Good morning, everyone. Welcome to Noble Corporation’s Second Quarter 2022 Earnings Conference Call. We appreciate your continued interest in the company. You can find a copy of our earnings report issued yesterday evening, along with the supporting statements and schedules in our website at noblecorp.com. Joining me today are Robert Eifler, President and Chief Executive Officer and Richard Barker, our Senior Vice President and CFO. Also joining on the call are Blake Denton, Vice President, Marketing and Contracts; and Joey Kawaja, Vice President of Operations. For today’s call, we will begin with prepared remarks, followed by Q&A. During the course of this call, we may make certain forward-looking statements regarding various matters related to our business and companies that are not historical facts. Such statements are based on current expectations and assumptions of management and are therefore subject to certain risks and uncertainties. Many factors could cause actual results to differ materially from these forward-looking statements and Noble does not assume any obligation to update these statements. 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 and including risks and uncertainties associated with our previously announced business combination with Maersk Drilling. Investors should carefully read our previous and ongoing disclosure with respect to such business combination, including in our press release issued yesterday and in our other filings with the SEC. Also note we are referencing non-GAAP financial measures in the call today. You can find the required supplemental disclosure for these measures, including the most directly comparable GAAP measure and an associated reconciliation in our earnings report issued yesterday and filed with the SEC. With that, I’d like to turn the call over to our CEO, Robert Eifler.

Thank you, Ian and welcome to Noble. We are very glad to have you with us. Welcome also to everyone joining us on the call today. I will start with commentary on our business environment and follow with highlights on the offshore drilling market and Noble’s global operations before turning the call over to Richard to review our financial results for the quarter. Starting off with some macro context, concerns of inflation interest rates in recession have frequented global headlines, but the view through our lens appears quite positive. The frequency and nature of customer conversations as well as global tender activity, I’ll point to an improving market for offshore rigs. This year has been far better in our industry than 2021. Next year is shaping up to be better than this year. And we have visibility to continuing improvement from there. Data from Rystad indicate nearly a trillion dollars of oil and gas project sanctioning to occur over the next 5 years, the majority of which will be directed offshore. 98% of those projects breakeven at an oil price below $60 per barrel and perhaps more compellingly, over 80% were sub $40 per barrel. The world needs affordable and reliable energy and offshore oil and gas developments represent some of the most economic, sustainable, and secure sources of energy on the globe. Over the last two quarterly calls, we’ve stated that Noble’s financial results would meaningfully improve as we progress through 2022 and our contracts reset to higher day rates. That step up is evident in our second quarter results with further improvement in sight to the second half of the year. Revenue, EBITDA and free cash flow all increased materially quarter-over-quarter as our business benefited from improving day rates, improved utilization, and solid cost management by the Noble…

Thank you, Robert and good morning all. In my remarks today, I plan to provide some brief highlights of our second quarter results and then discuss our outlook for the remainder of the year. Contract drilling services revenue for the second quarter totaled $262 million versus $195 million for the first quarter of 2022. This quarter’s revenue was positively impacted by a full quarter of operating days for the Noble Gerry de Souza, the commencement of the Noble Regina Allen operations in Guyana, and a full quarter impact of the March 1 day rate increases for the 4 rigs operating in Guyana under the CEA. Adjusted EBITDA for the second quarter was $84 million compared to $27 million in the previous quarter. This translates to an adjusted EBITDA margin of approximately 30% for the second quarter. Net income for the quarter was $37 million or $0.45 per diluted share. Capital expenditures totaled $31 million in the quarter, which includes $4 million of client reimbursable investments. Free cash flow in the second quarter was positive $56 million. Our balance sheet remains extremely strong, with net debt of just over $50 million and total liquidity of over $800 million. We continue to see increases in our revenue backlog. And as of June 30, our backlog stood at $2.1 billion. This does not include the two 3.5-year jack-up contracts in the Middle East, which was signed post quarter end and it does not adjust for the potential sale of the divestment rigs. Our backlog today is almost double where our backlog stood at the end of last year. The combination of this backlog and ongoing customer discussions give us more visibility and confidence in our financial profile than we have had for a long time. The second quarter was an important inflection for…

Thanks, Richard. 2022 will truly be a transformational year for Noble as we continue to execute on our strategic priorities to create a new and dynamic leader in the offshore drilling market. The combination with Maersk Drilling is central to these priorities. We have two remaining milestones before closing the transaction, which is anticipated to be October 3. Firstly, as I mentioned previously, we are awaiting for final clearance from the UK CMA, which we are hopeful to receive in the coming weeks. Secondly, we need to complete the Danish tender offer, which will officially launch tomorrow and run through mid-September. When the transaction was announced in November last year, I was excited about the potential for the combined company and the overwhelmingly strong transaction rationale. Since then, the outlook is stronger and as we have met the capability of the combined company to lead the industry and operational performance, technology innovation and sustainability, my excitement and belief in the merits of the transaction have grown even further. On close of the transaction, Noble will have scale and a platform to generate strong free cash flow driven by excellent assets, the best people and a culture committed to best-in-class safety performance and customer satisfaction. The two companies individually already had industry leading utilization, which combined with at least $125 million of synergies and a highly conservative balance sheet will allow us to deliver on our stated priority to return capital to shareholders. The outlook for the offshore market remains stronger today than at any point in the recent past and Noble is a critical component of that offshore value chain. I’d like to thank the entire Noble organization both offshore and onshore for their dedication to our customers and to operating safely everyday. And I look forward to working with the Maersk Drilling organization in the very near future.

Thank you, Robert. Angela, we are ready now to open the call for questions and answers.

[Operator Instructions] We will now take our first question from Fredrik Stene with Clarkson Securities. Please go ahead.

Hey, guys and congratulations on a very strong financial performance this quarter. I have a bunch of questions, but I will limit myself to begin with. So I wanted to touch a bit more on the expected performance going into the second half of the year here, you are saying that we should expect some other step-ups here. And I am sure that the fee rates etcetera will help a lot there. So, let’s start with those. If I remember correctly, you are doing this every March and September and then you have this lag before you start to see whatever rate you negotiated beforehand. So in addition to getting a new rate in September, I am sure you will also be meeting with Exxon to negotiate what’s going to happen into next year. So I was wondering if you could give any color on kind of what to expect on that part of your fleet when we are going to see the re-pricing in March next year for whatever you are agreeing this September given what we see in the U.S. Gulf of Mexico now?

Right. Yes, thanks. So the rate that – just to be clear, the rate that kicks in September 1 of course is already set. That rate was set in the kind of April timeframe this year. It’s a market rate at that point and then what will come through includes the discount, we will set the rate that come, that will come into effect in March of next year, won’t be set until later this year. So, those conversations haven’t started. That’s what’s called a fourth quarter conversation. And so, that will take into account all of the available market data when that conversation kicks off in the fourth quarter.

Okay. Robert, it seems like we should expect another step up than I presume given the way the market rates are going. Following up on the rest of the fleet here, you have some nice new data points, but you also have now a few other rigs rolling off their firm contracts in the later part of this year, such as the Gerry de Souza, and for example, the Stanley Lafosse in November. So I was wondering, are you in addition to looking at new work for those contracts, if you can comment on that? And also, if you are looking given what’s happening in Brazil, for example, are you now seeing any opportunity for the 2 stack assets as well to bring them back to work?

Blake, you want to?

Yes, sure. So thanks for the question, Fredrik. This is Blake here. So when you look at the drillships you mentioned there is some wide space, particularly on the legacy Pacific Drilling ships. I would say we are encouraged by the nature of the conversations we are having and the different opportunities that lay in front of those both with their current operators as well as others. So we feel like we have got good visibility for ongoing programs after that. I would say with respect to your second question on Petrobras, I mean, we have been watching Brazil closely. Obviously, we have quite a history there both in the country and specifically with Petrobras. I think the dynamics are now such that it’s an interesting opportunity for us. So we look forward to participating in the tender here that’s due in a couple of weeks. And it does bode an opportunity for reactivated rigs. Yes, the dynamics are there.

Yes. So, I think that’s – it’s going to be – I will just add on to that. That’s – it’s interesting, because the public nature of that tender, I think everyone will get visibility pretty quickly about how the market is looking at those longer term opportunities. It’s the term could justify some reactivations. And so we will see what come through. I would reiterate for our part, nothing has changed about the disciplined manner in which we are going to approach any opportunity that could justify a reactivation, which I am happy to repeat, but we have said a few times would be quite conservative.

That’s very helpful color, guys. Thank you so much. I will – that’s it from me for now. Thanks.

Thanks.

Thank you. Your next question comes from the line of Greg Lewis with BTIG. Please go ahead.

Hey, good morning, everybody. Thank you for taking my questions. Robert or Blake, I guess my first question and I am not looking for you to comment specifically on any of the Maersk rigs per se. But just as we look across the drillship fleet, let’s just say, what – and when we look at it as a whole or maybe we even go by market, as we think about pockets of strength in the market and clearly the Gulf of Mexico is strong, West Africa is picking up. I guess globally, there is a pickup in rates and tightness. As we think about rigs rolling off over the next few quarters, I guess two questions around that. One is, does location matter in terms of thinking about whether there is going to be I think you mentioned whitespace in between contracts starting up, i.e., is it hey, we should be thinking about a 30 to 60-day kind of air pocket or are we now in a market that’s tight enough where we should be thinking more about that more of a bull market continuation of rig utilization? And does that differ by region, i.e., obviously in the Gulf of Mexico? I assume it doesn’t, but maybe in parts of Asia, maybe it does, I don’t know.

Yes. I think I’d say someone like feel free to jump in. I think the short answer is I don’t think we are back to 100% utilization market. One of the reasons that we see so much value and are so proud of the CEA in Guyana, because we have that visibility. Regionally, I think it does matter a little bit, I think that the U.S. Gulf of Mexico there are higher number of our opportunities, but that region remains very, very short-term in nature. So there is whitespace there. I think the differences in West Africa just by nature of the operations those tend to be longer term opportunities. And I think that just makes more sense there. So they are fewer of them and they are longer in general. I think same can be said for Brazil. But I do think generally speaking, rigs have some whitespace when they are switching customers. So, it’s significantly better than a year ago, but we are not to a point where you can count on 100% utilization if you are switching customers. I’d also note in the very highest days, if you recall, Greg, we were able to get some contribution on mobilization for whitespace. I think where we are today in the market, mobilization conversations are coming very much back into play. They are probably still a little bit more weighted towards cost recovery than they are revenue protection in the whitespace.

Yes. And I would only add a couple of things. I wasn’t trying to forecast with whitespace forecast gaps, it was more just talking about our contract coverage thus far. I think in the UDW space, when we see a tightening market we have continued to see a customer preference for hot rigs. Robert mentioned mobilization coverage. So again, we are encouraged on the outlook for our fleet today and certainly look forward to marketing some really high-quality assets after the close of the transaction with Maersk.

Yes, absolutely. And then just more of a question around the pending asset sale of the 5 North Sea rigs, obviously, there is a cash buyer and I believe that the agreement is a cash agreement. I guess couple of things. One is, are any – or have there been or any deposits required? And $375 million is still a lot of money I realize maybe the roofs could have sold for more. But in the event that I guess what I am wondering is, could we see any seller financing in the event that there is not a – does that change anything in the event that the counterparty is unable to come up with $375 million in the firm cash?

Yes. So, there is a deposit. It’s kind of industry standard 10% deposit. There is no seller financing available and that is by law, by rule out of the UK. So, the competition authority there does not want to see any continuing link that could affect competition going forward.

Okay. Great. Okay. Hey everybody. Thank you for the time.

Thanks. Thanks Greg.

Thank you. Your next question comes from Samantha Hoh with Evercore. Please go ahead.

Hey, guys, congrats on a really great quarter. I wanted to maybe just dig back to one of Greg’s question, the Faye Kozack, that 400 clean rate seems really unusual for a one well contract. I was just wondering if maybe you could talk a little bit more about that. Was that just a very opportunistic scenario where they wanted it in a certain white space that you guys had available?

Yes. Sure. Samantha, thanks for the question. This is Blake. I think it’s just the nature of the – the capabilities of the rig and the demands of this particular program against the available rigs in the Gulf of Mexico at the time. It’s a great contract we look forward to working with LLOG. We have a long-standing relationship with them and we have been trying to do some work with them for some time. So, it’s an exciting opportunity. But again, I think if the rate is just a depiction of the alignment of the rig specs required versus the rigs available.

Okay. And then maybe more broadly, can you talk about how the rates are trending geographically? I realized that the U.S. is sort of pushing the leading edge on the ultra deepwater side. But where are we in terms of the other geographic basins? Is this West Africa kind of going to be catching up to them sometime next year, or how do you guys see the day rate progressing?

Yes. And [indiscernible], I think we said at the beginning of the year, one thing we expected to see this year was were other regions catching up with the U.S. and less of a discount for term. I think that has proven out as we have progressed through this year. There is I think still in – remember, in a couple of weeks, when these Brazil tenders come through what will be a great visibility, I think for everybody. But I think there is still probably some slight discount for term. Don’t think we have inflicted into a market where there is a premium for term yet. But I do think also that that rates have normalized somewhat this year, between the South America and West Africa and in the U.S. Gulf of Mexico.

Yes. I don’t have any anything further to add Samantha. I mean we will see that the fixtures, both in Brazil, as Robert mentioned in West Africa, and it will show there, they are catching up.

Okay. And just remind us again, like, what are you guys seeing in terms of reactivation costs? And how quickly you could get of course that rig reactivated?

Sure. So, we have the two as a reminder for anyone else. We have got the Meltem and the Scirocco. Of those, the Meltem is really the more capable rig overall. That’s a seventh generation rig that actually mobilized, that’s the U.S. just before the pandemic under Pacific. So, that’s almost certainly the first one that would come out. And if you think about an all-in cost, which includes labor and all the expenses associated with performing the shipyard work, that’s kind of a $75 million to $100 million price tag. And at this point, it’s let’s call it a year work. It could creep a little bit longer than a year, but we would say right around a year.

Okay. Great. Thanks so much, guys. Congrats again.

Thanks.

Thank you. Your next question comes from the line of David Smith with Pickering Energy. Your line is open.

Thank you. Hey. Good morning. Congratulations on the solid quarter and thank you for taking my questions.

Thank you, David.

So, just bigger picture CNB Border demand visibility growing, forward availability of premium drill ships is shrinking. I would be getting more nervous if I were a rent procurement manager. I am curious if you could give us any color on what you are seeing in customer conversations to secure forward availability, maybe compared to the year ago, maybe in terms of lead times, are they stretching out? Are you seeing any interest in longer contract terms?

Sure. So, contract term has ticked up. And we track lead time as well, it’s ticked up, it’s actually ticked up in the U.S. Gulf of Mexico. So, yes, behavior is changing. There is still because – there is still I think a persisting hesitation to contract longer than necessary. So, I think the behavior is still to try to contract on a more short-term basis. So, I don’t think we are to a place yet where customers are truly nervous to continue with your description. But I do think we are in a transition where people are starting to pay a whole lot more attention to what things look like a year out from now.

Appreciate that. And a follow-on to that question, recognizing that in some countries, customers have to tender. But for instances where they don’t, are you seeing any change in their approach in the market in terms of pursuing direct negotiations versus inviting a more competitive tender process?

We have seen an increase in direct negotiations in the U.S. Gulf of Mexico. I cannot say necessarily that that has followed in the same kind of to the same degree in other markets. And of course, other markets are restricted in most cases from that. But customers do want the rigs that they want, and there is less availability today. So, we have also seen this trend where customers are selecting fewer people to go through a tender process, where maybe the numbers are two to four instead of five to seven, something like that, which I think is a similar way of achieving some level of control over the rigs of winning that.

Great. Appreciate that color. If I could sneak one more and you touched on this with the comments on mobilization cost recovery, just noting that historically, when we see day rates moving up, contract terms and conditions are probably improving in the background. Just curious if you can give us any color around some other TNCs is especially around bonus opportunities, non-productive time allowance and cancellation provisions?

It’s a good point there and we have seen the improvement in contractual provisions. So, the risk allocation and the protection of the revenue, those suffered in the downturn as we fought hard for work. But as the market improves and it tightens up, we are able to improve the Ts and Cs as well.

Great. Thank you so much.

Thank you.

There are no further questions at this time. Mr. Ian Macpherson, I will turn the call back to you.

Thank you, Angela. And thank you everyone for your participation on our call today and for your continued interest in Noble. We look forward to speaking with you again soon.

This concludes today’s conference. You may now disconnect.