Investor Presentation
November 2019
Oceaneering1 .com
Forward‐Looking Statements
In accordance with the Safe Harbor provisions of the Private Securities Litigation Reform Act of 1995, Oceaneering cautions that statements in this presentation that express a belief, expectation, or intention are forward looking. 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.
The forward‐looking statements in this presentation include, among other things, statements about: offshore activity levels and the long‐term outlook for offshore, including expectations about Brent crude prices and subsea expenditures, offshore drilling activity, the contracted floating rig count, and subsea tree installations; expectations relating to our non‐energy segment, participation in offshore renewables, durations of new contract tenders; our future operations, our forecast market share, our outlook for the fourth quarter 2019, including at each reporting segment level, and the factors underlying our outlook; our Subsea Products backlog, to the extent backlog may be viewed as an indicator of future revenue or profitability; our expectations about umbilical and hardware order intake and our book‐to‐bill ratio for 2019; our expectations about the Ecosse acquisition; our full‐year 2019 and 2020 outlook information, including as to
free cash flow, adjusted EBITDA, capital expenditures, and unallocated expenses; and our focus on generating positive free cash flow, maintaining our strong liquidity position, improving our returns and maintaining our superior safety performance and quality. Although we believe that the expectations reflected in those forward‐ looking statements are reasonable, we can give no assurance that those expectations will prove to have been correct. Those statements are made by using various underlying assumptions and are subject to numerous risks, contingencies and uncertainties, including, among others: factors affecting the level of activity in the oil and gas industry; supply and demand of drilling rigs; oil and natural gas demand and production growth; oil and natural gas prices; fluctuations in currency markets worldwide; future global economic conditions; the loss of major contracts or alliances; future performance under our customer contracts; and the effects of competition. Should one or more of these risks or uncertainties materialize, or should the assumptions underlying the forward‐looking statements prove incorrect, actual outcomes could vary materially from those indicated.
For additional information regarding these and other factors that may affect our actual results, see our periodic filings with the Securities and Exchange Commission, including our most recent Reports on Forms 10‐K and 10‐Q.
You should not place undue reliance on forward‐looking statements. This presentation reflects the views of Oceaneering's management as of the date hereof. Except to the extent required by applicable law, Oceaneering undertakes no obligation to update or revise any forward‐looking statement.
Non‐GAAP Disclosures:
This presentation includes several "non‐GAAP" financial measures, as defined under Regulation G of the U.S. Securities Exchange Act of 1934, as amended. Oceaneering reports its financial results in accordance with U.S. generally accepted accounting principles, but believes that certain non‐GAAP financial measures provide useful supplemental information to investors regarding the underlying business trends and performance of its ongoing operations and are useful for period‐over‐period comparisons of those operations. The non‐GAAP measures in this presentation include EBITDA, Adjusted EBITDA, Adjusted Operating EBITDA and Free Cash Flow. These non‐GAAP financial measures should be considered as supplemental to, and not as substitutes for or superior to, the financial measures prepared in accordance with GAAP. The definitions of these non‐ GAAP financial measures and reconciliations to the most comparable GAAP measures are provided in the Supplemental Information section of this presentation, beginning on page 34.
2
Reasons to Own Oceaneering
- Increasing offshore activity levels
- Growing non‐energy segment
- Provider of integrated technology solutions
- Strong portfolio of diversified services and products, and market positions
- Geographically dispersed asset base and revenue streams
- Blue‐chip customer base
- Focus on eco‐friendly enabling opportunities
- Increasing participation in offshore renewables
3
Another Reason to Own Oceaneering ‐ Sustainability
Managing our business in a way that promotes:
- Safety and Health
- Environmental Sustainability
- Community Relations
- Workforce Diversity, and
- Ethics and Compliance
4
Five Operating Segments
Energy:
Remotely Operated Vehicles (ROV)
Subsea Products
Subsea Projects
Asset Integrity
Non‐Energy:
Advanced Technologies
5
Active in All Phases of the Offshore Oilfield Life Cycle
Phase | Exploration | Development | Production | Decommissioning |
% of Oceaneering Revenue* | 17% | 44% | 36% | 3% |
Market Driver | Floating | |
Drilling Rigs | ||
Business Segment and | • | ROV Services |
• | Survey (SP) | |
Product and Service | ||
• | Tooling (SSP) | |
Revenue Streams | ||
KEY | ||
ROV = Remotely Operated | ||
Vehicles | ||
SSP = Subsea Products | ||
SP = Subsea Projects | ||
AI = Asset Integrity |
*Estimates as of December 31, 2018.
Subsea Tree
Installations
- ROV Services
- Survey (SP)
- Tooling (SSP)
- IWOCS - Installation & Workover Control Systems (SSP)
- Subsea Hardware (SSP)
- Umbilicals (SSP)
- Vessel‐based Installation Services (SP)
- Inspection Services (AI)
- Seabed Preparation/ Trenching (SP)
Subsea Trees | Field | ||
In Service | Abandonments | ||
• | ROV Services | • | ROV Services |
• | Tooling (SSP) | • | Tooling (SSP) |
• | Subsea Work Systems | • | Subsea Work Systems |
• | (SSP) | (SSP) | |
IWOCS - (SSP) | • | IWOCS - (SSP) |
- Subsea Hardware (SSP)
- Vessel‐based Installation Services (SP)
- Inspection Services (AI)
6
Revenue Sources
Geographic Area | Services and Products | |||
100% | $1.9B | $1.9B | $1.9B | $1.9B |
35% | ||||
75% | 49% | 50% | 39% |
Industry Segments
$1.9B $1.9B
19% 22%
50%
25% 51% 50%
0%
65%
61%
81% 78%
2017 | 2018 | 2017 | 2018 | |||||
International | United States | Services | Products | |||||
2017 2018
Energy Segments Non‐energy Segment
7
Financial Overview, Quarterly
100%
75%
50%
25%
0%
Revenue
$519.3M | $495.8M | $497.6M |
21% | 20% | 20% |
12% | 12% | 12% |
20% | 15% | 15% |
27% | 28% | 30% |
20% | 25% | 23% |
2018 Q3 | 2019 Q2 | 2019 Q3 |
100%
75%
50%
25%
0%
‐25%
Adjusted Operating EBITDA*
$73.1M | $71.2M | $72.6M | |||||
13% | 11% | 5% | |||||
5% | 11% | 10% | |||||
19% | |||||||
28% | 35% | ||||||
24% | |||||||
39% | 50% | 51% | |||||
0% | |||||||
‐1% | |||||||
2018 Q3 | 2019 Q2 | 2019 Q3 | |||||
Adtech Asset Integrity
Subsea Projects Subsea Products
ROV
*Excludes Unallocated Expenses and the effects of certain specified items. | 8 |
For reconciliation of Adjusted Operating EBITDA to Operating Income, see the Supplemental Information. | |
Operating Segments Results,* Q3 2019
Q3 2019 | ||
compared to | Variance factors | |
Q2 2019 | ||
Consolidated Results | Higher | Met expectations |
ROV | Higher | • $2.8 million sale of equipment |
Subsea Products | Higher | • better‐than‐expected revenue and profitability in Service and |
Rental | ||
Subsea Projects | Lower | • flat revenue and stable call‐out activity |
Asset Integrity | Lower | • slightly lower revenue and continued competitive pricing for |
inspection services | ||
Advanced Technologies | Lower | • delays and cost overruns on certain Commercial business |
projects | ||
Unallocated Expenses | Lower | • lower accruals for incentive‐based compensation |
9
*Results are Operating Income
Liquidity and Cash Flow
Liquidity at Sept 30, 2019
- $340 million of cash
- $500 million undrawn unsecured revolving credit facility available until October 2021; thereafter $450 million available until January 2023
- $500 million bond due November 2024 is nearest maturity
Cash flow for the nine months ended Sept 30, 2019
- Cash flow from operations, $112 million
- Capital expenditures, $129 million
10
Remotely Operated Vehicles
Q3 2019
Revenue
23%
EBITDA Margin 33%
We provide ROVs, which are tethered submersible vehicles that are remotely operated from a vessel or onshore, to customers in the energy industry for drilling support and vessel‐based services, including subsea hardware installation, construction, pipeline inspection, survey and facilities inspection, maintenance and repair.
11
Oceaneering ROV Average Revenue per Day on Hire
~$7,500 for Q3 2019
Revenue / Day on Hire | ROV Adjusted EBITDA Margin | |
$12,500 | 100% | ||
Day on Hire | $10,000 | 80% | Adjusted |
$7,500 | 60% | ||
Average Revenue per | $5,000 | 40% | Margin EBITDA |
$2,500 | 20% | ||
$0 | 0% | ||
12
ROV Days on Hire and Utilization Rates
Q3 2019 - Fleet Utilization 60%; Drill Support 63%, Vessel‐based 37%
Drill Support Days | |||||
Vessel‐based Days | Fleet Utilization | ||||
ROV Fleet Utilization | |||||
30,000 | Rate | 30,000 | |||
86% | 100% | ||||
25,000 | 25,000 | ||||
75% | |||||
on Hire | 20,000 | 60% | on Hire | 20,000 | |
15,000 | 42% | 50% | 15,000 | ||
Days | Days | ||||
ROV | 10,000 | ROV | 10,000 | ||
25% | |||||
5,000 | 5,000 | ||||
0 | 0% | 0 |
ROV Days on Hire | ||
Vessel‐based % | Service | |
Drill Support % | ||
Utilization Rate | ||
100% | ||
72% | 75% | |
59% | 63% | |
50% | ||
41% | 37% | |
28% | 25% | |
0% |
Oceaneering ROV Drill Support Market Share
61% at September 30, 2019
Contracted Floaters, Working | Contracted Floaters, Not Working | OII % of Contracted Floaters | ||
Period End | 300 | 100% | |
225 | 75% | of % OII | |
Floating Rigs at | 150 | 50% | Rigs Floating |
75 | 25% | ||
Contracted | |||
0 | 0% |
14
Source: Rig data, IHS Petrodata at September 30, 2019
ROV Technologies
Enabling better control and video imaging, precise tool manipulation, and adherence to industry requirements
Liberty
(E‐ROV)
Communications via 4G, fiber, and satellite
Mission support centers
Stavanger (Norway),
Houston (Texas), and
Morgan City (Louisiana)
Traditional | Resident ROV | |
Freedom | ROV system | |
ROV Concept |
E‐ROV concept winner
2017 World Oil
New Horizons Idea Award
15
Subsea Products
Q3 2019
Revenue
30%
While most of our subsea products are sold, we also rent tooling, and provide IWOCS and subsea work systems as a service, including hydrate remediation, riserless light well intervention, well stimulation, dredging, and decommissioning.
EBITDA Margin 17%
16
Subsea Products
Manufactured Products | Service and Rental |
59% of Q3 Subsea Products Revenue | 41% of Q3 Subsea Products Revenue |
Production Control
Umbilicals
Supply electric and hydraulic power to subsea trees and inject chemicals into well streams.
Specialty Subsea
Hardware
Field development hardware used to connect production trees to umbilicals and flow lines. Also includes connectors and valves ‐ Oceaneering Grayloc, Oceaneering Pipeline Connection & Repair Systems (PCRS) and Oceaneering Rotator.
Installation and
Workover Control
Systems (IWOCS)
A temporary control system designed for both rig‐ and vessel‐based operations used for tree installation, completion, workover, intervention and decommissioning of subsea wells.
Tooling and Subsea Work
Systems
Provide more than 4,000 ROV tools for rental. Supports well intervention, drilling, construction, field maintenance, and plugging and abandonment activities.
17
Subsea Products Financials
2019 Book‐to‐bill ratio forecast to exceed 1.25
Subsea Products Backlog | Subsea Products Revenue | Book‐to‐Bill Ratio, TTM | |||
Revenue/ Backlog ($ in Millions) | $1,000 | 1.75 | |
$800 | 1.5 | TTMRatio, Bill‐to‐Book | |
1.25 | |||
$600 | 1 | ||
$400 | 0.75 | ||
$200 | 0.5 | ||
Products | 0.25 | ||
$0 | 0 | ||
18
Note: Book‐to‐Bill Ratio Data unavailable for Q1 2014 through Q3 2014.
Proven Well Access Capabilities
- IRIS and BORIS ‐ rigless, riserless light well intervention systems
- Reliably perform in depths to 10,000 feet and pressures to 10,000 psi
- Maximize production and increase the recovery rate from offshore oil and gas reservoirs or, alternatively, prepare wells to be plugged and abandoned
Riserless Intervention System
Winner 2017 World Oil
Best Well Intervention
Technology Award
19
Subsea Projects
Q3 2019
Revenue
15%
EBITDA Margin 10%
We provide project management, survey, subsea installation, and inspection, maintenance, and repair services. We service deepwater projects with dynamically positioned vessels that have our ROVs onboard, and shallow water projects with our manned diving operations, utilizing dive support vessels and saturation diving systems. We also provide seabed preparation, route clearance, and trenching services to the renewable energy and oil and gas industries.
20
Subsea Projects Overview
- Vessels
- Owner‐operated, Jones Act compliant
- Multi‐service vessels (3) - Deepwater installations, IMR, ROV and construction support.
- Diving support vessels (2) - Shelf installations, IMR, inspection, UWILD, and pipeline, salvage, survey, and diving work.
- Other support vessels (2) - Shelf survey, inspections, and scientific missions.
- Short‐term charters, as necessary
- Services
- Survey and Autonomous Underwater Vehicle (AUV) services
- Offshore engineering, seabed preparation, route clearance, and
trenching services
- Global Data Solutions
21
Asset Integrity
Q3 2019
Revenue
12%
EBITDA Margin (1)%
We deliver asset integrity management, analytics, maintenance and risk management, conventional and advanced non‐destructive testing (NDT), and specialist inspection solutions, principally to the oil and gas, power generation, and petrochemical industries.
22
Asset Integrity - What We Do and Where We Work
Our optimized, industry‐leading inspection services and integrity management solutions assure our customers are equipped with the data required to make informed, value‐adding decisions. We work onshore and topside offshore ‐‐ across the entire energy spectrum, oil and gas, nuclear, and renewables.
Inspection and Condition | Integrity Management |
Monitoring | |
Non‐Destructive Testing | Advanced Inspection | Pipeline Inspection | Permanently Installed | Rope Access |
(NDT) - | Services | Monitoring Systems | ||
CapEx / In‐Service | (PIMS) |
Onshore Upstream | Onshore Midstream | Onshore Downstream | Offshore Topside |
23
Advanced Technologies
Q3 2019
Revenue
20%
EBITDA Margin 4%
We provide engineering services and related manufacturing, principally to the U.S. Department of Defense, NASA and its prime contractors, and the commercial theme park industry. We also develop, implement, and maintain innovative, turnkey ride system solutions and automated guided vehicle solutions based on proprietary technology.
24
Advanced Technologies Overview
Government‐related Businesses | Commercial Businesses |
79% of Q3 2019 AdTech Revenues | 21% of Q3 2019 AdTech Revenues |
U.S. Navy Submarine | Dry Deck Shelter | Entertainment Systems | Automated Guided |
Rescue System | Maintenance & Submarine | "Dark Ride" Vehicles | Vehicle (AGV) Systems |
Maintenance |
We have an unparalleled understanding of the full spectrum of submarine rescue requirements, backed by hands‐on, at‐sea experience around the world, having provided engineering, technical, and operational support since 1992.
We support the U.S. Navy's Deep Submergence community by performing complex overhauls, planned maintenance, and emergency repair tasks for the Navy's six dry deck shelters.
We developed and patented an evolutionary motion‐based system capable of delivering high‐energy thrills in fully immersive 3D media‐based attractions at a fraction of the cost of other ride vehicles.
We develop, implement, and maintain innovative, turnkey logistic solutions based on AGV technology.
25
25
Operating Segments Outlook,* Q4 2019
Q4 2019 | ||
compared to | Variance factors | |
Q3 2019 | ||
Consolidated Results | Lower | |
ROV | Lower | • Decrease in Vessel‐support days on hire is forecast to outpace projected |
Increase in Drill‐support days on hire | ||
• Fleet utilization in high 50% range | ||
• "Churn" persists but is not worsening | ||
Subsea Products | Lower | • Higher revenue generated from Manufactured Products unit delivering |
lower margin products | ||
• Sufficient order intake to achieve forecasted book‐to‐bill ratio of 1.25 to | ||
1.40 for full year | ||
Subsea Projects | Lower | • Flat revenue |
• Seasonal decrease in U.S. GOM deepwater vessel and diving work projected | ||
to outweigh increase in Survey services | ||
Asset Integrity | Improved | • Modest improvement from cost controls |
Advanced Technologies | Improved | • Meaningful revenue increase and improved performance in Commercial units |
• Increase in operating margins to low double‐digit range |
26
*Outlook is for Operating Income results
Full‐year Outlook,* 2019
2019F compared to 2018 | ||
Consolidated Results | Higher | |
ROV | Higher | |
Subsea Products | Higher | |
Subsea Projects | Higher | |
Asset Integrity | Lower | |
Advanced Technologies | Flat | |
Unallocated Expenses | $125 million ‐ $130 million | Increased accruals for incentive‐based compensation |
EBITDA, Adjusted | $150 million ‐ $170 million | Positive earnings from all operating segments |
Capital Expenditures | ~$150 million | Spending within ROV segment to support projected 2020 |
activity | ||
Free Cash Flow | Positive | Generate cash from positive working capital changes |
in Q4 |
27
*Outlook is for Operating Income results, excluding EBITDA, Adjusted; Capital Expenditures; and Free Cash Flow
Full‐year Outlook,* 2020
2020F compared to 2019F | ||
Consolidated Results | Higher | |
ROV | Higher | |
Subsea Products | Higher | |
Subsea Projects | Higher | |
Asset Integrity | Higher | |
Advanced Technologies | Higher | |
Unallocated Expenses | ~$140 million | Increased accruals for incentive‐based compensation |
EBITDA, Adjusted | $180 million ‐ $220 million | Positive earnings from all operating segments |
Capital Expenditures | $70 million ‐ $100 million | Maintenance and lower growth spending |
Free Cash Flow | Improved | Significant increase with contribution from all operating |
segments and substantive cut in Capex |
28
*Outlook is for Operating Income results, excluding EBITDA, Adjusted; Capital Expenditures; and Free Cash Flow
Focus on Technology
Blue Ocean | ||
Interchangeable | ||
Riserless | ||
Riserless Intervention | ||
Intervention | ||
System (IRIS) | ||
System (BORIS) | ||
Satellite | ||
ROV Workover Control System (RWOCS), | ||
Agnostic | ||
skid‐mounted or standalone solutions | Intelligent | |
Link (SAIL), | ||
comms | ||
package | ||
supporting | ||
high | ||
bandwidth | ||
via diverse | ||
satellites | ||
Automated Guided Vehicles (AGV), mobile robotics and automation
Subsea Pumping Technology, subsea chemical reservoirs
Freedom ROV,
subsea smart docking station, 6‐month continuous subsea operation; modular design for interchangeable packages/sensors
Liberty ROV (E‐ROV), subsea garage w/ battery pack and tether, 4G network for real‐time remote piloting
29
Key Enablers to Offshore Energy
- Shortened project development life cycles
- Reduced development costs
- Recognized efficiency gains from technology advancements
- Customer focus on developing "core of the core" offshore assets
- Customer confidence in commodity price stabilization
30
Industry Outlook
Data points suggest an offshore cycle inflection is underway
- Deepwater/Ultra‐deepwater breakeven prices are down by ~$20 per barrel since mid‐2015
- Brent Crude minimum appears to have stabilized in range of $55 to $65 per barrel
- Offshore subsea spending projected to increase by >5% in 2020, year over year
- Contracted floating rig count expected to increase in 2019 for the first time since 2014
- Tree installations forecast to be over 300 per year for the next several years
- FID is expected for nearly 50 deepwater projects in 2019 and 2020*
- Less than 10 deepwater FIDs in 2018
- Offshore barrels foreast to continue at approximately 30% of global production
- By 2021, 80% of Shale investment will be required to maintain flat production**
- Expected to push additional investment offshore for better returns
31
Source: * Rystad Energy, October 2019. **EvercoreISI, February 2019
Conclusion
While the overall offshore energy markets remain challenging, we are encouraged by signs of improving activity in our targeted markets and in our businesses as the industry gradually rebounds.
Focus:
- Generating positive free cash flow
- Maintaining our strong liquidity position
- Improving our returns by:
- driving efficiencies in cost and performance throughout our organization; and
- engaging with our customers to develop value‐added solutions that increase their cash flow;
and above all,
- Maintaining our superior safety performance and quality
32
Investor Relations Contact
Mark Peterson
Vice President, Corporate Development and Investor Relations 713.329.4507
InvestorRelations@oceaneering.com
33
Supplemental Information
34
Net Income (Loss) Reconciliation to EBITDA
Earnings before interest, taxes, depreciation and amortization (EBITDA) is a non‐GAAP financial measurement. Oceaneering's management uses EBITDA because we believe that this measurement is a widely accepted financial indicator used by investors and analysts to analyze and compare companies on the basis of operating performance, and that this measurement may be used by some investors and others to make investment decisions. You should not consider EBITDA in isolation from or as a substitute for net income or cash flow measures prepared in accordance with generally accepted accounting principles or as a measure of profitability or liquidity. EBITDA calculations by one company may not be comparable to EBITDA calculations made by another company. The following table provides a reconciliation between net income (loss) (a GAAP financial measure) and EBITDA (a non‐GAAP financial measure) for Oceaneering's historical and projected results on a consolidated basis for the periods indicated:
Period Ended | 2017 | 2018 | 2019F | 2019F | 2020F | 2020F | |||||||||||||||||
(USD in millions) | Low | High | Low | High | |||||||||||||||||||
Net Income (Loss) | $ | 166.4 | $ | (212.3) | Income (Loss) before income taxes | $ | (90.0) | $ | (70.0) | $ | (55.0) | $ | (15.0) | ||||||||||
Depreciation & Amortization | 213.5 | 293.6 | Depreciation & Amortization | 205.0 | 205.0 | 200.0 | 200.0 | ||||||||||||||||
Subtotal | 379.9 | 81.3 | Subtotal | $ | 115.0 | $ | 135.0 | $ | 145.0 | $ | 185.0 | ||||||||||||
Interest Expense/Income, Net | 19.3 | 26.0 | Interest Expense/Income, Net | 35.0 | 35.0 | 35.0 | 35.0 | ||||||||||||||||
Income Tax Expense | (184.2) | 26.5 | |||||||||||||||||||||
EBITDA | 215.0 | 133.8 | EBITDA | $ | 150.0 | $ | 170.0 | $ | 180.0 | $ | 220.0 | ||||||||||||
Adjusted EBITDA** | $ | 222.4 | $ | 142.5 | |||||||||||||||||||
35
* For reconciliation of EBITDA to Adjusted EBITDA, see the Supplemental schedules that follow.
Operating Income (Loss) Reconciliation to Adjusted EBITDA and Adjusted Operating EBITDA
Adjusted EBITDA excludes the effects of certain specified items, as set forth in the table that follows. Adjusted Operating EBITDA is Adjusted EBITDA before Unallocated Expenses. We believe these are useful measurements for investors to review because they provide consistent measure of the underlying results of our ongoing business by individual business segment and on a consolidated basis. Furthermore, our management uses these measurements as measures of performance of our operations. Adjusted EBITDA and Adjusted Operating EBITDA are non‐GAAP financial measures. The following table provides a reconciliation between operating income (loss) (a GAAP financial measure) and Adjusted EBITDA and Adjusted Operating EBITDA (non‐GAAP financial measures) for Oceaneering's historical results on a consolidated basis and by segment for the periods indicated.
Year Ended Dec 31, 2017 | Subtotal | ||||||||||||||||||||||||||||||
(USD in millions) | Subsea | Subsea | Asset | Unallocated | |||||||||||||||||||||||||||
ROV | Advanced before Unallocated | Total | |||||||||||||||||||||||||||||
Operating Income (Loss)(GAAP) | Products | Projects | Integrity | Tech. | Expenses | Expenses | |||||||||||||||||||||||||
$ | 22.3 | $ | 45.5 | $ | 10.3 | $ | 11.2 | $ | 22.0 | $ | 111.3 | $ | (100.7) | $ | 10.6 | ||||||||||||||||
Depreciation & Amortization | 114.0 | 52.6 | 31.8 | 7.7 | 3.2 | 209.3 | 4.2 | 213.5 | |||||||||||||||||||||||
Other pre‐tax | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | (9.1) | (9.1) | |||||||||||||||||||||||
EBITDA | $ | 136.3 | $ | 98.1 | $ | 42.1 | $ | 18.9 | $ | 25.2 | $ | 320.6 | $ | (105.6) | $ | 215.0 | |||||||||||||||
Adjustments for the effects of: | |||||||||||||||||||||||||||||||
Charge related to prior year non‐ | 1.9 | 0.3 | ‐ | ‐ | ‐ | 2.2 | ‐ | 2.2 | |||||||||||||||||||||||
income related taxes | |||||||||||||||||||||||||||||||
Foreign Currency losses | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | 5.2 | 5.2 | |||||||||||||||||||||||
Total Adjustments | 1.9 | 0.3 | ‐ | ‐ | ‐ | 2.2 | 5.2 | 7.4 | |||||||||||||||||||||||
Adjusted EBITDA | $ | 138.2 | $ | 98.4 | $ | 42.1 | $ | 18.9 | $ | 25.2 | $ | 322.8 | $ | (100.4) | $ | 222.4 | |||||||||||||||
Adj Operating EBITDA, Segment % | 43% | 30% | 13% | 6% | 8% | 100% | $ | 1,921.5 | |||||||||||||||||||||||
Revenue | $ | 393.6 | $ | 625.5 | $ | 292.0 | $ | 236.8 | $ | 373.6 |
36
Operating Income (Loss) Reconciliation to Adjusted EBITDA and Adjusted Operating EBITDA
Adjusted EBITDA excludes the effects of certain specified items, as set forth in the table that follows. Adjusted Operating EBITDA is Adjusted EBITDA before Unallocated Expenses. We believe these are useful measurements for investors to review because they provide consistent measure of the underlying results of our ongoing business by individual business segment and on a consolidated basis. Furthermore, our management uses these measurements as measures of performance of our operations. Adjusted EBITDA and Adjusted Operating EBITDA are non‐GAAP financial measures. The following table provides a reconciliation between operating income (loss) (a GAAP financial measure) and Adjusted EBITDA and Adjusted Operating EBITDA (non‐GAAP financial measures) for Oceaneering's historical results on a consolidated basis and by segment for the periods indicated.
Year Ended Dec 31, 2018 | Subtotal | Unallocated | ||||||||||||||||||||||||||
(USD in millions) | ROV | Subsea | Subsea | Asset | Advanced before Unallocated | Total | ||||||||||||||||||||||
Operating Income (Loss)(GAAP) | Products | Projects | Integrity | Tech. | Expenses | Expenses | ||||||||||||||||||||||
$ | 1.6 | $ | 5.6 | $ | (86.0) | $ | 8.7 | $ | 33.9 | $ | (36.2) | $ | (109.3) | $ | (145.5) | |||||||||||||
Depreciation & Amortization | 111.3 | 53.1 | 114.5 | 6.9 | 3.1 | 288.9 | 4.7 | 293.6 | ||||||||||||||||||||
Other pre‐tax | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | (14.3) | (14.3) | ||||||||||||||||||||
EBITDA | $ | 112.9 | $ | 58.7 | $ | 28.5 | $ | 15.6 | $ | 37.0 | $ | 252.7 | $ | (118.9) | $ | 133.8 | ||||||||||||
Adjustments for the effects of: | ‐ | (9.3) | ||||||||||||||||||||||||||
Gain on sale of investment | ‐ | ‐ | ‐ | ‐ | ‐ | (9.3) | ||||||||||||||||||||||
Foreign Currency (gains) | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | 18.0 | 18.0 | ||||||||||||||||||||
Total Adjustments | ||||||||||||||||||||||||||||
‐ | ‐ | ‐ | ‐ | ‐ | ‐ | 8.7 | 8.7 | |||||||||||||||||||||
Adjusted EBITDA | $ | 112.9 | $ | 58.7 | $ | 28.5 | $ | 15.6 | $ | 37.0 | $ | 252.7 | $ | (110.2) | $ | 142.5 | ||||||||||||
Adj Operating EBITDA, Segment % | 45% | 23% | 11% | 6% | 15% | 100% | ||||||||||||||||||||||
Revenue | $ | 394.8 | $ | 515.0 | $ | 329.2 | $ | 253.9 | $ | 416.6 | $ | 1,909.5 |
37
Operating Income (Loss) Reconciliation to Adjusted EBITDA and Adjusted Operating EBITDA
Adjusted EBITDA excludes the effects of certain specified items, as set forth in the table that follows. Adjusted Operating EBITDA is Adjusted EBITDA before Unallocated Expenses. We believe these are useful measurements for investors to review because they provide consistent measure of the underlying results of our ongoing business by individual business segment and on a consolidated basis. Furthermore, our management uses these measurements as measures of performance of our operations. Adjusted EBITDA and Adjusted Operating EBITDA are non‐GAAP financial measures. The following table provides a reconciliation between operating income (loss) (a GAAP financial measure) and Adjusted EBITDA and Adjusted Operating EBITDA (non‐GAAP financial measures) for Oceaneering's historical results on a consolidated basis and by segment for the periods indicated.
3 mths Ended Sept 30, 2019 | Subtotal | ||||||||||||||||||||||||||
(USD in millions) | Subsea | Subsea | Asset | Advanced before Unallocated | Unallocated | Total | |||||||||||||||||||||
Operating Income (Loss)(GAAP) | ROV Products | Projects | Integrity | Tech. | Expenses | Expenses | |||||||||||||||||||||
$ | 10.1 | $ | 13.2 | $ | (0.6) | $ | (2.4) | $ | 3.0 | $ | 23.3 | $ | (28.5) | $ | (5.2) | ||||||||||||
Depreciation & Amortization | 26.8 | 12.1 | 8.1 | 1.6 | 0.7 | 49.3 | 1.2 | 50.5 | |||||||||||||||||||
Other pre‐tax | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | (3.4) | (3.4) | |||||||||||||||||||
EBITDA | |||||||||||||||||||||||||||
$ | 36.9 | $ | 25.3 | $ | 7.5 | $ | (0.8) | $ | 3.7 | $ | 72.6 | $ | (30.7) | $ | 41.9 | ||||||||||||
Adjustments for the effects of: | 3.5 | ||||||||||||||||||||||||||
Foreign Currency losses | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | 3.5 | ||||||||||||||||||||
Total Adjustments | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | 3.5 | 3.5 | |||||||||||||||||||
Adjusted EBITDA | $ | 36.9 | $ | 25.3 | $ | 7.5 | $ | (0.8) | $ | 3.7 | $ | 72.6 | $ | (27.2) | $ | 45.4 | |||||||||||
Adjusted Operating EBITDA, | 51% | 35% | 10% | ‐1% | 5% | 100% | |||||||||||||||||||||
Segment % | $ | 113.1 | $ | 150.8 | $ | 76.0 | $ | 59.3 | $ | 98.4 | $ | 497.6 | |||||||||||||||
Revenue |
38
Operating Income (Loss) Reconciliation to Adjusted EBITDA and Adjusted Operating EBITDA
Adjusted EBITDA excludes the effects of certain specified items, as set forth in the table that follows. Adjusted Operating EBITDA is Adjusted EBITDA before Unallocated Expenses. We believe these are useful measurements for investors to review because they provide consistent measure of the underlying results of our ongoing business by individual business segment and on a consolidated basis. Furthermore, our management uses these measurements as measures of performance of our operations. Adjusted EBITDA and Adjusted Operating EBITDA are non‐GAAP financial measures. The following table provides a reconciliation between operating income (loss) (a GAAP financial measure) and Adjusted EBITDA and Adjusted Operating EBITDA (non‐GAAP financial measures) for Oceaneering's historical results on a consolidated basis and by segment for the periods indicated.
3 mths Ended June 30, 2019 | Subtotal | Unallocated | ||||||||||||||||||||||||||
(USD in millions) | Subsea | Subsea | Asset | Advanced before Unallocated | Total | |||||||||||||||||||||||
Operating Income (Loss)(GAAP) | ROV Products | Projects | Integrity | Tech. | Expenses | Expenses | ||||||||||||||||||||||
$ | 8.7 | $ | 7.4 | $ | 0.1 | $ | (1.3) | $ | 7.2 | $ | 22.1 | $ | (31.7) | $ | (9.6) | |||||||||||||
Depreciation & Amortization | 26.9 | 12.4 | 7.5 | 1.5 | 0.8 | 49.1 | 1.2 | 50.3 | ||||||||||||||||||||
Other pre‐tax | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | (0.4) | (0.4) | ||||||||||||||||||||
EBITDA | $ | 35.6 | $ | 19.8 | $ | 7.6 | $ | 0.2 | $ | 8.0 | $ | 71.2 | $ | (30.9) | $ | 40.3 | ||||||||||||
Adjustments for the effects of: | (0.1) | |||||||||||||||||||||||||||
Foreign Currency (gains) | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | (0.1) | |||||||||||||||||||||
Total Adjustments | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | (0.1) | (0.1) | ||||||||||||||||||||
Adjusted EBITDA | $ | 35.6 | $ | 19.8 | $ | 7.6 | $ | 0.2 | $ | 8.0 | $ | 71.2 | $ | (31.0) | $ | 40.2 | ||||||||||||
Adjusted Operating EBITDA, | 50% | 28% | 11% | 0% | 11% | 100% | ||||||||||||||||||||||
Segment % | ||||||||||||||||||||||||||||
Revenue | $ | 120.4 | $ | 138.9 | $ | 75.1 | $ | 61.2 | $ | 100.2 | $ | 495.8 |
39
Operating Income (Loss) Reconciliation to Adjusted EBITDA and Adjusted Operating EBITDA
Adjusted EBITDA excludes the effects of certain specified items, as set forth in the table that follows. Adjusted Operating EBITDA is Adjusted EBITDA before Unallocated Expenses. We believe these are useful measurements for investors to review because they provide consistent measure of the underlying results of our ongoing business by individual business segment and on a consolidated basis. Furthermore, our management uses these measurements as measures of performance of our operations. Adjusted EBITDA and Adjusted Operating EBITDA are non‐GAAP financial measures. The following table provides a reconciliation between operating income (loss) (a GAAP financial measure) and Adjusted EBITDA and Adjusted Operating EBITDA (non‐GAAP financial measures) for Oceaneering's historical results on a consolidated basis and by segment for the periods indicated.
3 mths Ended Sept 30, 2018 | Subtotal | ||||||||||||||||||||||||||||
(USD in millions) | Subsea | Subsea | Asset | Advanced before Unallocated | Unallocated | Total | |||||||||||||||||||||||
Operating Income (Loss)(GAAP) | ROV Products | Projects | Integrity | Tech. | Expenses | Expenses | |||||||||||||||||||||||
$ | 0.8 | $ | 5.4 | $ | 6.1 | $ | 2.3 | $ | 8.9 | $ | 23.5 | $ | (25.0) | $ | (1.5) | ||||||||||||||
Depreciation & Amortization | 27.4 | 12.3 | 7.5 | 1.6 | 0.8 | 49.6 | 1.1 | 50.7 | |||||||||||||||||||||
Other pre‐tax | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | 3.6 | 3.6 | |||||||||||||||||||||
EBITDA | |||||||||||||||||||||||||||||
$ | 28.2 | $ | 17.7 | $ | 13.6 | $ | 3.9 | $ | 9.7 | $ | 73.1 | $ | (20.3) | $ | 52.8 | ||||||||||||||
Adjustments for the effects of: | ‐ | (9.3) | |||||||||||||||||||||||||||
Gain on sale of investment | ‐ | ‐ | ‐ | ‐ | ‐ | (9.3) | |||||||||||||||||||||||
Foreign Currency losses | ‐ | ‐ | ‐ | ‐ | ‐ | ‐ | 3.7 | 3.7 | |||||||||||||||||||||
Total Adjustments | |||||||||||||||||||||||||||||
‐ | ‐ | ‐ | ‐ | ‐ | ‐ | (5.6) | (5.6) | ||||||||||||||||||||||
Adjusted EBITDA | |||||||||||||||||||||||||||||
$ | 28.2 | $ | 17.7 | $ | 13.6 | $ | 3.9 | $ | 9.7 | $ | 73.1 | $ | (25.9) | $ | 47.2 | ||||||||||||||
Adjusted Operating EBITDA, | 39% | 24% | 19% | 5% | 13% | 100% | |||||||||||||||||||||||
Segment % | $ | 105.1 | $ | 137.1 | $ | 105.0 | $ | 62.3 | $ | 109.8 | $ | 519.3 | |||||||||||||||||
Revenue |
40
Free Cash Flow
"Free Cash Flow" (FCF) is a non‐GAAP financial measurement. FCF represents cash flow provided by operating activities less organic capital expenditures (i.e., purchases of property and equipment other than those in business acquisitions). Management believes that this is an important measure because it represents funds available to reduce debt and pursue opportunities that enhance shareholder value, such as making acquisitions and returning cash to shareholders through dividends or share repurchases.
Period Ended | 2015 | 2016 | 2017 | 2018 | 2019* | |||||||||||
(USD in millions) | ||||||||||||||||
Net Income (Loss) | $ | 231.0 | $ | 24.6 | $ | 166.4 | $ | (212.3) | $ | (85.5) | ||||||
Depreciation & Amortization | 241.2 | 250.2 | 213.5 | 293.6 | 153.3 | |||||||||||
Other Changes in Cash Provided by | 64.6 | (243.4) | (44.7) | 44.3 | ||||||||||||
Operating Activities | 91.7 | |||||||||||||||
Cash Provided by Operating Activities | 563.9 | 339.4 | 136.5 | 36.6 | 112.1 | |||||||||||
Purchases of Property & Equipment | (200.0) | (112.4) | (93.7) | (109.5) | (128.8) | |||||||||||
Free Cash Flow | $ | 363.9 | $ | 227.0 | $ | 42.8 | $ | (72.9) | $ | (16.7) |
41
*Nine months ended September 30, 2019
Oceaneering ROV Fleet - 276 ROVs
Geographic profile - September 30, 2019
ROV Count | Vessel Based, 101 ROVs | |
100 | |||||||
90 | 84 | ||||||
80 | 73 | ||||||
70 | |||||||
ROVs | 60 | ||||||
50 | 45 | ||||||
40 | 33 | ||||||
30 | 22 | 19 | |||||
20 | |||||||
10 | |||||||
0 | GOM | Africa | North Sea | Brazil | Asia/Pac | Other | |
42
Oceaneering ROV Leading Market Position
ROV Ownership | Contracted Floating Rig Market Share |
at Dec 31, 2018 | at September 30, 2019 |
275
25%
97 Contracted Rigs
61%
OII Subsea 7 Fugro DOF Subsea C‐Innovations Helix Saipem TMT Technip IKM Group Other
43
Source: Work‐class ROV Ownership ‐ Infield, Wood Mackenzie Business, December 31, 2018.
Offshore Activity Forecast to Increase
following 2018 inflection in select oilfield company backlogs
Technip FMC | TechnipFMC | AKER | OneSubsea | Dril‐Quip | OII Backlog | |||||
$750 | $30 | in$ Backlog, Equipment Subsea | ||||||
ProductsBacklog, $ in millions | $500 | $20 | ||||||
$250 | $10 | |||||||
Subsea | billions | |||||||
OII | $0 | $0 | ||||||
2015 | 2016 | 2017 | 2018 | |||||
2014 | 2019 Q3 | |||||||
44 | 44 | |||||||
Source: Company filings. Note: Aker NOK/USD and Technip EUR/USD conversions are US Treasury conversion rates at period end.
Subsea Spending Forecast to Begin Increasing in 2019
Spending ($ in millions)
$50,000
$40,000
$30,000
$20,000
Equipment | Services | SURF | ||
15,399
12,194 13,335
Offshore
$10,000
5,926 5,914
6,433
$0
7,154 7,787 8,949
2014 | 2015 | 2016 | 2017 | 2018 | 2019F | 2020F | 2021F |
45
Source: Rystad Energy, Oct 2019
Offshore Activity Forecast to Increase
following 2018 inflection in floating rig demand
400 | Contracted Floaters | Tree Installations, Forecast | |||||||
End | 350 | 350 | 354 | ||||||
300 | 320 | ||||||||
at Period | 297 | ||||||||
250 | |||||||||
200 | |||||||||
Count | 150 | 275 | |||||||
100 | 146 | 158 | 169 | ||||||
50 | |||||||||
0 | 2014 | 2015 | 2016 | 2017 | 2018 | 2019F | 2020F | 2021F | |
Sources: Forecasted SS Tree Installations, Rystad Energy. Forecasted Floating Rigs, IHS/OII Investor Relations, | 46 |
assuming repeating 2018 quarterly percentages of IHS‐forecasted Marketed Supply. | |
Breakevens Reduced since 2014
Meaningful reductions in ultra‐deep and deepwater categories
Global Liquids Supply Cost Curve - June 2014 | Global Liquids Supply Cost Curve - July 2017 |
$57
$34
Ultra Deepwater average breakeven price has decreased by $23/barrel since 2014
47
Source: Rystad Energy
Offshore Activity is Incentivized by Lower Breakevens and Stable Crude Prices
Major FIDs more than doubled from 2014 to 2017
Breakeven Price/barrel
$125
$100
$75
$50
$25
$0
Brent Crude $/barrel and Offshore Breakeven $/barrel
$125 | Brent | ||||||||||||||||
$115 | $100 | ||||||||||||||||
Crude | |||||||||||||||||
$75 | |||||||||||||||||
Price/barrel | |||||||||||||||||
$55 | |||||||||||||||||
$67 | |||||||||||||||||
$44 | $50 | ||||||||||||||||
$25 | |||||||||||||||||
Breakeven, Shelf | |||||||||||||||||
4 | 5 | 1 | ←Sanctioned major projects → 13 | 8 | 4 | Breakeven, Deepwater | |||||||||||
Breakeven, Ultradeep | |||||||||||||||||
$0 | |||||||||||||||||
2014 | 2017 | High close $/bbl | |||||||||||||||
Low close $/bbl |
48
Source: Average Breakevens, Rystad Energy. Brent crude, EIA. Project counts, Wood Mackenzie.
Global Offshore Infrastructure is Aging
Nearly 6,400 offshore streaming wells were installed prior to 2019; average is almost 12 1/2 years since start‐up
7,500 | 50 | .Avg | |||||
stream | 6,000 | 40 | since Years | ||||
Count of Installed Wells, on | 4,500 | 3,132 | 3,246 | Wells stream on of up‐start | |||
30 | |||||||
3,000 | 1,543 | 20 | |||||
1,500 | 255 | 10 | |||||
0 | 4 | 1,096 | 2,231 | 3,240 | 3,329 | ||
303 | 0 | ||||||
pre 1990 | 1990s | 2000s | 2010‐2018 | 2019F + |
Shelf Wells | Aggregate ≥400M Wells | Average Age, >400M | Average Age, Shelf | |||
49
Source: Well data, Infield, A Wood Mackenzie Business, June 2019.
Attachments
- Original document
- Permalink
Disclaimer
Oceaneering International Inc. published this content on 19 November 2019 and is solely responsible for the information contained therein. Distributed by Public, unedited and unaltered, on 19 November 2019 22:34:10 UTC