Investor Presentation February 2019 1 Forward-Looking Statements - - PowerPoint PPT Presentation
Investor Presentation February 2019 1 Forward-Looking Statements - - PowerPoint PPT Presentation
Investor Presentation February 2019 1 Forward-Looking Statements Statements contained in this investor presentation that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and
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Forward-Looking Statements
Statements contained in this investor presentation that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward- looking statements include words or phrases such as “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “project,” “could,” “may,” “might,” “should,” “will” and similar words and specifically include statements involving expected financial performance, effective tax rate, expected expense savings, day rates and backlog, estimated rig availability; rig commitments and contracts; contract duration, status, terms and other contract commitments; estimated capital expenditures; letters of intent or letters of award; scheduled delivery dates for rigs; the timing of delivery, mobilization, contract commencement, relocation or other movement of rigs; our intent to sell or scrap rigs; and general market, business and industry conditions, trends and outlook. Such statements are subject to numerous risks, uncertainties and assumptions that may cause actual results to vary materially from those indicated, including commodity price fluctuations, customer demand, new rig supply, downtime and other risks associated with offshore rig operations, relocations, severe weather or hurricanes; changes in worldwide rig supply and demand, competition and technology; future levels of offshore drilling activity; governmental action, civil unrest and political and economic uncertainties; terrorism, piracy and military action; risks inherent to shipyard rig construction, repair, maintenance or enhancement; possible cancellation, suspension or termination of drilling contracts as a result of mechanical difficulties, performance, customer finances, the decline or the perceived risk of a further decline in oil and/or natural gas prices, or other reasons, including terminations for convenience (without cause); the cancellation of letters of intent or letters of award or any failure to execute definitive contracts following announcements of letters of intent, letters of award or other expected work commitments; the outcome of litigation, legal proceedings, investigations or other claims or contract disputes; governmental regulatory, legislative and permitting requirements affecting drilling operations; our ability to attract and retain skilled personnel on commercially reasonable terms; environmental or other liabilities, risks or losses; debt restrictions that may limit our liquidity and flexibility; tax matters including our effective tax rate; and cybersecurity risks and threats. In addition to the numerous factors described above, you should also carefully read and consider “Item 1A. Risk Factors” in Part I and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II of our most recent annual report on Form 10-K, as updated in our subsequent quarterly reports on Form 10-Q, which are available on the SEC’s website at www.sec.gov or on the Investor Relations section of our website at www.enscoplc.com. Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward-looking statements, except as required by law.
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Key Themes
Offshore drilling recovery is underway Ensco is well positioned to participate in the recovery
- Offshore production critical to meeting growing oil and gas demand
- Years of underinvestment in future production has impacted reserve
lives for E&P customers
- E&P customers have greater cash flow to consider investments in
future production including offshore projects
- Offshore project sanctioning is increasing, leading to new contracts
and tenders for future work
- High-specification drilling rigs winning an outsized share of new work
- Attrition of less capable rigs expected to continue
- Concentrated fleet of high-quality assets capable of meeting
customer demand in deep- and shallow-water globally
- Track record of operational excellence and safety has led to
industry-leading customer satisfaction
- Leader in new contract awards as customer activity has increased
- Focused investments in innovation and technology help to
differentiate performance and reliability
- Solid financial position bolstered by strong liquidity and
manageable debt maturities
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Ensco’s Leading Position
Offshore Market Recovery
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Offshore Production Critical to Meeting Growing Global Oil & Gas Demand
Global Oil & Gas Production Global Oil & Gas Production – Offshore & Onshore
142 162 179
40 80 120 160 200 Oil Gas Total mm boe/d
Source: Rystad Energy
- Oil and gas production will
continue to be an important part of meeting global energy demand, with total production forecast to grow by 17 million barrels of oil equivalent per day by 2025
- Despite significant growth in
unconventional onshore production, offshore production represents 28% of
- verall oil and gas production
today – and expectations are that offshore production will provide approximately 5 million barrels of oil equivalent growth by 2025
70% 72% 72% 30% 28% 28%
Onshore Offshore
+17 mm boe/d
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Several Years of Underinvestment by Major E&Ps Has Impacted Reserves
Capital Expenditures by Major E&Ps1 Average Reserve Life for Major E&Ps
$ billions
- Major E&Ps reduced capital
expenditures by 56% from 2014 highs in response to lower commodity prices
- After three years of
significantly lower levels of investment, the average reserve life for the Major E&Ps has gradually declined to its lowest point in the past decade
- Capital expenditures for Major
E&Ps are estimated to have declined further in 2018, which could put additional pressure on average reserve lives
Source: Rystad Energy, SpareBank 1 Markets
1 Major E&P customers defined as BP, Chevron, ConocoPhillips, Eni, Equinor, Exxon, Repsol, Shell and Total
122 154 185 212 216 170 123 99 95
- 50
100 150 200 250 2010 2011 2012 2013 2014 2015 2016 2017 2018E
- 56%
10.9 12.0 12.3 12.8 12.9 12.1 11.1 10.7
8 9 10 11 12 13 14 2010 2011 2012 2013 2014 2015 2016 2017 years
- 17%
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Improving Market Conditions Have Led to Higher Customer Cash Flows
Free Cash Flow Breakeven Oil Prices for E&Ps
Source: SpareBank 1 Markets, FactSet
1 Free cash flow is calculated as analyst consensus estimates of operating cash flow less capital expenditures; major offshore E&P customers defined as Anadarko,
BP, Chevron, ConocoPhillips, Eni, Equinor, ExxonMobil, Petrobras, Repsol, Shell and Total
- More recently, lower free cash
flow breakeven oil prices for E&Ps, coupled with higher oil prices, have created a more conducive environment for new project investments
- Despite the recent pullback in
- il prices, expectations are
that free cash flow continues to grow in 2019, giving major
- ffshore customers greater
flexibility to invest in future production
Free Cash Flow of Major Offshore E&Ps1
- 11
- 3
65 112 109
- 20
20 40 60 80 100 120 140 2015 2016 2017 2018E 2019E $ billions 60 51 36 42 39 53 44 54 72 58 20 40 60 80 2015 2016 2017 2018E 2019E Free cash flow breakeven oil price Avg Brent crude price $/bbl
1
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Offshore Projects Economic at Current Oil Prices With More Approvals Expected
- Based on commentary from
major offshore customers, many offshore projects are economic at breakeven oil prices well below current levels
- New major offshore project
approvals in 2018 were more than 2.5x 2016 cyclical lows, with expectations of further increases in sanctioning activity during 2019
– New project approvals are a leading indicator of future capital expenditures
Average Offshore Breakeven Oil Prices
$27 <$30 $33 <$40 <$40 <$40
Statoil Total Respol Chevron Petrobras Shell
$/bbl
Pre-FID Norwegian Shelf Projects Brazil Pre-Salt Project Pre-FID Deepwater Projects Pre-FID Shallow- Water Projects Pre-FID Pre-Salt Projects Acquired Maersk portfolio
23 50 67 77 25 50 75 100 2016 2017 2018 2019E
Number of New Major Offshore Project Approvals
Source: Equinor 7 February 2017 capital markets day; call; Total 25 September 2017 investor day; Repsol 23 February 2017 earnings conference call; ExxonMobil 27 July 2018 earnings conference call, in reference to Carcara project; Petrobras 30 January 2018 Latin America investment conference presentation; Shell 26 July 2018 earnings conference call; Rystad Energy, major projects defined as projects with >$250 million of associated capital expenditures
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Offshore Rig Utilization Expected to Benefit From Increased E&P Investments
E&P Offshore Capital Expenditures
Source: Rystad Energy, IHS Markit RigPoint
- Given increased cash flow
and attractive new project economics, E&P offshore capital expenditures are expected to increase modestly in 2019 and continue growing steadily
- ver the next seven years
- Over the past three decades,
- ffshore drilling rig utilization
has moved in line with the rate of change in customer spending, suggesting further utilization increases in 2019 and 2020 from higher customer demand
- 30
- 20
- 10
10 20 30 40 30 40 50 60 70 80 90 100
Global Fleet Utilization (%, left axis) Change in E&P Offshore Capex (2Y rolling avg %, right axis)
Offshore Drilling Rig Utilization and E&P Capital Expenditures
166 150 153 169 177 198 224 260 293
- 50
100 150 200 250 300 350
2013 2014 2015 2016 2017 2018E 2019E 2020E 2021E 2022E 2023E 2024E 2025E
10% CAGR
$ billions
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- New contract awards in 2018
were 65% higher than 2016
– The number of 2018 floater contracts nearly doubled 2016 lows, while new jackup contract awards increased by 56%
- Despite lower year-to-year oil
prices, the number of open tenders for offshore rigs has increased 72% since year-end 2017, demonstrating customers’ willingness to look through near-term volatility to longer term oil prices and the improvement in offshore project economics
Offshore Rig Demand Showing Signs of Steady Improvement
63 102 116 142 171 222 2016 2017 2018 Floaters Jackups
Source: IHS Markit RigPoint as of February 2019
1 Classified as new mutual fixtures in IHS Markit RigPoint
Number of New Contracts1 Awarded
+65% +72%
Avg Brent Crude $/bbl $55 $65 40 46 32 78 Dec-17 Dec-18 Floaters Jackups
Number of Open Offshore Rig Tenders
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40% 60% 80% 100% Jan 16 Jul 16 Jan 17 Jul 17 Jan 18 Jul 18 Jan 19
Highest-Specification Drillships Winning More New Floater Contracts
Source: IHS Markit RigPoint as of February 2019
1 Classified as new mutual fixtures in IHS Markit RigPoint 2 Drillships delivered in 2013 or later, equipped with dual BOP and 2.5mm lbs. hookload derricks
Highest- Specification Drillships2
Drillship Utilization – Delivered Rigs
- The number of new drillship
contracts awarded worldwide during 2018 was more than 2.5x 2016 lows
- Highest-specification drillships that
deliver efficiencies for customers’
- ffshore projects are winning an
- utsized share of new work
– These assets currently represent 34
- ut of 110 delivered drillships, or
~30% of total supply, and won ~41%
- f all new drillship contracts awarded
in 2017 and 2018
- Utilization for these highest-
specification drillships increased by 17 percentage points during 2018 and is currently ~80%
3 14 14 10 18 22 13 32 36 2016 2017 2018 Highest-Specification Drillships Other Drillships
Number of New Drillship Contracts1 Awarded Worldwide
2
12
Modern Jackups Winning More New Contracts For Shallow-Water Work
40% 60% 80% 100% Jan 16 Jul 16 Jan 17 Jul 17 Jan 18 Jul 18 Jan 19
Source: IHS Markit RigPoint as of February 2019
1 Classified as new mutual fixtures in IHS Markit RigPoint 2 Jackups <20 years of age
Modern Jackups2 Older Jackups
Jackup Utilization – Delivered Rigs
- The number of new jackup
contracts awarded worldwide has increased by 56% over 2016 levels
- Modern jackups that deliver
efficiencies for customers’ offshore projects are winning an outsized share of new work
– These assets currently represent 285 out of 516 delivered jackups, or ~50% of total supply, and won ~64%
- f new jackup contracts awarded in
2017 and 2018
- Modern jackups have experienced
18ppt higher utilization than older jackups on average since the beginning of 2016
86 110 142 56 61 80 142 171 222 2016 2017 2018 Modern Jackups Older Jackups
Number of New Jackup Contracts1 Awarded Worldwide
2
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Substantial Portion of Current Global Supply are Retirement Candidates
- ~40 floaters1 could be candidates
for retirement based on age and contract expirations
- ~150 jackups1 could be retired as
expiring contracts and survey costs lead to the removal of older rigs from drilling supply
- Uncontracted newbuilds expected
to be delayed further, while several newbuilds in Brazil and China are unlikely to join the global fleet Global Rig Fleet
Source: IHS Markit RigPoint as of February 2019
1 Includes rigs >30 years of age that are idle without follow-on work or have contracts expiring before year-end 2019 without follow-on work and rigs 15 to 30
years of age that have been idle for more than two years and without follow-on work
Floaters Jackups Delivered Rigs Under Contract 126 312 Future Contract 25 36 Idle / Stacked 48 108 Marketed Fleet 199 456 Non-Marketed 43 61 Total Fleet 242 517 Marketed Utilization 76% 76% Total Utilization 62% 67% Newbuild Rigs Contracted 2 1 Uncontracted 25 23 Build in Brazil / China 14 53 Total Newbuilds 41 77
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Current Total Supply Illustrative Total Supply Illustrative Marketed Supply
Retirements Expected to Lead to Future Supply Contraction
- The global floater count could
decline by 11 rigs, or ~5%, if adjusted for likely retirements and newbuild deliveries
– Excluding another 25 floaters that are not currently marketed, illustrative marketed supply of 206 compares to contracted floater count of 149
- When adjusting for likely
retirements and newbuilds, the jackup count could decline by 102 rigs or ~20%
– Excluding another 10 jackups that are not currently marketed, illustrative marketed supply of 405 compares to contracted jackup count of 348
Illustrative Jackup Supply Illustrative Floater Supply
Current Total Supply Illustrative Total Supply Illustrative Marketed Supply
4 242 27
- 21
- 13
- 8
231 25 206
Build in Brazil Newbuilds1 Other Newbuilds >30yrs idle w/o future contract >30yrs rolling off contract by YE2019 15-30yrs idle for
- ver 2yrs
Non- marketed
34 517 23
- 96
- 58
- 5
415 10 405
Source: IHS Markit RigPoint as of February 2019, Ensco analysis
1 Build in Brazil newbuilds exclude 10 rigs that are unlikely to be delivered 2 Assumes 65% of uncontracted Chinese newbuilds enter the global supply
Chinese Newbuilds2 Other Newbuilds >30yrs idle w/o future contract >30yrs rolling off contract by YE2019 15-30yrs idle for
- ver 2yrs
Non- marketed
123 floaters retired since 3Q14 88 jackups retired since 3Q14
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Ensco’s Leading Position
Offshore Market Recovery
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Fleet Overview
Diverse Fleet Capable of Meeting a Broad Spectrum of Customers’ Well Program Requirements
Ultra-Deepwater Drillships Versatile Semisubmersibles Premium Jackups
Includes two drillships and one jackup under construction, excludes managed rigs and rigs announced for retirement
Total Rigs:
12 12 35
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Fleet Renewal Strategy Has Improved Our Ability to Meet Customer Demand
46% 20% 17% 17%
2013
- Fleet repositioned to
focus on newest, most technically-capable assets while maintaining exposure to both shallow- and deep-water markets
– 43 rigs are either a 6th generation or greater floater or a modern high- specification jackup, up significantly from just 24 in 2013
- Rebalanced fleet
enables us to better meet customer demand for highest-specification assets
22% 5% 37% 36%
Current
34% 73%
Fleet Composition
Newbuild Deliveries
8
Acquired Assets
11
Divestitures
30
Jackups > 20 years of age 2G-5G Floaters 6G+ Floaters Jackups < 20 years of age
Current fleet includes two drillships and one jackup under construction, excludes managed rigs and rigs announced for retirement
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ENSCO DS-14 ENSCO DS-13 ENSCO DS-12 ENSCO DS-11 ENSCO DS-10 ENSCO DS-9 ENSCO DS-7 Contracted Options Under Construction Available
Ensco Fleet Well Positioned to Meet Deepwater Customer Demand
Source: IHS Markit RigPoint as of February 2019
1Drillships delivered in 2013 or later, equipped with dual BOP and 2.5mm lbs. hookload derricks
12 7 4 4 4 4 3 6
RIG ESV RDC DO NE SDRL PACD All Other
Highest-Specification Drillships1
- Ensco fleet includes seven of 44
highest-specification drillships that are preferred by customers due to the efficiencies they deliver to offshore well programs
– Utilization of these assets increased by 17 percentage points during 2018, while utilization for other drillships remained flat over the same period
- Ensco’s highest-specification
drillships provide leverage to this improving segment of the market
– Portfolio approach to contracting rigs preserves exposure to improving contracting environment
2019 2020 2021
Ensco Contract Status – Highest-Specification Drillships
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Ensco Fleet Well Positioned to Meet Mid- & Shallow-Water Customer Demand
Source: IHS Markit RigPoint as of February 2019
1 Modern moored semisubmersibles classified as < 15 years of age with 5+ ram blowout preventers, 15K psi BOP working pressure and 2 million lbs. hookload; 2Jackups < 20 years of age; chart not inclusive of all modern jackups in the global supply; 3Seadrill includes NADL, reflects 50% ownership of SeaMex and
excludes newbuilds with no recourse to parent company
30 23 22 18 13 11 9 6 6
BORR RDC/ARO ESV SDRL Maersk NE Aban Northern SHLF
Modern Jackups2
- Ensco owns four of 28 modern moored
semisubmersibles in the global fleet with enhanced well-control capabilities
– Three of these rigs are equipped with a versatile moored-DP configuration including ENSCO 8503 and ENSCO 8505, which combined have won ~40% of new floater contracts signed in the Gulf of Mexico since 2014
- Ensco maintains one of the largest
modern jackup fleets in the industry, providing exposure to the shallow- water recovery
– Open tenders for jackup rigs have more than doubled since year-end 2017
Modern Moored Semisubmersibles1
6 4 4 3 3 2 2 1 3
RIG ESV ODL Maersk SDRL NODL Bluewhale DO All Other
3
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Safety & Operational Excellence
- Critical to customers, in
particular for complex well programs
- Safety metrics consistently
better than industry averages, and high levels of operational utilization
– 1% improvement in operational utilization increases annual revenue by approximately $17 million3
- Industry leader in customer
satisfaction in performance & reliability, safety & environment, deep- & ultra deepwater drilling and other geographical category
0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 2013 2014 2015 2016 2017 2018
Total Recordable Incident Rate1
Industry Ensco
1 YTD’18 Ensco statistics as of 4Q18; IADC industry statistics as of 3Q18 2 Operational utilization is adjusted for uncontracted rigs and planned downtime 3 Based on 2018 annual revenue
Safety and Operational Performance Provides Competitive Advantage and Benefits Financial Results
95% 95% 96% 99% 99% 98% 2013 2014 2015 2016 2017 2018
Fleet-Wide Operational Utilization2
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West Africa North Sea
Global Footprint with Diverse Customer Base
Mediterranean
Note: Certain customers may not have current contracts with Ensco
Customer Base Spans Majors, National Oil Companies and Independents
Middle East Southeast Asia Gulf of Mexico South America Australia
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Ensco’s High-Quality Fleet and Global Presence Has Led to Contract Awards
- Contracts have added
approximately 57 rig years2 to Ensco’s backlog
– Diverse rig fleet and global footprint have led to floater and jackup contracts across several regions – Three recent drillship contract awards including work
- ffshore West Africa and
South America – Several recent jackup contracts around the world including the Middle East, Asia Pacific & North Sea
11% 6% 5% 5% 5% 5% 4% Ensco Company 1 Company 2 Company 3 Company 4 Company 5 Company 6
Percentage of New Contracts Awarded since 20171
Source: IHS Markit RigPoint as of February 2019; Ensco analysis Note: Independent companies with most new contract awards include Aban Offshore, ARO Drilling, Noble, Rowan, Shelf Drilling and Transocean
1 Calculated by dividing the number of rig years contracted by Ensco for fixtures classified as New Mutual in IHS Markit RigPoint (approximately 62) by the
corresponding industry-wide total (approximately 576)
2 Calculated based on date of contract execution; number of rig years awarded differs from totals in industry databases due to timing delay between date of contract
execution and public disclosure of new contracts in certain cases.
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Leveraging Innovation & Technology to Solve Industry Challenges
1 Includes provisional and non-provisional patent filings completed or in progress since 1Q15
- Focused investments in
innovation that differentiate Ensco’s assets from the competition through better performance and reliability
- This includes developing
proprietary systems, processes and technology that improve the drilling process and productivity of Ensco’s operations
- These efforts have resulted in
more than 40 patent filings since 20151
Equipment Maintenance Placing Jackups on Location
- EAMS and EPIC systems increase
- perational uptime and decrease
lifecycle costs by optimizing asset selection and maintenance activities
- Proprietary PinSafe technology
creates significant cost savings for customers by optimizing jackup moves and reducing downtime spent waiting
- n weather
Drilling Process Efficiency
- Continuous Tripping Technology™ is a
patented system that fully automates the pipe tripping process without stopping to make or break connections, enabling 3x faster tripping speeds and delivering expected cost savings along with safer, more reliable operations
Continuous Tripping Technology
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Continuous Tripping Technology
Continuous Tripping Technology Illustration While Moving Into A Well
- Fully automated system implements
unique rotary table that moves vertically using a secondary hoisting system
- Rotary table moves in synchrony with
the top drive enabling pipe connections to be made up and broken out while the drill string is moving in or out of the well
– Conventional stand-by-stand method requires drill string to stop when pipe is being connected or broken
- Applicable across all water depths
and can be retrofitted to existing rigs, i.e. would not require a newbuild rig
– Recently installed on ENSCO 123 and system commissioning is underway
Groundbreaking Patented Technology Fully Automates Pipe Tripping Process At Constant Controlled Speed Without Stopping To Make Or Break Connections
Rotary table elevates above rig floor… …to make pipe connections with the top drive… …and moving back to the rig floor at a constant controlled speed to begin the process again
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Continuous Tripping Technology Helps to Lower Customers’ Offshore Project Costs
180 153 120 130 140 150 160 170 180 190 Conventional Tripping Continuous Tripping
Illustrative One-Year Deepwater Program
$ millions
- 6 wells / 60 days per well using
conventional tripping
- >30,000 ft per well on average
- $500k/day spread cost including rig rate
~15% or $27M
Source: Ensco analysis based on data collected from offshore activities performed by Ensco over the past 10 years, including more than 4,500 wells
1Assumes average tripping speed of 9,000 ft per hour
1
3x
Faster than conventional stand- by-stand tripping methods
10%
Reduction in total time on average for all wells, and up to 15% for drill wells > 30,000 feet1
$
For multi-well projects, savings could equate to tens of millions of dollars for the customer
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Solid Financial Position
Financial Position 31 December 2018
- $2.6 billion of liquidity
– $0.6 billion of cash and short-term investments – $2.0 billion revolving credit facility
- $2.2 billion of contracted revenue
backlog
- $4.4 billion of net debt & 35% net
debt-to-capital ratio1
- Customers want financially
strong counter-parties that are able to:
– Maintain rigs – Provide stable operations – Fulfill long-term contracts
- Flexibility to make selective
investments in:
– Technology & innovation – Opportunistic asset enhancements & high-grading Balance Sheet & Liquidity Provide Financial Flexibility
Source: Company Filings
1 Net debt is a non-GAAP financial measure and should be considered as a supplement to, and not as a substitute for, or superior to, financial measures prepared in accordance with
- GAAP. Net debt-to-capital is calculated as follows: long-term debt of $5.0 billion, less $0.6 billion of cash and short-term investments, divided by the sum of long-term debt of $5.0
billion plus shareholders’ equity of $8.1 billion, minus $0.6 billion of cash and short-term investments.
27 2044
Manageable Debt Maturities in Light of Balance Sheet & Liquidity
$123 $114 $955 $669 $1,000 $150 $850
2019 2020 2021 2022 2023 2024 2025 2026 2027 2040
$300
$ millions
$1,001 $1,805
Liquidity
$604
Available Revolver1 Cash & ST Inv. $2,607
Convertible Senior Notes Senior Notes
~$236 million of Maturities Before 2024
$2,003
Cash & Short-Term Investments Revolving Credit Facility
Other Considerations
- Undrawn revolver extends beyond all near-
term debt maturities
- Fully unencumbered fleet with no secured
debt in the capital structure and a secured debt basket of $750 million
- Generated ~$330 million of net proceeds from
asset sales since year-end 2013
Source: Company Filings
1 Borrowing capacity under revolving credit facility is $2.0B through September 2019, $1.3B from October 2019 through September 2020 and $1.2B from October 2020 through
September 2022
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- Ensco’s modern high-specification
assets can generate meaningful cash flow for debt service and capital commitments in normalized day rate environment
High-Quality Fleet Provides Meaningful Cash Flow in Market Recovery
Illustrative Annual EBITDA1 Contribution from Modern High-Specification Assets Only
Source: IHS Markit RigPoint
1 Fleet includes 21 6G+ floaters and 22 jackups < 20 years of age. EBITDA calculated using illustrative dayrates and a 90% utilization assumption less average opex of $150K/day for a
floater and $50K/day for a jackup over 365 days.
2Simplified discounted cash-flow analysis assumes 35-year useful life, average opex of $150K/day, $5 million of annual maintenance costs, $10 million of survey costs every five years for
floaters; and 30-year useful life, average opex of $50K/day, $2.5 million of annual maintenance costs, $7 million of survey costs every five years for jackups; and 90% operational
- utilization. Analysis excludes debt service costs, shore-based support costs, taxes, and assumes no residual value at the end of the asset life.
100 200 300 400 500
2002 2004 2006 2008 2010 2012 2014 2016 2018
$K/day Floaters Jackups
Historical Average Day Rates
$450K/day $250K/day $125K/day $75K/day
- Based on historical build costs, an average day
rate of ~$490K for floaters and ~$160K for jackups would be needed to meet a 15% unlevered internal rate of return2
– Since 2000, the average build costs for floaters was ~$665 million, while jackups averaged ~$200 million
Floater Dayrates $250K $350K $450K Jackup Dayrates $75K 715 1,405 2,095 $100K 896 1,586 2,276 $125K 1,077 1,767 2,456
EBITDA in $ millions