UDW Inc. NASDAQ: ORIG February 21, 2018 4 th Quarter Ended December 31, 2017 Earnings Presentation
Forward Looking Statements Matters discussed in this presentation may constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. The Private Securities Litigation Reform Act of 1995 provides safe harbor protections for forward-looking statements in order to encourage companies to provide prospective information about their business. The Company desires to take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 and is including this cautionary statement in connection with such safe harbor legislation. Forward-looking statements relate to s expectations, beliefs, intentions or strategies regarding the future. These statements may be identified by the use of words like anticipate, believe, estimate, expect, intend, may, plan, project, should, seek, and similar expressions. Forward-looking statements reflect s current views and assumptions with respect to future events and are subject to risks and uncertainties. The forward-looking statements in this presentation are based upon various assumptions, many of which are based, in turn, upon further assumptions, including without limitation, management s examination of historical operating trends, data contained in s records and other data available from third parties. Although believes that these assumptions were reasonable when made, because these assumptions are inherently subject to significant uncertainties and contingencies which are difficult or impossible to predict and are beyond s control, Ocean Rig cannot assure you that it will achieve or accomplish these expectations, beliefs or projections described in the forward- looking statements contained herein. Actual and future results and trends could differ materially from those set forth in such statements. Important factors that, in s view, could cause actual results to differ materially from those discussed in the forward-looking statements include factors related to (i) the offshore drilling market, including supply and demand, utilization, day rates and customer drilling programs, commodity prices, effects of new rigs and drillships on the market and effects of declines in oil and gas prices and downturns in the global economy and the market outlook for our various geographical operating sectors and classes of rigs and drillships; (ii) hazards inherent in the drilling industry and marine operations causing personal injury or loss of life, severe damage to or destruction of property and equipment, pollution or environmental damage, claims by third parties or customers and suspension of operations; (iii) newbuildings, upgrades, and shipyard and other capital projects; (iv) changes in laws and governmental regulations, particularly with respect to environmental matters; (v) the availability of competing offshore drilling vessels; (vi) political and other uncertainties, including risks of terrorist acts, war and civil disturbances; piracy; significant governmental influence over many aspects of local economies, seizure; nationalization or expropriation of property or equipment; repudiation, nullification, modification or renegotiation of contracts; limitations on insurance coverage, such as war risk coverage, in certain areas; political unrest; foreign and U.S. monetary policy and foreign currency fluctuations and devaluations; the inability to repatriate income or capital; complications associated with repairing and replacing equipment in remote locations; import-export quotas, wage and price controls imposition of trade barriers; regulatory or financial requirements to comply with foreign bureaucratic actions; changing taxation policies; and other forms of government regulation and economic conditions that are beyond our control; (vii) the performance of our rigs; (viii) our new capital structure; (ix) our ability to procure or have access to financing and access to financing and our ability comply with covenants in documents governing our debt; (x) our substantial leverage, including our ability to generate sufficient cash flow to service our existing debt and the incurrence of substantial indebtedness in the future; (xi) our ability to successfully employ our drilling units, our customer contracts, including contract backlog, contract commencements and contract terminations; (xii) our capital expenditures, including the timing and cost of completion of capital projects; (xiii) our revenues and expenses; (xiv) complications associated with repairing and replacing equipment in remote locations; and (xv) regulatory or financial requirements to comply with foreign bureaucratic actions, including potential limitations on drilling activities; (xvi) any litigation or adverse actions that may arise from our recently completed financial restructuring. Due to such uncertainties and risks, investors are cautioned not to place undue reliance upon such forward-looking statements. We caution you not to place undue reliance on these forward-looking statements. Except as required by law, we expressly disclaim any obligation to update and revise any forward looking statements to reflect changes in assumptions, the occurrence of unanticipated events, changes in future operating results over time or otherwise and we do not intend to do so. Risks and uncertainties are further described in reports of UDW Inc. filed with or submitted to the U.S. Securities and Exchange Commission, including the Company s most recently filed Annual Report on Form 20-F. 2
Q4 Results In-Line With Strong Operational Performance (Incom e Statem ent Expressed in Millions of U.S. Dollars except for share and per share data) Q4 2017 Adjustments Q4 2017 Adjusted REVENUES: Revenues 211.5 0.0 211.5 Q4 Revenue Efficiency of 98.7% EXPENSES: Drilling units operating expenses 61.6 (8.4) 53.2 Depreciation and amortization 26.2 0.0 26.2 General and administrative expenses 27.4 0.0 27.4 Loss on sale of fixed assets 0.1 0.0 0.1 Legal settlements and other, net (5.5) 0.0 (5.5) Operating income/(loss) 101.7 8.4 110.1 OTHER INCOME/(EXPENSES): Interest and finance costs, net of interest income (8.8) 0.0 (8.8) Reorganization gain, net 1.9 0.0 1.9 Other, net 0.3 0.0 0.3 Income taxes (15.7) 0.0 (15.7) Total other income/(expenses), net (22.3) 0.0 (22.3) Net income/ (loss) attributable to UDW Inc. Earnings/(loss) per common share, attributable to common stockholders, basic and diluted Weighted average number of shares, basic and 0.87 0.96 diluted 91,235,457 91,235,457 79.4 8.4 87.8 Q4 Adjusted EBITDA of $136.8m 3
Q4 2017 Revenue And Operating Expenses Summary During the quarter, we had 1,012 calendar days out of which 552 were uncontracted, 75 days were spent in hot stacking ( Poseidon) and 17 days were spent in mobilization ( Poseidon). Resulting in 368 available contracted drilling days, of which 363 were revenue earning days i.e. 98.7% Contracted Revenue Efficiency (1). Mobilization/ Uncontracted/Class Survey/Stacking Days Available Contracted Drilling Days Off-hire Days Revenue Earning Days Contracted Revenue Efficiency (1) Amortization of Deferred Revenues (a) (b) (a-b) (c) ($ mln) Total Fleet Q4 2017 644 368 5 363 98.7% $6.4 Our daily direct and onshore rig operating expenses this quarter averaged approximately $121k/unit (2) versus $118k (3) /unit during Q3 2017. Q4 2017 Direct & Onshore Rig Opex Q4 2017 Amortization of Deferred Opex (in USD million) ('000 USD/day) (2) (in USD million) Total / Average Fleet $52.1 $121 $0.4 (1) Contracted Revenue efficiency calculated based on revenue earning days over available contracted drilling days (i.e. calendar days net of mobilization, acceptance testing, uncontracted/idle and drydock days). (2) Opex of units in operation excluding opex of idle units, Olympia, Eirik Raude, Paros, Athena, Mylos, Apollo and Poseidon (hot-stacked and in mobilization during Q4 2017) for the respective idle days (3) Opex of units in operation excluding opex of idle units, Olympia, Eirik Raude, Paros, Athena, Mylos and Apollo for the respective idle days. 4
Best In Class Balance Sheet As of December 31, 2017 (excl. Apollo) Apollo Total Cash ($m) 738 45 783 Debt ($m) 450 82 532 Backlog ($m) (1) 969 46 1,015 No debt repayment until Term Loan maturity in 2024 Almost 7 year runway for the Company to take advantage of market recovery Apollo expected to be debt free by mid 2018 Apollo debt facility is ring-fenced and served exclusively from TOTAL termination payments Apollo to be included in Exit Term loan collateral pool, after debt facility repayment (1) (1) As of 31 December 2017, adjusted for subsequent events 5
('000 USD/day) '000 USD/day) Strong Operational Performance & Significant Cost Reductions Running costs of Operating Rigs only G&A 200 150 100 186 148 117 126 50 40 30 20 41 28 27 18 50 10 0 2014 2015 2016 2017 (3) 0 2014 2015 2016 2017 # of Op. Rigs: 9 10 6 5 # of Rigs: 9 10 11 11 TRIR (12 month rolling) (1) Revenue Efficiency (2) 0.6 0.5 0.4 0.3 0.2 0.49 0.42 0.22 0.48 100.0% 90.0% 80.0% 70.0% 95.4% 97.4% 96.4% 97.6% 0.1 60.0% 0 2014 2015 2016 2017 50.0% 2014 2015 2016 2017 (1) TRIR means, with respect to the Company, the total recordable incident rate: calculated as an amount equal to: (a) the product of (i) the number of recordable incidents (restricted work case, medical treatment case, lost time accident, or fatality) multiplied by (ii) 200,000, divided by (b) total working hours. (2) Revenue efficiency calculated based on revenue earning days over available contracted drilling days (i.e. calendar days net of mobilization, acceptance testing, uncontracted/idle and drydock days). 6
Meaningful Backlog With Reliable Counterparties Total Backlog of $969 million (1)(2)(3) Drilling Unit Type Built Operator Leiv Eiriksson Semi-Sub 2001 Lundin J F M A M $147k /day J 2018 $150k/day J A S O N D Corcovado Drillship 2011 Petrobras $495k/day (4) Las Palmas Poseidon Drillship 2011 Statoil $170k /day Walvis Bay Mykonos Drillship 2011 Petrobras $495k/day (4) Las Palmas Skyros Drillship 2013 Total $581k/day (5) Contract expires in Q3 2021 Operational Optional Wells Yard Stay Ready to Drill The Company s previously announced drilling contract of Poseidon with Statoil, for a one-well drilling program offshore Tanzania, has been successfully completed. The Poseidon is transiting to Walvis Bay, where it will replace its thrusters and will remain in ready-to-drill state, and be actively marketed for employment. The Company s drilling unit Mykonos, which is expected to complete her current drilling contract with Petrobras within March 2018, is planned to transit to Las Palmas, where it will remain in ready-to-drill state, and be actively marketed for employment. During the Mykonos stay in Las Palmas, the unit will be fitted with a full Managed Pressure Drilling (MPD) package The Company s drilling unit Corcovado, which is expected to complete her current drilling contract with Petrobras end of May 2018, is planned to transit to Las Palmas, where it will remain in ready-to-drill state, and be actively marketed for employment On January 12, 2018, Lundin declared their sixth option on the Leiv Eiriksson contract, which is now expected to have firm employment secured until August 2018. Should Lundin exercise its remaining six one-well options, the rig could be employed until the second half of 2019 On February 7, 2018, the Leiv Eriksson commenced its shipyard stay at Olen, Norway where it will undergo certain enhancements related to its contract with Lundin, conduct an intermediate survey and upgrade its BOP to 5-rams. (1) Excludes termination payments associated with the Apollo. (2) As of 31 December 2017, adjusted for subsequent events (3) Assuming Lundin does not exercise its optional wells. (4) Based on FX rate assumptions. (5) Current applicable dayrate. Note: The Eirik Raude, Olympia, Mylos, Athena, Paros and Apollo are actively marketed and available for drilling 7
# of units ($bn) Ultra-Deepwater Driller With 2 nd Largest Market Cap Offshore Drillers by number of units (Floaters) (1) Offshore Drillers by Market Capitalization 40 38 4.5 4.2 35 4.0 30 25 20 15 10 26 19 11 11 10 8 7 3.5 3.0 2.5 2.0 1.5 1.0 2.3 2.2 1.9 1.0 0.9 5 0 0.5 0.0 0.1 0.0 (1) Excludes all NB contracts, and 4 th Gen and below. Source. : Company data Source: Bloomberg (closing price as of 16-Feb-2018) 8
High Quality Assets With Superior Technology Harsh Environment UDW Semis Sister Drillships provide Benefits from Standardization Potential Optional Value 5 th generation Semisubmersibles Five 6 th generation Drillships Four 7 th generation Drillships Two 7 th generation NB Drillships Leiv Eiriksson Eirik Raude Corcovado Olympia Poseidon Mykonos Paros Mylos Skyros Athena Apollo Santorini Crete 11 drilling units Built at Dalian/Friedman Goldman Irving Bingo 9000 design Up to 7,500-10,000 ft. water depth capacity Up to 30,000 ft. drilling depth capacity Moored units and winterized for operations in extreme climates Compliant with UK and Norway regulations Built at Samsung Heavy Industries Sister Drillships with common equipment, spare parts and training standards Up to 10,000-12,000 ft. water depth capability Up to 40,000 ft. drilling depth capability with 6 and 7 ram BOPs Dual derricks for increased drilling activity/efficiency Accommodations for up to 215 personnel on board Mylos equipped with dual BOP Corcovado & Mykonos MPD Ready Current contractual Delivery in June 2018 and January 2019 at SHI Delivery installments with Builder s Credit No parent company guarantee from UDW Inc. Santorini sistership to Mylos, Skyros, Athena, Apollo Crete enhanced integrated design 9
Our Assets Are Well Preserved and Maintained Key Initiatives Online Condition Monitoring Systems Asset Optimization Improved performance, reliability and safety, reduced cost of ownership Rig Stacking Procedure Verified by 3 rd Party 5 rigs at Elefsis Bay anchorage, Greece Frontrunner in the industry Rolls Royce Thruster Monitoring System (2012) NOV Drilling Equipment Monitoring (2014) NOV BOP Monitoring and function logger (2014) ADC consider that the cold stacked preservation methods employed by on its drillships to be fit for purpose and have given the rigs equipment every opportunity for a successful reactivation when the time comes. This conclusion was based upon the visual inspections of the current equipment condition and the documented preservation philosophies by, OEMs and Corroless the 3 rd party preservation specialists. - Reports Issued in October 2017/January 2018 1 rig at Astakos quayside, Greece Sheltered locations Mooring analysis approved by BV certified surveyors Low humidity environment Easy access from operations head office, for following up on maintenance routines/preservation 10
USD Oil Price In The Right Zip Code For Improved Rig Demand Europe Brent Spot Price 140 120 100 80 60 40 20 0 Source: Thomson Reuters 11
2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 USDm Resources P50 (billion bbls) Cumulative % of total P50 resources Conditions Are Ripe For A Turnaround Average spending per offshore project per year Breakevens of undeveloped offshore liquids (P50) 300 25 100% 250 20 90% 80% 200 70% 15 60% 150 50% 100 50 10 5 40% 30% 20% 10% 0 0 0% Shelf (to 400 ft) Deep water (400+ ft) Resources Cumulative % Low activity led to severe deflation but lower breakevens: Over 80% of offshore is breakeven <$60 Source: Clarksons Platou Securities AS 12
Cash Flow Situation Key E&P Companies Source: SB1 Markets Research Note 1: Group consisting of Anadarko, BP, Chevron, ConocoPhillips, ENI, ExxonMobil, Repsol, Shell, Statoil, Total 13
Floating Rigs Awarded Floating Rigs Years awarded (per rig year) Floating Rigs Contracts awarded (Number of contracts) Tender activity is increasing but shorter program awarded => First sign of recovery Source: DNB Market and ODS 14
is Well Positioned for the Market Upturn High Quality Fleet & Track Record Fleet of 9 modern (6th and 7th generation) UDW Drillships, 2 UDW harsh environment semisubmersible rigs and contracts for 2 newbuildings (7th and 8th generation) UDW drillships with Samsung Heavy Industries Stacked assets are well preserved and maintained, as verified by 3 rd party inspection Strong relationships with customers Proven track record of safety, efficiency, drilling performance and cost control BEST IN CLASS BALANCE SHEET Negative net debt with no amortization due for the next 7 years (1) (maturity of $450m term loan in Q3 2024) Ample liquidity supported by cash balance of $738 million (2) $969 million backlog (3) Transparent corporate governance Majority independent board, with all major actions approved by three independent directors selected by the major outside shareholders In prime position to benefit from recovery in the offshore drilling market, whenever this occurs (1) Excluding ring-fenced Apollo debt facility. (2) Excluding cash associated with the Apollo. (3) Backlog, excluding termination payments associated with the Apollo. As of 31 December, 2017, adjusted for subsequent events. 15
Appendix
Liquidity & Capital Structure (in $ million) 31-Dec-17 Ownership on December 31, 2017 # Shares Total cash 783.1 Class A Shares 90,562,138 DnB Apollo Facility $475 million (net of financing 81.6 Class B Shares 1,005,844 fees) Deutsche Bank Loan $450 million 450.0 Number of Shares Outstanding as of Dec 31, 2017 91,567,982 Total debt 531.6 Free Float Shares 82,036,360 Total shareholders equity 2,203.2 % of free float Shares 89.6% Total capitalization 2,734.8 Net Debt (251.5) Equity Market Cap (1) 2,296.5 Debt to capitalization 19.4% Net Debt (251.5) Net Debt to Capitalization (9.2%) Enterprise Value 2,045.0 (1) (1) As of February 16, 2018. 17
Projected Deferred Revenue & Expense Amortization As of February 19, 2018 (USD million) Q1A 2017 Q2A 2017 Q3A 2017 Q4A 2017 FY 2017 Q1E 2018 Q2E 2018 Q3E 2018 Q4E 2018 Amortization of deferred revenues 7.5 6.3 6.3 6.4 26.5 10.9 2.5 1.3 1.3 Amortization of deferred expenses 5.0 0.7 0.4 0.4 6.4 5.4 0.4 0.4 0.4 Includes current accounting schedule and projected additions from future mobilizations Definitions Deferred Revenues include lump sum fees received related to mobilization, capital expenditures reimbursable for contract related rig upgrades etc. These revenues are capitalized and amortized through the duration of the contract. Deferred Expenses include costs (recurring operating expenses, tug boats & helicopter rentals etc.) incurred during mobilization, capital expenditures for contract related rig upgrades etc. These costs are capitalized and amortized through the duration of the contract. 18
Balance Sheet 19
Income Statement 20