e10vk
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
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þ |
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ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the fiscal year ended December 31, 2008
OR
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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)
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Delaware
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95-2628227 |
State or other jurisdiction
of incorporation or organization
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(I.R.S. Employer
Identification No.) |
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11911 FM 529 |
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Houston, Texas
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77041 |
(Address of principal executive offices)
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(Zip Code) |
Registrants telephone number, including area code: (713) 329-4500
Securities registered pursuant to Section 12(b) of the Act:
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Name of each exchange |
Title of each class |
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on which registered |
Common Stock, $0.25 par value |
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New York Stock Exchange |
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Rights to Purchase Series B Junior
Participating Preferred Stock
(currently traded with Common Stock)
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New York Stock Exchange
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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. þ Yes o 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. o Yes þ 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. þ Yes o No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is
not contained herein, and will not be contained, to the best of registrants 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. þ Yes o 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.
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Large accelerated filer þ
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Accelerated filer o
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Non-accelerated filer o
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Smaller reporting company o |
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(Do not check if a smaller reporting company) |
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Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the
Exchange Act). o Yes þ No
Aggregate market value of the voting stock held by nonaffiliates of the registrant computed by
reference to the closing price of $77.05 of the Common Stock on the New York Stock Exchange as of
June 30, 2008, the last business day of the registrants most recently completed second quarter:
$4,223,808,000
Number of shares of Common Stock outstanding at February 13, 2009: 54,625,402
Documents Incorporated by Reference:
Portions of the proxy statement relating to the registrants 2009 annual meeting of shareholders,
to be filed on or before April 30, 2009 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
Page 2
PART I
Item 1. BUSINESS.
GENERAL DEVELOPMENT OF BUSINESS
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. Through
the use of its applied technology expertise, Oceaneering also serves the defense and aerospace
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 requiring the use
of advanced deepwater technology. We are one of the worlds largest underwater services
contractors. The services and products we provide to the oil and gas industry include remotely
operated vehicles, built-to-order specialty hardware, engineering and project management, subsea
intervention services, nondestructive testing and inspection, manned diving and mobile offshore
production systems. We have locations in the U.S. and 17 other countries. Our international
operations, principally in the North Sea, West Africa, Brazil, Australia and Asia, accounted for
approximately 54% of our revenue, or $1.1 billion, for the year ended December 31, 2008.
Our
business segments are contained within two businesses services and products provided to the
oil and gas industry (Oil and Gas) and all other services and products (Advanced Technologies).
Our five business segments within the Oil and Gas business are Remotely Operated Vehicles
(ROVs), Subsea Products, Subsea Projects, Inspection and Mobile Offshore Production Systems. We
report our Advanced Technologies business as one segment. 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.
Oil and Gas. The focus of our Oil and Gas business has been toward increasing our asset base for
providing services and products for deepwater offshore operations and subsea completions.
ROVs. Prior to 1995, we purchased most of our ROVs, which are submersible vehicles operated from
the surface and widely used in the offshore oil and gas industry. However, in response to
increased demand for more powerful systems operating in deeper water, we expanded our capabilities
and established an in-house facility to design and build ROVs to meet the continued expansion of
our ROV fleet. In December 2007, we moved our ROV manufacturing operations to a larger facility in
Morgan City, LA. This facility consolidated several separate facilities we had in the area. We
have built over 200 ROV systems, and we are producing all our new ROVs in-house. For a few years
leading into 2005, except for units we have purchased from other ROV operators, we had kept the
number of our work-class ROVs at a constant level and built new systems for replacement and upgrade
of our existing fleet. In the first quarter of 2004, we completed the acquisition of 34 additional
work-class ROVs and related business operations from Stolt Offshore S.A. In the third quarter of
2004, we acquired 10 work-class ROVs and related equipment and business operations in North and
South America from Fugro N.V. During the four-year period ended December 31, 2008, in response to
increased demand in the deepwater market, we added 85 ROVs, 82 that we built and three that we
purchased from another company, and disposed of 26 ROVs.
Subsea Products. Through our Oceaneering Intervention Engineering division, we construct a variety
of built-to-order specialty subsea hardware. In 2003, we purchased Rotator AS, a designer and
manufacturer of subsea control valves, topside control valves, subsea chemical injection valves and
specialty control panels. In 2005, we acquired Grayloc Products, L.L.C. and subsidiary (together,
Grayloc), an oil and gas industry supplier of high performance clamp connectors used in
production manifold, flowline and valve installations. In 2007, we purchased Ifokus Engineering
AS, a designer and manufacturer of specialty subsea products, particularly ROV tooling. In 2008,
we purchased GTO Subsea AS (GTO), a Norwegian rental provider of specialized subsea dredging
equipment, including ROV-deployed units, to the offshore oil and gas industry.
Our Multiflex division provides various types of subsea umbilicals. Offshore operators use
umbilicals to control subsea wellhead hydrocarbon flow rates, monitor downhole and wellhead
conditions and perform chemical injection. They are also used to provide power and additional
fluid transfer to other subsea processing hardware, including pumps and gas separation equipment.
We entered this market in March 1994 through our purchase of the operating subsidiaries of
Multiflex International Inc. During 1998, we constructed an umbilical plant in Brazil and
relocated, modernized and increased the capabilities, including the production of steel tube
umbilicals, of our umbilical manufacturing facility in Scotland. Both facilities began operations
in the first half of 1999. During 2004, we moved our U.S. facility to a new location, which has
additional capacity and the capability of producing steel tube umbilicals, and added steel tube
capability to our plant in Brazil. In 2006, we increased the thermoplastic umbilical capability at
our Scotland facility.
Subsea Projects. Our Subsea Projects segment consists of our subsea installation, inspection,
maintenance and repair services in the Gulf of Mexico and Angola utilizing a fleet of three owned and two chartered dynamically
positioned deepwater vessels with integrated high-specification work-class ROVs
Page 3
onboard, and shallow water diving vessels and assets. The deepwater vessels are equipped with
thrusters that allow them to be dynamically positioned, which means they can maintain a constant
position at a location without the use of anchors. They are used in pipeline or flowline tie-ins,
pipeline crossings and subsea hardware interventions and installations. These vessels can carry
and install coiled tubing or umbilicals required to bring subsea well completions into production
(tie-back to production facilities). In 2006, we transferred our vessel The Performer from our
Advanced Technologies segment to our Subsea Projects segment. In 2007, we upgraded its dynamic
positioning system for deepwater inspection, maintenance and repair projects in the Gulf of Mexico.
In 2008, we moved The Performer to Angola to work under a one-year contract. We occasionally
charter vessels from others to augment our fleet. In 2006, we chartered a larger deepwater vessel,
the Ocean Intervention III, for three years, with extension options for up to six additional years.
The initial three-year term of the charter began in May 2007. We also chartered an additional
larger deepwater vessel, the Olympic Intervention IV, for an initial term of five years, which
began in the third quarter of 2008. We outfitted each of these larger deepwater vessels with two
of our high-specification work-class ROVs, and we expect to utilize these vessels to perform subsea
hardware installation and inspection, repair and maintenance projects, and to conduct well
intervention services in the ultra-deep waters of the Gulf of Mexico.
Inspection. Our Inspection segment provides nondestructive testing and inspection and integrity
management and assessment services. We supply inspection services to customers required to obtain
third-party inspections to satisfy contractual structural specifications, internal safety standards
or regulatory requirements. In January 2003, we acquired OIS International Inspection plc. This
acquisition approximately tripled the size of our Inspection services.
Mobile Offshore Production Systems. We own two mobile offshore production systems:
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the floating production, storage and offloading system Ocean Producer, which has
been operating offshore West Africa since December 1991; and |
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the mobile offshore production system Ocean Legend, which has been operating
offshore Western Australia since May 2001. |
We also purchased an oil tanker, the Ocean Pensador, in 2006 for possible conversion into a mobile
offshore production or storage system in the event we obtained a suitable contract. The Ocean
Pensador is currently laid up in Southeast Asia.
In December 2003, we purchased a 50% equity interest in Medusa Spar LLC, which owns 75% of a
production spar platform. Medusa Spar LLCs revenue is derived from processing oil and gas
production for a fee based on the volumes processed. The spar is currently located on the Medusa
field in the Gulf of Mexico. Medusa Spar LLC has a contract covering production from the Medusa
field and other nearby areas. Medusa Spar LLC financed its acquisition of its 75% interest in the
production spar platform using approximately 50% debt and 50% equity from its equity holders.
Medusa Spar LLC paid off the debt in 2008. For additional information regarding our interest in
Medusa Spar LLC, see Managements Discussion and Analysis of Financial Condition and Results of
Operation Results of Operations Other in Item 7 of Part II of this report.
General. 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, either directly through merger, consolidation or purchase, or indirectly through joint
ventures.
Advanced Technologies. In August 1992 and May 1993, we purchased two businesses that formed the
basis of our Advanced Technologies segment. The first business designed, developed and operated
robotic systems and ROVs specializing in non-oilfield markets and provided the basis for our
expansion into civil works projects and commercial theme park animation. The second business
designed, developed and fabricated spacecraft hardware and high-temperature insulation products.
In 2003, we acquired Nauticos Corporation, a provider of marine services support to governmental
and commercial customers.
FINANCIAL INFORMATION ABOUT SEGMENTS
For financial information about our business segments, please see the tables in Note 6 of the Notes
to Consolidated Financial Statements in this report, which present revenue, income from operations,
depreciation and amortization expense, equity earnings of unconsolidated affiliates and capital
expenditures for 2008, 2007 and 2006, and identifiable assets and goodwill by business segment as
of December 31, 2008 and 2007.
Page 4
DESCRIPTION OF BUSINESS
Oil and Gas
Our Oil and Gas business consists of ROVs, Subsea Products, Subsea Projects, Inspection and Mobile
Offshore Production Systems.
ROVs. ROVs are submersible vehicles 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,
installation and construction support, pipeline inspection and surveys, and subsea production
facility operation and maintenance. ROVs may be outfitted with manipulators, sonar, video cameras,
specialized tooling packages and other equipment or features to facilitate the performance of
specific underwater tasks. At December 31, 2008, we owned 227 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 and construction and field maintenance.
ROV revenue:
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Percent |
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of Total |
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Amount |
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Revenue |
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(in thousands) |
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2008 |
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$ |
625,921 |
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32 |
% |
2007 |
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531,381 |
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30 |
% |
2006 |
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410,256 |
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32 |
% |
Subsea Products. We construct a variety of built-to-order specialty subsea hardware to ISO 9001
quality requirements. These products include:
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various types of subsea umbilicals utilizing thermoplastic hoses and steel tubes; |
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installation and workover control systems; |
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ROV tooling and work packages; |
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subsea and topside control valves; |
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subsea chemical injection valves; |
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blowout preventer control systems; |
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production control equipment; |
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clamp connectors; and |
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pipeline repair systems. |
We market these products under the trade names Oceaneering Multiflex, Oceaneering Intervention
Engineering, Oceaneering Grayloc, Oceaneering Rotator and GTO Subsea.
Offshore well operators use subsea umbilicals and production control equipment to control subsea
wellhead hydrocarbon flow rates, monitor downhole and wellhead conditions and perform chemical
injection. They are also used to provide power and additional fluid transfer to other subsea
processing hardware, including pumps and gas separation equipment. ROV tooling and work packages
provide the operational link between an ROV and permanently installed equipment located on the sea
floor. Valves are used to control and meter hydrocarbon production flow rates and to inject
chemicals into production streams at the wellhead to enhance well flow characteristics.
Subsea Products revenue:
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Percent |
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of Total |
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Amount |
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Revenue |
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(in thousands) |
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2008 |
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$649,857 |
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33 |
% |
2007 |
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521,937 |
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30 |
% |
2006 |
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364,510 |
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29 |
% |
Page 5
Subsea Projects. We perform subsea intervention and hardware installation services in the Gulf of
Mexico and Angola from three owned and two chartered multiservice deepwater vessels. These services include: subsea well
tie-backs; pipeline/flowline tie-ins and repairs; pipeline crossings; umbilical and other subsea
equipment installations; subsea intervention; and inspection, repair and maintenance activities.
We supply commercial diving services to the oil and gas industry in the Gulf of Mexico using the
traditional techniques of air, mixed gas and saturation diving, all of which use surface-supplied
breathing gas. We do not use traditional diving techniques in water depths greater than 1,000
feet. We also use atmospheric diving systems, which enclose the operator in a surface pressure
diving suit, in water depths up to 2,300 feet.
Subsea Projects revenue:
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Percent |
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of Total |
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Amount |
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Revenue |
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(in thousands) |
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2008 |
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$ |
256,517 |
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13 |
% |
2007 |
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257,752 |
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15 |
% |
2006 |
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155,046 |
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12 |
% |
Inspection. Through our Oceaneering Inspection division, we offer a wide range of inspection
services to customers who are required to obtain 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.
Inspection revenue:
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Percent |
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of Total |
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Amount |
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Revenue |
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(in thousands) |
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2008 |
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$ |
249,109 |
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12 |
% |
2007 |
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219,686 |
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13 |
% |
2006 |
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169,014 |
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13 |
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Mobile Offshore Production Systems. We own two mobile offshore production systems, the Ocean
Legend and the Ocean Producer.
We also undertake engineering and project management of projects related to mobile offshore
production systems. We have managed the conversion of a jackup to a production unit and in-field
life extension and modifications to a floating production storage and offloading system. We also
perform engineering studies for customers evaluating field development projects.
We own a 50% equity interest in Medusa Spar LLC, which owns 75% of a production spar platform.
Medusa Spar LLCs revenue is derived from processing oil and gas production for a fee, based on the
volumes processed. The spar is currently located on the Medusa field in the Gulf of Mexico.
Medusa Spar LLC has a contract covering production from the Medusa field and other nearby areas.
We report our interest in this entitys results in equity earnings of unconsolidated affiliates.
Page 6
Mobile Offshore Production Systems revenue:
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Percent |
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of Total |
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Amount |
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Revenue |
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(in thousands) |
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2008 |
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$ |
39,274 |
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2 |
% |
2007 |
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50,103 |
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3 |
% |
2006 |
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52,931 |
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4 |
% |
Advanced Technologies
Our Advanced Technologies segment provides engineering services and related manufacturing to meet a
variety of industrial requirements, including ship and submarine husbandry, search and recovery,
maintenance and repair, commercial theme park equipment and engineering services and products for
the space industry. We do this in part by extending the use of existing assets and technology
developed in oilfield operations to new applications.
We work for customers having specialized requirements in underwater or other hazardous environments
outside the oil and gas industry. 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 Navys surface ships, submarines, piers, offshore structures and moorings. We provide
products and services to NASA and aerospace prime contractors and we manage the underwater
activities for astronaut training at NASAs Neutral Buoyancy Laboratory. Our NASA-related
activities substantially depend on continued government funding for space programs.
Advanced Technologies revenue:
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Percent |
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of Total |
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Amount |
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Revenue |
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(in thousands) |
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2008 |
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$ |
156,743 |
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8 |
% |
2007 |
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162,221 |
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9 |
% |
2006 |
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128,441 |
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10 |
% |
MARKETING
Oil and Gas. 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.
We market our ROVs, Subsea Products, Subsea Projects and Inspection 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.
We market our Mobile Offshore Production Systems primarily to international and foreign national
oil and gas companies. We offer systems for production and development of fields and prospects in
areas lacking pipelines and processing infrastructure. Our systems can also be used for extended
well testing and early production of marginal fields. Contracts are typically awarded on a
competitive-bid basis, generally for periods of one or more years.
In connection with the services we perform in our Oil and Gas business, we generally seek contracts
that compensate us on a dayrate basis. Under dayrate contracts, the contractor provides the ROV or
vessel 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 contractors control. Some dayrate contracts provide for
revision of the specified dayrates
Page 7
in the event of material changes in the cost of labor or
specified items. 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 prime contractors, and to
construction, theme parks and other industrial customers outside the energy sector. We also market
to insurance companies, salvage associations and other customers who have requirements for
specialized operations in deep water.
Major Customers. Our top five customers in 2008, 2007 and 2006 accounted for 31%, 36% and 23%,
respectively, of our consolidated revenue. For 2008 and 2007, all of our top five customers were
oil and gas exploration and production companies served by our Oil and Gas business segments. For
2006, four of our top five customers were oil and gas exploration and production companies served
by our Oil and Gas business segments. In 2007, BP plc and subsidiaries accounted for 14% of our
revenue. No single customer accounted for more than 10% of our consolidated revenue in 2008 or
2006. 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,
electronic components and plastics, are available from many sources. However, some components we
use to manufacture subsea umbilicals are available from limited sources. We can offer alternative
materials or technologies in many cases with the exception of certain kinds of steel tube, where we
are limited in the number of available suppliers, 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 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. Additionally, the availability of certain grades of aramid
fibers, which we use in the manufacture of our thermoplastic umbilicals, has historically been
limited due to demand for military use. Presently, this situation does not exist, and we believe
it is unlikely to return in the near future.
COMPETITION
Our businesses operate in highly competitive industry segments.
Oil and Gas
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, including technological applications in deeper
water (greater than 1,000 feet), on a worldwide basis enables us to compete effectively in
the oilfield exploration and development market. In some cases involving projects that require
less sophisticated equipment, small companies have been able to bid for contracts at prices
uneconomical to us.
ROVs. We believe we are the worlds largest owner/operator of work-class ROVs employed in oil and
gas related operations. We own 227 work-class ROVs, and estimate that this represents
approximately 35% of the work-class ROVs utilized in the oil and gas service industry. We compete
with several major companies on a worldwide basis and with numerous others operating locally in
various areas. We have fewer competitors in deeper water depths, as more sophisticated equipment
and technology is needed in deeper water.
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 from year to year based on market conditions. The ability to develop improved
equipment and techniques and to attract and retain skilled personnel is also an important
competitive factor in our markets.
Subsea Products. Although there are many competitors offering either specialized products or
operating in limited geographic areas, we believe we are one of a small number of companies that
compete on a worldwide basis for the provision of thermoplastic and steel tube subsea control
umbilical cables. Compared to current market demand, we are faced with overcapacity in the
umbilical manufacturing market.
Subsea Projects. We perform subsea intervention and hardware installation services in the Gulf of
Mexico and Angola from three owned and two chartered multiservice
deepwater vessels. We are one of many companies that
offer these services. In general, our competitors can move
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their vessels to the Gulf of Mexico
from other locations with relative ease. We also have many competitors in the supply of our
commercial diving services to the oil and gas industry in the Gulf of Mexico.
Inspection. The worldwide inspection market consists 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
inspection services market segments.
Mobile Offshore Production Systems. Although we are one of many companies that offer leased mobile
offshore production systems, we believe we are positioned to compete in this market when price is
not the determining factor. In the past several years, these services have been provided as more
of a commodity, hampering our ability to provide specialized solutions at prices meeting our return
objectives.
Frequently, oil and gas companies use prequalification procedures that reduce the number of
prospective bidders for their projects. In some countries, political considerations tend to favor
local contractors.
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 prototype equipment for customers.
SEASONALITY AND BACKLOG
A material amount of our consolidated revenue is generated from contracts for marine services in
the Gulf of Mexico and the North Sea, which are usually more active from April through November
compared to the rest of the year. Although most of our ROVs are engaged in providing drill support
services, we have increased our ROV activity in offshore construction and production field
maintenance. This change has increased the level of seasonality in our ROV operations, with the
low point expected to be in the first quarter of the year. Our Inspection segments operations
remain more active from April through November as compared to the rest of the year. Revenues in
our Mobile Offshore Production Systems, Subsea Products and Advanced Technologies segments are
generally not seasonal.
The amounts of backlog orders we believed to be firm as of December 31, 2008 and 2007 were as
follows (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of December 31, 2008 |
|
|
As of December 31, 2007 |
|
|
|
Total |
|
|
1 + yr* |
|
|
Total |
|
|
1 + yr* |
|
Oil and Gas |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROVs |
|
$ |
938 |
|
|
$ |
536 |
|
|
$ |
750 |
|
|
$ |
414 |
|
Subsea Products |
|
|
298 |
|
|
|
39 |
|
|
|
338 |
|
|
|
10 |
|
Subsea Projects |
|
|
103 |
|
|
|
|
|
|
|
72 |
|
|
|
|
|
Inspection |
|
|
250 |
|
|
|
132 |
|
|
|
239 |
|
|
|
64 |
|
Mobile Offshore
Production
Systems |
|
|
6 |
|
|
|
|
|
|
|
19 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
1,595 |
|
|
|
707 |
|
|
|
1,418 |
|
|
|
488 |
|
Advanced Technologies |
|
|
86 |
|
|
|
5 |
|
|
|
253 |
|
|
|
166 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
1,681 |
|
|
$ |
712 |
|
|
$ |
1,671 |
|
|
$ |
654 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* |
|
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 a number of U.S. and foreign patents and have numerous 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.
Page 9
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:
|
|
construction and equipping of offshore production and other marine facilities; |
|
|
|
marine vessel safety; |
|
|
|
protection of the environment; |
|
|
|
workplace health and safety; |
|
|
|
taxation of foreign earnings and earnings of expatriate personnel; |
|
|
|
license requirements for exportation of our equipment and technology; and |
|
|
|
currency conversion and repatriation. |
In addition, our Oil and Gas business depends on the demand for our products and services 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 U.S., 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 Oil and Gas products and services in the United Kingdom and Norway; |
|
|
|
our Remotely Operated Vehicle operations in Brazil and Canada; |
|
|
|
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.
Page 10
EMPLOYEES
As of December 31, 2008, we had approximately 7,900 employees. Our workforce varies seasonally and
peaks during the summer months. 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 6
of the Notes to Consolidated Financial Statements in this report, which present revenue for 2008,
2007 and 2006 and long-lived assets as of December 31, 2008 and 2007 attributable to each of our
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.
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 SECs 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.
EXECUTIVE OFFICERS OF THE REGISTRANT.
Executive Officers. The following information relates to our executive officers as of February 22,
2009:
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|
|
|
|
|
|
|
|
|
|
OFFICER |
|
EMPLOYEE |
NAME |
|
AGE |
|
POSITION |
|
SINCE |
|
SINCE |
|
T. Jay Collins
|
|
|
62 |
|
|
President and Chief Executive Officer and Director
|
|
|
1993 |
|
|
|
1993 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
M. Kevin McEvoy
|
|
|
58 |
|
|
Executive Vice President
|
|
|
1990 |
|
|
|
1979 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Marvin J. Migura
|
|
|
58 |
|
|
Senior Vice President and Chief Financial Officer
|
|
|
1995 |
|
|
|
1995 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
George R. Haubenreich, Jr.
|
|
|
61 |
|
|
Senior Vice President, General Counsel and Secretary
|
|
|
1988 |
|
|
|
1988 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Philip D. Gardner
|
|
|
58 |
|
|
Senior Vice President Subsea Products
|
|
|
2006 |
|
|
|
2004 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
W. Cardon Gerner
|
|
|
54 |
|
|
Vice President and Chief Accounting Officer
|
|
|
2006 |
|
|
|
2006 |
|
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.
Page 11
T. Jay Collins, President and Chief Executive Officer, joined Oceaneering in 1993 as Senior Vice
President and Chief Financial Officer. In 1995, he was appointed Executive Vice President
Oilfield Marine Services. He was appointed our President and Chief Operating Officer in 1998 and
our Chief Executive Officer in 2006. He was elected a director of Oceaneering in March 2002.
M. Kevin McEvoy, Executive Vice President, 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 and Executive
Vice President in 2006.
Marvin J. Migura, Senior Vice President and Chief Financial Officer, joined Oceaneering in 1995.
From 1975 to 1994, he held various financial positions with Zapata Corporation, then a diversified
energy services company, most recently as Senior Vice President and Chief Financial Officer from
1987 to 1994.
George R. Haubenreich, Jr., Senior Vice President, General Counsel and Secretary, joined
Oceaneering in 1988.
Philip D. Gardner, Senior Vice President Subsea Products, joined Oceaneering in 2004. He served
as President of Applied Hydraulic Systems Incorporated (AHI), an oilfield manufacturer and
service company, from 1998 to 2002, when it was acquired by Oil States International, Inc. He
continued to serve as President of AHI to 2004. He held various senior management positions with
Weatherford International Ltd. from 1992 to 1998.
W. Cardon Gerner, Vice President and Chief Accounting Officer, joined Oceaneering in September
2006. From 1999 to 2006, he held 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 1995 to 1999. He is a Certified Public Accountant.
ITEM 1A. RISK FACTORS.
Investors in our company should consider the following 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. 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 Oil and Gas 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; |
|
|
|
|
delays in deliveries of deepwater drilling rigs; |
|
|
|
|
the ability of the Organization of Petroleum Exporting Countries, or OPEC, to set and
maintain production levels and pricing; |
|
|
|
|
the level of production by non-OPEC countries; |
|
|
|
|
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; |
|
|
|
|
rapid technological changes; |
|
|
|
|
the political environment of oil-producing regions; |
|
|
|
|
the price and availability of alternative fuels; and |
|
|
|
|
overall economic conditions. |
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
Page 12
54% of our consolidated revenue in 2008. Risks associated with our operations in foreign areas
include risks of:
|
|
|
regional and global economic downturns. |
|
|
|
|
war and civil 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; |
|
|
|
|
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 war, other armed conflict or terrorist attacks. |
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,
political instability and civil unrest in West Africa, particularly Nigeria, and Indonesia 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 2008, we generated approximately 14%
from our operations in West Africa.
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 projected 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. In addition, even where a project proceeds as scheduled, it is possible that
contracted parties may default and fail to pay amounts owed to us. Material delays, suspensions,
cancellations or payment defaults could materially affect our financial condition, results of
operations and cash flows.
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. 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. Many of
our ROV contracts have 30-day notice termination clauses. We typically have no contractual right
upon cancellation to the total revenues 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.
The global financial crisis may impact our business and financial condition in ways that we
currently cannot predict.
The continuing credit crisis and related turmoil in the global financial system may have an impact
on our business and our financial condition. In particular, the cost of capital has increased
substantially while the availability of funds from the capital markets has diminished
significantly. Accordingly, our ability to access the capital markets may 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 may 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.
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 additional amounts under our revolving credit facility could
limit our ability to fund our future operations and growth.
The current economic situation 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. The uncertainty and volatility of the global
financial crisis may have further impacts on our business and our consolidated financial condition,
results of operations and cash flows that we currently cannot predict or anticipate.
Page 13
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 product and service 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 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; |
|
|
|
|
diversion of managements 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.
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, our operations depend, to a
considerable extent, on the continuing availability of such personnel. If we should suffer any
material loss 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. While we believe our wage rates are competitive and
our relationships with our employees are satisfactory, a significant increase in the wages paid by
other employers could result in a reduction in our workforce, increases in wage rates, or both. If
either of these events occurred for a significant period of time, our financial condition and
results of operations could be adversely impacted.
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. The precautions we take to prevent and detect misconduct, fraud or non-compliance
with applicable laws and regulations may not be effective, and 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.
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
Page 14
products and services. This factor is significant to our segments businesses, particularly in the
segments within our Oil and Gas business, where capital investment is critical to our ability to
compete.
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 you that any design will succeed in achieving
its stated goals under all potential future conditions, regardless of how remote.
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
Page 15
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:
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|
|
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; |
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|
|
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 |
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|
the authorization given to our board of directors to issue and set the terms of preferred
stock. |
In addition, we have adopted a shareholder rights plan that would cause extreme dilution to any
person or group who attempts to acquire a significant interest in Oceaneering without advance
approval of our board of directors, while the Delaware General Corporation Law would impose some
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 lease or own 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.
Oil and Gas. In general, our ROV, Subsea Projects and Inspection segments share facilities. Our
location in Morgan City, Louisiana is the largest of these facilities and 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 U.S. In 2007, we
moved to a larger facility in Morgan City that consolidated several separate facilities in the area.
We have regional support offices for our North Sea, West Africa and Southeast Asia operations in:
Aberdeen, Scotland; Stavanger, Norway; Dubai; and Singapore. We also have operational bases in
various other locations, the most significant of which are in Angola and Nigeria.
We use workshop and office space in Houston, Texas in both our Subsea Products and Mobile Offshore
Production Systems business segments. Our manufacturing facilities for our Subsea Products segment
are located in or near: Houston, Texas; Panama City, Florida; Edinburgh, Scotland; Nodeland and
Kristiansund, Norway; and Rio de Janeiro, 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. The Panama City,
Florida facility was completed in 2004, and has since added the additional capability to produce
steel tube umbilicals. We also added steel tube capability to our plant in Brazil during 2004 and
significantly increased our thermoplastic capability in Scotland in 2006. Operations of the mobile
offshore production unit Ocean Producer are supported through our office in Houston. Operations of
the Ocean Legend are supported from our office in Perth, Australia.
Our principal manufacturing facilities are located on properties we own or hold under a long-term
lease, expiring in 2014. The other facilities we use in our Oil and Gas business segments are on
properties we lease.
Advanced Technologies. Our primary facilities for our Advanced Technologies segment are leased
offices and workshops in Hanover, Maryland. We have regional support offices in Chesapeake,
Virginia; 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, and facilities in Houston, Texas, which primarily support our space industry
activities.
Page 16
ITEM 3. LEGAL PROCEEDINGS.
In the ordinary course of business, we are subject to actions for damages alleging personal injury
under the general maritime laws of the U.S., 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.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
No matter was submitted to a vote of our security holders, through the solicitation of proxies or
otherwise, during the last three months of the year ended December 31, 2008.
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
backlog, revenue, income and capital spending. Forward-looking statements are generally
accompanied by words such as estimate, project, predict, believe, expect, anticipate,
plan, forecast, budget, goal 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 Managements 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:
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worldwide demand for and prices of oil and gas; |
|
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|
|
the continued availability of qualified personnel; |
|
|
|
|
general economic and business conditions and industry trends; |
|
|
|
|
the volatility and uncertainties of credit markets; |
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|
|
the highly competitive nature of our businesses; |
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|
decisions about offshore developments to be made by oil and gas companies; |
|
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|
cancellations of contracts and the resulting adjustments to our backlog; |
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|
the increased use of subsea completions and our ability to capture associated market share; |
|
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|
the continued strength of the industry segments in which we are involved; |
|
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|
|
the levels of oil and gas production to be processed by the Medusa field production spar
platform; |
|
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|
|
our future financial performance, including availability, terms and deployment of capital; |
|
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|
|
our ability to obtain raw materials and parts on a timely basis and, in some cases, from
limited sources; |
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|
|
operating risks normally incident to offshore exploration, development and production
operations; |
|
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|
|
hurricanes and other adverse weather conditions; |
|
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|
delays in deliveries of deepwater drilling rigs; |
|
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|
cost and time associated with drydocking of our vessels; |
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|
changes in, or our ability to comply with, government regulations, including those
relating to the environment; |
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|
the risks associated with integrating businesses we acquire; |
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|
rapid technological changes; and |
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|
social, political, military and economic situations in foreign countries where we do
business and the
possibilities of 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
Page 17
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.
Part II
|
|
|
ITEM 5. |
|
MARKET FOR REGISTRANTS 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 2008 a certification of our Chief Executive Officer regarding
compliance with the Exchanges 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 Chief
Executive Officer and Chief 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):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2008 |
|
2007 |
|
|
High |
|
Low |
|
High |
|
Low |
For the quarter ended: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
March 31 |
|
$ |
76.40 |
|
|
$ |
54.37 |
|
|
$ |
43.64 |
|
|
$ |
35.40 |
|
June 30 |
|
|
82.49 |
|
|
|
60.63 |
|
|
|
54.08 |
|
|
|
42.10 |
|
September 30 |
|
|
78.22 |
|
|
|
49.00 |
|
|
|
76.85 |
|
|
|
52.03 |
|
December 31 |
|
|
52.10 |
|
|
|
18.05 |
|
|
|
85.88 |
|
|
|
62.07 |
|
On February 13, 2009, there were 497 holders of record of our common stock. On that date, the
closing sales price, as quoted on the New York Stock Exchange, was $32.85. We have not made any
common stock dividend payments since 1977, and we currently have no plans to pay cash dividends.
Our credit agreements contain restrictions on the payment of dividends. See Note 4 of Notes to
Consolidated Financial Statements included in this report.
We repurchased 986,400 shares of our common stock for $54.9 million in 2008. We did not repurchase
any shares of our common stock in 2007.
EQUITY COMPENSATION PLAN INFORMATION
The following presents equity compensation plan information as of December 31, 2008:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Number of securities |
|
|
Number of securities |
|
|
|
|
|
remaining available for |
|
|
to be issued upon |
|
Weighted-average |
|
future issuance under equity |
|
|
exercise of |
|
exercise price of |
|
compensation plans |
|
|
outstanding options, |
|
outstanding options, |
|
(excluding securities |
Plan Category |
|
warrants and rights |
|
warrants and rights |
|
reflected in the first column) |
Equity compensation plans approved by security holders |
|
|
71,000 |
|
|
$ |
16.54 |
|
|
|
1,816,617 |
|
Equity compensation plans not approved by security holders |
|
|
81,900 |
|
|
$ |
17.60 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
|
152,900 |
|
|
$ |
17.11 |
|
|
|
1,816,617 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
At December 31, 2008, there were: (1) no shares of Oceaneering common stock under equity
compensation plans not approved by security holders available for grant; and (2) 1,816,617 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, subject to no
more than a remaining 536,117 shares being used for awards other than stock options or stock
appreciation rights to employees and nonemployee directors of Oceaneering. In light of the expense
recognition requirements adopted by the Financial Accounting
Standards Board effective as of January 1, 2006, 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 each of these plans, see Note 8 of Notes to Consolidated
Financial Statements.
Page 18
ITEM 6. SELECTED FINANCIAL DATA.
The following table sets forth certain selected historical consolidated financial data and should
be read in conjunction with Managements 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:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
|
(in thousands, except per share amounts) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
2005 |
|
|
2004 |
|
|
Revenue |
|
$ |
1,977,421 |
|
|
$ |
1,743,080 |
|
|
$ |
1,280,198 |
|
|
$ |
998,543 |
|
|
$ |
780,181 |
|
Cost of services and products |
|
|
1,512,621 |
|
|
|
1,329,795 |
|
|
|
984,077 |
|
|
|
819,263 |
|
|
|
648,378 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross margin |
|
|
464,800 |
|
|
|
413,285 |
|
|
|
296,121 |
|
|
|
179,280 |
|
|
|
131,803 |
|
Selling, general and administrative expense |
|
|
147,242 |
|
|
|
123,662 |
|
|
|
101,785 |
|
|
|
85,211 |
|
|
|
67,939 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations |
|
$ |
317,558 |
|
|
$ |
289,623 |
|
|
$ |
194,336 |
|
|
$ |
94,069 |
|
|
$ |
63,864 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
199,386 |
|
|
$ |
180,374 |
|
|
$ |
124,494 |
|
|
$ |
62,680 |
|
|
$ |
40,300 |
|
Diluted earnings per share |
|
|
3.58 |
|
|
|
3.24 |
|
|
|
2.26 |
|
|
|
1.17 |
|
|
|
0.78 |
|
Depreciation and amortization, including
impairment charge |
|
|
115,029 |
|
|
|
93,776 |
|
|
|
80,456 |
|
|
|
79,613 |
|
|
|
65,619 |
|
Capital expenditures, including business
acquisitions |
|
|
252,277 |
|
|
|
233,795 |
|
|
|
193,842 |
|
|
|
142,269 |
|
|
|
153,184 |
|
Other Financial Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of December 31, |
(in thousands, except ratios) |
|
2008 |
|
2007 |
|
2006 |
|
2005 |
|
2004 |
|
Working capital ratio |
|
|
2.09 |
|
|
|
1.98 |
|
|
|
1.87 |
|
|
|
1.77 |
|
|
|
1.62 |
|
Working capital |
|
$ |
390,378 |
|
|
$ |
331,594 |
|
|
$ |
243,939 |
|
|
$ |
171,566 |
|
|
$ |
106,204 |
|
Total assets |
|
|
1,670,020 |
|
|
|
1,531,440 |
|
|
|
1,242,022 |
|
|
|
989,568 |
|
|
|
819,664 |
|
Long-term debt |
|
|
229,000 |
|
|
|
200,000 |
|
|
|
194,000 |
|
|
|
174,000 |
|
|
|
142,172 |
|
Shareholders equity |
|
|
967,654 |
|
|
|
915,310 |
|
|
|
696,764 |
|
|
|
536,118 |
|
|
|
454,437 |
|
Page 19
ITEM 7. MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATION.
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:
|
|
|
our business strategy; |
|
|
|
|
our plans for future operations; |
|
|
|
|
industry conditions; |
|
|
|
|
our expectations about 2009 earnings per share and segment operating results, and the
factors underlying those expectations, including our expectations about demand for our
deepwater oilfield services and products as a result of the factors we specify in the
Overview below; |
|
|
|
|
projections relating to subsea tree orders; |
|
|
|
|
the adequacy of our liquidity and capital resources to support our operations and
internally-generated growth initiatives; |
|
|
|
|
our projected capital expenditures for 2009; |
|
|
|
|
the adequacy of our accruals for uninsured expected liabilities from workers
compensation, maritime employers liability and general liability claims; |
|
|
|
|
our expectation that our total unrecognized tax benefits will not significantly increase
or decrease in the next 12 months; |
|
|
|
|
our expectations about the cash flows from our investment in Medusa Spar LLC, and the
factors underlying those expectations; |
|
|
|
|
our expectations regarding 2009 operating income for each of
our segments and the factors
underlying those expectations; |
|
|
|
|
our anticipated effective tax rate for 2009; and |
|
|
|
|
our backlog. |
These forward-looking statements are subject to various risks, uncertainties and assumptions,
including those we refer to under the headings Risk Factors and Cautionary Statement Concerning
Forward-Looking Statements 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 profitability for 2008, 2007 and 2006.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(dollars in thousands) |
|
2008 |
|
2007 |
|
2006 |
|
Revenue |
|
$ |
1,977,421 |
|
|
$ |
1,743,080 |
|
|
$ |
1,280,198 |
|
Gross Margin |
|
|
464,800 |
|
|
|
413,285 |
|
|
|
296,121 |
|
Gross Margin % |
|
|
24 |
% |
|
|
24 |
% |
|
|
23 |
% |
Operating Income |
|
|
317,558 |
|
|
|
289,623 |
|
|
|
194,336 |
|
Operating Income % |
|
|
16 |
% |
|
|
17 |
% |
|
|
15 |
% |
Net Income |
|
|
199,386 |
|
|
|
180,374 |
|
|
|
124,494 |
|
During 2008, we generated approximately 92% of our revenue, and 98% of our operating income, from
our services and products provided to the oil and gas industry. In 2008, we increased revenue by
13%, led by our Subsea Products (up 25%) and ROV (up 18%) segments. Our Subsea Products segment
revenue increased from sales of Oceaneering Intervention Engineering specialty subsea products and
Oceaneering Multiflex umbilicals. Our ROV segment increase was a result of an improvement in
average revenue per day on hire and growth in days on hire for our expanded work-class fleet.
The $199.4 million consolidated net income we earned in 2008 was the highest in our history. The
$19.0 million increase from 2008 net income was attributable to higher profit contributions from
our ROV, Subsea Products and Inspection segments, with each setting annual profit records. The ROV
and Subsea Products improvements reflected our strategic focus on deepwater and subsea
Page 20
completion
activity. Our Inspection increase was due to additional, higher-margin work on offshore production
platforms, LNG and petrochemical facilities and pipelines.
In 2008, we invested in the following major capital projects:
|
|
|
additions of work-class ROVs, including 21 placed into service during the year; |
|
|
|
|
expenditures to increase capabilities at our Subsea Products manufacturing facilities; and |
|
|
|
|
purchase of Norway-based GTO Subsea AS (GTO), a rental provider of specialized subsea
dredging and excavation equipment. |
For 2009, we expect the demand for many of our deepwater oilfield services and products will
decrease, with the exception of our ROV services. We believe the general decline in demand will be
driven by lower crude oil prices attributable to decreasing hydrocarbon demand from the ongoing
global recession. However, we expect our deepwater operations will be affected to a lower extent
than the general decline in worldwide oil and gas activities, as we believe the trend for our
customers to increasingly invest in deepwater projects will continue. Our belief is based on the
length of time needed to plan and execute deepwater projects, and the long-term outlook for oil and
gas supply, which includes limited non-OPEC supply growth, rapid reservoir depletion rates and
eventually increasing hydrocarbon demand.
We expect our 2009 diluted earnings per share to be in the range of $3.00 to $3.60, as compared to
$3.58 in 2008, with an increase in operating income in our ROV segment and decreases in our Subsea
Projects and Inspection segments. We anticipate ROV operating income to increase in 2009 as a
result of a higher average fleet size.
We believe the 2009 results from our Subsea Products segment could be similar to those of 2008.
The expected decline in demand for our Subsea Products should be substantially offset by improved
efficiencies and project execution in our manufacturing operations. However, further project
delays by our customers would result in a decrease in Subsea Products operating income from that of
2008.
We use our ROVs in the offshore oil and gas industry to perform a variety of underwater tasks,
including drill support, installation and construction support, pipeline inspection and surveys and
subsea production facility inspection, repair and maintenance. The largest percentage of our ROVs
is usually used to provide drill support services. Therefore, utilization of floating drilling
rigs is a leading market indicator for this business. The following table shows average floating
rig use and our ROV utilization.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2008 |
|
2007 |
|
2006 |
Average number of floating rigs in use |
|
|
201 |
|
|
|
196 |
|
|
|
191 |
|
ROV days on hire (in thousands) |
|
|
65 |
|
|
|
63 |
|
|
|
56 |
|
ROV utilization |
|
|
82 |
% |
|
|
87 |
% |
|
|
85 |
% |
According to industry data published by ODS-Petrodata, at the end of 2008 there were 211 floating
drilling rigs in the world. Ninety-eight additional floating rigs were on order and scheduled to
be delivered through 2012, and 70 of these have been contracted long-term, for an average term of
over six years. Demand for floating rigs is our primary driver of future growth prospects, on a
concurrent or delayed basis.
According to industry data published by Quest Offshore Resources, Inc., there were less than 600
subsea completions before 1990 and approximately 1,100 in the decade of the 1990s. Quest is
currently forecasting that there will be approximately 3,200 subsea completion installations in the
decade of the 2000s and over 7,000 in the decade of the 2010s. According to Quest, the projected
global market for subsea tree orders is expected to increase more than 80% in the 2009-2013 time
period compared to the previous five years. In addition to floating rig demand, subsea tree orders
are another leading indicator of the strength of the deepwater market and the primary demand driver
for our Subsea Products lines.
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 U.S. 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 managements most difficult,
subjective or complex judgments and (2) are the most critical to our reporting of results of
operations and financial position.
Page 21
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 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 occasionally in our Subsea Projects and Advanced Technologies segments, using the
percentage-of-completion method. In 2008, 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; |
|
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|
|
we can reasonably estimate our progress towards completion and our costs; |
|
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|
|
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 |
|
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|
|
we can be expected to perform our contractual obligations. |
Under the percentage-of-completion method, we 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 projects 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 improve our ability to 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.
Long-lived Assets. We evaluate our property and equipment for impairment whenever events or
changes in circumstances indicate that the carrying amounts may not be appropriate. We base these
evaluations on a comparison of the assets carrying values to forecasts of undiscounted cash flows
associated with the assets or quoted market prices. If an impairment has occurred, we recognize a
loss for the difference between the carrying amount and the fair value of the asset. Our
expectations regarding future sales and undiscounted cash flows are highly subjective, cover
extended periods of time and depend on a number of factors outside our control, such as changes in
general economic conditions, laws and regulations. Accordingly, these expectations could differ
significantly from year to year. In 2008, we recorded an impairment charge of $5.7 million to
reduce our investment in the Ocean Pensador, an oil tanker we are holding for possible conversion,
to its fair value.
We charge the costs of repair and maintenance of property and equipment to operations as incurred,
while we capitalize the costs of improvements. In September 2006, the Financial Accounting
Standards Board (FASB) issued FASB Staff Position No. AUG AIR-1, Accounting for Planned Major
Maintenance Activities. This FASB Staff Position prohibits companies from recognizing planned
major maintenance costs by accruing a liability over several reporting periods before the
maintenance is performed ¯ the accrue-in-advance method. We previously used the accrue-in-advance
method for anticipated drydocking of our vessels. This FASB Staff Position was effective for us
beginning January 1, 2007, and we have since charged drydocking expenses to the income statement as
incurred. There was no material effect on our financial statements from the change.
Goodwill. We account for acquisitions using the purchase method of accounting, with the purchase
price being allocated to the net assets acquired based on their fair market values at the date of
acquisition. In accordance with the requirements of Statement of Financial Accounting Standards
(SFAS) No. 142, Goodwill and Other Intangible Assets, we test the goodwill attributable to each
of our reporting units for impairment. Except for Inspection, which is tested as a single
reporting unit, our operating units are one level
below our business segments. We estimate fair value of the reporting units using discounted cash
flow methodologies and market comparable information. Changes in estimate of our future cash flows
may result in goodwill impairments in the future.
Loss Contingencies. We self-insure for workers compensation, maritime employers liability and
comprehensive general liability claims to levels we consider financially prudent and carry
insurance for exposures beyond the self-insurance levels, which can be by
Page 22
occurrence or in the
aggregate. We determine the level of accruals 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.
We are involved in various claims and actions against us, most of which are covered by insurance.
We believe that our ultimate liability, if any, that may result from these claims and actions will
not materially affect our financial position, cash flows or results of operations.
Income Taxes. Effective January 1, 2007, we adopted FASB Interpretation No. (FIN) 48, Accounting
for Uncertainty in Income Taxes. This interpretation clarifies the criteria for recognizing income
tax benefits under Statement of Financial Accounting Standards (SFAS) No. 109, and requires
disclosures about uncertain tax positions. Under FIN 48, the financial statement recognition of
the benefit for a tax position depends on the benefit being 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 is greater than 50 percent likely of being
realized upon ultimate settlement. We made an adjustment of $1.6 million to reduce our retained
earnings as of January 1, 2007 to record the effect of our adoption of this interpretation.
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 charged $0.4 million to income tax
expense in 2008 for penalties and interest for uncertain tax positions, which brought our total
liabilities for penalties and interest on uncertain tax positions to $3.2 million on our balance
sheet at December 31, 2008. Including associated foreign tax credits and penalties and interest,
we have accrued a net total of $5.7 million in the caption other long-term liabilities on our
balance sheet for unrecognized tax benefits. All additions or reductions to those liabilities
affect our effective income tax rate in the periods of change.
We do not believe that the total of unrecognized tax benefits will significantly increase or
decrease in the next 12 months.
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 authoritys 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 and our
estimates regarding the realizability of items such as foreign tax credits may change. In 2008,
2007 and 2006, we recorded reductions of income tax expense of $0.6 million, $1.1 million and $1.3
million, respectively, resulting from the resolution of uncertain tax positions related to certain
tax liabilities we recorded in prior years. 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. We
currently have no valuation allowances. 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 adjust the valuation allowances for our deferred tax assets. These adjustments to
the valuation allowance would impact our income tax provision in the period in which such
adjustments are identified and recorded.
For a summary of our major accounting policies and a discussion of recently adopted accounting
standards, please read Note 1 to our Consolidated Financial Statements.
Liquidity and Capital Resources
We consider our liquidity and capital resources adequate to support our operations and
internally-generated growth initiatives. At December 31, 2008, we had working capital of $390
million, including cash and cash equivalents of $11 million. Additionally, we had $196 million
available under our revolving credit facility, which currently extends to January 2012. We had
total borrowings of $229 million at December 31, 2008, with total maturities in 2009 of $105
million. The 2009 maturities include $85 million due under our
one-year term loan agreement. Maturities in 2009 are not classified as current as of December 31,
2008, since we are able and have the intent to extend the stated maturities by borrowing amounts
equal to the 2009 maturities under the revolving credit facility, with a maturity date after one
year. At December 31, 2008, our debt-to-total capitalization ratio was 19%. Our net cash provided
by operating activities was $248 million, $209 million and $151 million for 2008, 2007 and 2006,
respectively.
Page 23
Our capital expenditures, including business acquisitions, for 2008, 2007 and 2006 were $252
million, $234 million and $194 million, respectively. We plan to invest approximately $175 million
in 2009, the majority of which will support growth of our ROV fleet to meet firm demand. Capital
expenditures in 2008 included expenditures for: additions and upgrades to our ROV fleet; the
purchase of GTO for $40 million; vessel upgrades; and facility expansions for our specialty subsea
products. Capital expenditures in 2007 included expenditures for: additions and upgrades to our
ROV fleet; the purchase of Norway-based Ifokus Engineering AS (Ifokus), a designer and
manufacturer of specialty subsea products, for $20 million; vessel upgrades; the acquisition of a
small inspection company in the United Kingdom; and facility expansions in the United Kingdom,
Norway, Morgan City, LA and Houston. Our facility expansions in the United Kingdom, Norway and
Houston during 2007 related to our Subsea Products manufacturing operations, and our Morgan City
expansion supports our ROV and Subsea Projects operations. Our capital expenditures during 2006
included $113 million 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. In 2006, we
commenced improvements in our Subsea Products facilities, including the addition of equipment to
increase manufacturing capacity at our umbilical plant in the U.K. and our subsea valve facility in
Norway and purchased an oil tanker for possible future conversion to a mobile offshore production
and storage system in the event we obtain a suitable contract. We also began upgrades to a
dynamically positioned vessel and began construction of a saturation diving system to meet demand
in our Subsea Projects segment.
Our capital expenditures during 2008 and 2007 included $146 million and $122 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 plan to continue adding ROVs at levels we determine appropriate to meet market opportunities as
they arise. We added 21 and 31 ROVs to our fleet and disposed of four and seven units during 2008
and 2007, respectively, resulting in a total of 227 systems in the fleet at December 31, 2008.
In 2006, we chartered a larger deepwater vessel, the Ocean Intervention III, for three years, with
extension options for up to six additional years. The initial three-year term of the charter began
in May 2007. We also chartered an additional larger deepwater vessel, the Olympic Intervention IV,
for an initial term of five years, which began in the third quarter of 2008. We outfitted each of
these larger deepwater vessels with two of our high-specification work-class ROVs, and we expect to
utilize these vessels to perform subsea hardware installation and inspection, repair and
maintenance projects, and to conduct well intervention services in the ultra-deep waters of the
Gulf of Mexico.
We have not guaranteed any debt not reflected on our consolidated balance sheet. In December 2003,
we acquired a 50% interest in Medusa Spar LLC. At formation, Medusa Spar LLC borrowed $84 million,
or approximately 50% of its total capitalization, from a group of banks. The loan was repaid in
2008. We expect the majority of the positive net cash flow generated in the future by Medusa Spar
LLC will be distributed to the equity holders. We received $2.5 million, $3.4 million and $5.4
million of cash distributions from Medusa Spar LLC and recognized $1.9 million, $3.8 million and
$11.2 million of equity in the earnings of Medusa Spar LLC in 2008, 2007 and 2006, respectively.
Medusa Spar LLC is a variable interest entity under FIN 46R, Consolidation of Variable Interest
Entities. As we are not the primary beneficiary of Medusa Spar LLC, we are accounting for our
investment in Medusa Spar LLC using the equity method of accounting. At December 31, 2008, our
investment in Medusa Spar LLC was $63 million.
Our principal source of cash from operating activities is our net income, adjusted for the non-cash
expenses of depreciation and amortization (including impairment charge), deferred income taxes and
noncash compensation under our restricted stock plans. Our $248 million, $209 million and $151
million of cash provided from operating activities in 2008, 2007 and 2006, respectively, were net
of increases of $72 million, $55 million and $46 million, respectively, in accounts receivable and
increases of $17 million, $91 million and $84 million, respectively, in inventory and other current
assets. The increases in accounts receivable were due to increases in revenue in the fourth
quarter of the respective year as compared to the fourth quarter of the preceding year. At
December 31, 2008, we also had additional receivables related to our Subsea Projects diving and
vessel activity, including our work from The Performer, which we mobilized to Angola in the third
quarter of 2008. The initial customer payments on The Performers contract in Angola were delayed
beyond December 31, 2008, but have subsequently been made. The increases in inventory and other
current assets principally related to ROV requirements and Subsea Products raw materials. The raw
materials increases in 2007 and 2006 related to preparations for building goods in our Subsea
Products segment, which experienced revenue increases of 25% and 43% in 2008 and 2007,
respectively. The raw materials inventory decreased during 2008 as we have a lower backlog at
December 31, 2008 than we had at December 31, 2007. The increases in ROV inventory related to
equipment waiting for assembly into ROVs to be placed in service in subsequent years and increases
in parts to be used for servicing our growing ROV fleet.
In 2008, we used $246 million in investing activities, including $146 million to modernize and add
additional units to our ROV fleet and $78 million to increase our Subsea Products capabilities,
including our acquisition of GTO for $40 million. In 2007, we used $227 million in investing
activities, including $122 million to modernize and add additional units to our ROV fleet, $66
million to add capacity to our Subsea Products facilities, including our acquisition of Ifokus for
$20 million. In 2006, we used $187 million in investing activities, including $113 million to
modernize and add additional units to our ROV fleet and $38 million to add capacity to our Subsea
Products facilities.
Page 24
In 2008, 2007 and 2006, we received $2 million, $5 million and $8 million, respectively, in cash
flow from financing activities as proceeds from the sale of our common stock pursuant to the
exercise of employee stock options. In addition, in 2008, 2007 and 2006, we received $7 million,
$8 million and $7 million, respectively, of tax benefit realized from tax deductions in excess of
financial statement expense related to our stock-based compensation plans.
In September 2002, our Board of Directors approved a plan to repurchase up to 6,000,000 shares of
our common stock, subject to a $75 million aggregate purchase price limitation. During 2008, we
completed the authorized repurchases under the plan by repurchasing 986,400 shares at a total cost
of $54.9 million, which is reflected in our cash used in financing activities. Under our stock
repurchase plan, we repurchased 2,782,000 shares of common stock from 2002 through 2008 at a total
cost of $75 million. Through December 31, 2008, we had reissued all but 941,600 of these shares,
primarily in connection with stock-based compensation plans. For a description of our incentive
plans, please read Note 8 to our Consolidated Financial Statements.
Because of our significant foreign operations, we are exposed to currency fluctuations and exchange
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, 2008 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 and the
Norwegian kroner would result in lower operating income in our Inspection and ROV segments. See
Item 7A Quantitative and Qualitative Disclosures About Market Risk. 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.
Page 25
Results of Operations
Information on our business segments is shown in Note 6 of the Notes to Consolidated Financial
Statements included in this report.
Oil and Gas. The table that follows sets out revenue and profitability for the business segments
within our Oil and Gas business.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(dollars in thousands) |
|
2008 |
|
2007 |
|
2006 |
|
Remotely Operated Vehicles |
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
$ |
625,921 |
|
|
$ |
531,381 |
|
|
$ |
410,256 |
|
Gross Margin |
|
|
221,270 |
|
|
|
168,322 |
|
|
|
129,929 |
|
Gross Margin % |
|
|
35 |
% |
|
|
32 |
% |
|
|
32 |
% |
Operating Income |
|
|
190,343 |
|
|
|
144,242 |
|
|
|
111,022 |
|
Operating Income % |
|
|
30 |
% |
|
|
27 |
% |
|
|
27 |
% |
Utilization % |
|
|
82 |
% |
|
|
87 |
% |
|
|
85 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Subsea Products |
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
|
649,857 |
|
|
|
521,937 |
|
|
|
364,510 |
|
Gross Margin |
|
|
146,747 |
|
|
|
133,285 |
|
|
|
81,380 |
|
Gross Margin % |
|
|
23 |
% |
|
|
26 |
% |
|
|
22 |
% |
Operating Income |
|
|
96,046 |
|
|
|
92,804 |
|
|
|
53,645 |
|
Operating Income % |
|
|
15 |
% |
|
|
18 |
% |
|
|
15 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Subsea Projects |
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
|
256,517 |
|
|
|
257,752 |
|
|
|
155,046 |
|
Gross Margin |
|
|
81,534 |
|
|
|
100,577 |
|
|
|
65,119 |
|
Gross Margin % |
|
|
32 |
% |
|
|
39 |
% |
|
|
42 |
% |
Operating Income |
|
|
72,816 |
|
|
|
92,841 |
|
|
|
59,585 |
|
Operating Income % |
|
|
28 |
% |
|
|
36 |
% |
|
|
38 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Inspection |
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
|
249,109 |
|
|
|
219,686 |
|
|
|
169,014 |
|
Gross Margin |
|
|
48,518 |
|
|
|
37,195 |
|
|
|
28,501 |
|
Gross Margin % |
|
|
19 |
% |
|
|
17 |
% |
|
|
17 |
% |
Operating Income |
|
|
31,017 |
|
|
|
22,749 |
|
|
|
14,946 |
|
Operating Income % |
|
|
12 |
% |
|
|
10 |
% |
|
|
9 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Mobile Offshore Production Systems |
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
|
39,274 |
|
|
|
50,103 |
|
|
|
52,931 |
|
Gross Margin |
|
|
8,361 |
|
|
|
12,443 |
|
|
|
17,136 |
|
Gross Margin % |
|
|
21 |
% |
|
|
25 |
% |
|
|
32 |
% |
Operating Income |
|
|
6,730 |
|
|
|
11,048 |
|
|
|
16,001 |
|
Operating Income % |
|
|
17 |
% |
|
|
22 |
% |
|
|
30 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
$ |
1,820,678 |
|
|
$ |
1,580,859 |
|
|
$ |
1,151,757 |
|
Gross Margin |
|
|
506,430 |
|
|
|
451,822 |
|
|
|
322,065 |
|
Gross Margin % |
|
|
28 |
% |
|
|
29 |
% |
|
|
28 |
% |
Operating Income |
|
|
396,952 |
|
|
|
363,684 |
|
|
|
255,199 |
|
Operating Income % |
|
|
22 |
% |
|
|
23 |
% |
|
|
22 |
% |
In response to continued increasing demand to support deepwater drilling and identified future
construction and production maintenance work, we continue to build new ROVs. These new vehicles
are designed for use around the world in water depths of 10,000 feet or more. We added 21 and 31
ROVs in 2008 and 2007, respectively, while disposing of 11 units over the two-year period. We plan
to continue adding ROVs at levels we determine appropriate to meet market opportunities.
Page 26
For 2008 and 2007, our ROV revenue increased 18% and 30% over the respective prior years from
improvements in average revenue per day-on-hire and growth in days on hire for our expanded
work-class fleet. We grew our fleet size to 227 at December 31, 2008 from 210 at December 31, 2007
and 186 at December 31, 2006. Operating income increased by 32% in 2008 over 2007 and 30% in 2007
over 2006.
We anticipate ROV operating income to increase in 2009 as a result of a higher average fleet size.
In addition to having a full year of service from the units we added during 2008, we expect to add
approximately 24 to 30 ROVs in 2009.
Our Subsea Products revenue for 2008 and 2007 rose 25% and 43% over the respective prior year on
increased sales of our specialty subsea products and umbilicals. In 2008, our operating margin
percentage decreased from 18% to 15% due to higher costs of engineering and manufacturing on our
first two blowout preventer (BOP) control systems and slightly lower margins on several of our
other specialty product lines. In 2007, our operating margin increased from 15% to 18% as a result
of better design and pricing and improved manufacturing execution, including better throughput and
resolution during 2006 of startup problems at our U.S. umbilical plant.
We anticipate our Subsea Products segment operating income in 2009 could be similar to 2008, with
an anticipated decline in demand for our products offset by expected improvements in execution
performance in our manufacturing operations. However, further project delays by our customers
would result in a decrease in Subsea Products operating income from that of 2008. Our Subsea
Products backlog was $298 million at December 31, 2008 compared to $338 million at December 31,
2007.
Our 2008 Subsea Projects operating income declined $20 million from 2007 on relatively flat revenue
due to a softer market for our diving and shallow water vessel services, principally as a result of
the substantial completion of work associated with damage caused by hurricanes in 2004 and 2005;
costs incurred to mobilize the Olympic Intervention IV to the Gulf of Mexico and complete its
preparation for service; and expenses we incurred associated with regulatory inspection of four of
our vessels. The 2007 amount included a $3.5 million gain from the sale of an ROV support vessel.
The revenue shortage from the factors mentioned above was partially offset by additional revenue
from a full year of availability from the Ocean Intervention III and the fourth quarter utilization
of the Olympic Intervention IV.
In 2007, our Subsea Projects segment experienced higher revenue and operating income than 2006 from
an increase in hurricane damage-related projects. Our operating income rose by over 55% on an
increase in revenue of 66%. We continued to experience favorable pricing for and utilization of
our vessel and diving assets. Additionally, during the year we added a saturation diving system,
placed The Performer back into service after its upgrade, and chartered and utilized two
dynamically positioned vessels and a barge. Our margin percentages decreased due to the high
third-party cost content of the chartered assets.
We anticipate our 2009 operating income for Subsea Projects to be less than in 2008, as we foresee
a continuation of declining demand for our shallow water services and competitive pressure in our
deepwater vessel market, due to an increase in industry vessel availability.
In 2008 and 2007, our Inspection revenue and margins continued to increase, due to strong growth in
all of the geographic areas we serve. We continued to sell more value-added services at improved
pricing.
We expect that our Inspection segment operating income will decrease in 2009, due to a lower
exchange rate for the U.K. pound sterling against the U.S. dollar and decreased demand for our
services.
Our Mobile Offshore Production Systems two operating units continued to work under the same
contracts. The decreases in margins in 2008 were the result of a $5.7 million impairment charge to
reduce our investment in the Ocean Pensador, an oil tanker we are holding for possible conversion,
to its fair value and the decline in the dayrate of the Ocean Legend, as per the customer renewal
option terms in the existing contract. The decreases in margins in 2007 were the result of $2.8
million of expenses incurred to move the Ocean Pensador from the U.S. west coast to Southeast Asia
in the fourth quarter of 2007, and the decline in the dayrate of the Ocean Legend, as per the
customer renewal option terms in the existing contract. We moved the Ocean Pensador to better
position it in the marketplace. The vessel is now closer to several shipyards capable of modifying
it for production or storage service, either for us or another owner should we sell it.
We anticipate our Mobile Offshore Production Systems operating income in 2009 will decline from
2008 as a result of a lower dayrate going into effect in mid-May 2009 for the use of the Ocean
Legend, as per the customer renewal option terms in the existing contract, and the anticipated end
of the current contract on the Ocean Producer in early 2009.
Page 27
Advanced Technologies. The table that follows sets out revenue and profitability for this segment.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(dollars in thousands) |
|
2008 |
|
2007 |
|
2006 |
|
Revenue |
|
$ |
156,743 |
|
|
$ |
162,221 |
|
|
$ |
128,441 |
|
Gross Margin |
|
|
21,596 |
|
|
|
25,561 |
|
|
|
19,862 |
|
Gross Margin % |
|
|
14 |
% |
|
|
16 |
% |
|
|
15 |
% |
Operating Income |
|
|
9,773 |
|
|
|
14,458 |
|
|
|
11,585 |
|
Operating Income % |
|
|
6 |
% |
|
|
9 |
% |
|
|
9 |
% |
Our Advanced Technologies segments 2008 operating income was lower than 2007 due to the completion
in September 2007 of an engineering services contract that had been ongoing for more than five
years.
Our Advanced Technologies segments revenue and margins for 2007 increased from those of 2006 due
to increased work for the U.S. Navy on submarine repair and maintenance and general engineering
services.
We anticipate our Advanced Technologies 2009 operating income will be slightly higher than 2008.
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. A
portion of our restricted stock expense varies with the market price of our common stock. 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.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(dollars in thousands) |
|
2008 |
|
2007 |
|
2006 |
|
Gross margin expenses |
|
$ |
(63,226 |
) |
|
$ |
(64,098 |
) |
|
$ |
(45,806 |
) |
% of revenue |
|
|
3 |
% |
|
|
4 |
% |
|
|
4 |
% |
Operating expenses |
|
|
(89,167 |
) |
|
|
(88,519 |
) |
|
|
(72,448 |
) |
% of revenue |
|
|
5 |
% |
|
|
5 |
% |
|
|
6 |
% |
Our unallocated gross margin and operating expenses increased in 2007, primarily due to higher
compensation related to incentive plans as a result of record results and an escalation in
information technology-related costs to support our growth.
Other. The table that follows sets forth our significant financial statement items below the
operating income line.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(dollars in thousands) |
|
2008 |
|
2007 |
|
2006 |
|
Interest income |
|
$ |
907 |
|
|
$ |
1,198 |
|
|
$ |
730 |
|
Interest expense, net of amounts capitalized |
|
|
(13,485 |
) |
|
|
(15,333 |
) |
|
|
(12,920 |
) |
Equity earnings of unconsolidated affiliates: |
|
|
|
|
|
|
|
|
|
|
|
|
Medusa Spar LLC |
|
|
1,894 |
|
|
|
3,779 |
|
|
|
11,213 |
|
Other |
|
|
25 |
|
|
|
251 |
|
|
|
838 |
|
Other income (expense), net |
|
|
321 |
|
|
|
(2,020 |
) |
|
|
(3,302 |
) |
Provision for income taxes |
|
|
107,834 |
|
|
|
97,124 |
|
|
|
66,401 |
|
Interest expense decreased in 2008, primarily from lower interest rates on LIBOR-based borrowings
under our revolving credit agreement and term loan. Interest expense increased in 2007, primarily
because we used debt to partially finance capital
expenditures and acquisitions. Interest expense is net of capitalized interest of $1.0 million and
$0.1 million for 2007 and 2006, respectively. We capitalized less than $0.1 million of interest in
2008.
We earn equity income from our 50% investment in Medusa Spar LLC, which we acquired in December
2003. Medusa Spar LLC owns 75% of a production spar in the Gulf of Mexico and earns its revenue
from fees charged on production processed through the facility. In 2007, we experienced a decrease
in equity in earnings of unconsolidated affiliates from our investment in Medusa Spar LLC due to
lower production throughput at the spar, and this trend continued in 2008. If the operator of the
producing wells is able to either start producing from other zones in the existing wells, which are
anticipated to have higher flow rates than the currently-
Page 28
producing zones, or connect more wells to
the spar, the declining revenue trend would be reversed. However, we do not anticipate this will
occur in 2009.
Our effective tax rate, including foreign, state and local taxes, was 35% for each of 2008, 2007
and 2006, which included favorable resolutions of uncertain tax positions of $0.6 million, $1.1
million, $1.3 million, respectively, related to certain tax liabilities we recorded in prior years.
For 2009, we anticipate an effective tax rate of approximately 35%.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements, as defined by SEC rules.
Contractual Obligations
At December 31, 2008, we had payments due under contractual obligations as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments due by period |
|
(dollars in thousands) |
|
Total |
|
|
2009 |
|
|
2010-2011 |
|
|
2012-2013 |
|
|
After 2013 |
|
Long-term Debt |
|
$ |
229,000 |
|
|
$ |
105,000 |
|
|
$ |
20,000 |
|
|
$ |
104,000 |
|
|
$ |
|
|
Operating Leases |
|
|
170,052 |
|
|
|
41,250 |
|
|
|
54,065 |
|
|
|
38,721 |
|
|
|
36,016 |
|
Purchase Obligations |
|
|
76,743 |
|
|
|
76,743 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Long-term Obligations reflected
on our balance sheet under GAAP |
|
|
35,391 |
|
|
|
379 |
|
|
|
1,696 |
|
|
|
2,822 |
|
|
|
30,494 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL |
|
$ |
511,186 |
|
|
$ |
223,372 |
|
|
$ |
75,761 |
|
|
$ |
145,543 |
|
|
$ |
66,510 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
At December 31, 2008, we had outstanding purchase order commitments totaling $77 million, including
approximately $20 million for ROV winches and control umbilicals for ROV units and $16 million for
specialized steel tubes to be used in our manufacturing of steel tube umbilicals by our Subsea
Products segment. The winches and ROV umbilicals have been ordered for new ROVs and for
anticipated replacements due to normal wear and tear. We have ordered the specialized steel tubes
in advance to meet expected sales commitments. Should we decide not to accept delivery of the
steel tubes, we would incur cancellation charges of at least 10% of the amount canceled.
In November 2001, we entered into an agreement with our Chairman (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. The agreement provides for a
specific service period ending no later than August 15, 2011, during which the Chairman, acting as
an independent contractor, has agreed to serve as nonexecutive Chairman of our Board of Directors
for so long as our Board of Directors desires that he shall continue to serve in that capacity.
The agreement provides the Chairman with post-employment benefits for ten years following the
sooner to occur of August 15, 2011 or the termination of his services to us. The amendment in 2006
included a lump-sum cash buyout, paid in 2007, of the Chairmans entitlement to perquisites and
administrative assistance during that ten-year period (expected to run from 2011 to 2021). As a
result, we recorded $2.8 million of associated expense in the fourth quarter of 2006. The
agreement also provides for medical coverage on an after-tax basis to the Chairman, his spouse and
children during his service with us and thereafter for their lives. We are recognizing the net
present value of the post-employment benefits over the expected service period. If the service
period is terminated for any reason (other than the Chairmans refusal to continue serving), we
will recognize all the previously unaccrued benefits in the period in which that termination
occurs. Our total
accrued liabilities, current and long-term, under this post-employment benefit were $5.6 million
and $4.8 million at December 31, 2008 and 2007, 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.
Page 29
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 manage our exposure to
interest rate changes through the use of a combination of fixed- and floating-rate debt. See Note
4 of Notes to Consolidated Financial Statements included in this report for a description of our
long-term debt agreements, interest rates and maturities. We believe significant interest rate
changes would not have a material near term impact on our future earnings or cash flows. We have
interest rate hedges in place on $100 million of floating rate debt under our revolving credit
facility for the period August 2008 to August 2011. The hedges fix three-month LIBOR at 3.07%
until August 2009 and at 3.31% for the period August 2009 to August 2011.
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 and the Norwegian kroner would result in lower
operating income in our Inspection and ROV segments. 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 adjustments of ($106 million), $21 million and $17
million to our equity accounts in 2008, 2007 and 2006, 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 dollar.
We recorded foreign currency transaction gains (losses) of $0.7 million, ($0.3 million) and ($2.5
million) in our Consolidated Income Statements in 2008, 2007 and 2006, respectively, related to our
foreign operations. In 2006, the majority of our foreign currency losses related to our U.K.
operations. Some of our U.K. subsidiarys revenue is from U.S. dollar-denominated contracts; if
the U.S. dollar weakens against the British pound sterling, we will incur currency losses for the
period the related accounts receivable are outstanding.
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 in this item by reference.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
None.
Page 30
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 chief executive officer and chief 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 chief executive officer and chief financial officer concluded that
our disclosure controls and procedures were effective as of December 31, 2008 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 Commissions rules and forms. There has been no change in our internal
control over financial reporting that occurred during the year ended December 31, 2008 that has
materially affected, or is reasonably likely to materially affect, our internal control over
financial reporting.
Managements 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. 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, 2008.
Ernst & Young LLP, an independent registered public accounting firm, has audited our internal
control over financial reporting, as stated in their report which follows.
Page 31
Report of Independent Registered Public Accounting Firm
The Board of Directors and Shareholders of Oceaneering International, Inc.
We have audited Oceaneering International, Inc.s internal control over financial reporting as of
December 31, 2008, based on criteria established in Internal ControlIntegrated Framework issued by
the Committee of Sponsoring Organizations of the Treadway Commission (the COSO criteria).
Oceaneering International, Inc.s management is responsible for maintaining effective internal
control over financial reporting, and for its assessment of the effectiveness of internal control
over financial reporting included in the accompanying Managements Report on Internal Control Over
Financial Reporting. Our responsibility is to express an opinion on the Companys 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 companys 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
companys 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 companys 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. maintained, in all material respects, effective
internal control over financial reporting as of December 31, 2008, 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, 2008 and 2007, and the related consolidated statements of income,
cash flows, and shareholders equity and comprehensive income for each of the three years in the
period ended December 31, 2008 of Oceaneering International, Inc. and our report dated February 25,
2009 expressed an unqualified opinion thereon.
Houston, Texas
February 25, 2009
ITEM 9B. OTHER INFORMATION.
We have no other information to report for the fourth quarter of this year covered by this annual
report on Form 10-K that would have been required to be, and was not, reported on a Form 8-K.
Page 32
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 April 30, 2009, relating to our 2009 Annual Meeting of
Shareholders.
Information concerning our Audit Committee and the audit committee financial experts is
incorporated by reference from the sections entitled Election of Directors Corporate Governance
and The 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 Election of
Directors Code of Ethics for the Chief Executive Officer and Senior Financial Officers in the
proxy statement 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 Election of Directors Section 16(a)
Beneficial Ownership Reporting Compliance in the proxy statement referred to in this Item 10.
ITEM 11. EXECUTIVE COMPENSATION.
The information required by Item 11 is incorporated by reference from the sections entitled
Election of Directors Compensation Committee Interlocks and Insider Participation,
Compensation Discussion and Analysis, Report of the Compensation Committee, Compensation of
Executive Officers, and Director Compensation 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 Registrants Common Equity, Related
Stockholder Matters and Issuer Purchases of Equity Securities in Part II of this report and (2)
the section Election of Directors 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
Election of Directors Corporate Governance and Certain Relationships and Related Transactions
in the proxy statement referred to in Item 10 above.
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES.
The information required by Item 14 is incorporated by reference from the section entitled
Ratification of Appointment of Auditors Fees Incurred by Oceaneering for Ernst & Young LLP in
the proxy statement referred to in Item 10 above.
Page 33
Part IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES.
|
(a) |
|
Documents filed as part of this report. |
|
(i) |
|
Report of Independent Registered Public Accounting Firm |
|
|
(ii) |
|
Consolidated Balance Sheets (iii) Consolidated Statements of Income |
|
|
(iv) |
|
Consolidated Statements of Cash Flows
|
|
|
(v) |
|
Consolidated Statements of Shareholders Equity and Comprehensive Income |
|
|
(vi) |
|
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 included in the financial statements included
herein or in the related footnotes thereto. |
|
|
3. |
|
Exhibits: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Registration |
|
|
|
|
|
|
|
|
|
|
or File |
|
Form of |
|
Report |
|
Exhibit |
|
|
|
|
Number |
|
Report |
|
Date |
|
Number |
|
|
|
|
|
|
|
|
|
|
|
|
|
* 3.01
|
|
Restated Certificate of Incorporation
|
|
1-10945
|
|
10-K
|
|
Dec. 2000
|
|
|
3.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 3.02
|
|
Certificate of Amendment to Restated Certificate of Incorporation
|
|
1-10945
|
|
8-K
|
|
May 2008
|
|
|
3.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 3.03
|
|
Amended and Restated Bylaws
|
|
1-10945
|
|
8-K
|
|
Dec. 2007
|
|
|
3.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 4.01
|
|
Specimen of Common Stock Certificate
|
|
1-10945
|
|
10-K
|
|
March 1993
|
|
|
4 |
(a) |
|
|
|
|
|
|
|
|
|
|
|
|
|
* 4.02
|
|
Amended and Restated Shareholder Rights Agreement dated
as of November 16, 2001
|
|
1-10945
|
|
8-K
|
|
Nov. 2001
|
|
|
4.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 4.03
|
|
Note Purchase Agreement dated as of September 8, 1998 relating to
$100,000,000 6.72% Senior Notes due September 8, 2010
|
|
1-10945
|
|
10-Q
|
|
Sept. 1998
|
|
|
4.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 4.04
|
|
Amended and Restated Credit Agreement ($250,000,000 Revolving
Credit Facility with Accordion to $300,000,000) dated as of
January 2, 2004
|
|
1-10945
|
|
10-K
|
|
Dec. 2003
|
|
|
4.05 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 4.05
|
|
First Amendment to Amended and Restated Credit Agreement
dated January 22, 2007
|
|
1-10945
|
|
8-K
|
|
Jan. 2007
|
|
|
4.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 4.06
|
|
$85,000,000 Credit Agreement dated as of September 31, 2008
among Oceaneering International, Inc., Wells Fargo Bank, N.A. as
Administrative Agent and lender and other lender parties or to
become lender parties thereto
|
|
1-10945
|
|
8-K
|
|
Sept. 2008
|
|
|
4.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
We and certain of our consolidated subsidiaries are parties to debt instruments under which the total amount of securities
Regulation S-K, we agree to furnish a copy of those instruments to the Securities and Exchange Commission on request. |
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.01+
|
|
Defined Contribution Master Plan and Trust Agreement and
Adoption Agreement for the Oceaneering International, Inc.
Retirement Investment Plan
|
|
1-10945
|
|
10-K
|
|
Dec. 2001
|
|
|
10.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.02+
|
|
Amended and Restated Service Agreement dated as of
December 21, 2006 between Oceaneering and John R. Huff
|
|
1-10945
|
|
8-K
|
|
Dec. 2006
|
|
|
10.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.03+
|
|
Modification to Service Agreement dated as of December 21, 2006
between
Oceaneering and John R. Huff
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.9 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.04+
|
|
Trust Agreement dated as of
May 12, 2006 between Oceaneering and United Trust Company,
National Association |
|
1-10945 |
|
8-K |
|
May 2006 |
|
|
10.02 |
|
Page 34
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Registration |
|
|
|
|
|
|
|
|
|
|
or File |
|
Form of |
|
Report |
|
Exhibit |
|
|
|
|
Number |
|
Report |
|
Date |
|
Number |
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.05+
|
|
First Amendment to Trust Agreement dated as of May 12, 2006 between
Oceaneering International, Inc. and Bank of America National Association, as
successor trustee
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.10 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.06+
|
|
2002 Non-Executive Incentive Plan
|
|
1-10945
|
|
10-Q
|
|
Sept. 2002
|
|
|
10.03 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.07+
|
|
First Amendment to 2002 Non-Executive Incentive Plan of Oceaneering
International, Inc. |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.08+
|
|
Oceaneering International, Inc. Supplemental Executive Retirement Plan, as
amended and restated effective January 1, 2009
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.09+
|
|
Amended and Restated Oceaneering International, Inc. Supplemental
Executive Retirement Plan, as amended and restated effective January 1,
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.6 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.10+
|
|
Change-of-Control Agreements dated as of November 16, 2001
between Oceaneering and John R. Huff, T. Jay Collins, Marvin J.
Migura, M. Kevin McEvoy and George R. Haubenreich, Jr.
|
|
1-10945
|
|
10-K
|
|
Dec. 2001
|
|
|
10.06 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.11+
|
|
Form of First Amendment to Change-of-Control Agreement with T. Jay
Collins, M. Kevin McEvoy, Marvin J. Migura and George R. Haubenreich, Jr.
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.7 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.12+
|
|
First Amendment to Change-of-Control Agreement with John R. Huff.
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.8 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.13+
|
|
Oceaneering International, Inc. 2008 Cash Bonus Award Program
|
|
1-10945
|
|
10-Q
|
|
Mar. 2008
|
|
|
10.07 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.14+
|
|
Form of Indemnification Agreement dated November 16, 2001
between Oceaneering and each of its Directors,
Marvin J. Migura, M. Kevin McEvoy and George R.
Haubenreich, Jr.
|
|
1-10945
|
|
10-K
|
|
Dec. 2001
|
|
|
10.12 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.15+
|
|
2002 Incentive Plan
|
|
1-10945
|
|
10-Q
|
|
June 2002
|
|
|
10.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.16+
|
|
First Amendment to 2002 Incentive Plan of Oceaneering International, Inc.
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.17+
|
|
Amended and Restated 2002 Restricted Stock Unit Award Agreements with
John R Huff and Executive Officers
|
|
1-10945
|
|
10-Q
|
|
Sept. 2002
|
|
|
10.04 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.18+
|
|
Form of First Amendment to Oceaneering International, Inc. Amended and
Restated 2002 Restricted Stock Unit Award Incentive Agreement with
Executive Officers
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.19+
|
|
First Amendment to Oceaneering International, Inc. Amended and Restated
2002 Restricted Stock Unit Award Incentive Agreement with John R. Huff
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.20+
|
|
2005 Incentive Plan
|
|
333-124947
|
|
S-8
|
|
May 2005
|
|
|
4.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.21+
|
|
First Amendment to 2005 Incentive Plan of Oceaneering International, Inc.
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.22+
|
|
Form of 2006 Employee Restricted Stock Unit Agreement
for John R. Huff and Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2006
|
|
|
10.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.23+
|
|
Form of 2006 Performance Unit Agreement for John R. Huff,
and Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2006
|
|
|
10.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.24+
|
|
2006 Performance Award: Goals and Measures, relating to the
Form of 2006 Performance Unit Agreement
|
|
1-10945
|
|
8-K
|
|
Feb. 2006
|
|
|
10.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.25+
|
|
Form of 2007 Employee Restricted Stock Unit Agreement
for Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2007
|
|
|
10.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.26+
|
|
Form of 2007 Chairman Restricted Stock Unit Agreement
for John R. Huff
|
|
1-10945
|
|
8-K
|
|
Feb. 2007
|
|
|
10.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.27+
|
|
Form of 2007 Performance Unit Agreement for
Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2007
|
|
|
10.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.28+
|
|
Form of 2007 Chairman Performance Unit Agreement
for John R. Huff
|
|
1-10945
|
|
8-K
|
|
Feb. 2007
|
|
|
10.4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.29+
|
|
2007 Performance Award: Goals and Measures, relating to the
Form of 2007 Performance Unit Agreement and Form of
Chairman Performance Unit Agreement
|
|
1-10945
|
|
8-K
|
|
Feb. 2007
|
|
|
10.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 10.30+
|
|
Form of 2008 Employee Restricted Stock Unit Agreement
for Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2008
|
|
|
10.1 |
|
Page 35
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Registration |
|
|
|
|
|
|
|
|
|
|
or File |
|
Form of |
|
Report |
|
Exhibit |
|
|
|
|
Number |
|
Report |
|
Date |
|
Number |
|
|
|
|
|
|
|
|
|
|
|
|
|
10.31+
|
|
Form of 2008 Nonemployee Director Restricted Stock Agreement
for
Harris J. Pappas
|
|
1-10945
|
|
8-K
|
|
Feb. 2008
|
|
|
10.6 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.32+
|
|
Form of 2008 Chairman Restricted Stock Unit Agreement
for John R. Huff
|
|
1-10945
|
|
8-K
|
|
Feb. 2008
|
|
|
10.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.33+
|
|
Form of 2008 Performance Unit Agreement for
Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2008
|
|
|
10.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.34+
|
|
Form of 2008 Chairman Performance Unit Agreement
for John R. Huff
|
|
1-10945
|
|
8-K
|
|
Feb. 2008
|
|
|
10.4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.35+
|
|
2008 Performance Award: Goals and Measures, relating to the
Form of 2008 Performance Unit Agreement and Form of
Chairman Performance Unit Agreement
|
|
1-10945
|
|
8-K
|
|
Feb. 2008
|
|
|
10.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.36+
|
|
Form of 2009 Employee Restricted Stock Unit Agreement for Executive
Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2009
|
|
|
10.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.37+
|
|
Form of 2009 Nonemployee Director Restricted Stock Unit Agreement for
Jerold J. DesRoche, David S. Hooker, D. Michael Hughes and Harris J.
Pappas
|
|
1-10945
|
|
8-K
|
|
Feb. 2009
|
|
|
10.6 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.38+
|
|
Form of 2009 Chairman Restricted Stock Unit Agreement for John R. Huff
|
|
1-10945
|
|
8-K
|
|
Feb. 2009
|
|
|
10.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.39+
|
|
Form of 2009 Performance Unit Agreement for Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2009
|
|
|
10.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.40+
|
|
Form of 2009 Chairman Performance
Unit Agreement for John R. Huff
|
|
1-10945
|
|
8-K
|
|
Feb. 2009
|
|
|
10.4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.41+
|
|
2009 Performance Award: Goals and Measures, relating to the form of 2009
Performance Unit Agreement and 2009 Chairman Performance Unit
Agreement
|
|
1-10945
|
|
8-K
|
|
Feb. 2009
|
|
|
10.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 Chief Executive Officer |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
31.02
|
|
Rule 13a 14(a)/15d 14(a) certification of Chief Financial Officer |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
32.01
|
|
Section 1350 certification of Chief Executive Officer |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
32.02
|
|
Section 1350 certification of Chief Financial Officer |
|
|
|
|
|
|
|
|
|
|
|
|
|
* |
|
Exhibit previously filed with the Securities and Exchange Commission, as indicated, and
incorporated herein by reference. |
|
+ |
|
Management contract or compensatory plan or arrangement. |
Page 36
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto
duly authorized.
|
|
|
|
|
|
|
OCEANEERING INTERNATIONAL, INC.
|
|
Date: February 25, 2009 |
By: |
/s/ T. JAY COLLINS
|
|
|
|
T. Jay Collins |
|
|
|
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 |
|
Date |
|
|
|
|
|
/s/ T. JAY COLLINS
T. Jay Collins
|
|
Chief Executive Officer
and Director
(Principal
Executive Officer)
|
|
February 25, 2009 |
|
|
|
|
|
/s/ MARVIN J. MIGURA
Marvin J. Migura
|
|
Senior Vice President and
Chief
Financial Officer
(Principal Financial Officer)
|
|
February 25, 2009 |
|
|
|
|
|
/s/ W. CARDON GERNER
W. Cardon Gerner
|
|
Vice President and Chief
Accounting
Officer
(Principal Accounting Officer)
|
|
February 25, 2009 |
|
|
|
|
|
/s/ JOHN R. HUFF
John R. Huff
|
|
Chairman of the Board
|
|
February 25, 2009 |
|
|
|
|
|
/s/ JEROLD J. DESROCHE
Jerold J. DesRoche
|
|
Director
|
|
February 25, 2009 |
|
|
|
|
|
/s/ DAVID S. HOOKER
David S. Hooker
|
|
Director
|
|
February 25, 2009 |
|
|
|
|
|
/s/ D. MICHAEL HUGHES
D. Michael Hughes
|
|
Director
|
|
February 25, 2009 |
|
|
|
|
|
/s/ HARRIS J. PAPPAS
Harris J. Pappas
|
|
Director
|
|
February 25, 2009 |
Page 37
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 Cash Flows
Consolidated Statements of Shareholders Equity and Comprehensive Income
Notes to Consolidated Financial Statements
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 set forth in the financial statements
included herein or in the related footnotes thereto.
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 (the Company) as of December 31, 2008 and 2007, and the related
consolidated statements of income, cash flows and shareholders equity and comprehensive
income for each of the three years in the period ended December 31, 2008. These financial
statements are the responsibility of the Companys 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 financial statements referred to above present fairly, in all material
respects, the consolidated financial position of Oceaneering International, Inc. and
subsidiaries at December 31, 2008 and 2007, and the consolidated results of their operations
and their cash flows for each of the three years in the period ended December 31, 2008, in
conformity with U.S. generally accepted accounting principles.
As discussed in Note 3 to the consolidated financial statements, effective January 1, 2007,
the Company adopted FASB Interpretation No. 48, Accounting for Uncertainty in Income Taxes.
As discussed in Note 1, effective December 31, 2006, the Company adopted Statement of
Financial Accounting Standards No. 158, Employers Accounting for Defined Benefit Pension and
Other Postretirement Plans, an amendment of FASB Statements No. 87, 88, 106, and 132(R).
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, 2008, based on criteria established in Internal
Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the
Treadway Commission and our report dated February 25, 2009 expressed an unqualified opinion
thereon.
Houston, Texas
February 25, 2009
Page 38
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands, except share data) |
|
2008 |
|
|
2007 |
|
|
ASSETS |
|
|
|
|
|
|
|
|
Current Assets: |
|
|
|
|
|
|
|
|
Cash and cash equivalents |
|
$ |
11,200 |
|
|
$ |
27,110 |
|
Accounts receivable, net of allowances for doubtful
accounts |
|
|
446,719 |
|
|
|
370,612 |
|
Inventory and other current assets |
|
|
289,786 |
|
|
|
272,847 |
|
|
|
|
|
|
|
|
Total Current Assets |
|
|
747,705 |
|
|
|
670,569 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property and Equipment, at cost |
|
|
1,351,839 |
|
|
|
1,247,262 |
|
Less accumulated depreciation |
|
|
654,409 |
|
|
|
609,155 |
|
|
|
|
|
|
|
|
Net Property and Equipment |
|
|
697,430 |
|
|
|
638,107 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Assets: |
|
|
|
|
|
|
|
|
Goodwill |
|
|
118,706 |
|
|
|
111,951 |
|
Investments in unconsolidated affiliates |
|
|
63,930 |
|
|
|
64,655 |
|
Other |
|
|
42,249 |
|
|
|
46,158 |
|
|
|
|
|
|
|
|
Total other assets |
|
|
224,885 |
|
|
|
222,764 |
|
|
|
|
|
|
|
|
Total Assets |
|
$ |
1,670,020 |
|
|
$ |
1,531,440 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND SHAREHOLDERS EQUITY |
|
|
|
|
|
|
|
|
Current Liabilities: |
|
|
|
|
|
|
|
|
Accounts payable |
|
$ |
92,511 |
|
|
$ |
76,841 |
|
Accrued liabilities |
|
|
244,035 |
|
|
|
235,748 |
|
Income taxes payable |
|
|
20,781 |
|
|
|
26,386 |
|
|
|
|
|
|
|
|
Total Current Liabilities |
|
|
357,327 |
|
|
|
338,975 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term Debt |
|
|
229,000 |
|
|
|
200,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Long-term Liabilities |
|
|
116,039 |
|
|
|
77,155 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Commitments and Contingencies |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Shareholders Equity: |
|
|
|
|
|
|
|
|
Common Stock, par value $0.25 per share; 90,000,000
shares
authorized; 55,417,044 and 55,075,238 shares issued |
|
|
13,854 |
|
|
|
13,769 |
|
Additional paid-in capital |
|
|
224,245 |
|
|
|
210,388 |
|
Treasury stock; 941,600 and 0 shares, at cost |
|
|
(52,419 |
) |
|
|
|
|
Retained earnings |
|
|
850,690 |
|
|
|
651,304 |
|
Accumulated other comprehensive income |
|
|
(68,716 |
) |
|
|
39,849 |
|
|
|
|
|
|
|
|
Total shareholders equity |
|
|
967,654 |
|
|
|
915,310 |
|
|
|
|
|
|
|
|
Total Liabilities and Shareholders Equity |
|
$ |
1,670,020 |
|
|
$ |
1,531,440 |
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of these Consolidated Financial Statements.
Page 39
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
|
(in thousands, except per share data) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Revenue |
|
$ |
1,977,421 |
|
|
$ |
1,743,080 |
|
|
$ |
1,280,198 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of services and products |
|
|
1,512,621 |
|
|
|
1,329,795 |
|
|
|
984,077 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross Margin |
|
|
464,800 |
|
|
|
413,285 |
|
|
|
296,121 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Selling, general and administrative expense |
|
|
147,242 |
|
|
|
123,662 |
|
|
|
101,785 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from Operations |
|
|
317,558 |
|
|
|
289,623 |
|
|
|
194,336 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income |
|
|
907 |
|
|
|
1,198 |
|
|
|
730 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense, net of amounts capitalized |
|
|
(13,485 |
) |
|
|
(15,333 |
) |
|
|
(12,920 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Equity earnings of unconsolidated affiliates |
|
|
1,919 |
|
|
|
4,030 |
|
|
|
12,051 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense), net |
|
|
321 |
|
|
|
(2,020 |
) |
|
|
(3,302 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before Income Taxes |
|
|
307,220 |
|
|
|
277,498 |
|
|
|
190,895 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes |
|
|
107,834 |
|
|
|
97,124 |
|
|
|
66,401 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income |
|
$ |
199,386 |
|
|
$ |
180,374 |
|
|
$ |
124,494 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic Earnings per Share |
|
$ |
3.63 |
|
|
$ |
3.29 |
|
|
$ |
2.31 |
|
Diluted Earnings per Share |
|
$ |
3.58 |
|
|
$ |
3.24 |
|
|
$ |
2.26 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of common shares |
|
|
54,949 |
|
|
|
54,786 |
|
|
|
53,990 |
|
Incremental shares from stock equivalents |
|
|
773 |
|
|
|
969 |
|
|
|
1,001 |
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of common shares
and equivalents |
|
|
55,722 |
|
|
|
55,755 |
|
|
|
54,991 |
|
|
|
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of these Consolidated Financial Statements.
Page 40
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Cash Flows from Operating Activities: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
199,386 |
|
|
$ |
180,374 |
|
|
$ |
124,494 |
|
|
|
|
|
|
|
|
|
|
|
Adjustments to reconcile net income to net cash
provided by operating activities: |
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and amortization, including impairment charge |
|
|
115,029 |
|
|
|
93,776 |
|
|
|
80,456 |
|
Deferred income tax provision (benefit) |
|
|
45,876 |
|
|
|
10,265 |
|
|
|
(4,260 |
) |
Gain on asset sales |
|
|
(5,460 |
) |
|
|
(4,198 |
) |
|
|
|
|
Noncash compensation |
|
|
7,956 |
|
|
|
5,337 |
|
|
|
4,000 |
|
Distributions from unconsolidated affiliates greater than
(less than) earnings |
|
|
725 |
|
|
|
(33 |
) |
|
|
(2,898 |
) |
Increase (decrease) in cash from: |
|
|
|
|
|
|
|
|
|
|
|
|
Accounts receivable, net |
|
|
(71,903 |
) |
|
|
(55,357 |
) |
|
|
(45,758 |
) |
Inventory and other current assets |
|
|
(15,968 |
) |
|
|
(95,726 |
) |
|
|
(74,207 |
) |
Other assets |
|
|
4,527 |
|
|
|
1,462 |
|
|
|
(4,415 |
) |
Currency translation effect on working capital |
|
|
(44,224 |
) |
|
|
14,918 |
|
|
|
7,292 |
|
Accounts payable |
|
|
14,602 |
|
|
|
6,064 |
|
|
|
6,471 |
|
Accrued liabilities |
|
|
10,265 |
|
|
|
55,676 |
|
|
|
37,904 |
|
Income taxes payable |
|
|
(7,618 |
) |
|
|
(2,470 |
) |
|
|
12,663 |
|
Other long-term liabilities |
|
|
(5,279 |
) |
|
|
(1,213 |
) |
|
|
9,502 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total adjustments to net income |
|
|
48,528 |
|
|
|
28,501 |
|
|
|
26,750 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided by Operating Activities |
|
|
247,914 |
|
|
|
208,875 |
|
|
|
151,244 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash Flows from Investing Activities: |
|
|
|
|
|
|
|
|
|
|
|
|
Business acquisitions, net of cash acquired |
|
|
(42,976 |
) |
|
|
(25,099 |
) |
|
|
(1,491 |
) |
Purchases of property and equipment |
|
|
(209,301 |
) |
|
|
(208,696 |
) |
|
|
(192,351 |
) |
Dispositions of property and equipment |
|
|
5,886 |
|
|
|
6,941 |
|
|
|
6,826 |
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Used in Investing Activities |
|
|
(246,391 |
) |
|
|
(226,854 |
) |
|
|
(187,016 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash Flows from Financing Activities: |
|
|
|
|
|
|
|
|
|
|
|
|
Net (payments) proceeds from revolving credit facility |
|
|
(36,000 |
) |
|
|
25,561 |
|
|
|
40,000 |
|
Payments of 6.72% Senior Notes |
|
|
(20,000 |
) |
|
|
(20,000 |
) |
|
|
(20,000 |
) |
Proceeds from Term Loan |
|
|
85,000 |
|
|
|
|
|
|
|
|
|
Proceeds from issuance of common stock |
|
|
1,726 |
|
|
|
5,277 |
|
|
|
8,320 |
|
Excess tax benefits from stock-based compensation |
|
|
6,770 |
|
|
|
8,023 |
|
|
|
7,372 |
|
Purchases of treasury stock |
|
|
(54,929 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided by (Used in) Financing Activities |
|
|
(17,433 |
) |
|
|
18,861 |
|
|
|
35,692 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Increase (Decrease) in Cash and Cash Equivalents |
|
|
(15,910 |
) |
|
|
882 |
|
|
|
(80 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and Cash Equivalents Beginning of Period |
|
|
27,110 |
|
|
|
26,228 |
|
|
|
26,308 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and Cash Equivalents End of Period |
|
$ |
11,200 |
|
|
$ |
27,110 |
|
|
$ |
26,228 |
|
|
|
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of these Consolidated Financial Statements.
Page 41
OCEANEERING INTERNATIONAL, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF SHAREHOLDERS EQUITY AND COMPREHENSIVE INCOME
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive Income (Loss) |
|
|
|
|
|
|
Common Stock |
|
|
Additional |
|
|
Unearned |
|
|
|
|
|
|
|
|
|
|
Fair Value |
|
|
Currency |
|
|
|
|
|
|
|
|
|
Issued |
|
|
Paid-in |
|
|
Compen- |
|
|
Treasury |
|
|
Retained |
|
|
of Hedging |
|
|
Translation |
|
|
|
|
|
|
|
(in thousands) |
|
Shares |
|
|
Amounts |
|
|
Capital |
|
|
sation |
|
|
Stock |
|
|
Earnings |
|
|
Instruments |
|
|
Adjustments |
|
|
Pension |
|
|
Total |
|
|
Balance, December 31, 2005 |
|
|
53,558 |
|
|
$ |
13,390 |
|
|
$ |
172,656 |
|
|
$ |
(219 |
) |
|
$ |
|
|
|
$ |
348,031 |
|
|
$ |
518 |
|
|
$ |
4,291 |
|
|
$ |
(2,549 |
) |
|
$ |
536,118 |
|
Comprehensive Income: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
124,494 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
124,494 |
|
Change in fair value of interest rate hedge,
net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(165 |
) |
|
|
|
|
|
|
|
|
|
|
(165 |
) |
Pension-related adjustments, net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
843 |
|
|
|
843 |
|
Translation adjustments |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17,282 |
|
|
|
|
|
|
|
17,282 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Comprehensive Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
124,494 |
|
|
|
(165 |
) |
|
|
17,282 |
|
|
|
843 |
|
|
|
142,454 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjustment to initially apply SFAS No. 158,
net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,501 |
) |
|
|
(1,501 |
) |
Restricted stock expense |
|
|
228 |
|
|
|
57 |
|
|
|
2,604 |
|
|
|
1,060 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,721 |
|
Restricted stock forfeitures |
|
|
|
|
|
|
|
|
|
|
73 |
|
|
|
|
|
|
|
(73 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Restricted stock grant |
|
|
32 |
|
|
|
8 |
|
|
|
856 |
|
|
|
(917 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(53 |
) |
Stock options exercised |
|
|
622 |
|
|
|
155 |
|
|
|
8,092 |
|
|
|
|
|
|
|
73 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
8,320 |
|
Stock options expense |
|
|
|
|
|
|
|
|
|
|
333 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
333 |
|
Tax benefits from stock plans |
|
|
|
|
|
|
|
|
|
|
7,372 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,372 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2006 |
|
|
54,440 |
|
|
|
13,610 |
|
|
|
191,986 |
|
|
|
(76 |
) |
|
|
|
|
|
|
472,525 |
|
|
|
353 |
|
|
|
21,573 |
|
|
|
(3,207 |
) |
|
|
696,764 |
|
Adjustment to initially apply FIN No. 48,
net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,595 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,595 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted balance, January 1, 2007 |
|
|
54,440 |
|
|
|
13,610 |
|
|
|
191,986 |
|
|
|
(76 |
) |
|
|
|
|
|
|
470,930 |
|
|
|
353 |
|
|
|
21,573 |
|
|
|
(3,207 |
) |
|
|
695,169 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive Income: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
180,374 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
180,374 |
|
Change in fair value of interest rate hedge,
net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(277 |
) |
|
|
|
|
|
|
|
|
|
|
(277 |
) |
Pension-related adjustments, net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
396 |
|
|
|
396 |
|
Translation adjustments |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
21,011 |
|
|
|
|
|
|
|
21,011 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Comprehensive Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
180,374 |
|
|
|
(277 |
) |
|
|
21,011 |
|
|
|
396 |
|
|
|
201,504 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Restricted stock expense |
|
|
228 |
|
|
|
57 |
|
|
|
3,995 |
|
|
|
1,281 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,333 |
|
Restricted stock grant |
|
|
32 |
|
|
|
8 |
|
|
|
1,306 |
|
|
|
(1,314 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock options exercised |
|
|
375 |
|
|
|
94 |
|
|
|
5,183 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,277 |
|
Stock options expense |
|
|
|
|
|
|
|
|
|
|
4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4 |
|
Tax benefits from stock plans |
|
|
|
|
|
|
|
|
|
|
8,023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
8,023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2007 |
|
|
55,075 |
|
|
|
13,769 |
|
|
|
210,497 |
|
|
|
(109 |
) |
|
|
|
|
|
|
651,304 |
|
|
|
76 |
|
|
|
42,584 |
|
|
|
(2,811 |
) |
|
|
915,310 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive Income: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
199,386 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
199,386 |
|
Change in fair value of interest rate hedge
and other, net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(3,133 |
) |
|
|
|
|
|
|
|
|
|
|
(3,133 |
) |
Pension-related adjustments, net of tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
641 |
|
|
|
641 |
|
Translation adjustments |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(106,073 |
) |
|
|
|
|
|
|
(106,073 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Comprehensive Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
199,386 |
|
|
|
(3,133 |
) |
|
|
(106,073 |
) |
|
|
641 |
|
|
|
90,821 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Restricted stock expense |
|
|
224 |
|
|
|
56 |
|
|
|
5,965 |
|
|
|
1,935 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,956 |
|
Restricted stock grant |
|
|
32 |
|
|
|
8 |
|
|
|
1,984 |
|
|
|
(1,992 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock options exercised |
|
|
86 |
|
|
|
21 |
|
|
|
(805 |
) |
|
|
|
|
|
|
2,510 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,726 |
|
Tax benefits from stock plans |
|
|
|
|
|
|
|
|
|
|
6,770 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,770 |
|
Treasury stock purchases, 986,400 shares |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(54,929 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(54,929 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2008 |
|
|
55,417 |
|
|
$ |
13,854 |
|
|
$ |
224,411 |
|
|
$ |
(166 |
) |
|
$ |
(52,419 |
) |
|
$ |
850,690 |
|
|
$ |
(3,057 |
) |
|
$ |
(63,489 |
) |
|
$ |
(2,170 |
) |
|
$ |
967,654 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of these Consolidated Financial Statements.
Page 42
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 as defined in Financial Accounting Standards
Board (FASB) Interpretation No. (FIN) 46R, Consolidation of Variable Interest Entities,
if we determine that we are the primary beneficiary; otherwise, we account for these 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. All significant intercompany accounts and transactions have been eliminated.
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 the investment.
Accounts Receivable Allowances for Doubtful Accounts
The following table sets forth the activity of our allowances for doubtful accounts
receivable:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions |
|
|
|
|
|
|
|
|
|
|
Balance at |
|
|
Charged to |
|
|
Charged to |
|
|
|
|
|
|
Balance at |
|
|
|
beginning |
|
|
Costs and |
|
|
Other |
|
|
|
|
|
|
end of |
|
(in thousands) |
|
of Period |
|
|
Expenses |
|
|
Accounts |
|
|
Deductions |
|
|
Period |
|
|
For the year ended December 31, 2006 |
|
$ |
112 |
|
|
$ |
|
|
|
$ |
2 |
|
|
$ |
|
|
|
$ |
114 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the year ended December 31, 2007 |
|
$ |
114 |
|
|
$ |
964 |
|
|
$ |
49 |
|
|
$ |
103 |
|
|
$ |
1,024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the year ended December 31, 2008 |
|
$ |
1,024 |
|
|
$ |
455 |
|
|
$ |
121 |
|
|
$ |
108 |
|
|
$ |
1,492 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
We determine the need for allowances for doubtful accounts using the specific identification
method. We do not generally require collateral from our customers.
Inventory and Other Current Assets
Inventory and other current assets consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Inventory for remotely operated vehicles |
|
$ |
104,892 |
|
|
$ |
84,467 |
|
Other inventory, primarily raw materials |
|
|
130,690 |
|
|
|
140,943 |
|
Deferred income taxes |
|
|
14,627 |
|
|
|
13,576 |
|
Prepaids and other |
|
|
39,577 |
|
|
|
33,861 |
|
|
|
|
|
|
|
|
Total |
|
$ |
289,786 |
|
|
$ |
272,847 |
|
|
|
|
|
|
|
|
Inventory is valued at lower of cost or market. We determine cost using the weighted-average
method.
Property and Equipment
We provide for depreciation of property and equipment on the straight-line method over
estimated useful lives of three to 20 years for marine services equipment (such as ROVs,
vessels and diving equipment), up to 12 years for mobile offshore production equipment and
three to 25 years for buildings, improvements and other equipment.
We charge the costs of repair and maintenance of property and equipment to operations as
incurred, while we capitalize the costs of improvements. In September 2006, the FASB issued
FASB Staff Position No. AUG AIR-1, Accounting for Planned
Page 43
Major Maintenance Activities. This
Staff Position prohibits companies from recognizing planned major maintenance costs by
accruing a liability over several reporting periods before the maintenance is performed ¯ the
accrue-in-advance method. We previously used the accrue-in-advance method for anticipated
drydocking of our vessels. This Staff Position was effective for us beginning January 1,
2007, and we have since charged drydocking expenses to the income statement as incurred.
There was no material effect on our financial statements from the change.
We capitalize interest on assets where the construction period is anticipated to be more than
three months. We capitalized $1.0 million and $0.1 million of interest in 2007 and 2006,
respectively. We capitalized less than $0.1 million of interest in 2008. 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.
Our management periodically, and upon the occurrence of a triggering event, reviews the
realizability of long-lived assets, excluding goodwill and indefinite-lived intangibles,
which are held and used by us, 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 benefit 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 the 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 quoted market prices 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. In 2008, we recorded an
impairment charge of $5.7 million to reduce our investment in the Ocean Pensador, an oil
tanker we are holding for possible conversion, to its fair value, based on steel commodity
prices. This impairment charge was recorded in our cost of services and products in our
Mobile Offshore Production Systems segment.
Business Acquisitions
In March 2008, we purchased GTO Subsea AS (GTO), a Norwegian rental provider of specialized
subsea dredging equipment, including ROV-deployed units, to the offshore oil and gas industry
for $40 million. We accounted for this acquisition using the purchase method of accounting,
with the purchase price being allocated to the net assets acquired based on their fair market
values at the date of acquisition. Our goodwill, all nondeductible, associated with the
acquisition was $23.2 million, and other intangible assets were $8.1 million. The results of
operations of GTO are included in our consolidated statements of income from the date of
acquisition.
In July 2007, we acquired Ifokus Engineering AS (Ifokus), a designer and manufacturer of
specialty subsea products based in Norway, for $20 million. We accounted for this
acquisition using the purchase method of accounting, with the purchase price being allocated
to the net assets acquired based on their fair market values at the date of acquisition. Our
goodwill, all nondeductible, associated with the acquisition was $18 million, and other
intangible assets were $2 million. The results of operations of Ifokus are included in our
consolidated statements of income from the date of acquisition.
We also made several smaller acquisitions during the periods presented.
The above acquisitions were not material. As a result, we have not included pro forma
information related to the acquisitions in this report.
Goodwill and Intangible Assets
In accordance with the requirements of Statement of Financial Accounting Standards (SFAS)
No. 142, Goodwill and Other Intangible Assets, we tested the goodwill attributable to each of
our reporting units for impairment as of December 31, 2008,
2007 and 2006 and concluded that there was no impairment. Our reporting units are the
operating units one level below our business segments, except for Inspection, which is tested
as a single reporting unit. We estimated fair value using discounted cash flow methodologies
and market comparable information.
Within our balance sheet caption Other Assets: Other, at December 31, 2008 and 2007, we have
$21.4 million and $15.7 million, respectively, of intangible assets, primarily acquired in
connection with business combinations. These intangible assets include trade names,
intellectual property and customer relationships, and are being amortized over a weighted
average remaining life of approximately 11 years.
Page 44
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 occasionally in our Subsea Projects and Advanced Technologies segments,
using the percentage-of-completion method. In 2008, 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 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, also affect the progress and estimated cost of a projects 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. Although we are continually
striving to improve our ability to 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:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Revenue recognized |
|
$ |
173,625 |
|
|
$ |
193,473 |
|
Less: Billings to customers |
|
|
(136,113 |
) |
|
|
(171,070 |
) |
|
|
|
|
|
|
|
Revenue in excess of amounts billed |
|
$ |
37,512 |
|
|
$ |
22,403 |
|
|
|
|
|
|
|
|
Billings in Excess of Revenue Recognized on uncompleted fixed-price contracts accounted for
using the percentage-of-completion method are summarized as follows:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Amounts billed to customers |
|
$ |
18,263 |
|
|
$ |
56,434 |
|
Less: Revenue recognized |
|
|
(11,578 |
) |
|
|
(46,022 |
) |
|
|
|
|
|
|
|
Billings in excess
of revenue
recognized |
|
$ |
6,685 |
|
|
$ |
10,412 |
|
|
|
|
|
|
|
|
Stock-Based Compensation
We account for share-based compensation in accordance with SFAS No. 123 (revised 2004),
Share-Based Payment (SFAS No. 123R). SFAS No. 123R requires all share-based payments to
directors, officers and employees, including grants of stock options, to be recognized over
their vesting periods in the income statement based on their estimated fair
Page 45
values. SFAS No.
123R applies to all awards granted after December 31, 2005 and to awards modified,
repurchased or canceled after that date, as well as the unvested portion of awards granted
prior to December 31, 2005. Existing option grants caused us to recognize an additional
amount of less than $0.01 per diluted share of share-based compensation expense for 2006,
under the modified prospective transition alternative that we elected.
In light of the accounting expense recognition requirements established by SFAS No. 123R, the
Compensation Committee of our Board of Directors has expressed its intention to refrain from
using stock options as a component of 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. No stock options have been granted since 2005. For
more information on our employee benefit plans, see Note 8.
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. Our policy is to provide for deferred
U.S. income taxes on foreign income only to the extent such income is not to be invested
indefinitely in the related foreign entity. We provide a valuation allowance against
deferred tax assets when it is more likely than not that the asset will not be realized.
In June 2006, the FASB issued FIN 48, Accounting for Uncertainty in Income Taxes. This
interpretation clarifies the criteria for recognizing income tax benefits under SFAS No. 109,
Accounting for Income Taxes, and requires financial statement disclosures about uncertain tax
positions. Effective January 1, 2007, we adopted FIN 48. Under FIN 48, the financial
statement recognition of the benefit for a tax position depends on the benefit being 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
is greater than 50 percent 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 made an adjustment of $1.6
million to reduce our retained earnings as of January 1, 2007 to record the effect of our
adoption of this interpretation.
Foreign Currency Translation
The functional currency for several 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 accumulated as a component of shareholders equity. All foreign
currency transaction gains and losses are recognized currently in the Consolidated Statements
of Income. We recorded $0.7 million, ($0.3 million) and ($2.5 million) of foreign currency
gains (losses) in 2008, 2007 and 2006, respectively, and those amounts are included as a
component of Other income (expense), net.
Earnings Per Share
Basic and diluted earnings per share are computed by dividing net income by the weighted
average number of common shares and the weighted average number of common shares plus common
share equivalents, respectively.
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 or other comprehensive income, depending on whether a derivative
instrument is designated as part of a hedge relationship and, if it is, the type of hedge
relationship.
Reclassifications
Certain amounts from prior periods have been reclassified to conform with the current year
presentation.
Use of Estimates
The preparation of financial statements in conformity with accounting principles generally
accepted in the U.S. requires that our management make estimates and assumptions that affect
the reported amounts of assets and liabilities, disclosure of
Page 46
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.
Pension and Postretirement Benefits
In September 2006, the FASB issued SFAS No. 158, Employers Accounting for Defined Benefit
Pension and Other Postretirement Plans. SFAS No. 158 requires us to recognize the funded
status of the pension and postretirement plans in our balance sheet, along with a
corresponding noncash, after-tax adjustment to shareholders equity. Funded status is
determined as the difference between the fair value of plan assets and the projected benefit
obligation. Changes in the funded status will be recognized in other comprehensive income
(loss). We adopted SFAS No. 158 at the end of 2006, as required.
New Accounting Standards
The following is a summary of recent accounting pronouncements that are applicable to us.
In September 2006, the FASB issued SFAS No. 157, Fair Value Measurements. SFAS No. 157
defines fair value, establishes a framework for measuring fair value in accounting principles
generally accepted in the United States, and expands disclosures about fair value
measurements. SFAS No. 157 applies under other accounting pronouncements that require or
permit fair value measurements, except as otherwise specified therein. The effective date
for the application of SFAS No. 157 to certain items was deferred to January 1, 2009 by FASB
Staff Position (FSP) No. 157-2, and this statement will be effective for us at that time.
We have adopted SFAS No. 157 as required for the items where applicability was not deferred.
In October 2008, the FASB issued FSP No. 157-3, Determining the Fair Value of a Financial
Asset When the Market for That Asset Is Not Active. This FASB Staff Position became
effective immediately and is intended to clarify the application of SFAS No. 157 in a market
that is not active and provides an example to illustrate key considerations in determining
the fair value of a financial asset when the market for that asset is not active.
In December 2007, the FASB issued SFAS No. 141 (revised 2007), Business Combinations (SFAS
No. 141R). SFAS No. 141R still requires purchase accounting in business combinations, but
it:
|
|
|
requires an acquirer to recognize all assets and
liabilities acquired at the acquisition date, measured at their fair values
as of that date, with limited exceptions; |
|
|
|
|
requires the expensing of all transaction costs and
restructuring charges; |
|
|
|
|
requires the acquirer in a business combination achieved
in stages to recognize the identifiable assets and liabilities at the full
amounts of their fair market values at the acquisition date; and |
|
|
|
|
requires the acquirer to recognize contingent
consideration, including earn-out arrangements, at the acquisition date,
measured at its fair value at that date, with subsequent changes to be
recognized in earnings. |
SFAS No. 141R will apply to any acquisitions we complete on or after January 1, 2009, and
earlier adoption is not allowed.
In December 2007, the FASB issued SFAS No. 160, Noncontrolling Interests in Consolidated
Financial Statements, an amendment of ARB No. 51. SFAS No. 160 requires that revenue,
expenses, gains, losses, net income or loss and other comprehensive income be reported in the
consolidated financial statements at the consolidated amounts, and that the amount of net
income attributable to the noncontrolling interest (commonly called minority interest) be
reported separately in the consolidated statement of income. SFAS No. 160 also requires that
the minority ownership interest in subsidiaries be
separately presented in the consolidated balance sheets within equity. We currently report
the net income attributable to minority interests within our consolidated statements of
income below operating income, and we report minority interest ownership on our consolidated
balance sheets in other long-term liabilities. These items have not been material to us to
date. SFAS No. 160 requires prospective application for us effective January 1, 2009, and
earlier adoption is not allowed; however, presentation and disclosure are retroactively
required.
In March 2008, the FASB issued SFAS No. 161, Disclosures about Derivative Instruments and
Hedging Activities. SFAS No. 161 is intended to improve financial reporting about derivative
instruments and hedging activities by requiring enhanced disclosures to enable investors to
better understand the effects of these activities on an entitys financial position,
financial performance and cash flows. It will be effective for our first quarter 2009
financial statements, with early application encouraged.
In June 2008, the FASB issued FSP No. EITF 03-6-1, Determining Whether Instruments Granted in
Share-Based Payment Transactions Are Participating Securities (EITF 03-6-1). EITF 03-6-1
states that unvested share-based payment awards
Page 47
that contain non-forfeitable rights to
dividends or dividend equivalents (whether paid or unpaid) are participating securities and,
therefore, need to be included in the earnings allocation in computing earnings per share
under the two-class method described in paragraphs 60 and 61 of SFAS No. 128, Earnings per
Share. EITF 03-6-1 requires prospective application for us effective January 1, 2009, and
earlier adoption is not allowed; however, prior period earnings per share data will be
adjusted retrospectively to conform to EITF 03-6-1.
2. INVESTMENTS IN UNCONSOLIDATED AFFILIATES
Our investments in unconsolidated affiliates consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Medusa Spar LLC |
|
$ |
62,583 |
|
|
$ |
63,183 |
|
|
$ |
63,149 |
|
Other |
|
|
1,347 |
|
|
|
1,472 |
|
|
|
1,347 |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
63,930 |
|
|
$ |
64,655 |
|
|
$ |
64,496 |
|
|
|
|
|
|
|
|
|
|
|
In December 2003, we purchased a 50% equity interest in Medusa Spar LLC for $43.7 million.
Medusa Spar LLC owns a 75% interest in a production spar platform. Medusa Spar LLCs revenue
is derived from processing oil and gas production for a fee based on the volumes processed
(throughput). Medusa Spar LLC financed its acquisition of its 75% interest in the production
spar platform using approximately 50% debt and 50% equity from its equity holders. The debt
was repaid in 2008. We believe our maximum exposure to loss from our investment in Medusa
Spar LLC is our $63 million investment. Medusa Spar LLC is a variable interest entity. We
are not the primary beneficiary under FIN 46(R), since we own 50%, do not manage the
operations of the asset it owns and another owner guaranteed the revenue stream necessary for
it to repay its debt. As we are not the primary beneficiary, we are accounting for our
investment in Medusa Spar LLC under the equity method of accounting. Summarized 100%
financial information relative to Medusa Spar LLC and a reconciliation of the underlying
equity in net assets to our carrying value follows.
Page 48
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Medusa Spar LLC |
|
|
|
|
|
|
|
|
|
|
|
|
Condensed Balance Sheets |
|
|
|
|
|
|
|
|
|
|
|
|
ASSETS |
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents |
|
$ |
3,520 |
|
|
$ |
18,181 |
|
|
$ |
18,932 |
|
Other current assets |
|
|
2,456 |
|
|
|
879 |
|
|
|
1,487 |
|
Property and Equipment, net |
|
|
119,506 |
|
|
|
128,983 |
|
|
|
138,461 |
|
Other Non-Current Assets |
|
|
|
|
|
|
378 |
|
|
|
979 |
|
|
|
|
|
|
|
|
|
|
|
Total Assets |
|
$ |
125,482 |
|
|
$ |
148,421 |
|
|
$ |
159,859 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND MEMBERS EQUITY |
|
|
|
|
|
|
|
|
|
|
|
|
Current Maturities of Long-Term Debt |
|
$ |
|
|
|
$ |
8,810 |
|
|
$ |
11,499 |
|
Other Current Liabilities |
|
|
17 |
|
|
|
16 |
|
|
|
24 |
|
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities |
|
|
17 |
|
|
|
8,826 |
|
|
|
11,523 |
|
Long-Term Debt, net of current maturities |
|
|
|
|
|
|
12,928 |
|
|
|
21,738 |
|
Other Comprehensive Income |
|
|
|
|
|
|
233 |
|
|
|
1,097 |
|
Members Equity |
|
|
125,465 |
|
|
|
126,434 |
|
|
|
125,501 |
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities and Members Equity |
|
$ |
125,482 |
|
|
$ |
148,421 |
|
|
$ |
159,859 |
|
|
|
|
|
|
|
|
|
|
|
Condensed Statements of Operations |
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
$ |
14,455 |
|
|
$ |
18,839 |
|
|
$ |
34,216 |
|
Depreciation |
|
|
(9,478 |
) |
|
|
(9,478 |
) |
|
|
(9,477 |
) |
General and Administrative |
|
|
(118 |
) |
|
|
(112 |
) |
|
|
(109 |
) |
Interest |
|
|
(832 |
) |
|
|
(1,451 |
) |
|
|
(1,935 |
) |
|
|
|
|
|
|
|
|
|
|
Net Income |
|
$ |
4,027 |
|
|
$ |
7,798 |
|
|
$ |
22,695 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of the Carrying Value of the Investment to Underlying Equity in Net Assets: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Underlying Equity in Net Assets - 50% |
|
$ |
62,733 |
|
|
$ |
63,217 |
|
|
$ |
62,751 |
|
Basis Differences |
|
|
(150 |
) |
|
|
(34 |
) |
|
|
398 |
|
|
|
|
|
|
|
|
|
|
|
Carrying Value of Investment in Medusa Spar LLC in
the Consolidated Financial Statements |
|
$ |
62,583 |
|
|
$ |
63,183 |
|
|
$ |
63,149 |
|
|
|
|
|
|
|
|
|
|
|
Our 50% share of the cumulative undistributed earnings of Medusa Spar LLC was $20.9 million
and $21.4 million at December 31, 2008 and 2007, respectively.
3. INCOME TAXES
Effective January 1, 2007, we adopted FIN 48. This interpretation clarifies the criteria for
recognizing income tax benefits under SFAS No. 109, and requires disclosures about uncertain
tax positions. Under FIN 48, the financial statement recognition of the benefit for a tax
position depends on the benefit being 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 is greater than 50 percent likely of being realized
upon ultimate settlement. We made an adjustment of $1.6 million to our retained earnings
account as of January 1, 2007 to record the effect of our adoption of this interpretation.
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 charged $0.4
million to income tax expense in 2008 for penalties and interest taken on our financial
statements on uncertain tax positions, which brought our total liabilities for penalties and
interest on uncertain tax positions to $3.2 million on our balance sheet at December 31,
2008. Including associated foreign tax credits and penalties and interest, we have accrued a
total of $5.7 million in the caption other long-term liabilities on our balance sheet for
unrecognized tax benefits. All additions or reductions to those liabilities affect our
effective income tax rate in the periods of change.
Page 49
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:
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Beginning of year |
|
$ |
7,450 |
|
|
$ |
7,001 |
|
Additions based on tax positions related to the current year |
|
|
1,354 |
|
|
|
1,392 |
|
Reductions for expiration of statutes of limitations |
|
|
(402 |
) |
|
|
(587 |
) |
Settlements |
|
|
|
|
|
|
(356 |
) |
|
|
|
|
|
|
|
Balance at end of year |
|
$ |
8,402 |
|
|
$ |
7,450 |
|
|
|
|
|
|
|
|
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, including acquired companies from their respective dates of
acquisition. 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. The following table sets forth our provisions for income taxes.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
U.S. federal and state |
|
$ |
56,096 |
|
|
$ |
54,040 |
|
|
$ |
37,384 |
|
Foreign |
|
|
51,738 |
|
|
|
43,084 |
|
|
|
29,017 |
|
|
|
|
|
|
|
|
|
|
|
Total provision |
|
$ |
107,834 |
|
|
$ |
97,124 |
|
|
$ |
66,401 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current |
|
$ |
61,958 |
|
|
$ |
86,859 |
|
|
$ |
70,661 |
|
Deferred |
|
|
45,876 |
|
|
|
10,265 |
|
|
|
(4,260 |
) |
|
|
|
|
|
|
|
|
|
|
Total provision |
|
$ |
107,834 |
|
|
$ |
97,124 |
|
|
$ |
66,401 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash taxes paid |
|
$ |
66,594 |
|
|
$ |
82,171 |
|
|
$ |
49,876 |
|
|
|
|
|
|
|
|
|
|
|
As of December 31, 2008 and 2007, our worldwide deferred tax assets, liabilities and net
deferred tax liabilities were as follows:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Deferred tax assets: |
|
|
|
|
|
|
|
|
Deferred compensation |
|
$ |
21,014 |
|
|
$ |
26,297 |
|
Foreign tax credit carryforwards |
|
|
4,747 |
|
|
|
3,236 |
|
Accrued expenses |
|
|
6,578 |
|
|
|
7,009 |
|
Deferred income |
|
|
5,581 |
|
|
|
3,557 |
|
Net operating loss carryforwards |
|
|
866 |
|
|
|
1,483 |
|
Other |
|
|
6,894 |
|
|
|
12,067 |
|
|
|
|
|
|
|
|
Gross deferred tax assets |
|
|
45,680 |
|
|
|
53,649 |
|
Valuation allowance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total deferred tax assets |
|
$ |
45,680 |
|
|
$ |
53,649 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred tax liabilities: |
|
|
|
|
|
|
|
|
Property and equipment |
|
$ |
54,506 |
|
|
$ |
37,664 |
|
Basis difference in equity investments |
|
|
16,058 |
|
|
|
15,059 |
|
Unremitted foreign earnings |
|
|
10,497 |
|
|
|
7,509 |
|
Other |
|
|
22,196 |
|
|
|
6,398 |
|
|
|
|
|
|
|
|
Total deferred tax liabilities |
|
$ |
103,257 |
|
|
$ |
66,630 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net deferred income tax liability |
|
$ |
57,577 |
|
|
$ |
12,981 |
|
|
|
|
|
|
|
|
Page
50
Our net deferred tax liability is reflected on our balance sheet as follows:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Deferred tax liabilities |
|
$ |
72,204 |
|
|
$ |
26,557 |
|
Current deferred assets |
|
|
(14,627 |
) |
|
|
(13,576 |
) |
|
|
|
|
|
|
|
Net deferred income tax liability |
|
$ |
57,577 |
|
|
$ |
12,981 |
|
|
|
|
|
|
|
|
We have $17 million of earnings of our Swiss subsidiary, Oceaneering International AG, that
we consider indefinitely reinvested outside the U.S. and that we do not expect to repatriate.
None of our foreign tax credits are scheduled to expire before December 31, 2018.
We currently have no valuation allowances for deferred tax assets. We conduct business
through several foreign subsidiaries and, although we expect our consolidated operations to
be profitable, there is no assurance that profits will be earned in entities or jurisdictions
that have NOLs available. Income taxes, computed by applying the federal statutory income
tax rate of 35% to income before income taxes, are reconciled to the actual provisions for
income taxes as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Computed U.S. statutory expense |
|
$ |
107,527 |
|
|
$ |
97,124 |
|
|
$ |
66,862 |
|
State and local taxes and other, net |
|
|
307 |
|
|
|
|
|
|
|
(461 |
) |
|
|
|
|
|
|
|
|
|
|
Total provision for income taxes |
|
$ |
107,834 |
|
|
$ |
97,124 |
|
|
$ |
66,401 |
|
|
|
|
|
|
|
|
|
|
|
Included in the line for state and local taxes and other, net, for 2008, 2007 and 2006 are
credits of $0.6 million, $1.1 million and $1.3 million, respectively, from resolution of tax
contingencies related to certain tax liabilities we recorded in prior years.
The following lists the earliest tax years open to examination by tax authorities where we
have significant operations:
|
|
|
|
|
Jurisdiction |
|
Periods |
United States |
|
|
2005 |
|
United Kingdom |
|
|
2006 |
|
Norway |
|
|
2000 |
|
Angola |
|
|
2003 |
|
Nigeria |
|
|
2002 |
|
Brazil |
|
|
2003 |
|
Australia |
|
|
2005 |
|
Canada |
|
|
2005 |
|
4. DEBT
Long-term Debt consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
6.72% Senior Notes |
|
$ |
40,000 |
|
|
$ |
60,000 |
|
Term Loan |
|
|
85,000 |
|
|
|
|
|
Revolving credit facility |
|
|
104,000 |
|
|
|
140,000 |
|
|
|
|
|
|
|
|
Long-term Debt |
|
$ |
229,000 |
|
|
$ |
200,000 |
|
|
|
|
|
|
|
|
We have $40 million aggregate principal amount of 6.72% Senior Notes outstanding and
scheduled to be paid in two remaining equal annual installments each September through 2010.
In September 2008, we signed a one-year, unsecured term loan agreement providing for
borrowings of up to $85 million. In October 2008, we borrowed the $85 million and used the
proceeds to repay borrowings under our revolving credit facility. Under the Term Loan, we
have the option to borrow at the London Interbank Offered Rate (LIBOR) plus a margin of
1.75% or at the agent banks prime rate plus 0.75%.
Page
51
As of December 31, 2008, we had a $300 million revolving credit facility under an agreement
(the Credit Agreement) that currently extends to January 2012. We have to pay a commitment
fee ranging from 0.125% to 0.175% on the unused portion of the facility, depending on our
debt-to-capitalization ratio. Under the Credit Agreement, we have the option to borrow at
LIBOR plus a margin ranging from 0.50% to 1.25%, depending on our debt-to-capitalization
ratio, or at the agent banks prime rate. At December 31, 2008, we had $104 million of
borrowings outstanding under the Credit Agreement and $196 million available for borrowing.
The weighted average interest rates on all our outstanding borrowings were 4.3% and 6.2% at
December 31, 2008 and 2007, respectively.
The 6.72% Senior Notes contain restrictive covenants as to minimum net worth,
debt-to-capitalization ratio, fixed charge coverage, interest coverage and restricted
payments. Restricted payments, which include dividends and treasury stock purchases, are
limited from April 1, 1998, on a net basis, to the sum of $25 million plus 50% of our
consolidated net income after April 1, 1998, plus cash proceeds from any sales of our common
stock. The Credit Agreement contains restrictive covenants as to debt-to-capitalization
ratio and interest coverage.
We have interest rate hedges in place on $100 million of floating rate debt under our
revolving credit facility for the period August 2008 to August 2011. The hedges fix
three-month LIBOR at 3.07% until August 2009 and at 3.31% for the period August 2009 to
August 2011. We estimated the fair value of the interest rate hedges to be a liability of
$4.2 million at December 31, 2008. This liability valuation was arrived at using a
discounted cash flow model, which we believe uses Level 2 inputs, and is reflected on our
balance sheet as $1.5 million in current accrued liabilities and $2.7 million in other
long-term liabilities.
Scheduled maturities of Long-term Debt outstanding as of December 31, 2008 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6.72% |
|
|
|
|
|
|
Revolving |
|
|
|
|
(in thousands) |
|
Notes |
|
|
Term Loan |
|
|
Credit |
|
|
Total |
|
|
|
2009 |
|
$ |
20,000 |
|
|
$ |
85,000 |
|
|
$ |
|
|
|
$ |
105,000 |
|
2010 |
|
|
20,000 |
|
|
|
|
|
|
|
|
|
|
|
20,000 |
|
2011 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2012 |
|
|
|
|
|
|
|
|
|
|
104,000 |
|
|
|
104,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
40,000 |
|
|
$ |
85,000 |
|
|
$ |
104,000 |
|
|
$ |
229,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Maturities in 2009 are not classified as current as of December 31, 2008, since we are able
and have the intent to extend the stated maturities by borrowing amounts equal to the 2009
maturities under the revolving credit facility, with a maturity date after one year.
We made cash interest payments, net of amounts capitalized, of $13.6 million, $15.2 million
and $13.2 million in 2008, 2007 and 2006, respectively.
5. COMMITMENTS AND CONTINGENCIES
Lease Commitments
At December 31, 2008, we occupied several facilities under noncancellable operating leases
expiring at various dates through 2025. Future minimum rentals under all of our operating
leases, including vessel rentals, are as follows:
|
|
|
|
|
(in thousands) |
|
|
|
|
|
|
2009 |
|
$ |
41,250 |
|
2010 |
|
|
28,351 |
|
2011 |
|
|
25,714 |
|
2012 |
|
|
24,088 |
|
2013 |
|
|
14,633 |
|
Thereafter |
|
|
36,016 |
|
|
|
|
|
Total Lease Commitments |
|
$ |
170,052 |
|
|
|
|
|
Page
52
The above table includes $71 million related to the five-year time charter of a vessel and
crew, which began in the third quarter of 2008. Rental expense, which includes hire of
vessels, specialized equipment and real estate rental, was approximately $79 million,
$82 million and $34 million for 2008, 2007 and 2006, respectively.
Insurance
We self-insure for workers compensation, maritime employers liability and comprehensive
general liability claims to levels we consider financially prudent, and carry insurance for
exposures beyond the self-insurance levels, which can be by occurrence or in the aggregate.
We determine the level of accruals 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 all known liabilities. We
establish an additional reserve for incidents incurred but not reported to us for each year
using management estimates and based on prior experience. We believe that 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.
Litigation
Various 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 the ultimate
liability, if any, that may result from these actions and claims will not materially affect
our results of operations, cash flow or financial position.
Letters of Credit
We had $23 million and $21 million in letters of credit outstanding as of December 31, 2008
and 2007, respectively, as guarantees in force for self-insurance requirements and various
performance and bid 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.
At December 31, 2008, we had interest rate swaps in place related to $100 million of debt
under our revolving credit agreement. The fair value of the interest rate swap is deferred
in accumulated other comprehensive income and is subsequently reclassified into earnings in
the periods in which the hedged interest payments on the variable rate debt affect earnings.
Other financial instruments that potentially subject us to concentrations of credit risk are
principally cash and cash equivalents and accounts receivable. The carrying values of cash
and cash equivalents and bank borrowings approximate their fair values due to the short
maturity of those instruments or the short-term duration of the associated interest rate
periods. 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.
We estimated the fair value of our $40 million of 6.72% Senior Notes to be approximately
equal to their face value as of December 31, 2008. We arrived at this estimate by computing
the present value of the future principal and interest payments using a yield-to-maturity
interest rate for securities of similar quality and term.
6. 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 and aerospace industries. Our
Oil and Gas business consists of Remotely Operated Vehicles (ROVs), Subsea Products, Subsea
Projects, Mobile Offshore Production Systems and Inspection. Our ROV segment provides
submersible vehicles operated from the surface to support offshore oil and gas exploration,
production and construction activities. Our Subsea Products segment supplies a variety of
built-to-order specialty subsea hardware. Our Subsea Projects segment provides multiservice
vessels, oilfield diving and support vessel operations, which are used primarily in
inspection, repair and
Page
53
maintenance and installation activities. Our Inspection segment
provides customers with a wide range of third-party inspection services to satisfy
contractual structural specifications, internal safety standards and regulatory requirements.
Our Mobile Offshore Production Systems segment provides offshore production facilities
through two mobile offshore production systems that we own and a 50%-owned entity, which owns
75% of another system. 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.
The table that follows presents Revenue, Income from Operations, Depreciation and
Amortization Expense and Equity Earnings of Unconsolidated Affiliates by business segment:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Revenue |
|
|
|
|
|
|
|
|
|
|
|
|
Oil and Gas |
|
|
|
|
|
|
|
|
|
|
|
|
Remotely Operated Vehicles |
|
$ |
625,921 |
|
|
$ |
531,381 |
|
|
$ |
410,256 |
|
Subsea Products |
|
|
649,857 |
|
|
|
521,937 |
|
|
|
364,510 |
|
Subsea Projects |
|
|
256,517 |
|
|
|
257,752 |
|
|
|
155,046 |
|
Inspection |
|
|
249,109 |
|
|
|
219,686 |
|
|
|
169,014 |
|
Mobile Offshore Production Systems |
|
|
39,274 |
|
|
|
50,103 |
|
|
|
52,931 |
|
|
|
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
1,820,678 |
|
|
|
1,580,859 |
|
|
|
1,151,757 |
|
Advanced Technologies |
|
|
156,743 |
|
|
|
162,221 |
|
|
|
128,441 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
1,977,421 |
|
|
$ |
1,743,080 |
|
|
$ |
1,280,198 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from Operations |
|
|
|
|
|
|
|
|
|
|
|
|
Oil and Gas |
|
|
|
|
|
|
|
|
|
|
|
|
Remotely Operated Vehicles |
|
$ |
190,343 |
|
|
$ |
144,242 |
|
|
$ |
111,022 |
|
Subsea Products |
|
|
96,046 |
|
|
|
92,804 |
|
|
|
53,645 |
|
Subsea Projects |
|
|
72,816 |
|
|
|
92,841 |
|
|
|
59,585 |
|
Inspection |
|
|
31,017 |
|
|
|
22,749 |
|
|
|
14,946 |
|
Mobile Offshore Production Systems |
|
|
6,730 |
|
|
|
11,048 |
|
|
|
16,001 |
|
|
|
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
396,952 |
|
|
|
363,684 |
|
|
|
255,199 |
|
Advanced Technologies |
|
|
9,773 |
|
|
|
14,458 |
|
|
|
11,585 |
|
Unallocated Expenses |
|
|
(89,167 |
) |
|
|
(88,519 |
) |
|
|
(72,448 |
) |
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
317,558 |
|
|
$ |
289,623 |
|
|
$ |
194,336 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and Amortization Expense |
|
|
|
|
|
|
|
|
|
|
|
|
Oil and Gas |
|
|
|
|
|
|
|
|
|
|
|
|
Remotely Operated Vehicles |
|
$ |
55,948 |
|
|
$ |
46,305 |
|
|
$ |
40,357 |
|
Subsea Products |
|
|
22,016 |
|
|
|
17,201 |
|
|
|
12,307 |
|
Subsea Projects |
|
|
11,129 |
|
|
|
9,111 |
|
|
|
6,642 |
|
Inspection |
|
|
3,691 |
|
|
|
3,137 |
|
|
|
2,449 |
|
Mobile Offshore Production Systems |
|
|
16,690 |
|
|
|
13,510 |
|
|
|
13,168 |
|
|
|
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
109,474 |
|
|
|
89,264 |
|
|
|
74,923 |
|
Advanced Technologies |
|
|
1,425 |
|
|
|
1,438 |
|
|
|
2,167 |
|
Unallocated Expenses |
|
|
4,130 |
|
|
|
3,074 |
|
|
|
3,366 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
115,029 |
|
|
$ |
93,776 |
|
|
$ |
80,456 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Equity Earnings of Unconsolidated Affiliates |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Mobile Offshore Production Systems |
|
$ |
1,894 |
|
|
$ |
3,779 |
|
|
$ |
11,213 |
|
Advanced Technologies |
|
|
25 |
|
|
|
251 |
|
|
|
838 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
1,919 |
|
|
$ |
4,030 |
|
|
$ |
12,051 |
|
|
|
|
|
|
|
|
|
|
|
Page
54
We determine income from operations for each business segment before interest income or
expense, other income (expense), minority interests and provision for income taxes. We do
not consider an allocation of these items to be practical.
Depreciation and amortization expense for Mobile Offshore Production Systems in 2008 includes
an impairment charge of $5.7 million to reduce our investment in the Ocean Pensador to fair
value.
During 2007, revenue from one customer, BP plc and subsidiaries, in our oil and gas business
segments accounted for 14% of our total consolidated revenue. No individual customer
accounted for more than 10% of our consolidated revenue during 2008 or 2006.
The following table presents Assets, Property and Equipment and Goodwill by business segment
as of the dates indicated:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
|
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Assets |
|
|
|
|
|
|
|
|
Oil and Gas |
|
|
|
|
|
|
|
|
Remotely Operated Vehicles |
|
$ |
636,913 |
|
|
$ |
550,040 |
|
Subsea Products |
|
|
578,617 |
|
|
|
518,790 |
|
Subsea Projects |
|
|
164,749 |
|
|
|
140,870 |
|
Inspection |
|
|
64,218 |
|
|
|
69,996 |
|
Mobile Offshore Production Systems |
|
|
111,406 |
|
|
|
128,969 |
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
1,555,903 |
|
|
|
1,408,665 |
|
Advanced Technologies |
|
|
43,259 |
|
|
|
42,185 |
|
Corporate and Other |
|
|
70,858 |
|
|
|
80,590 |
|
|
|
|
|
|
|
|
Total |
|
$ |
1,670,020 |
|
|
$ |
1,531,440 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property and Equipment, net |
|
|
|
|
|
|
|
|
Oil and Gas |
|
|
|
|
|
|
|
|
Remotely Operated Vehicles |
|
$ |
364,043 |
|
|
$ |
306,260 |
|
Subsea Products |
|
|
161,498 |
|
|
|
151,064 |
|
Subsea Projects |
|
|
97,873 |
|
|
|
95,476 |
|
Inspection |
|
|
10,628 |
|
|
|
9,526 |
|
Mobile Offshore Production Systems |
|
|
43,265 |
|
|
|
58,273 |
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
677,307 |
|
|
|
620,599 |
|
Advanced Technologies |
|
|
6,170 |
|
|
|
4,761 |
|
Corporate and Other |
|
|
13,953 |
|
|
|
12,747 |
|
|
|
|
|
|
|
|
Total |
|
$ |
697,430 |
|
|
$ |
638,107 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Goodwill |
|
|
|
|
|
|
|
|
Oil and Gas |
|
|
|
|
|
|
|
|
Remotely Operated Vehicles |
|
$ |
25,614 |
|
|
$ |
27,734 |
|
Subsea Products |
|
|
68,997 |
|
|
|
56,783 |
|
Inspection |
|
|
13,641 |
|
|
|
16,980 |
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
108,252 |
|
|
|
101,497 |
|
Advanced Technologies |
|
|
10,454 |
|
|
|
10,454 |
|
|
|
|
|
|
|
|
Total |
|
$ |
118,706 |
|
|
$ |
111,951 |
|
|
|
|
|
|
|
|
All assets specifically identified with a particular business segment have been segregated.
Cash and cash equivalents, certain other current assets, certain investments and other assets
have not been allocated to particular business segments and are included in Corporate and
Other.
Page
55
The following table presents Capital Expenditures by business segment for the periods
indicated:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Capital Expenditures |
|
|
|
|
|
|
|
|
|
|
|
|
Oil and Gas |
|
|
|
|
|
|
|
|
|
|
|
|
Remotely Operated Vehicles |
|
$ |
146,363 |
|
|
$ |
121,643 |
|
|
$ |
112,838 |
|
Subsea Products |
|
|
78,424 |
|
|
|
65,727 |
|
|
|
38,000 |
|
Subsea Projects |
|
|
12,730 |
|
|
|
27,901 |
|
|
|
23,620 |
|
Inspection |
|
|
6,558 |
|
|
|
14,801 |
|
|
|
3,353 |
|
Mobile Offshore Production Systems |
|
|
208 |
|
|
|
650 |
|
|
|
13,614 |
|
|
|
|
|
|
|
|
|
|
|
Total Oil and Gas |
|
|
244,283 |
|
|
|
230,722 |
|
|
|
191,425 |
|
Advanced Technologies |
|
|
2,806 |
|
|
|
621 |
|
|
|
1,137 |
|
Corporate and Other |
|
|
5,188 |
|
|
|
2,452 |
|
|
|
1,280 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
252,277 |
|
|
$ |
233,795 |
|
|
$ |
193,842 |
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures in the table above include the costs of business acquisitions.
Geographic Operating Areas
The following table summarizes certain financial data by geographic area:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Revenue |
|
|
|
|
|
|
|
|
|
|
|
|
Foreign: |
|
|
|
|
|
|
|
|
|
|
|
|
West Africa |
|
$ |
284,523 |
|
|
$ |
225,879 |
|
|
$ |
151,580 |
|
United Kingdom |
|
|
251,660 |
|
|
|
242,680 |
|
|
|
156,328 |
|
Norway |
|
|
231,632 |
|
|
|
176,467 |
|
|
|
105,373 |
|
Brazil |
|
|
116,919 |
|
|
|
78,662 |
|
|
|
46,925 |
|
Asia |
|
|
108,090 |
|
|
|
90,223 |
|
|
|
55,481 |
|
Other |
|
|
69,755 |
|
|
|
66,749 |
|
|
|
84,150 |
|
|
|
|
|
|
|
|
|
|
|
Total Foreign |
|
|
1,062,579 |
|
|
|
880,660 |
|
|
|
599,837 |
|
United States |
|
|
914,842 |
|
|
|
862,420 |
|
|
|
680,361 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
1,977,421 |
|
|
$ |
1,743,080 |
|
|
$ |
1,280,198 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-Lived Assets |
|
|
|
|
|
|
|
|
|
|
|
|
Foreign: |
|
|
|
|
|
|
|
|
|
|
|
|
Europe |
|
$ |
199,703 |
|
|
$ |
180,911 |
|
|
$ |
120,321 |
|
West Africa |
|
|
88,895 |
|
|
|
81,647 |
|
|
|
69,230 |
|
Australia |
|
|
32,620 |
|
|
|
40,091 |
|
|
|
47,589 |
|
Brazil |
|
|
32,745 |
|
|
|
25,447 |
|
|
|
22,133 |
|
Asia |
|
|
45,462 |
|
|
|
37,380 |
|
|
|
14,319 |
|
Other |
|
|
17,197 |
|
|
|
7,551 |
|
|
|
8,844 |
|
|
|
|
|
|
|
|
|
|
|
Total Foreign |
|
|
416,622 |
|
|
|
373,027 |
|
|
|
282,436 |
|
United States |
|
|
486,264 |
|
|
|
462,109 |
|
|
|
408,979 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
902,886 |
|
|
$ |
835,136 |
|
|
$ |
691,415 |
|
|
|
|
|
|
|
|
|
|
|
Revenue is based on location where services are performed and products are manufactured.
Page
56
Additional Income Statement Detail
The following schedule shows our revenue, costs and gross margins by services and products:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, |
(in thousands) |
|
2008 |
|
|
2007 |
|
|
2006 |
|
|
Revenue: |
|
|
|
|
|
|
|
|
|
|
|
|
Services |
|
$ |
1,311,149 |
|
|
$ |
1,193,797 |
|
|
$ |
893,335 |
|
Products |
|
|
666,272 |
|
|
|
549,283 |
|
|
|
386,863 |
|
|
|
|
|
|
|
|
|
|
|
Total revenue |
|
|
1,977,421 |
|
|
|
1,743,080 |
|
|
|
1,280,198 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of Services and Products: |
|
|
|
|
|
|
|
|
|
|
|
|
Services |
|
|
935,752 |
|
|
|
860,582 |
|
|
|
634,243 |
|
Products |
|
|
513,643 |
|
|
|
405,115 |
|
|
|
304,028 |
|
Unallocated expenses |
|
|
63,226 |
|
|
|
64,098 |
|
|
|
45,806 |
|
|
|
|
|
|
|
|
|
|
|
Total cost of services and products |
|
|
1,512,621 |
|
|
|
1,329,795 |
|
|
|
984,077 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross margin: |
|
|
|
|
|
|
|
|
|
|
|
|
Services |
|
|
375,397 |
|
|
|
333,215 |
|
|
|
259,092 |
|
Products |
|
|
152,629 |
|
|
|
144,168 |
|
|
|
82,835 |
|
Unallocated expenses |
|
|
(63,226 |
) |
|
|
(64,098 |
) |
|
|
(45,806 |
) |
|
|
|
|
|
|
|
|
|
|
Total gross margin |
|
$ |
464,800 |
|
|
$ |
413,285 |
|
|
$ |
296,121 |
|
|
|
|
|
|
|
|
|
|
|
7. ACCRUED LIABILITIES AND OTHER LONG-TERM LIABILITIES
Accrued liabilities and other long-term liabilities consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
December 31, |
(in thousands) |
|
2008 |
|
|
2007 |
|
|
Accrued Liabilities: |
|
|
|
|
|
|
|
|
Payroll and related costs |
|
$ |
143,613 |
|
|
$ |
135,807 |
|
Accrued job costs |
|
|
62,112 |
|
|
|
48,814 |
|
Deferred revenue, including billings in excess of revenue recognized |
|
|
17,559 |
|
|
|
28,770 |
|
Self-insurance reserves for claims expected to be paid within one year |
|
|
2,670 |
|
|
|
1,775 |
|
Other |
|
|
18,081 |
|
|
|
20,582 |
|
|
|
|
|
|
|
|
Total Accrued Liabilities |
|
$ |
244,035 |
|
|
$ |
235,748 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Long-Term Liabilities: |
|
|
|
|
|
|
|
|
Deferred income taxes |
|
$ |
72,204 |
|
|
$ |
26,557 |
|
Supplemental Executive Retirement Plan |
|
|
16,921 |
|
|
|
22,444 |
|
Accrued post-employment benefit obligations |
|
|
11,178 |
|
|
|
13,396 |
|
Self-insurance reserves not expected to be paid within one year |
|
|
5,085 |
|
|
|
7,019 |
|
Other |
|
|
10,651 |
|
|
|
7,739 |
|
|
|
|
|
|
|
|
Total Other Long-Term Liabilities |
|
$ |
116,039 |
|
|
$ |
77,155 |
|
|
|
|
|
|
|
|
8. EMPLOYEE BENEFIT PLANS AND SHAREHOLDER RIGHTS PLAN
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 $12.9 million,
$9.6 million and $7.6 million for the plan years ended December 31, 2008, 2007 and 2006,
respectively.
Page
57
We also make matching contributions to other foreign employee savings plans similar in nature
to a 401(k) plan. In 2008, 2007 and 2006, these contributions, principally related to plans
associated with U.K. and Norwegian subsidiaries, were $5.1 million, $3.8 million and
$3.5 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 participants 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 2008, 2007 and 2006 were $2.6 million, $2.9 million and
$3.2 million, respectively.
We have defined benefit plans covering some of our employees in the U.K. and Norway. There
are no further benefits accruing under the U.K. plan, and the Norway plan is closed to new
participants. In accordance with SFAS No. 158, in 2006 we recognized the funded status of
the Norwegian plan by recording an adjustment to accumulated other comprehensive income
(loss) of ($1.5 million), net of tax of $0.8 million. The projected benefit obligations for
both plans were $17 million and $24 million, at December 31, 2008 and 2007, respectively, and
the fair values of the plan assets for both plans were $12 million and $16 million at
December 31, 2008 and 2007, respectively.
Incentive and Stock Option Plans
Under our 2005 Incentive Plan (the Incentive Plan), a total of 2,400,000 shares of our
common stock was 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 or types 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.
Options outstanding under the Incentive Plan and prior plans vest over a six-month or a
three-year period and are exercisable over a period of five or seven years after the date of
grant. Under the Incentive Plan, a stock option must have a term not exceeding seven years
from the date of grant and must have an exercise price of not less than the fair market value
of a share of our common stock on the date of grant. The Compensation Committee may not:
(1) grant, in exchange for a stock option, a new stock option having a lower exercise price;
or (2) reduce the exercise price of a stock option. In light of the expense recognition
requirements established by SFAS 123R, which we adopted effective as of January 1, 2006, 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.
In 2008, 2007 and 2006, the Compensation Committee granted awards of performance units under
the Incentive Plan to certain of our key executives and employees. In 2008 and 2007, our
Board of Directors granted awards of performance units under the Incentive Plan to our
Chairman of the Board. 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 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, 2010, 2009 and 2008 to be used as the
basis for the final value of the performance units. The final value of each performance unit
may range from $0 to $125. Upon vesting and determination of value, the value of the
performance units will be payable in cash. As of December 31, 2008, there were 296,267
performance units outstanding.
Page
58
The following is a summary of our stock option activity for the three years ended
December 31, 2008:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
|
|
|
|
Shares |
|
|
Average |
|
|
Aggregate |
|
|
|
under |
|
|
Exercise |
|
|
Intrinsic |
|
|
|
Option |
|
|
Price |
|
|
Value |
|
Balance at December 31, 2005 |
|
|
1,313,450 |
|
|
$ |
13.91 |
|
|
|
|
|
Granted |
|
|
|
|
|
|
|
|
|
|
|
|
Exercised |
|
|
(624,300 |
) |
|
|
13.24 |
|
|
$ |
14,589,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited |
|
|
(25,900 |
) |
|
|
12.20 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2006 |
|
|
663,250 |
|
|
|
14.61 |
|
|
|
|
|
Granted |
|
|
|
|
|
|
|
|
|
|
|
|
Exercised |
|
|
(374,850 |
) |
|
|
14.08 |
|
|
$ |
15,125,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited |
|
|
(2,400 |
) |
|
|
11.58 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2007 |
|
|
286,000 |
|
|
|
15.32 |
|
|
|
|
|
Granted |
|
|
|
|
|
|
|
|
|
|
|
|
Exercised |
|
|
(130,100 |
) |
|
|
13.27 |
|
|
$ |
7,125,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited |
|
|
(3,000 |
) |
|
|
13.51 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2008 |
|
|
152,900 |
|
|
$ |
17.11 |
|
|
$ |
1,839,000 |
|
|
|
|
|
|
|
|
|
|
|
The following table provides information about the options outstanding at December 31, 2008.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding |
|
Exercisable |
|
|
|
|
|
|
Weighted |
|
|
|
|
|
|
|
|
Number of |
|
Average |
|
Weighted |
|
Number of |
|
Weighted |
|
|
Shares at |
|
Remaining |
|
Average |
|
Shares at |
|
Average |
|
|
December 31, |
|
Contractual |
|
Exercise |
|
December 31, |
|
Exercise |
Range
of Exercise Prices |
|
2008 |
|
Life (years) |
|
Price |
|
2008 |
|
Price |
$14.48 16.06 |
|
|
50,900 |
|
|
|
0.3 |
|
|
$ |
15.45 |
|
|
|
50,900 |
|
|
$ |
15.45 |
|
$16.07 16.96 |
|
|
41,000 |
|
|
|
3.4 |
|
|
$ |
16.90 |
|
|
|
41,000 |
|
|
$ |
16.90 |
|
$16.97 18.64 |
|
|
61,000 |
|
|
|
1.0 |
|
|
$ |
18.64 |
|
|
|
61,000 |
|
|
$ |
18.64 |
|
The aggregate intrinsic value of our exercisable stock options was $1.8 million at
December 31, 2008. We received $1.7 million, $5.3 million and $8.3 million from the exercise
of stock options in 2008, 2007 and 2006, respectively. The excess tax benefit realized from
tax deductions from stock options for 2008, 2007 and 2006 was $2.0 million, $4.6 million and
$4.2 million, respectively. SFAS No. 123R requires that excess tax benefits from share-based
compensation be classified as a cash outflow in cash flows from operating activities and an
inflow in cash flows from financing activities in the statement of cash flows.
Restricted Stock Plan Information
During 2008, 2007 and 2006, the Compensation Committee granted restricted units of our common
stock to certain of our key executives and employees. During 2008 and 2007, our Board of
Directors granted restricted units of our common stock to our Chairman of the Board of
Directors and restricted common stock to our other nonemployee directors. During 2006, our
Board of Directors granted restricted common stock to our nonemployee directors. Over 70% of
the grants made in 2008, 2007 and 2006 to our employees 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 made to our Chairman of the Board of Directors can vest pro
rata over three years, provided the participant meets certain age and years-of-service
requirements. For the grants to each of the participant employees and the Chairman of our
Board of Directors, the participant will be issued a share of our common stock for the
participants vested common stock units at the earlier of three years or, if the participant
vested earlier after meeting the age and service requirements, at termination of employment
or service. The grants to our nonemployee directors vest in full on the first anniversary of
the award date conditional upon continued service as a director. Pursuant to grants of
restricted common stock units to our employees made prior to 2005, at the time of each
vesting, a participant receives a tax-assistance payment. Our tax-assistance payments were
$8.9 million in 2008, $7.0 million in 2007
and $7.3 million in 2006. The tax benefit realized from tax deductions in excess of
financial statement expense was $4.8 million, $3.4 million and $3.2 million in 2008, 2007 and
2006, respectively.
Page
59
The following is a summary of our unvested restricted stock and restricted stock units for
2008, 2007 and 2006:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
|
|
|
|
|
|
|
|
Average |
|
|
Aggregate |
|
|
|
|
|
|
|
Fair Value |
|
|
Intrinsic |
|
|
|
Shares |
|
|
at Grant Date |
|
|
Value |
|
Balance at December 31, 2005 |
|
|
1,016,700 |
|
|
$ |
9.47 |
|
|
|
|
|
Granted |
|
|
233,900 |
|
|
|
28.67 |
|
|
|
|
|
Issued |
|
|
(304,800 |
) |
|
|
9.03 |
|
|
$ |
13,131,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited |
|
|
(28,550 |
) |
|
|
10.81 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2006 |
|
|
917,250 |
|
|
|
14.47 |
|
|
|
|
|
Granted |
|
|
245,750 |
|
|
|
41.05 |
|
|
|
|
|
Issued |
|
|
(259,933 |
) |
|
|
12.02 |
|
|
$ |
13,770,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited |
|
|
(17,617 |
) |
|
|
25.44 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2007 |
|
|
885,450 |
|
|
|
22.35 |
|
|
|
|
|
Granted |
|
|
206,875 |
|
|
|
62.24 |
|
|
|
|
|
Issued |
|
|
(256,600 |
) |
|
|
13.62 |
|
|
$ |
17,880,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited |
|
|
(10,975 |
) |
|
|
46.83 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2008 |
|
|
824,750 |
|
|
$ |
34.75 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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. The restricted stock units granted in 2008, 2007 and 2006 carry no voting
rights, but they carry a dividend right should we pay dividends on our common stock.
Effective with our adoption of SFAS No. 123R at January 1, 2006, the unvested portions of our
grants of restricted stock units were valued at their estimated fair values as of their
respective grant dates. For grants made prior to 2006, we used a Black-Scholes methodology
to produce a Monte Carlo simulation model, which allows for the incorporation of the
performance criteria that had to be met before the awards were earned by the holders. The
valuations allowed for variables, such as volatility, the risk-free interest rate, dividends
and performance hurdles. The assumptions used for the grants prior to 2006 were: expected
volatility of 50% (based on historic analysis), risk-free interest rate of 2% and no
dividends. The grants in 2008, 2007 and 2006 were subject only to vesting conditioned on
continued employment; 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 $23.0 million, $25.0 million and
$17.0 million for 2008, 2007 and 2006, respectively. As of December 31, 2008, we had
$8.9 million of future expense to be recognized related to our restricted stock unit plans
over a weighted average remaining life of 1.7 years.
Stockholder Rights Plan
We adopted a Stockholder Rights Plan on November 20, 1992, which was amended and restated as
of November 16, 2001. Each Right initially entitles the holder to purchase from us a
fractional share consisting of one two-hundredth of a share of Series B Junior Participating
Preferred Stock, at a purchase price of $30 per fractional share, subject to adjustment. The
Rights generally will not become exercisable until ten days after a public announcement that
a person or group has acquired 15% or more of our common stock (thereby becoming an
Acquiring Person) or the commencement of a tender or exchange offer that would result in a
person or group becoming an Acquiring Person (the earlier of such dates being called the
Distribution Date). Rights were issued and will continue to be issued with all shares of
our common stock that are issued until the Distribution Date. Until the Distribution Date,
the Rights will be evidenced by the certificates representing our common stock and will be
transferable only with our common stock. Generally, if any person or group becomes an
Acquiring Person, each Right, other than Rights beneficially owned by the Acquiring Person
(which will thereupon become void), will thereafter entitle its holder to purchase, at the
Rights then-current exercise price, shares of our common stock having a market value of two
times the exercise price of the Right. At any time until ten days after a public
announcement that the Rights have been triggered, we will generally be entitled to redeem the
Rights for $0.01 and to amend the Rights in any manner other than certain specified
exceptions. Certain subsequent amendments are also permitted. The Rights expire on November
20, 2011.
Post-Employment Benefit
In November 2001, we entered into an agreement with our Chairman (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
Page
60
relinquished his position as Chief Executive Officer in May 2006 and began his
post-employment service period on December 31, 2006. The agreement provides for a specific
service period ending no later than August 15, 2011, during which the Chairman, acting as an
independent contractor, has agreed to serve as nonexecutive Chairman of our Board of
Directors for so long as our Board of Directors desires that he shall continue to serve in
that capacity. The agreement provides the Chairman with post-employment benefits for ten
years following the sooner to occur of August 15, 2011 or the termination of his services to
us. The amendment in 2006 included a lump-sum cash buyout, paid in 2007, of the Chairmans
entitlement to perquisites and administrative assistance during that ten-year period
(expected to run from 2011 to 2021). As a result, we recorded $2.8 million of associated
expense in the fourth quarter of 2006. The agreement also provides for medical coverage on
an after-tax basis to the Chairman, his spouse and children during his service with us and
thereafter for their lives. We are recognizing the net present value of the post-employment
benefits over the expected service period. If the service period is terminated for any
reason (other than the Chairmans refusal to continue serving), we will recognize all the
previously unaccrued benefits in the period in which that termination occurs. Our total
accrued liabilities, current and long-term, under this post-employment benefit were
$5.6 million and $4.8 million at December 31, 2008 and 2007, respectively.
As part of the arrangements relating to the Chairmans 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)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2008 |
Quarter Ended |
|
March 31 |
|
June 30 |
|
Sept. 30 |
|
Dec. 31 |
|
Total |
|
Revenue |
|
$ |
435,815 |
|
|
$ |
500,120 |
|
|
$ |
515,795 |
|
|
$ |
525,691 |
|
|
$ |
1,977,421 |
|
Gross profit |
|
|
98,666 |
|
|
|
118,290 |
|
|
|
127,596 |
|
|
|
120,248 |
|
|
|
464,800 |
|
Income from operations |
|
|
64,770 |
|
|
|
81,465 |
|
|
|
89,697 |
|
|
|
81,626 |
|
|
|
317,558 |
|
Net income |
|
|
41,279 |
|
|
|
52,123 |
|
|
|
54,975 |
|
|
|
51,009 |
|
|
|
199,386 |
|
Diluted earnings per share |
|
$ |
0.74 |
|
|
$ |
0.93 |
|
|
$ |
0.99 |
|
|
$ |
0.93 |
|
|
$ |
3.58 |
|
Weighted average number of
common shares and equivalents |
|
|
55,978 |
|
|
|
56,069 |
|
|
|
55,794 |
|
|
|
55,053 |
|
|
|
55,722 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2007 |
Quarter Ended |
|
March 31 |
|
June 30 |
|
Sept. 30 |
|
Dec. 31 |
|
Total |
|
Revenue |
|
$ |
344,004 |
|
|
$ |
432,041 |
|
|
$ |
485,424 |
|
|
$ |
481,611 |
|
|
$ |
1,743,080 |
|
Gross profit |
|
|
79,602 |
|
|
|
106,010 |
|
|
|
117,513 |
|
|
|
110,160 |
|
|
|
413,285 |
|
Income from operations |
|
|
53,536 |
|
|
|
76,298 |
|
|
|
85,605 |
|
|
|
74,184 |
|
|
|
289,623 |
|
Net income |
|
|
33,166 |
|
|
|
47,873 |
|
|
|
53,853 |
|
|
|
45,482 |
|
|
|
180,374 |
|
Diluted earnings per share |
|
$ |
0.60 |
|
|
$ |
0.86 |
|
|
$ |
0.96 |
|
|
$ |
0.81 |
|
|
$ |
3.24 |
|
Weighted average number of
common shares and equivalents |
|
|
55,474 |
|
|
|
55,678 |
|
|
|
55,821 |
|
|
|
55,934 |
|
|
|
55,755 |
|
Page
61
Exhibit Index
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Registration |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
or File |
|
Form of |
|
Report |
|
Exhibit |
|
|
|
|
|
|
|
|
Number |
|
Report |
|
Date |
|
Number |
*
|
|
|
3.01 |
|
|
Restated Certificate of Incorporation
|
|
1-10945
|
|
10-K
|
|
Dec. 2000
|
|
|
3.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
3.02 |
|
|
Certificate of Amendment to Restated Certificate of Incorporation
|
|
1-10945
|
|
8-K
|
|
May 2008
|
|
|
3.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
3.03 |
|
|
Amended and Restated Bylaws
|
|
1-10945
|
|
8-K
|
|
Dec. 2007
|
|
|
3.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
4.01 |
|
|
Specimen of Common Stock Certificate
|
|
1-10945
|
|
10-K
|
|
March 1993
|
|
|
4 |
(a) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
4.02 |
|
|
Amended and Restated Shareholder Rights Agreement dated
as of November 16,h 2001
|
|
1-10945
|
|
8-K
|
|
Nov. 2001
|
|
|
4.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
4.03 |
|
|
Note Purchase Agreement dated as of September 8, 1998 relating to
$100,000,000 6.72% Senior Notes due September 8, 2010
|
|
1-10945
|
|
10-Q
|
|
Sept. 1998
|
|
|
4.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
4.04 |
|
|
Amended and Restated Credit Agreement ($250,000,000 Revolving
Credit Facility with Accordion to $300,000,000) dated as of
January 2, 2004
|
|
1-10945
|
|
10-K
|
|
Dec. 2003
|
|
|
4.05 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
4.05 |
|
|
First Amendment to Amended and Restated Credit Agreement
dated January 22, 2007
|
|
1-10945
|
|
8-K
|
|
Jan. 2007
|
|
|
4.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
4.06 |
|
|
$85,000,000 Credit Agreement dated as of September 31, 2008
among Oceaneering International, Inc., Wells Fargo Bank, N.A. as
Administrative Agent and lender and other lender parties or to
become lender parties thereto
|
|
1-10945
|
|
8-K
|
|
Sept. 2008
|
|
|
4.1 |
|
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+ |
|
|
Defined Contribution Master Plan and Trust Agreement and
Adoption Agreement for the Oceaneering International, Inc.
Retirement Investment Plan
|
|
1-10945
|
|
10-K
|
|
Dec. 2001
|
|
|
10.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.02+ |
|
|
Amended and Restated Service Agreement dated as of
December 21, 2006 between Oceaneering and John R. Huff
|
|
1-10945
|
|
8-K
|
|
Dec. 2006
|
|
|
10.01 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.03+ |
|
|
Modification to Service Agreement dated as of December 21, 2006 between
Oceaneering and John R. Huff |
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.9 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.04+ |
|
|
Trust Agreement dated as of May 12, 2006 between Oceaneering
and United Trust Company, National Association
|
|
1-10945
|
|
8-K
|
|
May 2006
|
|
|
10.02 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.05+ |
|
|
First Amendment to Trust Agreement dated as of May 12, 2006 between
Oceaneering International, Inc. and Bank of America National Association,
as successor trustee
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.10 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.06+ |
|
|
2002 Non-Executive Incentive Plan
|
|
1-10945
|
|
10-Q
|
|
Sept. 2002
|
|
|
10.03 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.07+ |
|
|
First Amendment to 2002 Non-Executive Incentive Plan of Oceaneering
International, Inc. |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.08+ |
|
|
Oceaneering International, Inc. Supplemental Executive Retirement Plan, as
amended and restated effective January 1, 2009
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.09+ |
|
|
Amended and Restated Oceaneering International, Inc. Supplemental Executive
Retirement Plan, as amended and restated effective January 1, 2000
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.6 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.10+ |
|
|
Change-of-Control Agreements dated as of November 16, 2001
between Oceaneering and John R. Huff, T. Jay Collins, Marvin J.
Migura, M. Kevin McEvoy and George R. Haubenreich, Jr.
|
|
1-10945
|
|
10-K
|
|
Dec. 2001
|
|
|
10.06 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.11+ |
|
|
Form of First Amendment to Change-of-Control Agreement with T. Jay Collins,
M. Kevin McEvoy, Marvin J. Migura and George R. Haubenreich, Jr.
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.7 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.12+ |
|
|
First Amendment to Change-of-Control Agreement with John R. Huff.
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.8 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.13+ |
|
|
Oceaneering International, Inc. 2008 Cash Bonus Award Program
|
|
1-10945
|
|
10-Q
|
|
Mar. 2008
|
|
|
10.07 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.14+ |
|
|
Form of Indemnification Agreement dated November 16, 2001
between Oceaneering and each of its Directors,
Marvin J. Migura, M. Kevin McEvoy and George R.
Haubenreich, Jr.
|
|
1-10945
|
|
10-K
|
|
Dec. 2001
|
|
|
10.12 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.15+ |
|
|
2002 Incentive Plan
|
|
1-10945
|
|
10-Q
|
|
June 2002
|
|
|
10.01 |
|
Page
62
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.16+ |
|
|
First Amendment to 2002 Incentive Plan of Oceaneering International, Inc.
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.17+ |
|
|
Amended and Restated 2002 Restricted Stock Unit Award Agreements with John
R Huff and Executive Officers
|
|
1-10945
|
|
10-Q
|
|
Sept. 2002
|
|
|
10.04 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.18+ |
|
|
Form of First Amendment to Oceaneering International, Inc. Amended and
Restated 2002 Restricted Stock Unit Award Incentive Agreement with
Executive Officers
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.19+ |
|
|
First Amendment to Oceaneering International, Inc. Amended and Restated
2002 Restricted Stock Unit Award Incentive Agreement with John R. Huff
|
|
1-10945
|
|
10-Q
|
|
Dec. 2008
|
|
|
10.4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.20+ |
|
|
2005 Incentive Plan
|
|
333-124947
|
|
S-8
|
|
May 2005
|
|
|
4.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.21+ |
|
|
First Amendment to 2005 Incentive Plan of Oceaneering International, Inc.
|
|
1-10945
|
|
8-K
|
|
Dec. 2008
|
|
|
10.1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
|
10.22+ |
|
|
Form of 2006 Employee Restricted Stock Unit Agreement
for John R. Huff and Executive Officers
|
|
1-10945
|
|
8-K
|
|
Feb. 2006
|
|
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10.1 |
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*
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10.23+ |
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Form of 2006 Performance Unit Agreement for John R. Huff,
and Executive Officers
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1-10945
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8-K
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Feb. 2006
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10.2 |
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*
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10.24+ |
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2006 Performance Award: Goals and Measures, relating to the
Form of 2006 Performance Unit Agreement
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1-10945
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8-K
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Feb. 2006
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10.3 |
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*
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10.25+ |
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Form of 2007 Employee Restricted Stock Unit Agreement
for Executive Officers
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1-10945
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8-K
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Feb. 2007
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10.1 |
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*
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10.26+ |
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Form of 2007 Chairman Restricted Stock Unit Agreement
for John R. Huff
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1-10945
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8-K
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Feb. 2007
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10.3 |
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*
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10.27+ |
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Form of 2007 Performance Unit Agreement for
Executive Officers
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1-10945
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8-K
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Feb. 2007
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10.2 |
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*
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10.28+ |
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Form of 2007 Chairman Performance Unit Agreement
for John R. Huff
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1-10945
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8-K
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Feb. 2007
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10.4 |
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*
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10.29+ |
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2007 Performance Award: Goals and Measures, relating to the
Form of 2007 Performance Unit Agreement and Form of
Chairman Performance Unit Agreement
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1-10945
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8-K
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Feb. 2007
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10.5 |
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*
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10.30+ |
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Form of 2008 Employee Restricted Stock Unit Agreement
for Executive Officers
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1-10945
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8-K
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Feb. 2008
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10.1 |
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*
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10.31+ |
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Form of 2008 Nonemployee Director Restricted Stock Agreement
for
Harris J. Pappas
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1-10945
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8-K
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Feb. 2008
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10.6 |
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*
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10.32+ |
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Form of 2008 Chairman Restricted Stock Unit Agreement
for John R. Huff
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1-10945
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8-K
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Feb. 2008
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10.3 |
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*
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10.33+ |
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Form of 2008 Performance Unit Agreement for
Executive Officers
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1-10945
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8-K
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Feb. 2008
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10.2 |
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*
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10.34+ |
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Form of 2008 Chairman Performance Unit Agreement
for John R. Huff
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1-10945
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8-K
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Feb. 2008
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10.4 |
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*
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10.35+ |
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2008 Performance Award: Goals and Measures, relating to the
Form of 2008 Performance Unit Agreement and Form of
Chairman Performance Unit Agreement
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1-10945
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8-K
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Feb. 2008
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10.5 |
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10.36+ |
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Form of 2009 Employee Restricted Stock Unit Agreement for Executive Officers
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1-10945
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8-K
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Feb. 2009
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10.1 |
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10.37+ |
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Form of 2009 Nonemployee Director Restricted Stock Unit Agreement for
Jerold J. DesRoche, David S. Hooker, D. Michael Hughes and Harris J. Pappas
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1-10945
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8-K
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Feb. 2009
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10.6 |
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10.38+ |
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Form of 2009 Chairman Restricted Stock Unit Agreement for John R. Huff
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1-10945
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8-K
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Feb. 2009
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10.3 |
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10.39+ |
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Form of 2009 Performance Unit Agreement for Executive Officers
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1-10945
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8-K
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Feb. 2009
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10.2 |
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10.40+ |
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Form of 2009 Chairman Performance
Unit Agreement for John R. Huff
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1-10945
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8-K
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Feb. 2009
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10.4 |
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10.41+ |
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2009 Performance Award: Goals and Measures, relating to the form of 2009
Performance Unit Agreement and 2009 Chairman Performance Unit Agreement
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1-10945
|
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8-K
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Feb. 2009
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10.5 |
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Page
63
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21.01 |
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Subsidiaries of Oceaneering |
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23.01 |
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Consent of Independent Registered Public Accounting Firm |
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31.01 |
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Rule 13a 14(a)/15d 14(a) certification of Chief Executive Officer |
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31.02 |
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Rule 13a 14(a)/15d 14(a) certification of Chief Financial Officer |
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32.01 |
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Section 1350 certification of Chief Executive Officer |
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32.02 |
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Section 1350 certification of Chief Financial Officer |
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* |
|
Exhibit previously filed with the Securities and Exchange Commission, as indicated, and incorporated herein by reference. |
|
+ |
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Management contract or compensatory plan or arrangement. |
Page
64