Investor Presentation April 2015 1
Forward-Looking Statements Statements contained in this 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, day rates and backlog, estimated rig availability; rig commitments; scheduled delivery dates for rigs; the timing of delivery, mobilization, contract commencement, relocation or other movement of 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 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; our ability to realize the expected benefits from our redomestication and actual contract commencement dates; cybersecurity risks and threats; and the occurrence or threat of epidemic or pandemic diseases or any governmental response to such occurrence or threat 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. 2
Profile #1 in customer satisfaction five consecutive years Highest net income margins among major competitors Best ever total recordable incident rate in 2014 and 1Q15 High-quality fleet of floaters and jackups Broad diversification: customer, geography, rig type Capital management flexibility no significant debt maturities until 2Q19 $1.6 billion of cash and short-term investments $2.25 billion revolving credit facility $8.4 billion of contracted revenue backlog investment-grade credit ratings ~2.5% dividend yield; top half of S&P 500 Companies Note: Cash and short-term investments, revolving credit facility capacity and contracted revenue backlog as of 31 March 2015 3
Market Environment Sharp drop in commodity prices accelerated beginning late fourth quarter 2014 New lows/increased volatility for oil prices during customers budget season Capital expenditures declining in 2015 as customers re-evaluate programs in light of lower commodity prices Customers shortening contracts where permitted and requesting concessions Uncontracted newbuilds and customer sublets creating additional supply Aging of current global fleet should lead to more retirements and stacking, especially as rigs approach 30/35 year surveys Some newbuilds being cancelled and others being delayed 4
Sharp Decline in Oil Prices 20% 10% 0% -10% -20% -30% -40% -50% -60% Brent WTI Source: Thomson One; commodity prices indexed to 31 December 2013 close prices; data through 23 April 2015 5
Ensco s Proactive Fleet Management 2Q14 Moved five floaters to held for sale to proactively reduce expenses; one later sold for scrap value 3Q14 Sold four jackups for more than $200 million 4Q14 Classified additional 4 rigs as discontinued operations All held-for-sale rigs cold stacked to quickly reduce expenses 1Q15 Expedited cold stacking decision for ENSCO 8501 and ENSCO 8502 plus several jackups to accelerate cost savings 6
Proactive Steps to Address Market Downturn Reduce offshore discretionary compensation and onshore support costs 9% unit labor cost decrease beginning 2Q15 for total offshore compensation 15% Reduction in Force for onshore personnel including corporate staff o $27 million annualized savings beginning 2Q15 Highgrade fleet delivery of ENSCO DS-9 and ENSCO 110 divestitures and held-for-sale rigs Negotiate with vendors and suppliers to lower costs Successful 1Q15 debt offering to refinance $1.1 billion of near-term debt maturities and improve liquidity/capital management flexibility Reduced quarterly dividend to $0.15 per share to improve capital management flexibility during downturn 7
Strong operational, safety and financial performance 99.6% jackup operational utilization record TRIR of 0.34 revenues and margins increased year over year disciplined expense management #1 in customer satisfaction 5 th consecutive year Investment-grade credit ratings reaffirmed highest among major offshore drillers 1Q15 Highlights 8
Current Market Floaters Jackups Active Fleet Contracted 228 326 Uncontracted 33 58 Stacked Marketed Rigs 12 21 Total 273 405 % Contracted 84% 80% Newbuilds Under Construction 59 106 On Order / Planned 23 12 Total 82 118 Contracted 54% 7% Uncontracted 46% 93% Source: IHS-ODS Petrodata as of April 2015; competitive marketed floaters and jackups (independent leg cantilever rigs) 9
Newbuild Jackup Order Book 7% 8 Contracted, Established Drillers 118 Total 32% 38 Uncontracted, Established Drillers 60 Uncontracted, Non-Established Drillers 51% 12 On Order, All Uncontracted 10% Source: IHS-ODS Petrodata as of April 2015; marketed competitive jackups (independent leg cantilever rigs) 10
Newbuild Jackup Delivery Schedule 60 50 40 30 20 10 0 32 19 6 25 14 2 3 2 9 1 4 1 2015 2016 2017 2018 Uncontracted, Established Drillers On Order, Non-Established Drillers Contracted Non Established Drillers Under by Shipyard Constr. On Order Total China China Merchants Heavy Industry 16 16 Shanghai Waigaoqiao Shipbuilding 6 2 8 Yantai CIMC Raffles 6 6 Other 21 2 23 Subtotal 49 4 53 Singapore & Middle East Keppel FELS, Singapore 11 11 UAE & Dubai 3 3 Subtotal 11 3 14 Total 60 7 67 On Order, Established Drillers Uncontracted, Non-Established Drillers Source: IHS-ODS Petrodata as of April 2015; marketed competitive jackups (independent leg cantilever rigs) 11
Jackup Supply 80 127 169 59 125 23 198 106 22 263 65 24 18 20 303 308 Assumes all rigs On Order or partially completed including rigs built by Non- Established Drillers are built, delivered and complete customer acceptance testing Apr. 2015 Apr. 2016 Apr. 2017 Apr. 2018 < 15 years old 15-30 years old 30-35 years old > 35 years old Source: IHS-ODS Petrodata as of April 2015; marketed competitive jackups (independent leg cantilever rigs) 12
Newbuild Floater Order Book 82 Total 19% 16 Contracted 17 SETE Brasil, Under Construction 21% 32% 26 Uncontracted, Under Construction 12 SETE Brasil, On Order 11 Uncontracted, On Order 13% 15% Source: IHS-ODS Petrodata as of April 2015; marketed competitive floaters 13
Newbuild Floater Delivery Schedule 30 25 20 15 10 5 0 10 4 8 2 5 Under SETE Brasil by Shipyard Constr. On Order Total Estaleiro Atlantico Sul 4 3 7 Estaleiro Jurong Aracruz 4 3 7 BrasFELS, Angra dos Reis 5 1 6 Estaleiro Enseada do Paraguacu 2 4 6 Ecovix Engevix, Rio Grande do Sul 2 1 3 Total 17 12 29 1 2 14 10 2 9 6 4 2 1 1 1 2015 2016 2017 2018 2019 2020 Uncontracted, Under Construction SETE Brasil, On Order Contracted Uncontracted, On Order SETE Brasil, Under Construction Source: IHS-ODS Petrodata as of April 2015; marketed competitive floaters 14
Floater Supply 45 38 36 154 47 38 40 175 51 66 38 27 40 37 197 212 Assumes all rigs On Order or partially completed including rigs built in Brazilian shipyards are built, delivered and complete customer acceptance testing Apr. 2015 Apr. 2016 Apr. 2017 Apr. 2018 < 15 years old 15-30 years old 30-35 years old > 35 years old Source: IHS-ODS Petrodata as of April 2015; marketed competitive floaters 15
Newbuild Cancellations and Deferrals Jackups 6 jackups ordered by non-established drillers were cancelled since mid-year 2014 Seadrill delays 8 jackups with 2015/2016 scheduled deliveries by a total of 44 months Transocean delays 5 jackups with 2016/2017 expected deliveries by ten months each on average Floaters Reports suggest more than half of the 29 rigs in SETE Brasil program may be cancelled Atwood delays 2 drillships with 2015 expected deliveries by six months each 16
Increase in Rig Retirements and Cold Stacking Floaters Jackups 30 12 25 10 20 8 8 11 15 6 10 5 0 18 12 1 2 3 2Q14 3Q14 4Q14 1Q15 2Q15 4 2 0 4 3 1 1 2 2 1 2Q14 3Q14 4Q14 1Q15 2Q15 Scrapped Cold Stacked Scrapped Cold Stacked Source: IHS-ODS Petrodata as of April 2015; competitive marketed floaters and jackups (independent leg cantilever rigs); includes scrapped rigs, rigs to be scrapped and rigs converted to non-drilling units 17
Well Positioned to Manage Through Downturn Capital management flexibility Highest net income margin among major competitors Fleet highgrading 5 newbuild rigs under construction with differentiated designs prior floater upgrade investments benefiting 2015 results mooring capability to be added to select ENSCO 8500 Series rigs 19 rigs sold since beginning of 2010; 7 held-for-sale rigs as of 3/31/15 Global presence and diverse customer base operations across six continents extensive customer relationships: NOCs, Majors, IOCs 18
Organic Growth: Newbuild Contracts/Deliveries 2012.75 2013.75 2014.75 2015.75 2016.75 2017.75 2018.75 2019.75 2013 2014 2015 2016 2017 2018 2019 2020 ENSCO DS-7 ENSCO 120 ENSCO 121 ENSCO 122 ENSCO DS-9 ENSCO 110 ENSCO DS-8 ENSCO DS-10 ENSCO 123 ENSCO 140 ENSCO 141 3 yrs with Total 2+ yrs with Nexen 2 yrs w/ Wintershall 2 yrs with NAM 3 yrs with ConocoPhillips 5 yrs with Total Delivered & Contracted Delivered & Uncontracted Under Construction & Contracted Under Construction & Uncontracted Drillships Premium jackups 19
High Quality Fleet 63 Rig Fleet 9 11 3 40 ULTRA & DEEP WATER DRILLSHIPS DYNAMICALLY POSITIONED SEMISUBMERSIBLES MOORED SEMISUBMERSIBLES PREMIUM JACKUPS Note: Includes rigs under construction. Excludes managed rigs and rigs in discontinued operations 20
Global Platform Europe & Mediterranean U.S. Gulf of Mexico Ships 3 Semi 1 Jackups 11 Semis 6 Jackups 7 Middle East Africa Jackups 10 Ships 3 Jackups 1 Asia Pacific Brazil Semis 4 Under Construction Ships 2 Jackups 3 Ships 1 Semi 3 Jackups 8 Held for Sale Ships 1 Semis 4 Jackups 2 21
Contracted Revenue Backlog Diversification 29% 29% Semis Premium Jackups 24% 30% Independents National Oil Companies 42% Drillships 13% Europe & Med 10% Asia Pacific North & South America 21% Majors 46% 29% Note: Contracted revenue backlog as of 31 March 2015 Africa Middle East Brazil 12% 15% 22
Uptime = Net Inc. Margin = Customer Satisfaction 30.0% 29.6% Net Income Margin 19.1% 18.1% 17.7% 15.0% ESV SDRL DO NE RIG RDC Source: Thomson One; sum of trailing eight quarters of net income divided by sum of trailing eight quarters of revenue. Thomson One's data is based on aggregation of information collected from industry equity research analysts, and may not be based on GAAP reported financial data 23
Industry Leader in Customer Satisfaction Rated #1 Total Satisfaction Health, Safety & Environment Technology Special Applications Deepwater Drilling Shelf Wells Non-Vertical Wells Harsh Environment Wells North Sea Latin America & Mexico 24
Safety, Health & Environment 1.2 1.0 0.8 Total Recordable Incident Rate Record 1Q15 safety performance as measured by TRIR Leading-edge safety management systems 0.6 0.4 0.2 0.0 2008 2009 2010 2011 2012 2013 2014 YTD 2015 Ensco Note: 2015 TRIR for Industry is as of 4Q14 Industry Major competitive advantage; especially versus non-established drillers 25
Capital Management and Financial Position Investment-grade credit ratings from Moody s/s&p; top ratings among major offshore drillers No significant debt maturities until 2Q19 $1.6 billion of cash and short-term investments 31% net debt-to-capital ratio (net of $1.6 billion of cash and short-term investments) $2.25 billion available revolving credit facility $8.4 billion of contracted revenue backlog Reduced quarterly dividend to improve capital management flexibility Note: Cash and short-term investments, net debt-to-capital ratio, revolving credit facility capacity and contracted revenue backlog as of 31 March 2015 26
Credit Ratings BBB+ BBB+ BBB- BBB- Investment Grade BB+ Not Rated ESV DO NE RDC RIG SDRL Source: Bloomberg composite credit ratings as of 24 April 2015 27
Contracted Revenue Backlog $8.4 Billion Total $ billions $2.8 $2.7 $1.6 $1.3 2Q15-4Q15 2016 2017 2018+ Note: Contracted revenue backlog as of 31 March 2015 28
Capital Expenditures $ billions ~$1.7B 0.175 0.175 Note: Final rig enhancement and sustaining project capital expenditure budgets for 2016 and 2017 TBD once budgets are completed. Zero capital expenditures for newbuild construction in 2017. <$1.0B 1.35 TBD TBD 0.40 TBD TBD 2Q15-4Q15 2016 2017 Newbuild construction Rig enhancements Sustaining 29
Debt Maturity Profile $ millions $3,000 Upsized Revolving Credit Facility to $2.25B in Sep. 2014 $2,700 $2,400 $2,100 $1,800 $1,500 $2,250 $1,500 $1,200 $900 $600 $300 $0 No significant debt maturities for four years $7 $7 $500 $900 $625 $700 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 $150 $300 2027 2040 $1,025 2044 Note: As of 16 April 2015. Approximately $200 million of cash as of 31 March 2015 was used to extinguish 3.25% senior notes due 2016 that remained outstanding following first quarter 2015 tender offer and $51 million of aggregate principal amount of MARAD obligations 30
Leader in customer satisfaction five consecutive years Highest net income margin among major competitors Best ever total recordable incident rate High-quality fleet of floaters and jackups 10 year average age for go-forward floater fleet o 4 year average age for ultra-deepwater fleet Technology advantages, e.g. ENSCO 120 Series jackups and Samsung GF 12,000 drillships $8.4 billion of contracted revenue backlog Disciplined expense management Capital management flexibility Ensco s Strengths Note: Contracted revenue backlog as of 31 March 2015 31
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