operating income consist of those within gross margin plus general and
administrative expenses related to corporate functions.
The table that follows sets out our unallocated expenses.
(dollars in thousands)
Gross margin expenses
% of revenue
Operating expenses
% of revenue
Year Ended December 31,
2016
(46,720) $
2015
(71,704) $ (111,089)
2014
$
2%
2%
3%
(84,203)
(114,247)
(150,010)
4%
4%
4%
Our unallocated expenses have trended with the amounts of our incentive compensation expenses.
Our unallocated gross margin and operating expenses decreased in 2016 and in 2015, due to lower
compensation expenses related to the expected annual bonuses and valuation of performance units
awarded under our incentive plan. We expect higher incentive plan compensation expenses in 2017,
as 2016 included downward revisions of estimated expenses for the performance units outstanding
under the incentive plan.
Other. The table that follows sets forth our financial statement items below the operating income
line.
(dollars in thousands)
Interest income
Interest expense, net of amounts capitalized
Equity earnings (loss) of unconsolidated affiliates
Other income (expense), net
Provision for income taxes
Year Ended December 31,
2016
2015
2014
$
3,900 $
607 $
(25,318)
244
(6,244)
18,760
(25,050)
2,230
(15,336)
105,250
293
(4,708)
(51)
(387)
195,148
Interest income increased in 2016 from our investment in Angola bonds, as mentioned in"Liquidity
and Capital Resources" above.
In addition to interest on borrowings, interest expense includes amortization of loan costs, fees for
lender commitments under our revolving credit agreement and fees for standby letters of credit and
bank guarantees that banks issue on our behalf for performance bonds, bid bonds and self-insurance
requirements.
38
Interest expense increased in 2015 over 2014 from higher average debt levels. We capitalized $3.7
million, $2.4 million and $0.7 million of interest in 2016, 2015 and 2014, respectively, associated
with the new-build vessel described under "Liquidity and Capital Resources" above.
Included in other income (expense), net are foreign currency transaction losses of $4.8 million,
$15.4 million and $0.5 million for 2016, 2015 and 2014, respectively. The losses in 2016 and 2015
primarily related to Angola, which devalued its currency by 18% in 2016 and 24% in 2015. We likely
would incur further foreign currency exchange losses in Angola if additional currency devaluations
occur. In 2016, other income (expense), net also includes curtailment costs of $1.1 million related
to the Norway defined benefit plan.
Our effective tax rate, including foreign, state and local taxes, was 43.3%, 31.3%, and 31.3% for
2016, 2015 and 2014, respectively, which included a combination of expiring statutes of limitations
and the resolution of uncertain tax positions of $0.9 million, $1.3 million and $0.9 million,
respectively, related to certain liabilities for uncertain tax positions we recorded in prior years. In
2016, the increase in the effective tax rate was primarily due to a change in the mix of income or
losses between the U.S. and certain foreign jurisdictions. This resulted in a recapture of prior year
U.S. manufacturing deductions and a limitation of the current benefit from certain foreign tax
payments. In 2015 and 2014, the primary difference between our effective tax rates and the U.S.
federal statutory rate of 35% was from our intent to indefinitely reinvest in certain of our
international operations. Therefore, we were not providing for U.S. taxes on a portion of our foreign
earnings. In 2017, we cannot project a meaningful effective rate, as the rate is less significant at a
low pretax income or a pretax loss position. We do project a discrete additional income tax provision
in the first quarter of 2017 in accordance with a new accounting standard associated with our share-
based incentive plan.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements, as defined by SEC rules.
Contractual Obligations
At December 31, 2016, we had payments due under contractual obligations as follows:
(dollars in thousands)
Payments due by period
Long-term Debt
Vessel Charters
Other Operating Leases
Purchase Obligations
Total
2017
$ 800,000 $
— $
26,260
255,699
24,970
31,478
160,471
149,954
2017-2018 2019-2020 After 2020
30,000 $ 270,000 $ 500,000
1,290
49,193
10,413
138,807
36,221
—
59
45
Other Long-term Obligations reflected on
our Balance Sheet under GAAP
TOTAL
64,592
1,452
$ 1,307,022 $ 207,854 $
3,011
57,785
2,344
93,907 $ 308,610 $ 696,651
The vessel charter obligations in the table above do not include any optional extension periods.
At December 31, 2016, we had outstanding purchase order commitments totaling $160 million,
including approximately $25 million for the construction of a new subsea support vessel scheduled
for delivery in 2017.
In 2001, we entered into an agreement with our Chairman of the Board of Directors (the
"Chairman") who was also then our Chief Executive Officer. That agreement was amended in 2006
and in 2008. Pursuant to the amended agreement, the Chairman relinquished his position as Chief
Executive Officer in May 2006 and began his post-employment service period on December 31,
2006, which continued through August 15, 2011, during which service period the Chairman, acting
as an independent contractor, agreed to serve as nonexecutive Chairman of our Board of Directors.
The agreement provides the Chairman with post-employment benefits for ten years following
August 15, 2011. The agreement also provides for medical coverage on an after-tax basis to the
39
Chairman, his spouse and children for their lives. We recognized the net present value of the post-
employment benefits over the expected service period. Our total accrued liabilities, current and
long-term, under this post-employment benefit were $4.5 million and $5.1 million at December 31,
2016 and 2015, respectively.
Effects of Inflation and Changing Prices
Our financial statements are prepared in accordance with generally accepted accounting principles in
the United States, using historical U.S. dollar accounting, or historical cost. Statements based on
historical cost, however, do not adequately reflect the cumulative effect of increasing costs and
changes in the purchasing power of the dollar, especially during times of significant and continued
inflation.
In order to minimize the negative impact of inflation on our operations, we attempt to cover the
increased cost of anticipated changes in labor, material and service costs, either through an estimate
of those changes, which we reflect in the original price, or through price escalation clauses in our
contracts. Inflation has not had a material effect on our revenue or income from operations in the
past three years, and no such effect is expected in the near future.
40
Item 7A. Quantitative and Qualitative Disclosures About Market Risk.
We are currently exposed to certain market risks arising from transactions we have entered into in
the normal course of business. These risks relate to interest rate changes and fluctuations in foreign
exchange rates. We do not believe these risks are material. We have not entered into any market
risk sensitive instruments for speculative or trading purposes. We currently have two interest rate
swaps in place on a total of $200 million of the Senior Notes. See Note 6 of Notes to Consolidated
Financial Statements included in this report for a description of these interest rate swaps. We
typically manage our exposure to interest rate changes through the use of a combination of fixed-
and floating-rate debt. See Note 5 of Notes to Consolidated Financial Statements included in this
report for a description of our revolving credit facility and interest rates on our borrowings. We
believe significant interest rate changes would not have a material near-term impact on our future
earnings or cash flows.
Because we operate in various oil and gas exploration and production regions in the world, we
conduct a portion of our business in currencies other than the U.S. dollar. The functional currency
for several of our international operations is the applicable local currency. A stronger U.S. dollar
against the U.K. pound sterling, the Norwegian kroner and the Brazilian real would result in lower
operating income. We manage our exposure to changes in foreign exchange rates principally
through arranging compensation in U.S. dollars or freely convertible currency and, to the extent
possible, by limiting compensation received in other currencies to amounts necessary to meet
obligations denominated in those currencies. We use the exchange rates in effect as of the balance
sheet date to translate assets and liabilities as to which the functional currency is the local currency,
resulting in translation adjustments that we reflect as accumulated other comprehensive income or
loss in the shareholders' equity section of our Consolidated Balance Sheets. We recorded negative
adjustments of $6 million, $119 million and $129 million to our equity accounts in 2016, 2015 and
2014, respectively. Negative adjustments reflect the net impact of the strengthening of the U.S.
dollar against various foreign currencies for locations where the functional currency is not the U.S.
dollar. Conversely, positive adjustments reflect the effect of a weakening U.S. dollar.
Included in other income (expenses), net are foreign currency transaction losses of $4.8 million,
$15.4 million and $0.5 million for 2016, 2015 and 2014, respectively. The losses in 2016 and 2015
primarily related to Angola, which devalued its currency by 18% in 2016 and 24% in 2015. We likely
would incur further foreign currency exchange losses in Angola if additional currency devaluations
occur.
As of December 31, 2016, we had the equivalent of approximately $32.0 million of cash in kwanza in
Angola reflected on our balance sheet. To mitigate our currency exposure risk in Angola, we have
used kwanza to purchase $59.1 million equivalent Angolan central bank (Banco Nacional de Angola)
bonds with various maturities throughout 2018. The bonds are denominated as U.S. dollar
equivalents, so that, upon payment of semi-annual interest and principal upon maturity, payment is
made in kwanza, equivalent to the respective U.S. dollars at the then-current exchange rate.
Item 8.
Financial Statements and Supplementary Data.
In this report, our consolidated financial statements and supplementary data appear following the
signature page to this report and are incorporated into this item by reference.
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial
Disclosure.
None.
41
Item 9A. Controls and Procedures.
Disclosure Controls and Procedures
In accordance with Rules 13a-15 and 15d-15 under the Securities Exchange Act of 1934, as amended
(the "Exchange Act"), we carried out an evaluation, under the supervision and with the participation of
management, including our principal executive officer and principal financial officer, of the
effectiveness of our disclosure controls and procedures (as that term is defined in Rules 13a-15(e) and
15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based on that
evaluation, our principal executive officer and principal financial officer concluded that our disclosure
controls and procedures were effective as of December 31, 2016 to provide reasonable assurance that
information required to be disclosed in our reports filed or submitted under the Exchange Act is
recorded, processed, summarized and reported within the time periods specified in the Securities and
Exchange Commission's rules and forms.
Internal Control over Financial Reporting
There has been no change in our internal control over financial reporting that occurred during the
quarter ended December 31, 2016 that has materially affected, or is reasonably likely to materially
affect, our internal control over financial reporting.
Management's Report on Internal Control Over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over
financial reporting (as that term is 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, but not
absolute, assurance regarding the reliability of financial reporting and the preparation of financial
statements for external reporting purposes in accordance with accounting principles generally accepted
in the United States of America. We developed our internal control over financial reporting through a
process in which our management applied its judgment in assessing the costs and benefits of various
controls and procedures, which, by their nature, can provide only reasonable assurance regarding the
control objectives. You should note that the design of any system of controls is based in part on
various assumptions about the likelihood of future events, and we cannot assure you that any system
of controls will succeed in achieving its stated goals under all potential future conditions, regardless of
how remote. 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 and procedures may deteriorate.
Under the supervision and with the participation of our management, including our principal executive,
financial and accounting officers, we have conducted an evaluation of the effectiveness of our internal
control over financial reporting based on the framework in Internal Control – Integrated Framework
issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework).
This evaluation included a review of the documentation surrounding our financial reporting controls, an
evaluation of the design effectiveness of these controls, testing of the operating effectiveness of these
controls and an evaluation of our overall control environment. Based on that evaluation, our
management has concluded that our internal control over financial reporting was effective as of
December 31, 2016.
Ernst & Young LLP, the independent registered public accounting firm that audited our financial
statements, has audited our internal control over financial reporting, as stated in their report that
follows.
42
Report of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholders of Oceaneering International, Inc.
We have audited the internal control over financial reporting of Oceaneering International, Inc. and
subsidiaries 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"). Oceaneering International, Inc. and subsidiaries' management is
responsible for maintaining effective internal control over financial reporting, and for its assessment of
the effectiveness of internal control over financial reporting included in the accompanying
Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an
opinion on the company's internal control over financial reporting based on our audit.
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight
Board (United States). Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether effective internal control over financial reporting was maintained
in all material respects. Our audit included obtaining an understanding of internal control over financial
reporting, assessing the risk that a material weakness exists, testing and evaluating the design and
operating effectiveness of internal control based on the assessed risk, and performing such other
procedures as we considered necessary in the circumstances. We believe that our audit provides a
reasonable basis for our opinion.
A company's internal control over financial reporting is a process designed to provide reasonable
assurance regarding the reliability of financial reporting and the preparation of financial statements for
external purposes in accordance with generally accepted accounting principles. A company's internal
control over financial reporting includes those policies and procedures that (1) pertain to the
maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and
dispositions of the assets of the company; (2) provide reasonable assurance that transactions are
recorded as necessary to permit preparation of financial statements in accordance with generally
accepted accounting principles, and that receipts and expenditures of the company are being made
only in accordance with authorizations of management and directors of the company; and (3) provide
reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or
disposition of the company's assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect
misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the
risk that controls may become inadequate because of changes in conditions, or that the degree of
compliance with the policies or procedures may deteriorate.
In our opinion, Oceaneering International, Inc. and subsidiaries 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 Oceaneering International, Inc. and
subsidiaries as of December 31, 2016 and 2015, and the related consolidated statements of income,
comprehensive income, shareholders' equity and cash flows for each of the three years in the period
ended December 31, 2016, and our report dated February 24, 2017 expressed an unqualified opinion
thereon.
Houston, Texas
February 24, 2017
Item 9B.
Other Information.
None.
43
/s/ ERNST & YOUNG LLP
Part III
Item 10. Directors, Executive Officers and Corporate Governance.
The information with respect to the directors and nominees for election to our Board of Directors is
incorporated by reference from the section "Election of Directors" in our definitive proxy statement to
be filed on or before May 1, 2017, relating to our 2017 Annual Meeting of Shareholders.
Information concerning our Audit Committee and the audit committee financial experts is
incorporated by reference from the sections entitled "Corporate Governance" and "Committees of the
Board – Audit Committee" in the proxy statement referred to in this Item 10. Information
concerning our Code of Ethics is incorporated by reference from the section entitled "Code of Ethics"
for the Chief Executive Officer and Senior Financial Officers in the proxy statement previously
referred to in this Item 10.
The information with respect to our executive officers is provided under the heading "Executive
Officers of the Registrant" following Item 1 of Part I of this report. There are no family relationships
between any of our directors or executive officers.
The information with respect to the reporting by our directors and executive officers and persons
who own more than 10% of our Common Stock under Section 16 of the Securities Exchange Act of
1934 is incorporated by reference from the section entitled "Section 16(a) Beneficial Ownership
Reporting Compliance" in the proxy statement previously referred to in this Item 10.
Item 11. Executive Compensation.
The information required by Item 11 is incorporated by reference from the sections entitled
"Compensation Committee Interlocks and Insider Participation," "Compensation Discussion and
Analysis," "Report of the Compensation Committee," "Compensation of Executive Officers," and
"Compensation of Nonemployee Directors" in the proxy statement referred to in Item 10 above.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related
Stockholder Matters.
The information required by Item 12 is incorporated by reference from (1) the Equity Compensation
Plan Information table appearing in Item 5 – "Market for Registrant's Common Equity, Related
Stockholder Matters and Issuer Purchases of Equity Securities" in Part II of this report and (2) the
section "Security Ownership of Management and Certain Beneficial Owners" in the proxy statement
referred to in Item 10 above.
Item 13. Certain Relationships and Related Transactions, and Director Independence.
The information required by Item 13 is incorporated by reference from the sections entitled
"Corporate Governance" and "Certain Relationships and Related Transactions" in the proxy statement
referred to in Item 10 above.
Item 14. Principal Accounting Fees and Services.
The information required by Item 14 is incorporated by reference from the section entitled
"Ratification of Appointment of Independent Auditors – Fees Incurred for Audit and Other Services
provided by Ernst & Young LLP" in the proxy statement referred to in Item 10 above.
44
Part IV
Item 15. Exhibits, Financial Statement Schedules.
(a) Documents filed as part of this report.
1. Financial Statements:
(i) Report of Independent Registered Public Accounting Firm
(ii) Consolidated Balance Sheets
(iii) Consolidated Statements of Income
(iv) Consolidated Statements of Comprehensive Income
(v) Consolidated Statements of Cash Flows
(vi) Consolidated Statements of Shareholders' Equity
(vii) Notes to Consolidated Financial Statements
2. Financial Statement Schedules:
All schedules for which provision is made in the applicable regulations of the
Securities and Exchange Commission have been omitted because they are not
required under the relevant instructions or because the required information is not
significant.
3.
Exhibits:
*
*
*
*
*
*
*
*
*
3.01 Restated Certificate of Incorporation
3.02 Certificate of Amendment to Restated
Certificate of Incorporation
Registration
or File
Number
Form of
Report
1-10945
1-10945
10-K
8-K
3.03 Certificate of Amendment to Restated
1-10945
8-K
Certificate of Incorporation
3.04 Amended and Restated Bylaws
4.01 Specimen of Common Stock Certificate
1-10945
1-10945
4.02 Credit Agreement, dated as of October 27,
1-10945
8-K
10-K
8-K
2014, by and among Oceaneering
International, Inc., Wells Fargo Bank,
National Association, as administrative agent
and swing line lender, and certain lenders
party thereto
Report
Date
Dec. 2000
May 2008
May 2014
Aug. 2015
Mar. 1993
Oct. 2014
4.03 Agreement and Amendment No. 1 to Credit
1-10945
8-K
Agreement
4.04 Agreement and Amendment No. 2 to Credit
1-10945
8-K
Agreement
Nov. 2015
Nov. 2016
4.05
Indenture dated, November 21, 2014,
between Oceaneering International, Inc. and
Wells Fargo Bank, National Association, as
Trustee, relating to senior debt securities of
Oceaneering International, Inc.
1-10945
8-K
Nov. 2014
Exhibit
Number
3.01
3.1
3.1
3.1
4(a)
4.1
4.1
4.1
4.1
*
4.06 First Supplemental Indenture, dated
November 21, 2014, between Oceaneering
International, Inc. and Wells Fargo Bank,
National Association, as Trustee, providing
for the issuance of Oceaneering
International, Inc.’s 4.650% Senior Notes
due 2024 (including Form of Notes).
1-10945
8-K
Nov. 2014
4.2
45
We and certain of our consolidated subsidiaries are parties to debt instruments under which the total amount
of securities authorized does not exceed 10% of our total consolidated assets. Pursuant to paragraph 4(iii)(A)
of Item 601(b) of Regulation S-K, we agree to furnish a copy of those instruments to the Securities and
Exchange Commission on request.
10.01+ Oceaneering International, Inc. Retirement
Investment Plan, with amendments through
December 28, 2016
*
10.02+ Oceaneering Retirement Investment Plan
Trust Agreement effective December 31,
2013
1-10945
10-K
Dec. 2014
10.13
*
10.03+ Amended and Restated Service Agreement
1-10945
8-K
dated as of December 21, 2006 between
Oceaneering and John R. Huff
*
10.04+ Modification to Service Agreement dated as
1-10945
8-K
of December 21, 2006 between Oceaneering
and John R. Huff
*
10.05+ Trust Agreement dated as of May 12, 2006
1-10945
8-K
between Oceaneering and United Trust
Company, National Association
*
10.06+ First Amendment to Trust Agreement dated
1-10945
8-K
Dec. 2006
10.1
Dec. 2008
10.9
May 2006
10.2
Dec. 2008
10.10
as of May 12, 2006 between Oceaneering
International, Inc. and Bank of America
National Association, as successor trustee
*
10.07+ Oceaneering International, Inc.
Supplemental Executive Retirement Plan, as
amended and restated effective January 1,
2009
*
10.08+ Amended and Restated Oceaneering
International, Inc. Supplemental Executive
Retirement Plan, as amended and restated
effective January 1, 2000 (for Internal
Revenue Code Section 409A-grandfathered
benefits)
1-10945
8-K
Dec. 2008
10.5
1-10945
8-K
Dec. 2008
10.6
*
*
*
*
*
*
*
*
*
*
*
*
*
*
10.09+ Change-of-Control Agreement dated as of
November 16, 2001 between Oceaneering
and M. Kevin McEvoy
1-10945
10-K
Dec. 2001
10.06
10.10+ Form of First Amendment to Change-of-
1-10945
8-K
Control Agreement with M. Kevin McEvoy
10.11+ Form of Change-of-Control Agreement and
1-10945
8-K
Annex for Roderick A. Larson
10.12+ Form of Change-of-Control Agreement
10.13+ Form of Indemnification Agreement
10.14+ 2010 Incentive Plan
1-10945
1-10945
8-K
8-K
333-166612 S-8
10.15+ Amended and Restated 2010 Incentive Plan
1-10945
DEF 14A
10.16+ Form of 2016 Restricted Stock Unit
1-10945
8-K
Agreement
10.17+ Form of 2016 Performance Unit Agreement
1-10945
10.18+ Form of 2016 Performance Award: Goals and
Measures, relating to the form of 2016
Performance Unit Agreement
1-10945
8-K
8-K
Dec. 2008
Aug. 2015
May 2011
May 2011
May 2010
Apr. 2015
Feb. 2016
Feb. 2016
Feb. 2016
10.19+ Form of 2016 Nonemployee Director
Restricted Stock Agreement
1-10945
8-K
Feb. 2016
10.20+ 2016 Annual Cash Bonus Award Program
1-10945
8-K
Summary
Feb. 2016
10.21+ Form of 2015 Restricted Stock Unit
Agreement
1-10945
8-K
Feb. 2015
10.22+ Form of 2015 Performance Unit Agreement
1-10945
8-K
Feb. 2015
10.7
10.3
10.5
10.4
4.6
Appendix A
10.1
10.2
10.3
10.4
10.5
10.1
10.2
46
*
10.23+ 2015 Performance Award: Goals and
Measures, relating to the form of 2015
Performance Unit Agreement
*
10.24+ Form of 2015 Nonemployee Director
Restricted Stock Agreement for Messrs.
Collins, Huff, Hughes, Murphy and Pappas
*
10.25+ Form of 2015 Nonemployee Director
Restricted Stock Agreement for Mr.
DesRoche
1-10945
8-K
Feb. 2015
10.3
1-10945
8-K
Feb. 2015
10.4
1-10945
8-K
Feb. 2015
10.5
*
*
*
*
*
*
10.26+ Oceaneering International, Inc. 2015 Annual
1-10945
8-K
Bonus Program Award Summary
10.27+ Form of 2014 Employee Restricted Stock
1-10945
8-K
Unit Agreement for Executive Officers
10.28+ Form of 2014 Chairman Restricted Stock
1-10945
8-K
Unit Agreement for Mr. Huff
10.29+ Form of 2014 Performance Unit Agreement
1-10945
8-K
for Executive Officers
10.30+ Form of 2014 Chairman Performance Unit
1-10945
8-K
Agreement for Mr. Huff
Feb. 2015
Feb. 2014
Feb. 2014
Feb. 2014
Feb. 2014
10.31+ 2014 Performance Award: Goals and
Measures, relating to the form of 2014
Performance Unit Agreement for its
executive officers and 2014 Chairman
Performance Unit Agreement
1-10945
8-K
Feb. 2014
10.7
10.1
10.3
10.2
10.4
10.5
*
10.32+ Form of 2014 Nonemployee Director
Restricted Stock Agreement for Messrs.
Collins, DesRoche, Hughes, Murphy and
Pappas
1-10945
8-K
Feb. 2014
10.6
*
10.33+ Oceaneering International, Inc. 2014 Annual
1-10945
8-K
Bonus Award Program Summary
Feb. 2015
10.6
12.01 Computation of Ratio of Earnings to Fixed Charges
21.01 Subsidiaries of Oceaneering
23.01 Consent of Independent Registered Public Accounting Firm
31.01 Rule 13a – 14(a)/15d – 14(a) certification of principal executive officer
31.02 Rule 13a – 14(a)/15d – 14(a) certification of principal financial officer
32.01 Section 1350 certification of principal executive officer
32.02 Section 1350 certification of principal financial officer
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
* Exhibit previously filed with the Securities and Exchange Commission, as indicated,
and incorporated herein by reference.
+ Management contract or compensatory plan or arrangement.
47
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.
SIGNATURES
OCEANEERING INTERNATIONAL, INC.
Date: February 24, 2017
By:
/S/ M. KEVIN MCEVOY
M. Kevin McEvoy
Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed
below by the following persons on behalf of the registrant and in the capacities and on the dates
indicated.
Signature
Title
/S/ M. KEVIN MCEVOY
M. Kevin McEvoy
Chief Executive Officer and Director
(Principal Executive Officer)
Date
February 24, 2017
/S/ ALAN R. CURTIS
Senior Vice President and Chief Financial Officer
February 24, 2017
Alan R. Curtis
(Principal Financial Officer)
/S/ W. CARDON GERNER
Senior Vice President and Chief Accounting Officer
February 24, 2017
W. Cardon Gerner
(Principal Accounting Officer)
/S/ JOHN R. HUFF
Chairman of the Board
February 24, 2017
John R. Huff
/S/ WILLIAM B. BERRY
Director
William B. Berry
/S/ T. JAY COLLINS
Director
T. Jay Collins
/S/ D. MICHAEL HUGHES
Director
D. Michael Hughes
/S/ PAUL B. MURPHY, JR.
Director
Paul B. Murphy, Jr.
/S/ JON ERIK REINHARDSEN Director
Jon Erik Reinhardsen
/S/ STEVEN A. WEBSTER
Director
Steven A. Webster
February 24, 2017
February 24, 2017
February 24, 2017
February 24, 2017
February 24, 2017
February 24, 2017
48
INDEX TO FINANCIAL STATEMENTS AND SCHEDULES
Index to Financial Statements
Report of Independent Registered Public Accounting Firm
Consolidated Balance Sheets
Consolidated Statements of Income
Consolidated Statements of Comprehensive Income
Consolidated Statements of Cash Flows
Consolidated Statements of Shareholders' Equity
Notes to Consolidated Financial Statements
Summary of Major Accounting Policies
Selected Balance Sheet Information
Income Taxes
Selected Income Statement Information
Debt
Commitments and Contingencies
Operations by Business Segment and Geographic Area
Employee Benefit Plans
Selected Quarterly Financial Data (unaudited)
Index to Schedules
All schedules for which provision is made in the applicable regulations of the Securities and Exchange
Commission have been omitted because they are not required under the relevant instructions or
because the required information is not significant.
49
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders of Oceaneering International, Inc.
We have audited the accompanying consolidated balance sheets of Oceaneering International, Inc.
and subsidiaries as of December 31, 2016 and 2015, and the related consolidated statements of
income, comprehensive income, shareholders' equity 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 Oceaneering International, Inc. and subsidiaries as of
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), Oceaneering International, Inc.'s 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 24, 2017 expressed an unqualified opinion thereon.
Houston, Texas
February 24, 2017
/s/ ERNST & YOUNG LLP
50
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(in thousands, except share data)
ASSETS
Current Assets:
Cash and cash equivalents
Accounts receivable, net of allowances for doubtful accounts of $8,288 and
$5,893
Inventory
Other current assets
Total Current Assets
Property and Equipment, at cost
Less accumulated depreciation
Net Property and Equipment
Other Assets:
Goodwill
Other non-current assets
Total Other Assets
Total Assets
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable
Accrued liabilities
Total Current Liabilities
Long-term Debt
Other Long-term Liabilities
Commitments and Contingencies
Shareholders' Equity:
Common Stock, par value $0.25 per share; 360,000,000 shares authorized;
110,834,088 shares issued
Additional paid-in capital
Treasury stock; 12,768,726 and 12,984,829 shares, at cost
Retained earnings
Accumulated other comprehensive income (loss)
Total Shareholders' Equity
Total Liabilities and Shareholders' Equity
December 31,
2016
2015
$ 450,193 $
385,235
489,749
280,130
42,523
1,262,595
2,728,125
1,574,867
1,153,258
443,551
270,911
714,462
612,785
328,453
191,020
1,517,493
2,772,580
1,505,849
1,266,731
426,872
218,440
645,312
$ 3,130,315 $ 3,429,536
$
77,593 $
430,771
508,364
793,058
312,250
118,277
497,679
615,956
795,836
439,010
27,709
227,566
(731,202)
2,295,234
(302,664)
1,516,643
27,709
230,179
(743,577)
2,364,786
(300,363)
1,578,734
$ 3,130,315 $ 3,429,536
The accompanying Notes are an integral part of these Consolidated Financial Statements.
51
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31,
(in thousands, except per share data)
Revenue
Cost of services and products
Gross Margin
Selling, general and administrative expense
Income from Operations
Interest income
Interest expense, net of amounts capitalized
Equity earnings (losses) of unconsolidated affiliates
Other income (expense), net
Income before Income Taxes
Provision for income taxes
Net Income
Cash dividends declared per Share
Basic Earnings per Share
Weighted average basic shares outstanding
Diluted Earnings per Share
Weighted average diluted shares outstanding
2016
2015
$ 2,271,603 $ 3,062,754 $ 3,659,624
2,800,423
1,992,376
2014
279,227
208,463
70,764
3,900
(25,318)
244
(6,244)
43,346
18,760
$
$
$
$
24,586 $
0.96 $
0.25 $
98,035
0.25 $
98,424
2,457,325
605,429
231,619
373,810
607
(25,050)
2,230
(15,336)
336,261
105,250
231,011 $
1.08 $
2.35 $
98,417
2.34 $
98,808
859,201
230,871
628,330
293
(4,708)
(51)
(387)
623,477
195,148
428,329
1.03
4.02
106,593
4.00
107,091
The accompanying Notes are an integral part of these Consolidated Financial Statements.
52
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(in thousands)
Net Income
Other comprehensive income (loss), net of tax:
Foreign currency translation
Pension-related adjustments
Other comprehensive income (loss)
Comprehensive Income
$
22,285 $
Year Ended December 31,
2016
2015
2014
$
24,586 $
231,011 $
428,329
(5,559 )
3,258
(2,301 )
(118,705)
1,532
(117,173)
113,838 $
(128,666)
(1,947)
(130,613)
297,716
The accompanying Notes are an integral part of these Consolidated Financial Statements.
53
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
Currency translation effect on working capital, excluding cash
(9,183 )
(in thousands)
Cash Flows from Operating Activities:
Net income
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation and amortization
Deferred income tax provision
Inventory write-downs
Net loss (gain) on dispositions of property and equipment
Noncash compensation
Excluding the effects of acquisitions, increase (decrease) in cash
from:
Accounts receivable
Inventory
Other operating assets
Accounts payable and accrued liabilities
Income taxes payable
Other operating liabilities
Total adjustments to net income
Net Cash Provided by Operating Activities
Cash Flows from Investing Activities:
Purchases of property and equipment
Business acquisitions, net of cash acquired
Other investments
Distributions of capital from unconsolidated affiliates
Dispositions of property and equipment and life insurance
proceeds
Net Cash Used in Investing Activities
Cash Flows from Financing Activities:
Net proceeds of 4.65% Senior Notes, net of issuance costs
Net proceeds (payments) of bank credit facilities, net of new loan
costs
Excess tax benefits (deficiencies) from employee benefit plans
Cash dividends
Purchases of treasury stock
Net Cash Provided by (Used in) Financing Activities
Effect of exchange rates on cash
Net Increase (Decrease) in Cash and Cash Equivalents
Cash and Cash Equivalents—Beginning of Period
Year Ended December 31,
2016
2015
2014
$
24,586 $
231,011 $
428,329
250,247
98
30,490
387
14,687
123,036
17,833
53,946
(117,133 )
(38,985 )
(9,487 )
315,936
340,522
(112,392 )
(30,121 )
(39,130 )
6,470
—
—
(3,004 )
(94,138 )
—
(97,142 )
(8,951 )
64,958
385,235
241,235
29,090
25,990
4,917
17,289
178,796
33,192
(65,786)
(30,228)
(44,783)
(45,943)
(14,372)
329,397
560,408
229,779
70,717
—
(1,165)
20,034
(8,482)
66,327
(11,197)
(21,603)
(43,507)
(15,639)
8,169
293,433
721,762
(199,970)
(224,018)
(19,531)
5,963
(386,883)
(39,788)
—
4,772
—
493,125
49,665
248,429
247
(106,454)
(100,459)
(157,001)
(11,706)
(45,479)
430,714
385,235 $
3,932
(109,742)
(590,384)
45,360
(8,366)
339,284
91,430
430,714
5,702
376
2,427
(169,471 )
(437,180)
(419,472)
Cash and Cash Equivalents—End of Period
$ 450,193 $
The accompanying Notes are an integral part of these Consolidated Financial Statements.
54
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
Accumulated Other
Comprehensive Income
(Loss)
Common Stock Issued
Amount
$
27,709
Additional
Paid-in
Capital
Treasury
Stock
Retained
Earnings
Currency
Translation
Adjustments
(in thousands)
Balance, December 31, 2013
Net Income
Other Comprehensive Income
Restricted stock unit activity
Restricted stock activity
Tax benefits from employee benefit plans
Cash dividends
Treasury stock purchases, 8,900,000
shares
Balance, December 31, 2014
Net Income
Other Comprehensive Income
Restricted stock unit activity
Restricted stock activity
Tax benefits from employee benefit plans
Cash dividends
Treasury stock purchases, 2,000,000
shares
Balance, December 31, 2015
Net Income
Other Comprehensive Income
Restricted stock unit activity
Restricted stock activity
Shares
110,834
—
—
—
—
—
—
110,834
—
—
—
—
—
—
—
110,834
—
—
—
—
Tax benefits (deficiencies) from employee
benefit plans
Cash dividends
Balance, December 31, 2016
—
—
110,834
$ 222,402
$
(75,736) $ 1,921,642
$
—
—
—
—
—
—
—
—
4,311
(1,005)
3,932
—
—
—
8,198
1,005
—
—
428,329
—
—
—
—
(109,742)
(590,384)
27,709
229,640
(656,917)
2,240,229
—
—
—
—
—
—
—
—
—
—
—
2,163
(1,871)
11,928
1,871
—
—
247
—
—
231,011
—
—
—
—
(106,454)
27,709
230,179
(743,577)
2,364,786
—
—
—
—
—
—
$ 27,709
—
—
2,338
(1,947)
(3,004)
—
—
—
10,428
1,947
—
—
24,586
—
—
—
—
(94,138)
(50,144 ) $
—
(128,666)
—
—
—
—
(178,810)
—
(118,705)
—
—
—
—
(297,515)
—
(5,559)
—
—
—
—
Pension
Total
(2,433) $ 2,043,440
—
428,329
(1,947)
(130,613 )
—
—
—
—
12,509
—
3,932
(109,742 )
(590,384 )
(4,380)
1,657,471
—
231,011
1,532
(117,173 )
—
—
—
—
—
14,091
—
247
(106,454 )
(100,459 )
(2,848)
1,578,734
—
3,258
—
—
—
—
24,586
(2,301 )
12,766
—
(3,004 )
(94,138 )
$ 227,566
$ (731,202) $ 2,295,234
$ (303,074 ) $
410
$ 1,516,643
(100,459)
—
—
The accompanying Notes are an integral part of these Consolidated Financial Statements.
55
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SUMMARY OF MAJOR ACCOUNTING POLICIES
Principles of Consolidation. The consolidated financial statements include the accounts of
Oceaneering International, Inc. and our 50% or more owned and controlled subsidiaries. We also
consolidate entities that are determined to be variable interest entities if we determine that we are
the primary beneficiary; otherwise, we account for those entities using the equity method of
accounting. We use the equity method to account for our investments in unconsolidated affiliated
companies of which we own an equity interest of between 20% and 50% and as to which we have
significant influence, but not control, over operations. We use the cost method for all other long-
term investments. Investments in entities that we do not consolidate are reflected on our balance
sheet in Other non-current assets. All significant intercompany accounts and transactions have been
eliminated.
Use of Estimates. The preparation of financial statements in conformity with accounting principles
generally accepted in the United States ("U.S. GAAP") requires that our management make
estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of
contingent assets and liabilities at the date of the financial statements and the reported amounts of
revenue and expense during the reporting period. Actual results could differ from those estimates.
Reclassifications. Certain amounts from prior periods have been reclassified to conform with the
current year presentation.
Cash and Cash Equivalents. Cash and cash equivalents include demand deposits and highly liquid
investments with original maturities of three months or less from the date of investment.
Accounts Receivable – Allowances for Doubtful Accounts. We determine the need for allowances for
doubtful accounts using the specific identification method. We do not generally require collateral
from our customers.
Inventory. Inventory is valued at lower of cost or market. We determine cost using the weighted-
average method. During 2016, we recorded inventory write-downs totaling $30.5 million for excess
inventory of $25.2 million in our ROV segment and $5.3 million in our Subsea Products segment. In
2015, we recorded inventory write-downs totaling $26.0 million: $15.7 million attributable to
remotely operated vehicle components, as we determined the components would not be used as a
result of the deterioration in market conditions, and $10.3 million in our Subsea Products segment,
primarily the result of our decision to cease manufacturing subsea blow out preventer ("BOP")
control systems.
Property and Equipment and Long-Lived Intangible Assets. We provide for depreciation of property
and equipment on the straight-line method over estimated useful lives of eight years for ROVs, three
to 20 years for marine services equipment (such as vessels and diving equipment), and three to 25
years for buildings, improvements and other equipment.
Long-lived intangible assets, primarily acquired in connection with business combinations, include
trade names, intellectual property and customer relationships and are being amortized with a
weighted average remaining life of approximately nine years. Amortization expense on intangible
assets was $10.2 million, $7.8 million and $6.6 million in 2016, 2015 and 2014, respectively.
We charge the costs of repair and maintenance of property and equipment to operations as incurred,
while we capitalize the costs of improvements that extend asset lives or functionality.
We capitalize interest on assets where the construction period is anticipated to be more than three
months. We capitalized $3.7 million, $2.4 million and $0.7 million of interest in 2016, 2015 and
2014, respectively. We do not allocate general administrative costs to capital projects. Upon the
disposition of property and equipment, the related cost and accumulated depreciation accounts are
relieved and any resulting gain or loss is included as an adjustment to cost of services and products.
56
Our management periodically, and upon the occurrence of a triggering event, reviews the
realizability of our property and equipment and long-lived intangible assets to determine whether
any events or changes in circumstances indicate that the carrying amount of the asset may not be
recoverable. For long-lived assets to be held and used, we base our evaluation on impairment
indicators such as the nature of the assets, the future economic benefits of the assets, any historical
or future profitability measurements and other external market conditions or factors that may be
present. If such impairment indicators are present or other factors exist that indicate that the
carrying amount of an asset may not be recoverable, we determine whether an impairment has
occurred through the use of an undiscounted cash flows analysis of the asset at the lowest level for
which identifiable cash flows exist. If an impairment has occurred, we recognize a loss for the
difference between the carrying amount and the fair value of the asset. For assets held for sale or
disposal, the fair value of the asset is measured using fair market value less cost to sell. Assets are
classified as held-for-sale when we have a plan for disposal of certain assets and those assets meet
the held for sale criteria.
Business Acquisitions. We account for business combinations using the acquisition method of
accounting, with acquisition prices being allocated to the assets acquired and liabilities assumed
based on their fair values at the respective dates of acquisition.
We made several smaller acquisitions during the periods presented, none of which were material.
In April 2015, we completed the acquisition of C & C Technologies, Inc. ("C&C"). C&C is a global
provider of ocean-bottom mapping services in deepwater utilizing customized autonomous
underwater vehicles and provides marine construction surveys for both surface and subsea assets,
as well as satellite-based positioning services for drilling rigs and seismic and construction vessels.
C&C also provides land and near-shore survey services along the U.S. Gulf Coast and in Mexico, and
performs shallow water conventional geophysical surveys in the U.S. Gulf of Mexico. The acquisition
price of approximately $224 million was paid in cash. We have accounted for this acquisition by
allocating the purchase price to the assets acquired and liabilities assumed based on their estimated
fair values at the date of acquisition. Based on the terms of the acquisition agreement, all of our
goodwill and other intangible assets associated with the C&C acquisition will be deductible for income
tax purposes. We have included C&C's operations in our consolidated financial statements starting
from the date of closing, and its operating results are reflected in our Subsea Projects segment. The
acquisition of C&C did not have a material effect on our operating results, cash flows from operations
or financial position.
Goodwill. In our annual evaluation of goodwill impairment, we first assess qualitative factors to
determine whether the existence of events or circumstances leads to a determination that it is more
likely than not that the fair value of a reporting unit is less than its carrying amount. If, after
assessing the totality of events or circumstances, we determine it is more likely than not that the fair
value of a reporting unit exceeds its carrying amount, performing the two-step impairment test is
unnecessary. However, if we conclude otherwise, then we are required to perform the first step of
the two-step impairment test. We tested the goodwill attributable to each of our reporting units for
impairment as of December 31, 2016 and 2015 and concluded that there was no impairment. The
only changes in our reporting units' goodwill balances during the periods presented are from
business acquisitions, as discussed above, and currency exchange rate changes. For information
regarding goodwill by business segment, see Note 7.
Revenue Recognition. We recognize our revenue according to the type of contract involved. On a
daily basis, we recognize revenue under contracts that provide for specific time, material and
equipment charges, which we bill periodically, ranging from weekly to monthly.
57
We account for significant fixed-price contracts, which we enter into mainly in our Subsea Products
segment, and to a lesser extent in our Subsea Projects and Advanced Technologies segments, using
the percentage-of-completion method. In 2016, we accounted for 16% of our revenue using the
percentage-of-completion method. In determining whether a contract should be accounted for using
the percentage-of-completion method, we consider whether:
• the customer provides specifications for the construction of facilities or production of goods or
for the provision of related services;
• we can reasonably estimate our progress towards completion and our costs;
• the contract includes provisions as to the enforceable rights regarding the goods or services
to be provided, consideration to be received and the manner and terms of payment;
• the customer can be expected to satisfy its obligations under the contract; and
• we can be expected to perform our contractual obligations.
Under the percentage-of-completion method, we generally recognize estimated contract revenue
based on costs incurred to date as a percentage of total estimated costs. Changes in the expected
cost of materials and labor, productivity, scheduling and other factors affect the total estimated
costs. Additionally, external factors, including weather or other factors outside of our control, may
also affect the progress and estimated cost of a project's completion and, therefore, the timing of
income and revenue recognition. We routinely review estimates related to our contracts and reflect
revisions to profitability in earnings immediately. If a current estimate of total contract cost
indicates an ultimate loss on a contract, we recognize the projected loss in full when we determine it.
In prior years, we have recorded adjustments to earnings as a result of revisions to contract
estimates. Although we are continually striving to accurately estimate our contract costs and
profitability, adjustments to overall contract costs could be significant in future periods.
We recognize the remainder of our revenue when persuasive evidence of an arrangement exists,
delivery has occurred or services have been rendered, price is fixed or determinable and collection is
reasonably assured.
Revenue in Excess of Amounts Billed is classified as accounts receivable and relates to recoverable
costs and accrued profits on contracts in progress. Billings in Excess of Revenue Recognized on
uncompleted contracts are classified in accrued liabilities.
Revenue in Excess of Amounts Billed on uncompleted fixed-price contracts accounted for using the
percentage-of-completion method is summarized as follows:
(in thousands)
Revenue recognized
Less: Billings to customers
Revenue in excess of amounts billed
December 31,
2016
538,986 $
(488,814)
50,172 $
2015
694,690
(649,550)
45,140
$
$
Billings in Excess of Revenue Recognized on uncompleted fixed-price contracts accounted for using
the percentage-of-completion method are summarized as follows:
(in thousands)
Amounts billed to customers
Less: Revenue recognized
Billings in excess of revenue recognized
December 31,
2016
178,914 $
(81,800)
97,114 $
2015
302,904
(190,812)
112,092
$
$
Stock-Based Compensation. We recognize all share-based payments to directors, officers and
employees over their vesting periods in the income statement based on their estimated fair values.
For more information on our employee benefit plans, see Note 8.
58
Income Taxes. We provide income taxes at appropriate tax rates in accordance with our
interpretation of the respective tax laws and regulations after review and consultation with our
internal tax department, tax advisors and, in some cases, legal counsel in various jurisdictions. We
provide for deferred income taxes for differences between carrying amounts of assets and liabilities
for financial and tax reporting purposes. We provide for deferred U.S. income taxes on foreign
income only to the extent such income is not indefinitely reinvested in foreign entities. We provide a
valuation allowance against deferred tax assets when it is more likely than not that the asset will not
be realized.
We recognize the benefit for a tax position if the benefit is more likely than not to be sustainable
upon audit by the applicable taxing authority. If this threshold is met, the tax benefit is then
measured and recognized at the largest amount that we believe is greater than 50% likely of being
realized upon ultimate settlement. We account for any applicable interest and penalties on uncertain
tax positions as a component of our provision for income taxes on our financial statements.
Foreign Currency Translation. The functional currency for most of our foreign subsidiaries is the
applicable local currency. Results of operations for foreign subsidiaries with functional currencies
other than the U.S. dollar are translated into U.S. dollars using average exchange rates during the
period. Assets and liabilities of these foreign subsidiaries are translated into U.S. dollars using the
exchange rates in effect at the balance sheet date, and the resulting translation adjustments are
recognized, net of tax, in accumulated other comprehensive income as a component of shareholders'
equity. All foreign currency transaction gains and losses are recognized currently in the Consolidated
Statements of Income. We recorded $(4.8) million, $(15.4) million and $(0.5) million of foreign
currency transaction gains (losses) in 2016, 2015 and 2014, respectively, and those amounts are
included as a component of Other income (expense), net.
Earnings per Share. For each year presented, the only difference between our annual calculated
weighted average basic and diluted number of shares outstanding is the effect of outstanding
restricted stock units.
Repurchase Plans. In February 2010, our Board of Directors approved a program to repurchase up
to 12 million shares of our common stock. In 2014, we completed the purchase of the shares
authorized under that program by repurchasing the remaining 8.9 million shares for $590 million.
The total cost for the repurchase of the 12 million shares of our common stock was $677 million.
In December 2014, following completion of the February 2010 program, our Board of Directors
approved a new share repurchase program under which we may repurchase up to 10 million shares
of our common stock on a discretionary basis. The December 2014 program calls for the
repurchases to be made in the open market, or in privately negotiated transactions from time to
time, in compliance with applicable laws, rules and regulations, including Rule 10b-18 under the
Securities Exchange Act of 1934, as amended, subject to market and business conditions, levels of
available liquidity, cash requirements for other purposes, applicable legal requirements and other
relevant factors. The timing and amount of any repurchases will be determined by management
based on its evaluation of these factors. We expect that any shares repurchased under the new
program will be held as treasury stock for future use. The new program does not obligate us to
repurchase any particular number of shares. Under the new program, we had repurchased 2 million
shares of our common stock for $100 million through December 31, 2016. We account for the shares
we hold in treasury under the cost method, at average cost.
Financial Instruments. We recognize all derivative instruments as either assets or liabilities in the
balance sheet and measure those instruments at fair value. Subsequent changes in fair value are
reflected in current earnings, other comprehensive income or changes in assets or liabilities,
depending on whether a derivative instrument is designated as part of a hedge relationship and, if it
is, the type of hedge relationship. See Note 6 for information relative to the interest rate swaps we
have in effect.
59
New Accounting Standards. In May 2014, the Financial Accounting Standards Board ("FASB") issued
Accounting Standards Update ("ASU") 2014-09, "Revenue from Contracts with Customers."
ASU 2014-09, as amended, completes the joint effort by the FASB and International Accounting
Standards Board to improve financial reporting by creating common revenue recognition guidance
for U.S. GAAP and International Financial Reporting Standards. ASU 2014-09 applies to all
companies that enter into contracts with customers to transfer goods or services. ASU 2014-09 is
effective for us for interim and annual reporting periods beginning after December 15, 2017. Early
application is not permitted before periods beginning after December 15, 2016. We are currently
determining the impacts of ASU 2014-09 on our existing contracts. We have formed a project team
for this implementation. Our approach includes performing a detailed review of contracts
representative of our different businesses and comparing historical accounting policies and practices
to the requirements of this update. Because the update will impact our business processes, systems
and controls, we are also developing a project plan for the implementation. We have chosen to
apply ASU 2014-09 by recognizing the cumulative effect of applying ASU 2014-09 at the date of
initial application and not adjusting comparative information. Our evaluation of the requirements of
ASU 2014-09 is ongoing and we have not yet determined its impact on our consolidated financial
statements.
In July 2015, the FASB issued ASU 2015-11, "Inventory - Simplifying the Measurement of
Inventory." ASU 2015-11 requires companies to measure inventory at the lower of cost or net
realizable value rather than at the lower of cost or market. Net realizable value is the estimated
selling price in the ordinary course of business, less reasonably predictable costs of completion,
disposal and transportation. This guidance is effective for our inventories beginning
January 1, 2017. We do not anticipate that this update will have a material impact on our
consolidated financial statements.
In September 2015, the FASB issued ASU 2015-16, "Business Combinations - Simplifying the
Accounting for Measurement-Period Adjustments." This update requires that an acquirer recognize
adjustments to provisional amounts that are identified during the measurement period in the
reporting period in which the adjustment amounts are determined. The update requires that the
acquirer record, in the same period’s financial statements, the effect on earnings of changes in
depreciation, amortization, or other income effects, if any, as a result of the change to the
provisional amounts, calculated as if the accounting had been completed at the acquisition date. The
update requires an entity to present separately on the face of the income statement or disclose in
the notes the portion of the amount recorded in current-period earnings by line item that would have
been recorded in previous reporting periods if the adjustment to the provisional amounts had been
recognized as of the acquisition date. ASU 2015-16 became effective for our financial statements
January 1, 2016. This update has not had a material impact on our consolidated financial
statements.
In November 2015, the FASB issued ASU 2015-17, "Balance Sheet Classification of Deferred Taxes."
Previous GAAP required an entity to separate deferred income tax liabilities and assets into current
and noncurrent amounts in a classified statement of financial position. The update requires that
deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial
position. ASU 2015-17 is effective for our financial statements issued for fiscal years beginning after
December 15, 2016, and interim periods within those fiscal years. Earlier application is permitted,
and we have adopted this update for our December 31, 2016 balance sheet. This update did not
have a material impact on our consolidated financial statements. Prior periods were not
retrospectively adjusted.
60
In January 2016, the FASB issued ASU 2016-01, "Financial Instruments—Overall (Subtopic 825-10)
Recognition and Measurement of Financial Assets and Financial Liabilities." This update:
• requires equity investments (except those accounted for under the equity method of
accounting or those that result in consolidation of the investee) to be measured at fair value
with changes in fair value recognized in net income;
• simplifies the impairment assessment of equity investments without readily determinable fair
values by requiring a qualitative assessment to identify impairment. When a qualitative
assessment indicates that impairment exists, an entity is required to measure the investment
at fair value;
• eliminates the requirement to disclose the method(s) and significant assumptions used to
estimate the fair value that is required to be disclosed for financial instruments measured at
amortized cost on the balance sheet;
• requires entities to use the exit price notion when measuring the fair value of financial
instruments for disclosure purposes;
• requires an entity to present separately in other comprehensive income the portion of the
total change in the fair value of a liability resulting from a change in the instrument-specific
credit risk when the entity has elected to measure the liability at fair value in accordance with
the fair value option for financial instruments;
• requires separate presentation of financial assets and financial liabilities by measurement
category and form of financial asset (that is, securities or loans and receivables) on the
balance sheet or the accompanying notes to the financial statements; and
• clarifies that an entity should evaluate the need for a valuation allowance on a deferred tax
asset related to available-for-sale securities in combination with the entity’s other deferred
tax assets.
ASU 2016-01 will be effective for us beginning on January 1, 2018. We are currently assessing the
impact of these requirements on our consolidated financial statements and future disclosures.
In February 2016, the FASB issued ASU No. 2016-02, "Leases." This update requires reporting
entities to separate the lease components from the non-lease components in a contract and
recognize lease assets and lease liabilities on the balance sheet for substantially all lease
arrangements. ASU No. 2016-02 is effective for us beginning January 1, 2019. We are currently
evaluating the requirements of ASU 2016-02 and have not yet determined its impact on our
consolidated financial statements.
In March 2016, the FASB issued ASU 2016-09, "Compensation – Stock Compensation Improvements
to Employee Share-Based Payment Accounting." This update requires that all excess tax benefits
and tax deficiencies (including tax benefits of dividends on share-based payment awards) should be
recognized as income tax expense or benefit in the income statement. The tax effects of exercised
or vested awards should be treated as discrete items in the reporting period in which they occur. An
entity also should recognize excess tax benefits regardless of whether the benefit reduces taxes
payable in the current period. Currently, an entity must determine, for each award, whether the
difference between the deduction for tax purposes and the compensation cost recognized for
financial reporting purposes results in either an excess tax benefit or a tax deficiency. The
amendments in this update are effective for us beginning January 1, 2017. Through
December 31, 2016, we recognized excess tax benefits in additional paid-in capital, and tax
deficiencies have been recognized as an offset to accumulated excess tax benefits. In 2017, we
expect a tax deficiency in the first quarter and, under this new standard, we will recognize it as a
discrete item in the income statement rather than in additional paid-in capital. We do not anticipate
that this update will have a material effect on our consolidated financial statements.
61
In August 2016, the FASB issued ASU 2016-15, "Classification of Certain Cash Receipts and Cash
Payments." This update was issued to clarify a diversity in practice in how certain cash receipts and
cash payments are presented and classified in the statement of cash flows and addresses eight
specific cash flow issues, with the objective of reducing the existing diversity in practice. One of the
items addressed affects how we previously treated cash proceeds received from the settlement of
corporate-owned life insurance policies. These proceeds are now classified in our statement of cash
flows as cash inflows from investing activities.
In October 2016, the FASB issued ASU 2016-16, "Income Taxes (Topic 740) – Intra-Entity Transfers
of Assets Other than Inventory." Current U.S. GAAP generally prohibits the recognition of current
and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an
outside party. The amendments in this update will eliminate the exception for an intra-entity transfer
of an asset other than inventory. Two common examples of assets included within the scope of this
update are intellectual property and property, plant and equipment. The exception for an intra-entity
transfer of inventory will remain in place. The amendments in this update are effective for us
beginning January 1, 2018. We do not anticipate that this update will have a material effect on our
consolidated financial statements.
In January 2017, the FASB issued ASU 2017-04, "Intangibles—Goodwill and Other (Topic 350)
Simplifying the Test for Goodwill Impairment." This update simplifies how an entity is required to
test goodwill for impairment by eliminating Step 2 from the goodwill impairment test. Step 2
measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s
goodwill with the carrying amount of that goodwill. Under the amendments in this update, an entity
should perform its annual, or interim, goodwill impairment test by comparing the fair value of a
reporting unit with its carrying amount. An entity should recognize an impairment charge for the
amount by which the carrying amount exceeds the reporting unit’s fair value; however, the loss
recognized should not exceed the total amount of goodwill allocated to that reporting unit.
Additionally, an entity should consider income tax effects from any tax deductible goodwill on the
carrying amount of the reporting unit when measuring the goodwill impairment loss, if applicable.
An entity still has the option to perform the qualitative assessment for a reporting unit to determine
if the quantitative impairment test is necessary. The amendments in this update are effective for us
beginning January 1, 2020. Early adoption is permitted after January 1, 2017, and the update is to
be applied on a prospective basis. We do not anticipate that this update will have a material effect
on our consolidated financial statements.
62
2. SELECTED BALANCE SHEET INFORMATION
The following is information regarding selected balance sheet accounts:
(in thousands)
Inventory:
Remotely operated vehicle parts and components
Other inventory, primarily raw materials
Total
Other Current Assets:
Deferred income taxes
Prepaid expenses
Total
Other Non-Current Assets:
Intangible assets, net
Angola bonds
Cash surrender value of life insurance policies
Investment in unconsolidated affiliates
Deferred income taxes
Other
Total
Accrued Liabilities:
Payroll and related costs
Accrued job costs
Deferred revenue
Income taxes payable
Other
Total
Other Long-Term Liabilities:
Deferred income taxes
Supplemental Executive Retirement Plan
Long-Term Incentive Plan
Accrued post-employment benefit obligations
Other
Total
63
December 31,
2016
2015
$ 118,236 $ 163,539
161,894
164,914
$ 280,130 $ 328,453
$
— $ 57,337
42,523
133,683
$ 42,523 $ 191,020
$ 87,801 $ 93,701
—
59,130
60,160
39,826
12,187
55,924
49,144
—
11,807
19,671
$ 270,911 $ 218,440
$ 141,485 $ 161,228
79,857
59,331
122,223
35,126
157,042
20,395
72,606
79,157
$ 430,771 $ 497,679
$ 236,113 $ 353,181
46,931
49,163
—
4,648
15,650
7,511
22,326
15,737
$ 312,250 $ 439,010
3. INCOME TAXES
Our provisions for income taxes and our cash taxes paid are as follows:
(in thousands)
Current:
Domestic
Foreign
Total current
Deferred:
Domestic
Foreign
Total deferred
Total provision for income taxes
Cash taxes paid
Year Ended December 31,
2015
2014
2016
$
(6,899 ) $
25,561
18,662
(8,617)
8,715
98
$
$
18,760 $
75,819 $
11,028 $
65,132
76,160
17,856
106,575
124,431
40,284
(11,194)
29,090
105,250 $
119,591 $
73,520
(2,803)
70,717
195,148
139,724
The components of income before income taxes are as follows:
(in thousands)
Domestic
Foreign
Income before income taxes
$
$
Year Ended December 31,
2015
2016
(180,132 ) $
223,478
43,346 $
51,018 $
285,243
336,261 $
2014
110,800
512,677
623,477
As of December 31, 2016 and 2015, our worldwide deferred tax assets, liabilities and net deferred
tax liabilities were as follows:
(in thousands)
Deferred tax assets:
Deferred compensation
Deferred income
Accrued expenses
Other
Gross deferred tax assets
Valuation allowance
Total deferred tax assets
Deferred tax liabilities:
Property and equipment
Unremitted foreign earnings not considered indefinitely reinvested
Basis difference in equity investments
Other
Total deferred tax liabilities
Net deferred income tax liability
December 31,
2016
2015
$
$
$
$
$
38,602 $
9,830
24,663
60,885
133,980
(4,200)
129,780 $
86,237 $
257,414
10,055
—
353,706 $
223,926 $
46,973
18,787
12,624
55,547
133,931
—
133,931
126,079
296,018
7,678
—
429,775
295,844
64
Our net deferred tax liability is reflected within our balance sheet as follows:
(in thousands)
Deferred tax liabilities
Current deferred tax assets
Long-term deferred tax assets
Net deferred income tax liability
December 31,
2016
236,113 $
—
(12,187)
223,926 $
2015
353,181
(57,337)
—
295,844
$
$
At December 31, 2016, we had approximately $51 million of foreign tax credits and no U.S. net
operating losses available to reduce future payments of U.S. federal income taxes. The tax credits
expire commencing in 2024. We assessed the recoverability of our deferred tax assets and believe it
is more likely than not that a portion of our loss carryforwards in foreign jurisdictions will not be
realized. As a result, we have established a deferred tax asset valuation allowance of $4.2 million.
Reconciliations between the actual provision for income taxes on continuing operations and that
computed by applying the United States statutory rate to income before income taxes were as
follows:
United States statutory rate
Valuation allowance
Foreign tax rate differential
Other items, net
Total effective tax rate
Year Ended December 31,
2016
2015
2014
35.0 %
9.7
(4.1 )
2.7
43.3 %
35.0 %
—
(2.5 )
(1.2 )
31.3 %
35.0 %
—
(2.6 )
(1.1 )
31.3 %
In 2016, we incurred a recapture of a portion of previously-taken U.S. manufacturing deductions.
This increased our effective tax rate by 1.9% and this increase is part of the 2.7% of other items,
net in the table above.
We consider $623 million of unremitted earnings of our foreign subsidiaries to be indefinitely
reinvested. It is not practical for us to compute the amount of additional U.S. tax that would be due
on this amount. We have provided deferred income taxes on the foreign earnings not considered
indefinitely reinvested.
We recognize the benefit for a tax position if the benefit is more likely than not to be sustainable
upon audit by the applicable taxing authority. If this threshold is met, the tax benefit is then
measured and recognized at the largest amount that we believe is greater than 50% likely of being
realized upon ultimate settlement.
We account for any applicable interest and penalties on uncertain tax positions as a component of
our provision for income taxes on our financial statements. We increased/(decreased) income tax
expense by $1.2 million, $(0.9) million and $(0.4) million in 2016, 2015 and 2014, respectively, for
penalties and interest on uncertain tax positions, which brought our total liabilities for penalties and
interest on uncertain tax positions to $3.2 million and $2.0 million on our balance sheets at
December 31, 2016 and 2015, respectively. All additions or reductions to those liabilities would
affect our effective income tax rate in the periods of change.
65
A reconciliation of the beginning and ending amount of gross unrecognized tax benefits, not
including associated foreign tax credits and penalties and interest, is as follows:
(in thousands)
Beginning of year
Additions based on tax positions related to the current year
Reductions for expiration of statutes of limitations
Additions based on tax positions related to prior years
Reductions based on tax positions related to prior years
Settlements
Year Ended December 31,
2015
2014
2016
$
5,245 $
1,999
(1,028)
114
—
—
5,575 $
260
(1,649)
1,059
—
—
5,245 $
7,168
432
(1,572)
254
(707)
—
5,575
Balance at end of year
$
6,330 $
Including associated foreign tax credits and penalties and interest, we have accrued a net total of
$6.4 million in the caption "other long-term liabilities" on our balance sheet at December 31, 2016
for unrecognized tax benefits. We do not believe that the total of unrecognized tax benefits will
significantly increase or decrease in the next 12 months.
We file a consolidated U.S. federal income tax return for Oceaneering International, Inc. and our
domestic subsidiaries. We conduct our international operations in a number of locations that have
varying laws and regulations with regard to income and other taxes, some of which are subject to
interpretation. Our management believes that adequate provisions have been made for all taxes
that will ultimately be payable, although final determination of tax liabilities may differ from our
estimates.
Our tax returns are subject to audit by taxing authorities in multiple jurisdictions. These audits often
take years to complete and settle. The following lists the earliest tax years open to examination by
tax authorities where we have significant operations:
Jurisdiction
United States
United Kingdom
Norway
Angola
Brazil
Australia
Periods
2013
2012
2006
2013
2010
2012
66
4. SELECTED INCOME STATEMENT INFORMATION
The following schedule shows our revenue, costs and gross margins by services and products:
(in thousands)
Revenue:
Services
Products
Total revenue
Cost of Services and Products:
Services
Products
Unallocated expenses
Total cost of services and products
Gross margin:
Services
Products
Unallocated expenses
Total gross margin
5.
DEBT
Year Ended December 31,
2015
2014
2016
$ 1,509,786 $ 2,001,167 $ 2,336,304
1,323,320
761,817
2,271,603
1,330,218
615,438
46,720
1,992,376
1,061,587
3,062,754
1,585,305
800,316
71,704
2,457,325
3,659,624
1,742,411
946,923
111,089
2,800,423
179,568
146,379
(46,720)
$
279,227 $
415,862
261,271
(71,704)
605,429 $
593,893
376,397
(111,089)
859,201
Long-term Debt consisted of the following:
(in thousands)
4.650% Senior Notes due 2024:
Principal of the notes
December 31,
2016
2015
$ 500,000 $ 500,000
Issuance costs, net of amortization
Fair value of interest rate swaps on $200 million of principal
(5,385)
(1,557)
(6,073)
1,909
300,000
300,000
—
—
$ 793,058 $ 795,836
Term Loan Facility
Revolving Credit Facility
Long-term Debt
In October 2014, we entered into a new credit agreement (as amended, the "Credit Agreement")
with a group of banks to replace our prior principal credit agreement. The Credit Agreement
provides for a $300 million three-year term loan (the "Term Loan Facility") and a $500 million five-
year revolving credit facility (the "Revolving Credit Facility"). Subject to certain conditions, the
aggregate commitments under the Revolving Credit Facility may be increased by up to $300 million
at any time upon agreement between us and existing or additional lenders. Borrowings under the
Revolving Credit Facility and the Term Loan Facility may be used for general corporate purposes.
Simultaneously with the execution of the Credit Agreement and pursuant to its terms, we repaid all
amounts outstanding under, and terminated, the prior credit agreement.
In November 2015, we entered into an Agreement and Amendment No. 1 to Credit Agreement
("Amendment No. 1"). Amendment No. 1 amended the Credit Agreement to (1) replace the
maximum leverage ratio financial covenant with a new financial covenant restricting the maximum
total capitalization ratio (defined in Amendment No. 1 to be the ratio of consolidated debt to total
capitalization) to 55% and (2) extend the maturities of the Term Loan Facility and the Revolving
Credit Facility by one year each, which maturity terms have since been superseded by amendment,
as described below.
In November 2016, we entered into an Agreement and Amendment No. 2 to Credit Agreement
("Amendment No. 2"). Amendment No. 2 amended the Credit Agreement to, among other things,
extend the maturities of the Term Loan Facility and the Revolving Credit Facility to October 25, 2019
and October 25, 2021, respectively, with the extending Lenders, which represent 90% of the existing
67
commitments of the Lenders, such that (a) the total commitments for the Revolving Credit Facility
will be $500 million until October 25, 2020 and thereafter $450 million until October 25, 2021, and
(b) the outstanding term loan advances pursuant to the Term Loan Facility will be $300 million until
October 27, 2018 and thereafter $270 million until October 25, 2019.
Borrowings under the Credit Agreement bear interest at an Adjusted Base Rate or the Eurodollar
Rate (both as defined in the Credit Agreement), at our option, plus an applicable margin initially
based on our Leverage Ratio (as defined in the Credit Agreement) and, at our election, based on the
ratings of our senior unsecured debt by designated ratings services, thereafter to be based on such
debt ratings. The applicable margin varies: (1) in the case of advances bearing interest at the
Adjusted Base Rate, from 0.125% to 0.750% for borrowings under the Revolving Credit Facility and
from 0% to 0.500% for borrowings under the Term Loan Facility; and (2) in the case of advances
bearing interest at the Eurodollar Rate, from 1.125% to 1.750% for borrowings under the Revolving
Credit Facility and from 1.000% to 1.500% for borrowings under the Term Loan Facility. The
Adjusted Base Rate is the highest of (1) the per annum rate established by the administrative agent
as its prime rate, (2) the federal funds rate plus 0.50% and (3) the daily one-month LIBOR plus 1%.
We pay a commitment fee ranging from 0.125% to 0.300% on the unused portion of the Revolving
Credit Facility, depending on our Leverage Ratio. The commitment fees are included as interest
expense in our consolidated financial statements.
The Credit Agreement contains various covenants that we believe are customary for agreements of
this nature, including, but not limited to, restrictions on our ability and the ability of each of our
subsidiaries to incur debt, grant liens, make certain investments, make distributions, merge or
consolidate, sell assets, enter into transactions with affiliates and enter into certain restrictive
agreements. We are also subject to a maximum Capitalization Ratio of 55%. The Credit Agreement
includes customary events of default and associated remedies. As of December 31, 2016, we were
in compliance with all the covenants set forth in the Credit Agreement.
In November 2014, we completed the public offering of $500 million aggregate principal amount of
4.650% Senior Notes due 2024 (the "Senior Notes"). We pay interest on the Senior Notes on
May 15 and November 15 of each year, beginning on May 15, 2015. The Senior Notes are scheduled
to mature on November 15, 2024. We may redeem some or all of the Senior Notes prior to maturity
at specified redemption prices. We used the net proceeds from the offering for general corporate
purposes, including funding the C&C acquisition, other capital expenditures and repurchases of
shares of our common stock.
We incurred $6.9 million of issuance costs related to the Senior Notes and $2.2 million of new loan
costs, including costs of the Amendments, related to the Credit Agreement. We are amortizing these
costs, which are included on our balance sheet as a reduction of debt for the Senior Notes and as an
other non-current asset for the Credit Agreement, to interest expense over ten years for the Senior
Notes and over six years for the Revolving Credit Facility and the Term Loan Facility.
We made cash interest payments of $29.2 million, $27.2 million and $3.7 million in 2016, 2015 and
2014, respectively.
68
6. COMMITMENTS AND CONTINGENCIES
Lease Commitments
At December 31, 2016, we occupied several facilities under noncancellable operating leases expiring
at various dates through 2035. Future minimum rentals under all of our operating leases, including
vessel rentals, are as follows:
(in thousands)
2017
2018
2019
2020
2021
Thereafter
Total Lease Commitments
$
56,448
27,782
22,701
19,380
16,841
138,807
$
281,959
Rental expense, which includes hire of vessels, specialized equipment and real estate rental, was
approximately $205 million, $229 million and $257 million in 2016, 2015 and 2014, respectively.
Insurance
We self-insure for workers' compensation, maritime employer's liability and comprehensive general
liability claims to levels we consider financially prudent, and, beyond the self-insurance level of
exposure, we carry insurance, which can be by occurrence or in the aggregate. We determine the
level of accruals for claims exposure by reviewing our historical experience and current year claim
activity. We do not record accruals on a present-value basis. We review larger claims with insurance
adjusters and establish specific reserves for known liabilities. We establish an additional reserve for
incidents incurred but not reported to us for each year using our estimates and based on prior
experience. We believe we have established adequate accruals for uninsured expected liabilities
arising from those obligations. However, it is possible that future earnings could be affected by
changes in our estimates relating to these matters.
69
Litigation
On June 17, 2014, Peter L. Jacobs, a purported shareholder, filed a derivative complaint against all of
the then current members of our board of directors and one of our former directors, as defendants,
and our company, as nominal defendant, in the Court of Chancery of the State of Delaware. Through
the complaint, the plaintiff is asserting, on behalf of our company, actions for breach of fiduciary
duties and unjust enrichment in connection with prior determinations of our board of directors
relating to nonexecutive director compensation. The plaintiff is seeking relief including disgorgement
of payments made to the defendants, an award of unspecified damages and an award for attorneys’
fees and other costs. We and the defendants filed a motion to dismiss the complaint and a
supporting brief on which the Court has not yet ruled. In any event, our company is only a nominal
defendant in this litigation, and we do not expect the resolution of this matter to have a material
adverse effect on our results of operations, cash flows or financial position.
In the ordinary course of business, we are subject to actions for damages alleging personal injury
under the general maritime laws of the United States, including the Jones Act, for alleged
negligence. We report actions for personal injury to our insurance carriers and believe that the
settlement or disposition of those claims will not have a material adverse effect on our consolidated
financial position, results of operations or cash flows.
Various other actions and claims are pending against us, most of which are covered by insurance.
Although we cannot predict the ultimate outcome of these matters, we believe that our ultimate
liability, if any, that may result from these other actions and claims will not materially affect our
results of operations, cash flows or financial position.
Letters of Credit
We had $54 million and $58 million in letters of credit outstanding as of December 31, 2016 and
2015, respectively, as guarantees in force for self-insurance requirements and various bid and
performance bonds, which are usually for the duration of the applicable contract.
Financial Instruments and Risk Concentration
In the normal course of business, we manage risks associated with foreign exchange rates and
interest rates through a variety of strategies, including the use of hedging transactions. As a matter
of policy, we do not use derivative instruments unless there is an underlying exposure.
Other financial instruments that potentially subject us to concentrations of credit risk are principally
cash and cash equivalents and accounts receivable. The carrying value of cash and cash equivalents
approximates its fair value due to the short maturity of the underlying instruments. Accounts
receivable are generated from a broad group of customers, primarily from within the energy
industry, which is our major source of revenue. Due to their short-term nature, carrying values of
our accounts receivable and accounts payable approximate fair market value. The carrying values of
borrowings under the Credit Agreement approximate their fair values, because the short-term
durations of the associated interest rate periods result in the applicable interest rates reflecting
market changes to interest rates. Our borrowings under the Credit Agreement are classified as
Level 2 in the fair value hierarchy under U.S. GAAP (inputs other than quoted prices in active
markets for similar assets and liabilities that are observable or can be corroborated by observable
market data for substantially the full term for the assets or liabilities).
Since the second quarter of 2015, the exchange rate for the Angolan kwanza relative to the U.S.
dollar has been declining. As our functional currency in Angola is the U.S. dollar, we recorded foreign
currency transaction gains (losses) related to the kwanza of $(7.3) million, $(17.4) million and $0.4
million in 2016, 2015 and 2014, as a component of Other income (expense), net in our Consolidated
Statements of Income for those respective periods. Our foreign currency transaction losses related
primarily to the remeasurement of our Angolan kwanza cash balances to U.S. dollars. Conversion of
cash balances from kwanza to U.S. dollars is controlled by the central bank in Angola, and the
central bank has slowed this process since mid-2015, causing our kwanza cash balances to increase.
70
As of December 31, 2016, we had the equivalent of approximately $32.0 million of cash in kwanza in
Angola reflected on our balance sheet. To mitigate our currency exposure risk in Angola, we have
used kwanza to purchase $59.1 million equivalent Angolan central bank (Banco Nacional de Angola)
bonds with various maturities throughout 2018. The bonds are denominated as U.S. dollar
equivalents, so that, upon payment of semi-annual interest and principal upon maturity, payment is
made in kwanza, equivalent to the respective U.S. dollars at the then-current exchange rate. We
have classified these instruments as held-to-maturity, and have recorded the original cost on our
balance sheet as other non-current assets. We estimated the fair market value of the Angolan bonds
to be $57.5 million at December 31, 2016 using quoted prices. Since the market for the Angolan
bonds is not an active market, the fair value of the Angolan bonds is classified within Level 2 in the
fair value hierarchy under U.S. GAAP.
We estimated the fair market value of the Senior Notes to be $495 million at December 31, 2016
based on quoted prices. Since the market for the Senior Notes is not an active market, the fair value
of the Senior Notes is classified within Level 2 in the fair value hierarchy under U.S. GAAP.
We have two interest rate swaps in place on a total of $200 million of the Senior Notes to
November 2024. The agreements swap the fixed interest rate of 4.650% on $200 million of the
Senior Notes to the floating rate of one month LIBOR plus 2.426% on $100 million and one month
LIBOR plus 2.823% on the other $100 million. We estimate the fair value of the interest rate swaps
to be a net liability of $1.6 million at December 31, 2016, with $2.2 million included on our balance
sheet in our other long-term liabilities, and $0.6 million included in non-current assets. These values
were arrived at using a discounted cash flow model using Level 2 inputs.
7. OPERATIONS BY BUSINESS SEGMENT AND GEOGRAPHIC AREA
Business Segment Information
We are a global oilfield provider of engineered services and products, primarily to the offshore oil and
gas industry, with a focus on deepwater applications. Through the use of our applied technology
expertise, we also serve the defense, aerospace and commercial theme park industries. Our Oilfield
business consists of Remotely Operated Vehicles ("ROVs"), Subsea Products, Subsea Projects and
Asset Integrity. Our ROV segment provides submersible vehicles operated from the surface to
support offshore oil and gas exploration, development and production activities. Our Subsea
Products segment supplies a variety of specialty subsea hardware and related services. Our Subsea
Projects segment provides multiservice subsea support vessels and oilfield diving and support vessel
operations, primarily for inspection, maintenance and repair and installation activities. Since
April 2015, we have also provided survey, autonomous underwater vehicle ("AUV") and satellite-
positioning services. Our Asset Integrity segment provides asset integrity management and
assessment services and nondestructive testing and inspection. Our Advanced Technologies
business provides project management, engineering services and equipment for applications in non-
oilfield markets. Unallocated Expenses are those not associated with a specific business segment.
These consist of expenses related to our incentive and deferred compensation plans, including
restricted stock and bonuses, as well as other general expenses, including corporate administrative
expenses.
There are no differences in the basis of segmentation or in the basis of measurement of segment
profit or loss in the year ended December 31, 2016 from those used in our consolidated financial
statements for the years ended December 31, 2015 and 2014.
71
The table that follows presents Revenue, Income from Operations, Depreciation and Amortization
Expense and Equity Earnings of Unconsolidated Affiliates by business segment:
(in thousands)
Revenue
Oilfield
Year Ended December 31,
2015
2014
2016
Remotely Operated Vehicles
$
522,121 $
692,030
472,979
275,397
1,962,527
807,723 $ 1,069,022
959,714
1,238,746
604,484
372,957
2,744,878
317,876
3,396,577
588,572
500,237
309,076
263,047
$ 2,271,603 $ 3,062,754 $ 3,659,624
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Total
Income from Operations
Oilfield
Remotely Operated Vehicles
$
25,193 $
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Unallocated Expenses
Total
75,938
34,476
7,551
143,158
11,809
(84,203)
$
70,764 $
Depreciation and Amortization Expense
Oilfield
Remotely Operated Vehicles
$
140,967 $
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Unallocated Expenses
Total
53,759
34,042
14,336
243,104
3,120
4,023
$
250,247 $
192,514 $
175,585
92,034
18,235
478,368
9,689
(114,247)
373,810 $
320,550
281,239
107,852
55,469
765,110
13,230
(150,010)
628,330
143,364 $
49,792
29,863
10,713
233,732
2,549
4,954
241,235 $
145,691
46,085
18,561
12,775
223,112
2,574
4,093
229,779
We determine income from operations for each business segment before interest income or expense,
other income (expense) and provision for income taxes. We do not consider an allocation of these
items to be practical.
During 2016, we recognized restructuring expenses of $11.6 million, attributable to each reporting
segment as follows:
• Remotely Operated Vehicles - $3.8 million;
• Subsea Products - $3.7 million;
• Subsea Projects - $2.1 million;
• Asset Integrity - $1.4 million;
• Advanced Technologies - $0.5 million; and
• Unallocated Expenses - $0.1 million.
The restructuring expenses were all severance costs, of which $8.4 million was unpaid at
December 31, 2016.
72
During 2015, we recognized restructuring expenses of $25.4 million, attributable to each reporting
segment as follows:
• Remotely Operated Vehicles - $7.2 million;
• Subsea Products - $8.7 million;
• Subsea Projects - $2.5 million;
• Asset Integrity - $6.4 million;
• Advanced Technologies - $0.2 million; and
• Unallocated Expenses - $0.4 million.
The restructuring expenses consisted substantially of severance costs that totaled $23.1 million
during the year, of which $7.0 million was unpaid at December 31, 2015 and paid in 2016.
During each of 2016, 2015 and 2014, revenue from one customer, BP plc and subsidiaries,
accounted for 18% of our total consolidated annual revenue.
The following table presents Assets, Property and Equipment and Goodwill by business segment as of
the dates indicated:
(in thousands)
Assets
Oilfield
Remotely Operated Vehicles
$
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Corporate and Other
Total
Property and Equipment, net
Oilfield
Remotely Operated Vehicles
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Corporate and Other
Total
Goodwill
Oilfield
Remotely Operated Vehicles
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Total
December 31,
2016
2015
755,894 $
833,919
608,411
261,410
2,459,634
101,756
568,925
951,001
890,041
671,019
295,955
2,808,016
97,764
523,756
$ 3,130,315 $ 3,429,536
$
485,063 $
344,973
273,384
24,571
1,127,991
12,057
13,210
580,315
348,042
277,695
35,359
1,241,411
12,614
12,706
$ 1,153,258 $ 1,266,731
$
$
24,406 $
99,336
154,823
143,144
421,709
21,842
443,551 $
24,344
88,279
149,389
143,018
405,030
21,842
426,872
All assets specifically identified with a particular business segment have been segregated. Cash and
cash equivalents, certain other current assets, certain investments and certain other assets have not
been allocated to particular business segments and are included in Corporate and Other.
73
The following table presents Capital Expenditures, including business acquisitions, by business
segment for the periods indicated:
(in thousands)
Capital Expenditures
Oilfield
Year Ended December 31,
2015
2014
2016
Remotely Operated Vehicles
$
50,339 $
Subsea Products
Subsea Projects
Asset Integrity
Total Oilfield
Advanced Technologies
Corporate and Other
Total
56,669
25,602
3,910
136,520
2,742
3,251
$
142,513 $
57,558 $
69,434
276,308
9,841
413,141
5,015
5,832
423,988 $
188,848
112,851
91,918
27,027
420,644
2,352
3,675
426,671
Geographic Operating Areas
The following table summarizes certain financial data by geographic area:
(in thousands)
Revenue
Foreign:
Africa
United Kingdom
Norway
Asia and Australia
Brazil
Other
Total Foreign
United States
Total
Long-Lived Assets
Foreign:
Norway
Africa
United Kingdom
Asia and Australia
Brazil
Other
Total Foreign
United States
Total
Year Ended December 31,
2015
2014
2016
$
486,615 $
304,635
166,180
196,679
73,280
66,870
1,294,259
659,038 $
367,326
250,272
245,978
118,056
116,647
1,757,317
1,305,437
795,229
456,804
488,789
317,277
185,299
98,881
2,342,279
977,344
1,317,345
$ 2,271,603 $ 3,062,754 $ 3,659,624
$
277,949 $
234,921
102,140
66,279
61,418
44,166
786,873
274,868 $
205,440
138,327
71,438
57,896
43,128
791,097
1,070,841
332,503
215,122
113,191
90,061
99,269
56,079
906,225
1,027,428
838,273
$ 1,814,301 $ 1,861,938 $ 1,744,498
Revenue is based on location where services are performed and products are manufactured.
74
8. EMPLOYEE BENEFIT PLANS
Retirement Investment Plans
We have several employee retirement investment plans that, taken together, cover most of our full-
time employees. The Oceaneering Retirement Investment Plan is a 401(k) plan in which U.S.
employees may participate by deferring a portion of their gross monthly salary and directing us to
contribute the deferred amount to the plan. We match a portion of the employees' deferred
compensation. Our contributions to the 401(k) plan were $20.0 million, $22.8 million and $21.3
million for the plan years ended December 31, 2016, 2015 and 2014, respectively.
We also make matching contributions to foreign employee savings plans similar in nature to a 401(k)
plan. In 2016, 2015 and 2014, these contributions, principally related to plans associated with U.K.
and Norwegian subsidiaries, were $12.1 million, $15.1 million and $18.7 million, respectively.
The Oceaneering International, Inc. Supplemental Executive Retirement Plan covers selected key
management employees and executives, as approved by the Compensation Committee of our Board
of Directors (the "Compensation Committee"). Under this plan, we accrue an amount determined as
a percentage of the participant's gross monthly salary and the amounts accrued are treated as if
they are invested in one or more investment vehicles pursuant to this plan. Expenses related to this
plan during 2016, 2015 and 2014 were $3.3 million, $3.3 million and $3.3 million, respectively.
We have defined benefit plans covering some of our employees in the U.K. and Norway. At
December 31, 2015, there were no further benefits accruing under the U.K. plan, and the Norway
plan was closed to new participants. During 2016, we agreed to settlements with almost all the
participants in the Norway plan. Our curtailment costs for the Norway plan in 2016 were $1.1 million
and are included in other income (expense), net. The projected benefit obligations for the plans
were $18 million (U.K. only in 2016) and $28 million, at December 31, 2016 and 2015, respectively,
and the fair values of the plan assets (using Level 2 inputs) for both plans were $19 million (U.K.
only in 2016) and $26 million at December 31, 2016 and 2015, respectively.
Incentive Plan
Under our Amended and Restated 2010 Incentive Plan (the "Incentive Plan"), shares of our common
stock are made available for awards to employees and nonemployee members of our Board of
Directors.
The Incentive Plan is administered by the Compensation Committee; however, the full Board of
Directors makes determinations regarding awards to nonemployee directors under the Incentive
Plan. The Compensation Committee or our Board of Directors, as applicable, determines the type(s)
of award(s) to be made to each participant and sets forth in the related award agreement the terms,
conditions and limitations applicable to each award. Stock options, stock appreciation rights and
stock and cash awards may be made under the Incentive Plan. There has been no stock option
activity after December 31, 2010 and there are no options outstanding under the Incentive Plan. We
have not granted any stock options since 2005 and the Compensation Committee has expressed its
intention to refrain from using stock options as a component of employee compensation for our
executive officers and other employees for the foreseeable future. Additionally, the Board of
Directors has expressed its intention to refrain from using stock options as a component of
nonemployee director compensation for the foreseeable future.
75
In 2016, 2015 and 2014, the Compensation Committee granted awards of performance units to
certain of our key executives and employees and, in 2014, our Board of Directors granted
performance units under a prior incentive plan to our Chairman of the Board of Directors (our
"Chairman"). The performance units awarded are scheduled to vest in full on the third anniversary
of the award date, or pro rata over three years if the participant meets certain age and years of
service requirements. The Compensation Committee and the Board of Directors have approved
specific financial goals and measures (as defined in the Performance Award Goals and Measures),
based on our cumulative cash flow from operations and a comparison of return on invested capital
and cost of capital for each of the three-year periods ending December 31, 2018, 2017 and 2016 to
be used as the basis for the final value of the performance units. The final value of each
performance unit granted in 2016, 2015 and 2014 may range from $0 to $150. Upon vesting and
determination of value, the value of the performance units will be payable in cash. Compensation
expense (benefit) related to the performance units was $(4.2) million, $6.8 million and $22.8 million
in 2016, 2015 and 2014, respectively. As of December 31, 2016, there were 437,223 performance
units outstanding.
During 2016, 2015 and 2014, the Compensation Committee granted restricted units of our common
stock to certain of our key executives and employees. During 2016, our Board of Directors granted
restricted common stock to our nonemployee directors. During 2015 and 2014, our Board of
Directors granted restricted units of our common stock to our Chairman and restricted common
stock to our other nonemployee directors. Over 65%, 65%, and 60% of the grants made to our
employees in 2016, 2015 and 2014, respectively, vest in full on the third anniversary of the award
date, conditional upon continued employment. The remainder of the grants made to employees and
all the grants of restricted stock units made to our Chairman vest pro rata over three years, as these
participants meet certain age and years-of-service requirements. For the grants of restricted stock
units to each of the participant employees and the Chairman, the participant will be issued a share of
our common stock for the participant's vested restricted stock units at the earlier of three years or, if
the participant vested earlier after meeting the age and service requirements, following termination
of employment or service. The grants of restricted stock to our nonemployee directors were
scheduled to vest in full on the first anniversary of the award date conditional upon continued service
as a director, with one exception. In February 2015, we granted shares of restricted common stock
to a director who had given written notice of his intention to retire from our board of directors.
Those shares were to vest if the director's service continued until the election of directors at our
subsequent annual meeting of shareholders in May 2015. The director fulfilled that requirement by
resigning concurrent with that election and the shares of restricted stock became vested.
In April 2009, the Compensation Committee adopted a policy that Oceaneering will not provide U.S.
federal income tax gross-up payments to any of its directors or executive officers in connection with
future awards of restricted stock or stock units. This policy had no effect on the existing change-in-
control agreement with one of our executive officers or the existing service agreement with our
Chairman, which provide for tax gross-up payments that could become applicable to such future
awards in limited circumstances, such as following a change in control of Oceaneering. Since
August 2010, there have been no outstanding awards that provide for tax gross-up payments.
The tax benefit (additional charge) realized from tax deductions in excess of (less than) the financial
statement expense of our restricted stock grants was $(3.0) million, $(0.9) million and $3.1 million
in 2016, 2015 and 2014, respectively.
76
The following is a summary of our restricted stock and restricted stock unit activity for 2016, 2015
and 2014:
Balance at December 31, 2013
Granted
Issued
Forfeited
Balance at December 31, 2014
Granted
Issued
Forfeited
Balance at December 31, 2015
Granted
Issued
Forfeited
Number
960,290 $
299,274
(411,800)
(33,364)
814,400
380,991
(311,119)
(52,981)
831,291
587,953
(278,572)
(88,665)
Balance at December 31, 2016
1,052,007 $
Weighted
Average
Fair Value
Aggregate
Intrinsic
Value
52.53
70.63
43.57 $ 29,043,000
62.66
63.30
52.40
57.94 $ 16,518,000
60.45
60.49
27.90
61.48 $ 7,866,000
43.03
43.48
The restricted stock units granted in 2016, 2015 and 2014 carry no voting rights and no dividend
rights. Each grantee of shares of restricted common stock is deemed to be the record owner of
those shares during the restriction period, with the right to vote and receive any dividends on those
shares.
Grants of restricted stock units are valued at their estimated fair values as of their respective grant
dates. The grants in 2016, 2015 and 2014 were subject only to vesting conditioned on continued
employment or service as a nonemployee director; therefore, these grants were valued at the grant
date fair market value using the closing price of our stock on the New York Stock Exchange.
Compensation expense under the restricted stock plans was $13.9 million, $15.9 million and $17.2
million for 2016, 2015 and 2014, respectively. As of December 31, 2016, we had $13.3 million of
future expense to be recognized related to our restricted stock unit plans over a weighted average
remaining life of 1.7 years.
77
Post-Employment Benefit
In 2001, we entered into an agreement with our Chairman who was also then our Chief Executive
Officer. That agreement was amended in 2006 and in 2008. Pursuant to the amended agreement,
the Chairman relinquished his position as Chief Executive Officer in May 2006 and began his post-
employment service period on December 31, 2006, which continued through August 15, 2011,
during which service period the Chairman, acting as an independent contractor, agreed to serve as
nonexecutive Chairman of our Board of Directors. The agreement provides the Chairman with post-
employment benefits for ten years following August 15, 2011. The agreement also provides for
medical coverage on an after-tax basis to the Chairman, his spouse and children for their lives. We
recognized the net present value of the post-employment benefits over the expected service period.
Our total accrued liabilities, current and long-term, under this post-employment benefit were $4.5
million and $5.1 million at December 31, 2016 and 2015, respectively.
As part of the arrangements relating to the Chairman's post-employment benefits, we established an
irrevocable grantor trust, commonly known as a "rabbi trust," to provide the Chairman greater
assurance that we will set aside an adequate source of funds to fund payment of the post-retirement
benefits under this agreement, including the medical coverage benefits payable to the Chairman, his
spouse and their children for their lives. In connection with establishment of the rabbi trust, we
contributed to the trust a life insurance policy on the life of the Chairman, which we had previously
obtained, and we agreed to continue to pay the premiums due on that policy. When the life
insurance policy matures, the proceeds of the policy will become assets of the trust. If the value of
the trust exceeds $4 million, as adjusted by the consumer price index, at any time after January 1,
2012, the excess may be paid to us. However, because the trust is irrevocable, the assets of the
trust are generally not available to fund our future operations until the trust terminates, which is not
expected to be during the lives of the Chairman, his spouse or their children. Furthermore, no tax
deduction will be available for our contributions to the trust; however, we may benefit from future
tax deductions for benefits actually paid from the trust (although benefit payments from the trust
are not expected to occur in the near term, because we expect to make direct payments of those
benefits for the foreseeable future).
SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)
(in thousands, except per share data)
Quarter Ended
Revenue
Gross margin
Income from operations
Net income
Year Ended December 31, 2016
June 30
Sept. 30
Dec. 31
Total
March 31
$
608,344 $
625,539 $
549,275 $
97,480
48,099
25,103
95,233
38,380
22,309
35,443
(11,856)
488,445 $ 2,271,603
51,071
279,227
(3,859)
70,764
(11,798)
(11,028)
24,586
Diluted earnings per share
$
0.26 $
0.23 $
(0.12 ) $
(0.11 ) $
0.25
Weighted average number of
diluted shares outstanding
98,286
98,424
98,061
98,064
98,424
Quarter Ended
Revenue
Gross margin
Income from operations
Net income
March 31
$
786,772 $
810,303 $
743,613 $
Year Ended December 31, 2015
Sept. 30
Dec. 31
June 30
Total
163,449
106,650
69,499
167,545
107,940
65,468
168,313
113,464
68,539
722,066 $ 3,062,754
106,122
605,429
45,756
27,505
231,011
373,810
Diluted earnings per share
$
0.70 $
0.66 $
0.70 $
0.28 $
2.34
Weighted average number of
diluted shares outstanding
99,912
98,893
98,185
98,268
98,808
78
NEXXUS ROV supporting a
subsea tieback field.
Annual Report 2016 DIRECTORS
John R. Huff, Chairman
A Director of Suncor Energy Inc. and Hi-Crush GP
LLC, the general partner of Hi-Crush Partners LP
William B. Berry
A Director of Continental Resources, Inc. and
Frank’s International N.V.
T. Jay Collins
A Director of Murphy Oil Corporation, Pason
Systems Inc., and NuMat Technologies, Inc.; and a
Director and Chairman of Texas Institute of Science,
Inc.
D. Michael Hughes
Owner of The Broken Arrow Ranch and
affiliated businesses
M. Kevin McEvoy
Chief Executive Officer of Oceaneering
International, Inc. and a Director of EMCOR
Group, Inc.
Paul B. Murphy, Jr.
Chief Executive Officer, President, and a Director
of Cadence Bancorp, LLC; and a Director of Hines
Real Estate Investment Trust, Inc.
Jon Erik Reinhardsen
President and Chief Executive Officer of Petroleum
Geo-Services ASA; and a Director of Borregaard
ASA and Telenor ASA
Steven A. Webster
Co-Managing Partner of Avista Capital Partners LP;
Director and Chairman of Carrizo Oil & Gas, Inc.;
Director of Era Group, Inc.; and Trust Manager of
Camden Property Trust
SENIOR MANAGEMENT
M. Kevin McEvoy
Chief Executive Officer
Roderick A. Larson
President
Clyde W. Hewlett
Chief Operating Officer
Alan R. Curtis
Senior Vice President and
Chief Financial Officer
W. Cardon Gerner
Senior Vice President and
Chief Accounting Officer
David K. Lawrence
Senior Vice President,
General Counsel and Secretary
John P. Kreider
Senior Vice President,
Advanced Technologies
Eric A. Silva
Senior Vice President,
Operations Support
Stephen P. Barrett
Senior Vice President,
Business Development
William J. Boyle
Senior Vice President,
Asset Integrity
Martin J. McDonald
Senior Vice President,
Remotely Operated Vehicles
Marvin J. Migura
Senior Vice President
Robert P. Moschetta
Senior Vice President, Health
Safety Environment/Training/
Quality
Oceaneering International, Inc. GENERAL INFORMATION
Stock Symbol: OII
Stock traded on NYSE
CUSIP Number: 675232102
Please direct communications
concerning stock transfer
requirements or lost certificates to
our transfer agent.
OII Account Information
www.computershare.com/investor
Telephone: 781.575.2879 or
877.373.6374
Fax: 781.575.3605
Hearing Impaired/TDD:
800.952.9245
Annual Shareholders’ Meeting
Date: May 5, 2017
Time: 8:30 a.m. CDT
Location:
Oceaneering International, Inc.
11911 FM 529
Houston, TX 77041
Transfer Agent and Registrar
Computershare Trust Co., N.A.
P.O. Box 30170
College Station, TX 77842-3170
Overnight Deliveries:
211 Quality Circle, Suite 210
College Station, TX 77845
Independent Registered
Public Accounting Firm
Ernst & Young LLP
5 Houston Center
1401 McKinney Street
Houston, TX 77010-4034
Counsel
Baker Botts L.L.P.
One Shell Plaza
910 Louisiana Street
Houston, TX 77002-4995
FORWARD-LOOKING STATEMENTS
In accordance with the safe-harbor provisions of
the Private Securities Litigation Reform Act of 1995,
Oceaneering cautions that statements in this 2016
annual report which are forward-looking, and provide
other than historical information, involve risks,
contingencies and uncertainties that may impact our
actual results of operations, including those we refer
to under the headings “CAUTIONARY STATEMENT
CONCERNING FORWARD-LOOKING STATEMENTS”
and “Risk Factors” in Part I of the accompanying
Annual Report on Form 10-K. These forward-looking
statements more specifically include: (1) statements in
the 2016 Letter to Shareholders about Oceaneering’s:
expectations regarding declining offshore activity in
2017; outlook for a continued decline in customer
spending in specified areas in 2017; anticipation of
being marginally profitable at the operating income
level on a consolidated basis in 2017; anticipated
2017 capital expenditures; expectation to generate
a substantial amount of free cash flow in 2017;
expectations beyond 2017, including with respect to
an increase in deepwater expenditures and improving
demand for our services and products; expectation
that deepwater will play a critical role in global supply
growth; and intention to expand its ability to participate
in the deepwater market; and (2) other statements
identified in Part II, Item 7 – “Management’s Discussion
and Analysis of Financial Condition and Results of
Operations” of the accompanying Annual Report on
Form 10-K. Although we believe that the expectations
reflected in such forward-looking statements are
reasonable, because of the inherent limitations in the
forecasting process, as well as the relatively volatile
nature of the industries in which we operate, we can
give no assurance that those expectations will prove to
have been correct. Accordingly, evaluation of our future
prospects must be made with caution when relying on
forward-looking information.
Annual Report 2016 Connecting What’s Needed with What’s Next™
Oceaneering International, Inc.
11911 FM 529 I Houston, Texas I 77041-3000
713.329.4500 | oceaneering.com
Oceaneering International, Inc.