Ladies and gentlemen, good day and welcome to the third quarter 2020 Transocean earnings conference call. Today’s conference is being recorded. At this time, I would like to turn the conference over to Mr. Lexington May, Manager of Investor Relations. Please go ahead, sir.

Thank you, David. Good morning and welcome to Transocean’s third quarter 2020 earnings conference call. A copy of our press release covering financial results along with supporting statements and schedules, including reconciliations and disclosures regarding non-GAAP financial measures are posted on our website at deepwater.com. Joining me on this morning’s call are Jeremy Thigpen, President and Chief Executive Officer; Mark Mey, Executive Vice President and Chief Financial Officer, and Roddie Mackenzie, Senior Vice President of Marketing, Innovation and Industry Relations. During the course of this call, Transocean management may make certain forward-looking statements regarding various matters related to our business and company that are not historical facts. Such statements are based upon the current expectations and certain assumptions and are therefore subject to certain risks and uncertainties. Many factors could cause actual results to differ materially. Please refer to our SEC filings for more information regarding our forward-looking statements, including the risks and uncertainties that could impact our future results. Also, please note that the company undertakes no duty to update or revise forward-looking statements. Following Jeremy and Mark’s prepared comments, we will conduct a question and answer session. During this time, to give more participants an opportunity to speak on this call, please limit yourself to one initial question and one follow-up. Thank you very much. I’ll now turn the call over to Jeremy.

Thank you, Lex, and welcome to our employees, customers, investors and analysts participating in today’s call. As we have since March, we continue to work remotely to do our part to prevent the spread of COVID-19; therefore, please forgive any challenges associated with maintaining audio quality during this call. As reported in yesterday’s earnings release for the third quarter, Transocean delivered adjusted EBITDA margin of almost 41% with $338 million in adjusted EBITDA on $830 million in adjusted revenue. Importantly, this strong operating performance, which was driven by our experienced and committed teams, enabled us to generate $81 million in operating cash flow. Despite a number of challenges, including a global pandemic and an extremely active storm season in the Gulf of Mexico, we continued to deliver safe, reliable and efficient operations for our customers around the world. During the third quarter, we had 26 active rigs across 10 countries. To put just some of our pandemic-related challenges in perspective, I will share with you that before a crew change, 14 of our rigs require crew members to enter a secured quarantine period ranging from five to 14 days, depending on customer protocols and country regulations, and they must also have a negative COVID-19 test before joining the rig. In addition to the delays associated with quarantines and testing, to reduce overall exposure, we have asked more than 2,500 of our crew members to serve extended hitches, meaning even more time away from home, family and friends. In addition to the quarantine period and extended hitches, while onboard our rigs, our crews are subjected to daily temperature checks and are required to wear face coverings and practice certain social distancing protocols when possible. Needless to say, these are suboptimal operating conditions, yet our crews persevere with absolute resolve. Their sacrifice and dedication to our company are truly inspiring. It’s not just our crew members demonstrating their commitment to Transocean’s success. Our excellent customer service could not be delivered without the contribution of the entire organization, including our shore-based staff. The logistics involved in planning, coordinating, testing and executing the movement of thousands of personnel, spare parts and pieces of equipment during a global lockdown is nothing short of extraordinary. COVID-19 has forced our organization to adapt. Our offices around the world largely remain closed and our employees continue to work remotely to help mitigate the spread of the virus. Virtual meetings and remotely provided expert technical rig support are the new normal and as a testament to the strength and resilience of our entire organization, we have continued to deliver the same high level of performance as we did before COVID-19. For all of this, I extend my deepest gratitude to all of the men and women of Transocean for the personal sacrifices they make each and every day to keep our rigs operating safely, reliably and efficiently to support our customers. We face tremendous challenges as a result of COVID-19; however, the strength and resilience our team has demonstrated throughout this pandemic is truly remarkable. We will continue to take every necessary precaution to keep our crews and our shore-based personnel safe and healthy for as long as necessary while we deliver best-in-class operating performance to our customers. Now looking more closely at our third quarter performance, as a whole our fleet continues to meet and often exceed expectations. I’m extremely proud of our crews for the $10 million in performance bonuses achieved during the third quarter as a result of exceeding our customers’ drilling schedules. This is a direct result of our collective effort each day to continuously improve Transocean, including through our investment in high specification assets, the development and deployment of innovative technologies, and our industry-leading training programs. In addition, we have aligned interest with our customers by linking compensation and performance, a practice that many of our competitors have eschewed, resulting in an enhancement to our revenues. Obviously, this high level of performance helps in the efficient conversion of our $8 billion backlog into revenue and ultimately into cash. Now turning to the fleet, starting in Canada, the Transocean Barents recently completed a successful campaign with Equinor. Since future prospects in Canada are somewhat bleak and demand in Norway continues to be robust, we have already begun the process to prepare her for mobilization to Norway. In Trinidad, the DD3 completed her first full quarter of operations with Shell and continues on her one-year contract until mid-2021. We believe the DD3 is well placed and we are encouraged about potential follow-on opportunities in the area. In the U.K., Chrysaor kicked off its 10-month campaign with the Paul B. Loyd Junior. As you may recall, the work was originally slated for the 712 but was transferred to the Paul B. Loyd, allowing us to further rationalize our fleet. Last quarter, we reported the anticipated early termination of the Deepwater India’s work in Egypt; however, upon review of the successful drilling program coupled with the improvement of oil prices, Burullus reversed course and fulfilled the full program without early termination. This kept the India drilling into July. Unfortunately, with no near-term prospects on the horizon, we moved quickly to cold stack her in Greece. Moving to Offshore India, I’m pleased to report Reliance exercised its 180-day option on the KG1. This will keep her busy through the second quarter of 2021. Moving to Asia Pacific, the DD1 recently completed her successful campaign in Australia with Chevron. As we currently do not see any near-term opportunities for her, we have decided to cold stack her. Finally, the KG2 just this week commenced her contract with Woodside in Myanmar and is currently on standby at a reduced day rate. We believe that Woodside will commence mobilization in January at which point we will be on full operating day rate of $250,000 per day. In addition to keeping our active fleet working, we remain diligent in assessing our fleet for ongoing marketability, and as we have demonstrated since the start of the downturn in 2014, once we determine that a rig has few profitable opportunities, we quickly remove her from our active fleet. Consistent with past practice and our disciplined philosophy on retirement of less competitive units, upon completion of her recent drilling campaign, we decided to recycle the Transocean Arctic. Looking now at upcoming market opportunities, the contracting environment has materially improved from when we last spoke three months ago, when there was minimal customer interest. As a reminder, when we entered 2020, we were starting to see tangible signs of the recovery unfolding. Our high specification harsh environment assets were fully utilized, day rates exceeded $300,000, and visibility to future work was very encouraging and improving, and in the ultra-deepwater market utilization was also starting to trend higher. Indeed, at the end of 2019 and early 2020, we were awarded several ultra-deepwater fixtures with day rates around $250,000 a day, which represented a 100% increase from fixtures signed earlier in 2019. In light of these data points, we were increasingly optimistic that the protracted market recovery was picking up sustainable momentum. Unfortunately, the world was hit with COVID-19, reducing demand for energy. This, when coupled with the temporary increase in supply that was spurred by production disputes among major producers, drove oil prices to historic lows, stalling the momentum that we were experiencing through early 2020. Understandably, this caused many of our customers to pause and reassess how and when to utilize their respective portfolios and ultimately led to them delaying many of the projects that we expected to be sanctioned in the latter half of this year and the first half of 2021. While the delay in awards has certainly been disheartening, we are encouraged by the fact that most of these previously anticipated projects have not been cancelled; instead, they’ve been deferred by approximately 12 months. In fact, our bidding activity level this quarter has doubled from the low point in the second quarter and has returned to pre-COVID levels. During the third quarter, we participated in 18 bids which is the same amount we participated in during the fourth quarter of 2019, just before COVID hit. Taking a closer look around the globe and starting in the U.S. Gulf of Mexico, while the near term is a bit challenging, a handful of projects with start dates in the second half of 2021 are beginning to emerge among independents, IOCs and NOCs. In Brazil, Petrobras recently awarded long term fixtures for the Tres Marinas project in the pre-salt and we expect to see several more Petrobras awards in the near future. Furthermore, Equinor has recently re-tendered its four-year program in the Bacalhau field, and we remain encouraged by the improving activity in Brazil. Moving over to Norway, we are excited about the opportunities unfolding as a result of the Norwegian government’s recent enactment of favorable tax incentives for oil and gas projects sanctioned over the next two years. We anticipate this market will continue to tighten as more projects are brought forward to capitalize on the favorable investment incentives. In fact, we’ve identified two dozen projects that could be given the green light as a result of the tax change. If all of these projects move forward, we believe that the market for high specification assets could be sold out as we exit 2021 and enter 2022, and with the most recent fixtures for such assets around the $300,000 per day mark plus performance bonus incentives, we are optimistic about the future prospects of our industry-leading fleet in Norway, which once again will soon include the Transocean Barents. In Africa, excluding Total’s multi-year tender for Mozambique, which could be awarded in the coming months, we see several medium and long term programs that could be awarded for work beginning in 2021. In the Asia Pacific region, including Australia, we anticipate 11 awards will be made over the next few months for work starting in 2021. As you may know, this region has demonstrated continued activity through these difficult times and the volume of opportunities is nearing pre-COVID-19 levels. In summary, while we are certainly disappointed that the ultra-deepwater recovery continues to be delayed, we are encouraged by the emergence of multiple opportunities for work in 2021 and beyond. While we take some comfort in our approximately $8 billion backlog, we remain very pragmatic, recognizing the challenges to the industry and specifically those that Transocean will continue to face in the near term. As such, we will continue to take the necessary actions to preserve and enhance liquidity, including but not limited to delivering flawless operations that enable us to convert as much of our backlog into revenue as possible, further improving our cost structure to fit the evolving active fleet, quickly cold stacking or scrapping non-working idle assets, and executing timely and opportunistic financing transactions. In this regard, as you likely know, the third quarter was very active from a capital markets perspective. During the period, we undertook a series of actions to reduce our debt and more importantly did so while also improving our liquidity forecast. As a result, during the quarter we successfully reduced our debt by almost $1 billion, reducing our interest expense and extending our liquidity runway as we continue to navigate through this economic cycle. As we have demonstrated over the last several years, we’re not done. Our finance and legal teams have proven time and again that we can successfully execute fiscally responsible transactions and favorably resolve disputes as they arise. We will continue to be proactive in managing our balance sheet in a way that enables us to continue to invest in our people, our assets, and the development of new and differentiating technologies. I would now like to provide a few comments regarding the state of the offshore drilling sector from our perspective. The majority of our peers have either formally started the restructuring process or have taken steps that indicate that they are likely to do so in the near future. Given our large backlog, strong operating performance and liquidity enhancing balance sheet transactions, Transocean is in a very different and advantageous position relative to our competitors, as we are not currently facing a restructuring decision nor are we experiencing the difficult and sometimes demoralizing and crippling distractions associated with such a process. Instead, we believe we have the liquidity to continue to prudently invest in our business and importantly, we’re able to maintain a singular focus on delivering best-in-class operations to our customers. As our competitors emerge from restructuring, it is possible that we may see some consolidation, which we believe is a natural and inevitable result based upon industry economics. Furthermore, marketable supply of rigs is likely to fall at a pace that we expect will eventually meet with the contracted rig count, which we are already starting to see; therefore, when oil prices stabilize at more favorable levels, an inflection in rig contracting should have an almost immediate and positive impact on day rates due to the shortage of marketable rigs and the significant expense associated with reactivating stacked rigs. Transocean will continue to take the necessary actions to ensure that we maintain the most competitive fleet in the industry and remain disciplined in our approach to contracting that fleet. In conclusion, Transocean has strategically assembled the largest and most competitive floating fleet in the industry with the industry’s most experienced crews and shore-based support teams. We maintain the largest contracted fleet with the strongest and most lucrative backlog, providing us with the visibility to future cash flows that we need to continue to invest in the training of our crews and the maintenance of our assets. As such, we are best positioned to survive this latest challenge and benefit from the eventual market recovery. We’ve accepted that a full-scale recovery in the deepwater offshore market will not likely begin before the middle of 2021; however, as the market has begun to stabilize, it gives us confidence that our customers will be ready to increase their offshore activity in the years to come. In the interim, we are committed to our customers and to the preservation and generation of cash flows. We are proud to have positioned ourselves as the clear leader in harsh environment and ultra-deepwater drilling and will continue to strategically refine our fleet to further enhance that position. As such, we expect that our marketed fleet will remain the industry’s most utilized as we successfully navigate this current economic cycle.

Thank you, Jeremy, and good day to all. During today’s call, I will briefly recap our third quarter results, provide guidance for the fourth quarter, and provide preliminary estimates on our financial expectations for 2021. Lastly, I will provide an update on our liquidity forecast through 2022. As reported in our press release for the third quarter of 2020, we reported net income attributable to controlling interests of $359 million or $0.51 per diluted share. After adjusting for several items associated with the retirement and restructuring of our debt and discrete tax items and unfavorable items associated with the loss on disposal of assets and liability management costs, we reported an adjusted net loss of $59 million or $0.11 per diluted share. Further details are included in our press release. Highlights for our third quarter include adjusted EBITDA of $338 million, reflecting strong fleet-wide revenue efficiency coupled with robust performance bonuses, fleet-wide revenue efficiency exceeding 96% reflecting our operational excellence and strong backlog conversion, $81 million in operating cash flow. Looking closer at our results during the third quarter, we delivered adjusted contract drilling revenues of $773 million driven primarily by strong revenue efficiency and $10 million performance bonuses across the fleet, as well as a short extension of the Transocean Barents drilling contract. Operating and maintenance expense in the third quarter was $470 million. This is better than our guidance and due to the timing of in-service maintenance and lower than expected costs associated with COVID-19. During the quarter, we recognized approximately $14 million of COVID-related expenses, of which approximately half are reimbursable by our customers. Turning to the cash flow and balance sheet, we ended the third quarter with total liquidity of approximately $2.9 billion, including unrestricted cash and cash equivalents of approximately $1.4 billion, approximately $200 million of restricted cash for debt service, and a $1.3 billion undrawn revolving credit facility. As Jeremy mentioned, during the quarter we undertook a series of steps to further strengthen our balance sheet by meaningfully reducing our debt. In early August, we initiated exchange transactions for multiple series of our debt maturities, utilizing currency and as promoted by existing indentures and new senior guaranteed debt structure. As a result of these exchanges, we’ll be able to reduce our debt burden by almost a billion dollars without consuming any cash, thereby improving liquidity by approximately $250 million through 2024, which is inclusive of $90 million of net interest savings. Interest savings from the maturity of the exchange bonds exceeds $560 million. Furthermore, during the quarter we also opportunistically repurchased approximately $49 million of our debt in the open market, resulting in more than $20 million of savings. We continued our efforts to improve our balance sheet in October by initiating a cash tender offer for several series of our near-dated debt maturities. As noted in the press release last week, tender participation has been very good and we’ve already retired approximately $348 million face value of debt at a discount of approximately 39%, resulting in a balance sheet improvement of more than $135 million. Including cash interest savings, this tender also improved our liquidity through 2025 by approximately $200 million thus far. The tender offer closes on November 9. The exchange transactions and cash tender are the latest actions in a long list of financing transactions that we’ve undertaken to improve our financial flexibility and capital structure since the beginning of the industry downturn six years ago. Since 2016, we have retired approximately $9.4 billion of mostly near-dated maturities through various ordinary course and liability management transactions and issued approximately $9.3 billion of new debt to the debt capital markets. We will continue to take actions to improve our liquidity runway and capital structure for the benefit of our shareholders. Let me now provide an update on our expectations for the fourth quarter. For the fourth quarter of 2020, we expect our adjusted contract drilling revenues to be approximately $710 million, reflecting a revenue efficiency of 95% fleet wide. This reflects lower fleet-wide activity as five rigs - the Discovery India, Discovery Inspiration, Transocean Barents, Transocean Leader, and Transocean Arctic all concluded their recent respective drilling campaigns. Furthermore, the Inspiration is now warm stacked in the U.S. Gulf of Mexico, the India and the Leader have both been cold stacked in Greece and Norway respectively, and as Jeremy mentioned, we have scrapped the Arctic and we are mobilizing the Barents to Norway, where she’ll be well positioned for work in 2021. We expect fourth quarter O&M expense to be approximately $455 million, a quarter-over-quarter decrease attributable to lower activity as a result of rigs rolling off contract. We expect G&A expense for the fourth quarter to be approximately $42 million, in line with the prior quarter. Net interest expense for the fourth quarter is expected to be approximately $145 million. This forecast includes capitalized interest of approximately $13 million and interest income of $1 million. Capital expenditures, including capitalized interest for the fourth quarter, are anticipated to be approximately $55 million. This includes approximately $37 million for our new build drill ships under construction and $18 million of maintenance capex. Our cash taxes for the fourth quarter are expected to be approximately $3 million. Now I’d like to provide a first look at our financial expectations for 2021. We anticipate adjusted contract drilling revenue to be between $2.6 billion and $2.8 billion, 80% of which monetizes previously established contract backlog. Furthermore, we believe our full year 2021 operations and maintenance expense will be between $1.4 billion and $1.6 billion. Finally, we expect G&A to be between $150 million and $160 million. Turning now to our projected liquidity at December 31, 2022, including our undrawn revolving credit facility and potential securitization of the Deepwater Titan, our end of year 2022 liquidity is estimated between $1.1 billion and $1.3 billion. This liquidity forecast includes an estimated remaining 2020 capex of $55 million and a 2021 capex expectation of $1.5 billion. The 2021 capex includes $1.4 billion related to our new builds and $100 million for maintenance capex. As always, our capex guidance excludes any speculative rig reactivations or upgrades. Now I’d like to address the recent news regarding our compliance with the New York Stock Exchange. During October, we received a continued listing standard notice from the NYSE because the average closing price of our shares fell below one dollar during a consecutive 30-day trading period. We have plans to remediate this deficiency and regain compliance well within the time period allotted by the NYSE, and we remain in compliance with all other NYSE listing standards. In conclusion, in addition to the safe and efficient operation of our rigs, we continue to focus on preserving and enhancing our liquidity while opportunistically reducing our debt. We will proactively manage our balance sheet and capital expenditure requirements and explore all opportunities to reduce costs without compromising operational integrity or the safety of our employees.

Thanks, Mark. David, we’re now ready to take questions. As a reminder to the participants, please limit yourself to one initial question and one follow-up question.

[Operator instructions] Our first question comes from Connor Lynagh with Morgan Stanley.

Yes, thanks. I wanted to focus on the back half of ’21 opportunities you were discussing. I appreciate the commentary around that. I guess what we’re trying to figure out is what do you think the customer sensitivity to oil prices is these days, and how would you think about--if oil prices remain broadly where they are today or move up $5 to $10, how would you think about the relative sensitivity of those opportunities?

Hey, Connor, this is Jeremy. I’ll let Roddie chime in. From our perspective, there’s still so much uncertainty in the world - you know, when do we find a real solve, if you will, for COVID, and what does that do to global economies and when does that take place, and then how does that impact oil prices certainly. As we saw in 2019, we had a relatively stable oil price that bounced around $60 a barrel for quite a period of time, and that’s really where we started to see these offshore projects pick up with some earnest, so I think right now our customers are growing increasingly encouraged that oil prices have moved up from their bottoms, have stabilized a bit, and that if we can get through the election and determine what the landscape is going to look like there and then start to find, whether it’s a vaccine or whatever solve for COVID, I think that gives them even more confidence. If you can get oil prices up closer to $50 a barrel, I think we start to see quite a bit more activity. Roddie, I don’t know if you want to add to that?

Yes, just add to the fact that if we do go up another $10 or $15, that will really make a huge difference because I think as you mentioned this before, our customers have spent a tremendous amount of time retooling their wells, simplifying their designs to make them more and more profitable at around the $50 mark, so I think if we can see something sustained at around the $50 mark, then that’s going to bode very, very well for offshore drilling, where our competitiveness has relatively increased substantially over the past few years.

Yes, makes sense. If you could speak in broad terms - I know you don’t want to give away too much for competitive reasons, but these opportunities that you’re starting to see, how should we think about--and certainly I think you alluded to this on the harsh environment side of things, but on the benign environment rigs, where do you see contract durations, rates trending? It certainly seems like things have been holding up a bit better relative to the prior downturn, but just any broad comments around that would be helpful.

Yes, that’s a really interesting point. We were actually going to make that point, that if you compare to where we were before in the previous blip, day rates, as Jeremy had alluded to, had been down pretty low in the mid 100s, but now we’re seeing that the bottom end of this is clearly not there. I think some of the lowest rates we’re really seeing are the 180 to 190 mark. While we are certainly not there, some folks are, but there seems to be--you know, just the economic reality of delivering the service is kicking in. I think we also expect to see that with the number of tenders that are coming out in places like Brazil, a lot of awards being made in other parts of Latin America, the day rates seem to be less of a spread and everything seems to be moving up a bit. You may see some near term competitive stuff, but we think because a lot of these tenders are now multi-year, in fact there’s probably at least half a dozen multi-year tenders out there just now, we think that is going to have folks bidding above 200 and those are--they’re looking at four and five-year terms of well above 200. They’re going to be closer to 300. So it remains to be seen whether the operators move on those right now, but certainly we’re optimistic about that because we certainly haven’t seen the depth of day rate drop that we did last time around, so clearly economics are better this go round.

Yes, just to sneak one more in here, what do you attribute that change in behavior to? Is it less optimism, less logic of well, I just maintain the customer now and I’ll monetize later? Is it more financial constraints? Basically what I’m trying to figure out here is if your competitors do emerge with cleaner balance sheets, probably not a ton of liquidity but maybe more than they’re working with today, does that derail this discipline or do you think it’s more sustainable than that?

I don’t believe it does. I think it could in the short term if you’re looking at individual rigs that are rolling off contract and they’re just looking for a near term filler opportunity. You might see a little more competitive play to try to just position that rig for a short duration, but as we said in the prepared remarks and we’re starting to see play out, we’re starting to see more rigs cold stacked more quickly, more rigs scrapped, and so the real active marketable fleet is shrinking and so if you want to get into one of these long term arrangements and it’s going to require a rig reactivation, like you said, their liquidity will be improved but you’re looking at a $50 million-plus ticket to reactivate an asset. You can’t do that at today’s day rates - you have to go much higher or you have to get compensated on the front end from the operator. Go ahead, Roddie?

Yes, I was going to add to that, that there’s been a few mistakes made in the past. You’ve seen folks do the reactivation and mobilization speculatively and it just didn’t work out, so I think there’s a lot of hard lessons being learned and I also think there’s going to be a tremendous expectation to create some form of earnings from these contracts. As Jeremy said, reactivation costs are going to curtail that dip in the rates again, but more interesting than that, the relative utilization of high spec assets is only going to get better. As the opportunities have dropped in the latest COVID dip, so has the number of active rigs, so if you look at the chart of the seventh-gen drill ships, of those that are stacked, the vast majority are cold stacked, so they aren’t coming out anytime soon. We actually look at the list that I track, there’s six or seven rigs that are listed as being warm stacked and we know that four to five of them already have leading positions in tenders that will take them out of the market. So you really do find yourself in a situation that’s similar to the back end of 2019, when we saw that boost in rates from that 150 level up to the 250 level, and it’s just driven by the fact that there are fewer assets available.

Makes sense. Thanks for the color.

Thank you. Our next question comes from Taylor Zurcher with Tudor Pickering Holt.

Hey, good morning, and thank you. Appreciate all the color, or the initial color on 2021, and if I’m doing my math correctly, the implied EBITDA number for 2021 is much better than what consensus is thinking right now. Mark, I think I heard you say that at the revenue line, about 80% of your forecast is contracted today, and so a two-part question. For the other 20%, could you help us understand which rigs that are currently idled today are going to help move the needle the most or that you see the best opportunity for work in 2021 embedded in that forecast? Then secondarily, it seems like the biggest delta would be, at least versus our thinking, would be on the cost side, so good to see that. If I just take the midpoint of the cost guidance for 2021, I think it’s about $1.5 billion - divide that by four, that’s $375 million type quarterly run rate for 2021 relative to $455 million you’re guiding to in Q4 this year. Just hoping you could help us understand how you get to that structurally lower cost run rate moving forward absent a number of rigs rolling off contract in the coming quarters. Thank you.

Thank you, good morning. Let me respond to your first question regarding the 20% of spec revenue that’s brought into our forecast. It’s really down to four or five rigs, one being the Asgard, the Inspiration, the DD3, and the Norge, and those are almost equally split between those, and then we’ve also got two other rigs, the Petrobras 10,000 and the Nautilus that come in at much lower numbers for next year. So like I said, four rigs would drive the vast majority of that 20% of spec revenue. As you look at the cost for next year, it’s not--I think your calculation of dividing the 1.5 by four is a way of doing it, but as you know, rigs are going to be coming off throughout the year. As they come off, costs would be reducing on a quarter-by-quarter basis. Next year, we also see the full benefit of our cost-cutting efforts which we implemented this year throughout the second half of the year.

Got it, that’s helpful. Second question is on liability management from here. Clearly you’ve been extremely busy over the past few months, which has been really good to see. Moving forward, you still have quite a bit of capex slated for 2021 on the two new builds that you have remaining. Can you talk about the timing of those back-end payments and whether there’s any potential to potentially push those out a little bit to the right? We’ve seen a lot of your competitors do that over the years, and I know you’ve got contracts in place for these two rigs and there’s some time constraints there, but do you see any potential as part of your liability management playbook to figure out a way to push those back-end payments to the right a little bit?

I would look at that in a different light. That really isn’t liability management. We have a commitment to the shipyard for those two rigs and obviously the final payments have been delayed several times in the past, but those rigs are now slated to be delivered next year. We would need to take delivery of those rigs and pay the payments at the time. That being said, we’re always in conversation with our vendors, including the shipyards, and there’s a potential that something could happen there, but at this stage we are not pointing to anything specific.

Understood. Thanks for the answers.

Thank you. Our next question comes from Kurt Hallead with RBC.

Hey, good morning. Thanks for that color. I wanted to come back around, make sure that I understood some of the dynamics around the market outlook correctly. You guys talked about how currently ultra-deepwater rates are in the 180 to 190 range effectively. It looks like they’re unchanged over the last few months. Then you mentioned at least half a dozen tenders on multiple years, and then I thought I heard something that with day rates approaching $300,000 a day for those multi-year tenders. Can you go back and just clarify that a bit?

Yes, sure. I said the low end is that 180 to 190. We’re seeing responses to tenders all the way up to $300K a day. That’s really because of the length of term. I would say that the near term market is somewhere between 180 to 230, and then that long term market looks to be substantially higher. It really depends on how many rigs will be taken by these long term prospects, and what you see there is essentially the low bidders being taken first, so as those rigs come off the market - in other words, they’re committed, then the balance of rigs available combined with the relative few number of warm assets, we think that’s going to really help push the dynamic. Hopefully, that makes sense. As we see an uptick in bidding activity now, that should translate into an uptick in awards six, nine, 12 months from now.

Got it. All right, that’s helpful. Then Jeremy, I wonder if you could help us put into context, you’ve been among the leaders of taking assets out of the market and rationalizing your fleet. I was wondering if you could give us some general sense as to maybe how many rigs you could expect to rationalize in 2021 and maybe put that into broader context of how many industry-wide assets could be rationalized next year.

Well, I take offense to among the leaders - I mean, we’ve been the clear leader, unfortunately. With respect to our own fleet, I think you can continue to watch us follow past practice. We’ve been pretty consistent - as rigs roll off contract and we see limited prospects for them, and we don’t see them as overly marketable or profitable going forward, we won’t waste any time in removing those assets from our fleet. But I’d tell you, given what we’ve done so far, we’ve pulled the vast majority of those assets out of the fleet, as you well know, but certainly there could be a couple more going forward but we’ll address those as they come. Regarding the rest of the industry, it will be interesting to see how these competitors emerge from restructuring and whether as part of that restructuring they are forced to retire or recycle some of the older, less capable assets. Our expectation is they will because they’re just too costly to keep around and not overly viable going forward. That will certainly help with the supply side on the spread sheet, but candidly, we’ve said for a long time now we’re not as worried about the total number in the Excel spreadsheet because we know a lot of these rigs will never find another contract, but optically it will certainly improve things.

Okay, great.

Yes, we just see several of our competitors, as they’re transitioning management teams, are making a lot of overtures around just simply taking that supply out because, A, it’s just not viable, and B, it does not help market dynamics, so we encourage that.

Got it. Maybe one for Mark - what do you anticipate the securitization of the Titan being?

Kurt, as you know, that’s a five-year contract with Chevron at a pretty healthy rate, so I think we could get somewhere between $350 million and $400 million of secured financing against that rig.

Okay, that’s awesome. Thanks for the color, everybody. Appreciate it.

Thank you. Our next question comes from Fredrik Stene with Clarksons Platou Securities.

Hey guys, thank you for your optimistic comments today. It’s nice to hear that it’s more activity out there now than it was three months ago. What I’m wondering about today has to do with rig efficiency and how your customers have approached that. I’m thinking Equinor, with their recent award, was very vocal that they’re now looking even more at cost per well versus just day rate, so have you--I think it’s been in place for some time, but have you felt that even more now when you’re hearing about the high-grading of fleet, cold stacking, scrapping, etc., leaving the best assets on water? Is that something that you feel will be important both from a competitive standpoint going forward, but also from a utilization standpoint? As a follow-up to that, I think I mentioned Equinor - you’re taking the Barents to Norway. How do you view the re-contracting chance for the four rigs you have with Equinor already? Thanks.

Let me take the efficiency question first. Look - that’s been the push over the past several years, and really I think why we’re seeing offshore, particularly deepwater and harsh environment, doing well in terms of collecting bonuses and that kind of stuff, it’s all about that well cost, and the push for the well cost, it’s not only obvious that it’s better to drill a well for less the cost, but it typically brings the well on earlier, so then you have less spread rate that runs for a longer time, then you get earlier production and you get to drill more wells in the same period of time, so it really is the catalyst to more and more activity. So yes, we are fully behind that push. We have our customers equally participating in upgrades to rigs and allowing us to make substantial compensation on that, so it’s a very healthy environment from that point of view in terms of performance and high specification assets. You’ll have heard us say many times that that is our philosophy, is to be at that cutting edge of performance, but not because it’s just not only fun to be there but because it drives the economics of more activity and puts you in a better spot reputation-wise with the customers, that they know if they pick up a Transocean rig, then they’re going to be drilling the fastest wells out there. That’s really important for us and obviously makes a big difference in terms of how much we can collect on a contract and how much profitability is in it for the operators as well. The second part of your question was around bringing the Barents to Norway. Look - that’s her natural home, she was in Norway for a long time, she operated extremely well there. Brought over to Canada, very successful campaign from our point of view operations-wise; also from a financial point of view it worked out very well, so we bring her back to Norway. Without tipping our hand, we’re in discussions with a few folks, but we think that the market in Norway is--continues to be robust for those high specification and high-performing assets. We do see a bifurcation between the lower spec assets or the--how would you say, the lower performance reputations, and in rates that is driving apart at a substantial clip, so really we think those high specification assets are going to see work, they’re going to see it at solid rates, and while there may be a few gaps here and there on schedules, we think it’s going to be fairly robust activity, especially towards the second half of ’21 when we begin to see a lot of the tax incentives that were offered by the Norwegian government kick in and stimulate more activity. Anyway, that’s the long and the short of the reason for bringing her to Norway, but that seems to be a really good fit for the rig and we’re fairly positive on that.

Super, thanks. Just to follow up there, the four rigs that you have with Equinor in Norway already, how do you view the outlook of those rigs? I’ve spent a lot of time discussing with investors around those rigs, so I think anything that you can give - do you think that they will be extended, that there’s work for that kind of rigs, the midwater rigs, completion drilling, etc. in the same way that you will find work for the Barents, that you believe that these will continue to be Equinor’s workhorses also when the firm terms expire?

Yes, so when we look at those, the CATDs and the kind of work that they deliver, they are absolutely fit for purpose, and not only are they fit for purpose for when they were built but we’ve done some upgrades to them. We’ve brought them more and more into the digital realm, so with Equinor we’ve worked to enhance the performance of those rigs and they’re extremely pleased with the results that that has borne, and actually again for us, results in collection of bonuses and those kind of things. But we continue on that push of keeping those rigs right up there in terms of performance and the latest digital technologies, and as we see it and as the feedback we get is that Equinor are very keen to see them continue in that vein beyond their firm contracts, the contracts do have options on them, so we think there’s plenty of scope for those to be extended in the not-too-distant future.

As a final follow-up to that, do you think if there’s an extension that it’s fair to assume that they have options, but maybe a rate that’s more in line with the current market type of discussion?

I think it’s a little early to say, but that’s always a possibility. But you know, without engaging in significant and earnest negotiation on those, I think I’ll not be drawn in that for now. We’ll just wait to see how that pans out when we do enter full-time negotiations.

Thank you. Our final question will come from Sean Meakim with JP Morgan.

Thanks, good morning. Most of my questions have been covered here, so just one on the back end. Maybe Mark, can we just talk about what type of liquidity levels are needed to run the business at current activity, and if you take possession of the new build next year, how does your liquidity position look relative to your needs exiting ’21? Anything else that needs to be done besides securing the secure financing on the Titan?

Sean, I gave you our estimate for liquidity end of 2022. I haven’t broken out the 2021 right now, but we can certainly get that to you. But we’ve built in the payments to JSPL for those rigs, the Atlas and the Titan. We’ve also built in the potential financing using the cash flow from the Chevron contract on the Titan, so all of that has been built in. In addition to that, as I mentioned earlier, we took a significant action this year with regard to reducing our shore base overhead, our G&A, and any other costs associated with running the business, which has been implemented as our rig count came down during the second half of this year. You just heard me talk about five rigs that came off contract this quarter, so as those rigs come off, obviously correspondingly we reduce the folks involved in managing those rigs. That is what I would point to with regard to costs.

Thank you. I’ll now turn it back to Mr. Lexington May for closing comments.

Thank you, David, and thank you everyone for your participation on today’s call. If you have further questions, please feel free to contact me. We look forward to talking with you again when we report our fourth quarter 2020 results. Have a good day.

Ladies and gentlemen, that concludes the third quarter 2020 Transocean earnings conference call. You may disconnect your phone lines and thank you for joining us this morning.