Exhibit 99.3

Borr Drilling LimitedQ2 2019 results presentation29 August 2019

Important information and disclaimer 2 | This presentation (the “Presentation”) has been prepared by Borr Drilling Limited (the “Company”) and sets forth general background information about the Company's activities current as at the date hereof. Information in this Presentation, including forecast financial information, should not be considered as advice or a recommendation to investors or potential investors in relation to holding, purchasing or selling securities or other financial products or instruments and does not take into account your particular investment objectives, financial situation or needs. Before acting on any information you should consider the appropriateness of the information having regard to these matters, any relevant offer document and in particular, you should seek independent financial advice. 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Highlights 3 | Operating revenues of $86.6 million, net loss of $103.2 million and Adjusted EBITDA of negative $4.9 million forthe second quarter of 2019Technical utilization for the operating rigs was 98.8% in the second quarter and 99.0% for the first six months of 2019The results include $31.5 million in mark to market losses related to Valaris forward contractsTotal accumulated backlog awarded in 2019 of $300 million and 3600 daysCompleted loan financing in a total amount of $645 million and thereby the existing fleet is fully financed with no final maturity until 2022.Completed the successful activation/reactivations and commencement of contracts for five premium jack-up rigs in the second quarter, and three after quarter endCompleted the initial public offering on New York Stock Exchange under the ticker BORR, issuing 5,750,000 shares at a price of $9.30 per share The Company uses certain financial information calculated on a basis other than in accordance with accounting principles generally accepted in the United States (US GAAP) including Adjusted EBITDA. Adjusted EBITDA as used herein represent net loss less: depreciation and impairment of non-current assets, amortisation of contract backlog, net financials, gain from bargain purchase and income tax expense. Adjusted EBITDA is included as a supplemental disclosure because the Company believes that the measure provides useful information regarding the Company’s operational performance.

Key Financials Q2 2019 4 | Income Statement USDm YTD 2019 Q2 2019 Q1 2019 Operating revenues 138.5 86.6 51.9 Gain on disposals 3.9 3.9 - Rig operating and maintenance expenses (138.5) (81.4) (57.1) Depreciation (48.5) (24.6) (23.9) Impairment (11.4) - (11.4) Amortisation of contract backlog (14.5) (7.1) (7.4) G&A (24.1) (14.0) (10.1) Total operating expenses (237.0) (127.1) (109.9) Operating loss (94.6) (36.6) (58.0) Total financial income (expenses), net (62.3) (64.1) 1.8 Loss before income taxes (156.9) (100.7) (56.2) Tax (2.7) (2.5) (0.2) Net loss (159.6) (103.2) (56.4) Basic loss per share ($/share) (1.52) (0.98) (0.52) Comments Q2 2019 Operating revenues increase was mainly due to the commencement of contracts for five rigs in the quarter and improved rates on MSS1Gain on disposals related to sale of the standard rigs “Baug” and“C20051”Rig operating and maintenance expenses increase was primarily driven by five more rigs in operation in the second quarter as compared to the first quarter of 2019, partly offset by lower reactivation costs asImpairment in Q1 2019 relates to the anticipated sale of the cold stacked, standard jack-up rig “Eir”, sale to be completed early in 2020 for $3 million with subjects.Amortization of contract related to acquired contracts from the Paragon transaction. We expect the remaining $5.6 million will be fully amortised by the end of 2019.G&A includes $1.0 million non-cash charges linked to long-term share option program, in addition to higher legal costs and professional fees in the quarterTotal financial income (expenses), net includesmark-to-market losses on forward contracts relating for shares in Valaris of $31.5 million,other financial expenses of $8.3 million, mainly consisting of the expensing of previously capitalised costs related to refinanced debt;a mark-to-market loss on the Call Spread derivative related to the Company’s convertible bonds of $5.2 millioninterest expense of $20.1 million (additionally, interest of $4.54million was capitalised in the quarter)

Key Financials Q2 2019 5 | Balance Sheet Key Numbers USDm Q2 2019 Q1 2019 Q4 2018 Total assets 3,196.0 3,098.4 2,913.7 Total liabilities 1,823.1 1,626.6 1,380.2 Total equity 1,372.9 1,471.8 1,533.5 Cash and cash equivalents 44.8 29.4 27.9 Restricted cash 62.0 29.4 63.4 Movements in 2019 Total assets increased by US$282.3 million primarily due toAcquisition of “Thor” at the end of March 2019Delivery of the newbuilding “Njord” in January Offset by:Ordinary depreciationImpairment of US$11 million for sale of standard Jack-up drilling“Eir” rig in Q1 2019Total liabilities increased by US$442.9 million, mainly attributable toUS$398.6 million in long-term debtIncrease in current liabilitiesTotal available free liquidity (cash and cash equivalents excluding restricted cash, plus available amounts under available credit facilities) at the end of the second quarter was $119.8 million, including undrawn amounts under credit facilities of $75.0 million.

Fleet Status Report August 2019 FLEET SUMMARY Contractual Developments Other Fleet Updates Time Rig Client Contract status Apr-19 Odin PanAmerican Commenced contract Apr-19 Gerd Exxon Commenced contract Apr-19 Natt First E&P Commenced contract Apr-19 Ran Spirit Energy Commenced contract May-19 Groa Exxon Commenced contract May-19 Prospector 5 Neptune Commenced contract May-19 Mist Vestigo Commenced contract Jul-19 Dhabi II ADNOC 3 Years Extension from July 19 Aug-19 Grid Pemex Commenced contract Aug-19 Gersemi Pemex Commenced contract Aug-19 Odin Pemex Contract: Q3 2019 to Q2 2021 Aug-19 Prospector 1 Undisclosed LOA: Q4 2019 to Q1 2020 Aug-19 Prospector 5 Undisclosed LOA: Q3 2020 to Q3 2021 * Includes Eir, which is under sales agreement, expected to be concluded early 2020, subject to conditions Operating / Committed Available Cold Stack Under Construction Premium Jack-Ups 30 12 8 2 8 Standard Jack-UpsTotal Jack-Ups 4 2 1 1 * 34 Semi - Submersible 1 1 Total Fleet 35 15 9 3 8 6 |

0 10 20 30 40 50 60 70 80 90 100 Total oil production Offshore oil production Renewables Is offshore drilling obsolete? Value of oil produced offshore per year1 590 390 0 100 200 300 400 500 600 700 Total offshore Total shallow water Value public offshore drilling industry 9 1) Based on USD60/brl – total offshore oil production 27m 7 | 32 0 100 200 300 400 500 600 700 Total market cap Total EV Offshore is ~3x size of renewables MMBOE/day Shallow water De ep w ater USDbn/year USDbn

Day-rates up – share price down Borr Drilling # rigs operating 0 2 4 6 8 10 12 14 16 Dec-17 Jun-18 Dec-18 Jun-19 Day-rates up – share price down 0 20 40 60 80 100 120 0 5 10 15 20 25 30 35 40 Jan 2017 Jul 2017 Jan 2018 Jul 2018 Jan 2019 Jul 2019 BDRILL Dayrates (RHS) Source: Borr Drilling, DNB Markets 8 | BDRILL share price in USD USDk/day

800 850 900 950 Jack-up market is a growth market – shallow water the place to be “As offshore momentum builds, shallow water rig activity grew by 14% in the first half…” - “offshore exploration is up more than 30% y/y”– Schlumberger Q2 conference callI’m excited by what I see internationally, a continue broad–based recovery across multiple geographies, primarily driven by land and shallow water”– Halliburton CEO Q2 conference call 100 110 120 130 140 150 160 275 285 295 305 315 325 335 US onshore rig count Floater rig count Jack-up rig count1100 200 375190 3651050180 355170 3451000 Source: Bloomberg and IHS 9 |

0 20 40 60 80 100 120 140 2010 2014 Jan-19 Committed/Tenders Saudi Arabia UAE Qatar Kuwait Middle-East tenders The jack-up market is growing Core countries are drilling significantly more today Rig intensity going up - 2 4 6 8 10 12 14 # Jack-ups pr mmboe production – Saudi-Arabia # Jack-ups 2000: 2 Jack-ups needed for 1m/day production 2019: 12 Jack-ups needed for 1m/day production Rig intensity up 5.5x Outstanding and expected tenders Source: IHS Petrodata, DNB Markets, Borr Drilling 10

25 52 19 0 10 20 30 40 50 60 2010 2014 Jan-19 You need to drill to get oil – Mexico activity coming back Mexican production is dropping due to less drilling Activity is coming back now Source: Rystad Energy, Borr Drilling 1500 1600 1700 1800 1900 2000 2100 2200 2300 Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Mexico Crude Production (kbpd)2400 19 15 Today Awarded 15 contracts Uncovered 9 11 |

89% 1009590858075706560 Market trends confirming the modern rig strategy Marketed Utilization continues to trend upwards… Modern JU availability is tight Source: IHS, Borr Drilling Marketed Utilization (%) Modern (>=2000) Standard (<2000) Average 45040035030025020015010050 2014 2015 2016 2017 2018 2019 … while market bifurcation continues to play outModern Standard 230 177 251 114 + 42% 12 -50% Supply and Demand matrix Modern rigs # of rigs Total fleet 295 Not marketed 12 Marketed fleet 283 Marketed utilisation 89% Contracted fleet 251 Utilization competitive modern jackups Mar 2019 Jun 2019 Aug 2019 North Sea 96% 97% 97% Middle East 88% 92% 94% West Africa 91% 100% 100% 166 130

“Competitive fleet” Why modern jack-ups? Large part of the fleet is old Old rigs are not qualified for key tenders Source: Rystad Energy and Management dataNote (1): As of 12 June, 11 jack-up rigs have been delivered in 2019 >40% of the fleet is more than 30 years old 0 15 30 45 60 75 90 197119731975197719791981198319851987198919911993199619992001200320052007200920112013201520172019 Delivered jack-ups1 NOC 2018 tender ( 1 – 2 Rigs) Age requirement: 2008 or newer QatarGas 2019 tender (6 – 8 rigs) Age requirement: 2011 or newer Pemex 2019 tender (6 – 8 Rigs) Age requirement: 2008 or newer ENI 2019 tender (1 Rig)Age requirement: 2008 or newer Hochki 2019 tender (1 Rig) Age requirement: 2003 or newer ADNOC 2017 tender (8-10 Rigs)Age requirement: 2011 or newer KOC 2018 tender (2 Rigs)Age requirement: 2008 or newer Chevron 2019 tender (1 Rig)Age requirement: 2003 or newer Chevron 2018 tender (3 Rigs) Age requirement: 2008 or newer PTTEP 2019 Tender (1 Rig) Age requirement: 2008 or newer 13

Jack-up rig count set to surpass 400 14 Current contract rig count of 365 units set to increase by at least another 40 Visible incremental demand Middle-East 16 South East Asia 10 Mexico 11 West Africa 5 India 3 Rest of the world ? Total >40 Source:

Yard supply quickly diminishing Only 21 rigs with same standard as the Borr rigs left – 7 smaller units 0 20 40 60 80 100 120 Jan-17 Current China Singapore RoW Source: IHS 15

Singapore newbuilds premium day-rates – low activation cost Source: Borr Drilling –competitors’ costs Includes significant contract specific upgrades 13 40 40 40 18 11 15 10 9 0 10 20 30 40 50 60 Borr Drilling is generating year 1 EBITDA > capex – the others struggle to cover capex over contract period807270 Borr Singapore NB RigCo cold stacked RigCo CJ-46 RigCo 116E RigCo CJ-46Ready to drill capex EBITDA year 1 16 |

Significant cash-flow potential 17 Run-rate illustrative EBITDA and cash-flow *Excluding possible activation cost and contract preparation Day rate scenario Current market Average 10y Last 10y peak Day-rate USD/day 100,000 145,000 250,000 Utilisation Pct 98% 98% 98% Opex and G&A USD/day 50,000 50,000 50,000 # rigs working 30 30 30 Revenue USDm 1,073 1,556 2,683 Revenue tax " -43 -62 -107 Costs " -548 -548 -548 EBITDA " 483 946 2,028 Interest cost " -120 -120 -120 Free cash flow " 363 826 1,908 1 incremental rig contracted improves free cash flow to equity by ~USD20m/year* Borr Drilling still has16 units left to contract – market cap is ~USD550m

Summary 18 Jack-up rig count increased from 296 to 365 since 2017 - 89% utilization of marketed modern rigs Stranded rigs in shipyards down from 103 to 28 Visible demand for at least 40 incremental rigs Borr has commenced contracts for 8 modern units from March to August 2019 Currently positive free-cash flow from operations after financing cost 1 incremental rig fixed at current rates of USD100k/day gives ~USD20m/year in FCF – 4% vs market cap Strong increase in EBITDA expected the coming quarters – financing completed