Exhibit 99.1

Borr Drilling Limited – Investor Presentation

Please find enclosed investor presentation from Borr Drilling Limited.

21 May 2020

Hamilton Bermuda

 Borr Drilling LimitedExtending runway with minimum $315m in improved liquidity to 2022May 21, 2020  

 2  THE INFORMATION CONTAINED HEREIN DOES NOT CONSTITUTE AN OFFER TO SELL OR THE SOLICITATION OF AN OFFER TO BUY NOR SHALL THERE BE ANY SALE OF THE SECURITIES REFERRED TO HEREIN IN ANY JURISDICTION IN WHICH SUCH OFFER, SOLICITATION OR SALE WOULD BE UNLAWFUL PRIOR TO REGISTRATION, EXEMPTION FROM REGISTRATION OR QUALIFICATION UNDER THE SECURITIES LAWS OF ANY JURISDICTION. IT IS SOLELY FOR USE AS AN INVESTOR PRESENTATION AND IS PROVIDED FOR INFORMATION PURPOSES ONLY. THIS PRESENTATION DOES NOT CONTAIN ALL OF THE INFORMATION THAT IS MATERIAL TO AN INVESTOR. BY ATTENDING THE PRESENTATION AND/OR READING THE PRESENTATION SLIDES YOU AGREE TO BE BOUND AS FOLLOWS:The information contained herein does not constitute an offer to subscribe to or a solicitation of an offer to subscribe to securities in any member state within EEA in which such offer or solicitation is unlawful, unless in reliance upon applicable EEA prospectus exceptions, whereby no EEA prospectus, registration or similar action would be required within EEA. Forward Looking Statements: This presentation includes forward looking statements. Forward looking statements are, typically, statements that do not reflect historical facts and may be identified by words such as "anticipate", "believe", "continue", "estimate", "expect", "intends", "may", "should", "will" and similar expressions and include the equity raise, use of proceeds, the waivers and amendments to agreements with stakeholders including the terms thereof, the improvements to liquidity, allocations, changes to the application period, settlement, offshore activity levels and outlook for oil prices and demand, expected impact of cost savings initiatives including improvements to cashflow and balance sheet strengthening measures, liquidity expectations, and other non-historical statements. The forward-looking statements in this announcement are based upon various assumptions, many of which are based, in turn, upon further assumptions, which are, by their nature, uncertain and subject to significant known and unknown risks, contingencies and other factors which are difficult or impossible to predict and which are beyond our control. Such risks, uncertainties, contingencies and other factors could cause actual events to differ materially from the expectations expressed or implied by the forward-looking statements included herein. In addition to the important factors and matters discussed elsewhere in this report, important factors that, in our view could cause actual results to differ materially from those discussed in the forward looking statements include the risk that we may not be able to agree such terms with such parties or if we do agree such terms such parties may not obtain necessary board/credit committee approvals necessary for such amendments, risks relating to executing definitive documentation for such amendments if agreed, risks relating to our debt instruments including risks relating to our ability to comply with covenants and the risk of cross defaults, risks relating to our liquidity including the risk that we may have insufficient liquidity be able to fund operations, we may be unable to raise necessary funds through issuance of additional debt or equity and may have to delay or cancel discretionary capital expenditures, we may be unable to obtain extension or additional waivers or unable to meet our obligations under our debt instruments or waiver conditions resulting in cross defaults and that we may be delisted from the New York Stock Exchange as well as in our most recent annual report and in the section entitled “Risk Factors” in our filings with the Securities and Exchange Commission.  Important information 

 Key components of the improved liquidity package  3    Provides the Company with a liquidity runway even without any new contracts or renewals    The proposed deal includes the following key elements: + Rescheduling of yard commitments+ Deferral of debt amortization+ Conversion of cash interest to pay-in-kind (PIK) interest+ Amendment of covenants= Total estimated improvement in liquidity of more than $315m until Q1 2022 

 Amended financing creates very low cash-breakeven rates for 2020e and 2021e  4  Required 2021e bareboat contribution per jack-up and # of jack-ups in operation to cover direct cash costs  Cash interest for 2021 estimated to $40m, $6k/day in stacking cost per rig. 25 jack-ups deliveredBareboat contribution, current market, based on $80k/day, 97% utilisation, $50k/day opexBareboat contribution, 15 year average, based on $140k/day, 97% utilisation, $50k/day opexExcludes any tax on revenueSource: Borr Drilling, IHS Petrodata, DNB Markets  # of jack-ups in operation  Needed bareboat per jack-up $k/day  Bareboat contribution, 15 year average, jack-ups  Bareboat contribution, current market, jack-ups  # of jack-ups in operation  0  12  18  25  SG&A ($m)  -20  -20  -25  -30  Stacking cost ($m)  -55  -28  -15  0  Cash interest ($m)  -40  -40  -40  -40  Total costs ($m)  -115  -88  -80  -70  Bareboat needed to cover direct cash costs    $20.2k/day  $12.2k/day  $7.7k/day 

 Mexico integrated contracts – learning curve has improved operations  5  First wells behind schedule – recovery for geologic event  Last wells significantly ahead of schedule  Source: Borr Drilling  Planned time: 58 daysActual time: 50 days  Planned time: 44 daysActual time: 34 days  Planned time: 58 daysActual time: 78 days              Planned time: 80 daysActual time: 180 days  Geological eventloss reversed in Q1 2020    Core sampleson client request 

 Attractive entry point – solid upside  6  The value case  The cash-flow case  Implied value of EV per rig of $98m, based on ~$2.6bn net debt. Share price of $1.2. Assumes $50k/day in operating costs including SG&AIllustrative EBITDA per jack up given various dayrate levelsSource: Borr Drilling    Borr implied value  $m per jack-up  Dayrate per jack-up $k/day  EV/EBITDA  $m in EBITDA per jack-up  Depreciated value of a jack-up 

 Historic dayrates give support to debt service  7  Estimated historic bareboat contribution per premium jack-ups vs required rate for debt service  Assumes Q1 2020 net debt + remaining capex estimated to ~$2.6bnBareboat calculated as TC-rate less applicable opex1) Average age based on 28 modern jack-up built after 2010.Source: Borr Drilling, DNB Markets  Contribution required for debt service with 28 rigs in operation – $29k/day  Fully invested net debt  $2,600m  # units  28  Average net debt per rig  $92.9m  Average age of fleet1  3  Age when debt is 0  20 years      Amort per rig (17y)  $14k/day  Interest per rig (6%)  $15k/day  Debt service per rig  $29k/day  Contribution required to cover direct cash costs 2021e – $20k/day  $k/day 

 Shallow water oil production - quick payback – driven by NOCs  8  Jack-up demand is mainly brownfield – 75% NOCs  Core NOCs are drilling significantly more today  Source: IHS Petrodata, DNB Markets, Borr Drilling  # jack-ups contracted  Brownfield  Greenfield  Exploration  Greenfielddevelopment  Infill drilling  Workover  P&A  3%  2%  6 months  3 months  2 years  3 years  7 years  3-4 years  1 year  6 months  Time to first oil  Global demand by type of OilCo        Jack-up  Floater  NOC %  74.7%  34.6%  IOC %  25.3%  65.4% 

     The global jack-up fleet is old – modern rigs will likely get utilisation  9  Modern jack-ups gaining market share  Historic jack-up demand vs age of supply  >35% of the fleet is > 20 years old  1) Assumed scrapping of 10 owner operated rigs. Borr Drilling assumptionSource: IHS Petrodata, Rystad, Borr Drilling  1985  1971  1973  1975  1977  2015  1979  1981  2005  1983  1987  1989  2003  1991  1993  1996  1999  2001  2007  2009  2013  2011  2017  2019  2010 – 2022259 rigs  2000 – 201096 rigs  1968 – 2000167 rigs    355 “modern” rigs  Premium jack-up rig count  Standard jack-up rig count  114  254  193  225  Premium jack-up rig count  114  254  193  225     # jack-ups  Total fleet  522  Stacked standard units  -55  Standard with <12 months contract left  -39  Standard owner operated exp scrapped1)  -10  Expected total fleet mid-21  418  Under construction (not marketed)  -45  2000-2010 cold stacked (not marketed)  -13  Expected marketed supply mid-2021  360  Average demand 342 rigs  “Legacy” fleet     Delivered jack-ups pr year    Modern jack-up rig count    Standard jack-up rig count 

 Could oil market be similar to 1998? – “Asian flu” created the upturn  10  Oil prices bottomed when inventories peaked  Next 6 year – dayrates went to $230k/day  Similarities to 1999 cycle  Source: Bloomberg, IHS Petrodata, DNB Markets  $k/day  # NB delivered  Day-rates + 400% in 24 months           1998/99  2020  OECD oil inventory  ~2,800  ~3,400  Inventory day of demand  ~37  ~34  Oil price at peak inventory  $11/brl  -$37 ?  Oil price 24 months after  $30/brl  ?  Trough day-rates  ~$15k/day  $60-80k/day  Day-rates after 24 months  ~$100k/day  ?  Day-rates after 36 months  ~$130k/day  ?  Years of E&P underinvestment  3 years  5 years   

 Oil the best performing sector last month – turning point?  11  Oil services in context1)  Lessons from the last cycle2)  Energy weighting in % of technology3)  1) 100m brl/day at $35/brl. Market cap all listed oil services. Market cap all listed offshore drillers2) Assumes average date-rate of $140k/day from 2002 to 2020 at 90% utilisation. Opex of $50k/day3) Energy weighting % of the S&P 500 divided by technology % of the S&P 500. Higher ratio means relative size of energy vs technologySource: Bloomberg, DNB Markets  $bn  $m