Earnings Call: Q1 2021

May 4, 2021

Good day, ladies and gentlemen. Welcome to PetroRio's conference call to discuss First Quarter twenty twenty one Results. Thank you for waiting. At this time, all participants are in listen only mode. Later, we will conduct a question and answer session for analysts and investors when further instructions to participate will be provided. This event is also being broadcast simultaneously over the Internet via webcast and may be accessed through PetroRio's Investor Relations website at ir.petroreiosa.com.br by clicking on the banner First Q twenty twenty one Earnings Release. Before proceeding, let me mention that forward looking statements that might be made during this conference call relative to the company's business perspective, projections and operating and financial goals are based on the beliefs and assumptions of PetroRio's management and on information currently available to the company. Forward looking statements are not a guarantee of performance. They involve risks, uncertainties and assumptions as they are related to future events and therefore depend on circumstances that may or may not occur in the future. Investors should understand that general economic conditions, industry conditions and other operating factors could also affect the future results of PetroRio and could cause results to differ materially from those expressed in such forward looking statements. I would now like to turn the conference over to Mr. Roberto Montero, CEO Mr. Milton Rangel, CFO and Mr. Francois Mar Fernandez, COO. Mr. Montero, please go ahead. Good day. Thank you very much for joining us today. I would like to once again start this call thanking the PetroRio team. We are living difficult and challenging moments, but we have been performing really well amidst all of the difficulties that we are all facing on a day to day basis. So I would like to start thanking my team for their perseverance and discipline. Now moving to Slide three, we have the highlights of the period. The first highlight that I think it is important to underscore is our EBITDA. In the first quarter, our EBITDA totaled $428,000,000, 12x higher than the 2020. Of course, in 2020, we already felt the early COVID effects. The pandemic started in March 2020, so we have a little bit of an effect there. As part of this EBITDA, we have to take into account two important things this year. First, a higher production, most likely a record mark in the company's history and a Brent oil price that is also higher. We took an average and it was higher than $60 per barrel. It's been a while since we have seen this happen. A second point about this first quarter that is important to highlight was our follow on offer. We raised $370,000,000 approximately BRL 2,000,000,000 in January. We had a capital increase. We had a book that was more than 3x oversubscribed, meaning we had three times more orders than the size of the book. So it was very successful. And here, I would like once again to thank both our new shareholders and the shareholders already in our base at the time. We always had a lot of support from all of them. This follow on prepared the company for growth, either organic growth via investments in the fields that we already have or preparing for inorganic growth through acquisition of new fields. We also had the approval by AMP, the regulatory agency of the 30% stake of Frade field that we had acquired from Petrobras in 2019. And this was finally approved in February 2021. We also acquired the working interest belonging to Total in the Wahoo field, 28.6%. As we mentioned in the past, we were interested in acquiring that, so we finalized that deal. And we also had a certification of reserves and resources, 92,000,000 barrels of 1C resources and reserves for the company. This was very interesting because we already included Wahoo Field. We've already included the 64.3% working interest of Wahoo. So this gives us a pretty good idea of 1C reserves, which in the future can become 1P after the declaration of commerciality and so on and so forth. Now moving to Slide four, please. Here, I'm going to address some items in perhaps more detail, and then I'll turn the floor to Francois Mar. Well, the first point on Slide four was a reduction of our lifting cost. We have here $14.3 reducing the lifting cost a bit quarter over quarter. It's still a little below what we would like. The main reason why it fell a little below our expectation was some downtime at Polvo, given a problem we had in the boiler of the FPSO operated by BW. This cost us a little bit, although the number is a little lower than in q four twenty at $14.3, so a very good lift in cost. We could have done even better. The next item here is increased production. The main reason explaining this increase in production was the approval of the 30% stake belonging to Petrobras. We increased from an average production of 29,900 to 31,300. As we mentioned in the first quarter, we had the stoppage of the Volvo FPSO, a downtime of ten days on account of the boiler. And we had stoppage of one month in the TBMT field to Barao Martello. And here it's important to differentiate the issues. Of course, the FPSO performance is something that we have to address and this will be addressed. It is being addressed as we will keep this FPSO until July. Now the bump, the SB, that's the day today of an oil company. We'll continue to have pumps that fail. This is our day today. Of course, it did catch us a little by surprise because this TPMT ESP requires a rig called Kingmaker that we acquired in the end of last year, but it is in the process of overhaul. So now we have just finished the overhaul process of this rig, and we will replace the electric submersible pump, ESP. But these pumps are routine for the company. These things will continue to happen. It's not a surprise. But the FPSO, yes, that was a little surprising and we are taking measures in addressing that topic. Well, our cash position increased to 3,370,000,000.00, almost $600,000,000 in cash. So when I said that the company is prepared for what's coming in the future, that's what I meant. We have a lot of firepower, almost $600,000,000 in cash, and this is reflected on our our net debt over EBITDA ratio that was 1.2 times in the 2020, which was already a good number and is now down to minus 0.95. In other words, we used to be a net debt company and are now a net cash company. We used to have more debt than cash, and now we have more cash than debt. This is what this indicator means. And even if we were to eliminate the effect of the follow on offer, we would still have seen an improvement in the company's leverage. So the company performed well operationally speaking. In addition, the company also had the follow on on top of this good performance that make the company completely prepared and ready for the next challenges and for the next steps we'll take to drive organic and inorganic growth. With that, I will turn the floor to Francois Mar to discuss our operations, and then Milton will speak about the financials, and I will be back at the end to talk about the next steps. Thank you very much, Francois Mar. Thank you, Roberto. Hello, everyone. Starting on Slide five, we have the performance of our assets. The most relevant highlight in this quarter, given all the numbers that we know well in this table and that everyone monitors, the relevant point is in February. On February 5, we completed the deal of the remaining 30% stake of Frade Field. Now we own 100% of the field and that has had a positive impact on the company's total production. So that's the Friday line item. The other fields, POFO and TBMT posted a certain reduction in production, and I will explain later on what caused that. It was an a one time off event. And here's the lifting cost. This is indeed the main indicator of the company's operations. And here, we see return to a better level than presented in the prior quarter when there was an upward push, and I will detail this on the next slide. Please go to Slide six. We see on the top left hand corner, the traditional graph showing the evolution of the company's lifting cost. In q four twenty, we had an increase in this number, but we worked to bring it back to more comfortable numbers, better numbers for the company. But, again, we had some complications particularly linked to Polvo Field where we had a problem with the FPSO at Polvo, which is chartered and is reaching the end of its contract life. I will detail this further on when I talk about the operating performance of Polvo. We also had a problem with one well at TBMT field where an ESP pump failed. I'll speak more about that when I speak about that specific asset. So we have one less well operational at TBMT. On the positive side, we had some impacts that helped our production and that kind of offset these issues. We integrated the final 30% volume that remained of Friday when the deal was finally recognized in February. And we had all of the measures that we adopted along the year. Even holding back on some maintenance service, we are now able to do everything that we postponed before, and we are still controlling costs. Also, we had a little help from the foreign exchange with the BRL depreciating vis a vis the US dollar, and that helped a little. We are fully aware that the main indicator for the company in economic terms is the lifting cost. So a good deal of our effort is focused on that. We believe we are going to have one more difficult quarter while we finalize the tieback of Volvo and TBMTs still operating with the Volvo FPSO. And then we should expect a considerable improvement. On slide seven, we will speak in more detail about Frade. Operationally speaking, the field had a good quarter, unfortunately impacted by the performance of one well, MUB3, where we had hydrate formation that actually started in the previous quarter, a problem that had not been solved. As we can see, operating if we can see operating efficiency considering our full production capacity versus actual production. So that had a negative impact on the operating efficiency of the field as a whole. But the FPSO is performing well and all of the metrics of the field look good. In the April, we started a scheduled maintenance that was actually scheduled for last year, but we postponed it on account of the pandemic. It started now on April 28, and it should last eight days. Now moving to slide eight, let's speak a little about Polvo. Polvo field had another complicated quarter given the low performance of the FPSO Polvo, which is chartered for the field and it's getting to the end of its contract. We expect the transition from FPSO Polvo to FPSO Bravo at TBMT by July. So in this final phase, we are running into some complications, slow performance of some of the equipment. We had practically ten days of downtime in the energy generation system, which is boiler based on that FPSO, and that impacted the process as well. That really hindered production and performance at Volvo. On the other hand, we are sparing no efforts to continue with a good operation in this remaining period of the FPSO, operating with safety, good numbers and hopefully and as much as possible in good operating conditions until the end of the contract. Also in this quarter, we were able to finally complete all the remaining geological and financial analysis to start drilling another well in the Eocene Reservoir. This began in Q1 twenty twenty one and drilling of this well is unfolding well. We expect to finish it and put it into production in the coming weeks and we'll keep the market informed about this. Moving to Slide 10, to Tubarao Martalo Field, TBMT. Here, to be highlighted, there's a problem we had in Well 44, a problem linked to flow assurance, but our team was able to control it relatively fast and the well is back to operating in normal conditions. In the March, the ESP pump failed in Well 8. The pump is responsible for pumping out the production of the well. It failed in the March. The well has been shut down since then, and we are waiting for the work over to replace this electric submersible pump, ESP. And here, two observations are in order. The first is that TB and T field as well as Polvo both produce heavy oil and require submersible pumps, ESP, to issue production at the field, when these pumps fail or stop, we have to be ready to replace them immediately. We do this as a routine at Povu and are now starting to do it at TBMT. The second observation is that we made the right decision last year when we acquired a specific rig to carry out workovers at TBMT precisely to handle this type of situation. So we are working to prepare this rig. We are actually finalizing it. This pump failure cut us a little before we expected, but the rig is practically ready to start operating and to do the workover by the May or June. I believe that by July or August, that well will be online again. FPSO Bravo showed good efficiency. It is very good equipment that makes us very hopeful and strengthens our investment thesis because all of the complications and low efficiency that we have at FPSO Polvo will be offset by this FPSO at Tubara Martello. Moving now to Slide 11, and let me give you a general update on the Povo to BMT tieback. The project is advancing full steam and the physical progress is over 60%. The financial part is also according to plan. So far, everything is on plan, on budget. Despite all the difficulties imposed by the pandemic and all, so our crews are able to deal with all that. As for manufacturing of lines and delivery of equipment, it is all going according to plan to be finalized by July. Well, number 10 at TBNT should come into play more or less in parallel. As soon as we finish the work over to replace the pump at Well 8, the teams will come in with the rig to complete Well Number 10 to finish by September. On the right, we see an illustration of one of the coils that has part of the production flexible line. Please go to slide 12, where I give you an update on the Wahoo block. We acquired the 28.6% stake that belonged to Total. With that, PetroRio owns 64.3% of the block. What matters is that we were already the operator of the part acquired from BP, 35.7%. With that, we started preliminary engineering work to fine tune the knowledge and see what kind of solutions we can use to improve financial costs and how we can bring forward the startup of operations. In other words, to improve all conditions. We'll prepare the development plan DP in the coming months, and we believe that by the end of the second half, we should be coming to an agreement with the rest of the consortium and submitting the development plan to the agency for approval. So excellent news. On Slide 13, we see the company's certification of reserves and resources. In this quarter, we updated the numbers already including Wahoo block and showing a significant increase in all scenarios. I'd like to draw your attention to this part on the right, where we see an increase in reserve levels. We practically doubled one p and one p plus one c from 2020 to 2021. And here, we can see two representative figures. $17,000,000 additional from Wahoo related to PetroRio's share of 64.3%, also representing the figure of the field and the potential to help us grow the company. And another important number is the evolution of 1P reserves of the assets that we already have in production, TBMT, Polvo and Frade, from 01/2013 to 01/2018. And this already considering what was produced along 2020. This reflects an increase of over 10,000,000 barrels and more than 10% of what we have in one year with production at full steam. All the other reserves, 2b plus 2c and 3b plus 3c have had considerable increases. Another important point for us to consider is the extension of Frade field's lifespan. Once we form another cluster, Frade plus Wahoo, we extend production that was expected to end in 2034 to 02/1954, proving once again that the company chose the right strategy to extend the lifespan of fields and increase recovery factors. With that, I end my presentation. I turn the floor to Milton. Thank you. Thank you, Francois Mer. Good afternoon, everyone. To continue our presentation on Slide 14, we present the company's financial performance in the quarter. Considering the columns excluding the impact of IFRS 16, our revenue totaled million dollars resulting from the sale of approximately 1,000,000 barrels of Friday and about 900,000 barrels considering POVO and TBMT, plus the revenue from MANATY of about R27 million dollars Considering cost of goods sold, royalties, G and A and other operating revenues and expenses, our EBITDA was BRL407 million in the quarter, 62% EBITDA margin. Another highlight is our financial result, million negative, very much influenced by foreign exchange variation to be explained in the next slide. With that, we reported a loss in Q1 twenty of almost BRL40 million. And if we consider the effects of IFRS 16, this loss reached million. The last highlight on this slide is our adjusted EBITDA, a strong EBITDA of BRL427 million. I'd like to remind you that this adjusted EBITDA excludes non recurring items and non operational items. In other words, it better reflects the company's ability to generate cash. And we also reached an EBITDA margin of 65% in the quarter, a higher margin compared with all quarters in 2020. Given the recovery in oil prices as well as synergies captured by the company and cost reduction initiatives, so we were able to deliver a very high profitability margin As regards IFRS 16 results, adjusted EBITDA was close to BRL $470,000,000 in the quarter with a 72% EBITDA margin. To continue moving on to Slide 15, let's speak about the financial results of the company in more detail. We have two columns here, one excluding and one including IFRS 16 results. And the main point that I would like to highlight has to do with this line item, a loss of R211 million dollars in our financial result regarding foreign exchange variation on intercompany loans. So what's happening here? We had some Brazilian companies in our PetroRio group that were taking on intercompany loans from foreign companies in our group, particularly in Luxembourg. So these Brazilian companies borrowed money in dollars and the real depreciated in the quarter with a dollar real ratio of around one to 5.8, depending on the moment along the quarter. And with that, we recognize that this loss linked to the exchange variation impacting these loans. Due to accounting rules, we are not able to deduct these losses from the gains that Luxembourg companies had with the same loans. And this happens because Luxembourg companies already reporting dollars in this foreign exchange gain given that they are creditors, is adjusted directly via shareholders' equity. So the result shows this distortion. What stands out is the loss of the borrowing Brazilian companies. However, the counterpart is not observed in the result because it is booked directly in the shareholder equity through the CTA. So this is just a little bit of information to explain why we have this kind of pollution in our financial result. In addition, we highlight that exchange variation does not have a direct impact on the financial health of PetroRio because the majority of the cash is invested mainly in foreign currency, mainly dollars. And our revenues, the company's EBITDA is very much exposed to foreign currency given that we sell oil and oil is priced in dollars. So a good part of our variation, a good part of our cash generation is also dollarized. Now moving to slide 16, let's speak a little about funding. The first graph on the left shows the evolution of the cost of the company's working capital or indebtedness cost. Given the very successful follow on and improved liquidity of the company as well as improved loan profile overall for the company, we have been getting loan facilities for working capital at more and more attractive costs. We have been working with world class banks, both Brazilian and foreign banks, and we have been replacing more expensive debt that we carried in our balance sheet by cheaper loans. So well, another very important piece of information related to this is that we have been able to replace expensive debt by cheaper debt. But despite of lower cost, we have been able to increase the duration of loans for working capital. We used to have loans payable in six or nine months, but now all of these new loan facilities have a duration of one year. So not only were we able to improve the cost profile, but also the duration profile of our debt simultaneously. On the right, we see the amortization schedule. As I explained, we had a very successful follow on raising more than 2,000,000,000 BRL. This provided important reinforcement for our cash, giving the company very comfortable liquidity to serve the obligations that we have both in the short term, less than twelve months, and to serve our commitments in the second or third year, and generally speaking, a better situation for the company. I'd like to remind you that we've been very successful in rolling over a good part of our debt, which gives us even more peace of mind regarding our financial position. Lastly, please go to Slide 17 for more details regarding the company's leverage. An indicator that we like to follow-up close is net debt over adjusted EBITDA ratio. I'd like to remind you that adjusted EBITDA excludes non recurring and non operational effects. Thus, it better depicts the company's cash generation. As regards the recent past, the first quarter of the year, because of the follow on, we are now a net cash company. So this ratio is now negative. It is now at minus 0.9 time approximately with a net cash of more than BRL 1,000,000,000. Another important point that I would like to highlight is that even if we were to exclude the effect of the follow on on PetroRio's cash, this ratio would have been 0.6 times of leverage. Now in Q1, when we compare this with 1.2 times in December 2020, also without the follow on effect, because the follow on happened in February, this shows that the company has a strong ability to generate operating cash. Regardless of the follow on, we would have been able to post a significant reduction in the company's leverage quarter on quarter. And now I turn the floor back to Roberto, who will talk about the next steps and then we will have the Q and A. Thank you very much. Thank you, Milton. Well, I will I will go over the next steps before we open up the floor to questions. The first, as expected, is our focus on safety and health so that we can continue to perform as we have done in recent quarters even in the middle of this whole confusion, the COVID pandemic, etcetera. Now getting into more detail about our operating projects, we now have some very important projects going on. The first, as Francois Mar mentioned, is the tieback project between POVO and TBMT, which we expect for the July. The project is unfolding well, and it is a very important project for the company because in addition to increasing a lot the efficiency of both fields, it also reduces both our lifting cost and CO two emissions. So it is a project that optimizes everything. It is a very interesting project that is about to finish. Then we have here two wells, one at Polvo as we decided to drill the Eocene reservoir at Polvo, and we expect to have it operational soon. And then we have the TBMT well to be drilled in 2021. So two wells that should start production in the coming months. In addition to that, we have to prepare to begin the drilling campaign at Friday. Our goal would be to start drilling at Friday field this year. Now let's speak about things that are not set operational in nature that have more to do with regulatory and M and As. The approval of Wahoo by A and P, it is very important to have that so that we can declare commerciality of the field and start preparing for the tieback project between Wahoo and Friday. And lastly, a strong focus on inorganic growth through acquisitions, M and A opportunities as this has been our DNA in recent quarters and years. So these are the next steps that we have ahead of us. And with that, I'd like to open the floor to questions. Here with me, we have Francois Marra, COO Milton, CFO, and Emiliano, our legal administrative and regulatory officer. Thank you very much. And let's have the questions now, please. Ladies and gentlemen, we will now begin the question and answer session for Our first question comes from Christian Audi with Santander. Thank you. Hello, Roberto Milton from SoMa. To start, congratulations on the results. Very positive results across the board, production, volume, costs and the financials. So congratulations. I had three questions. One of them is more strategic. The first question, Roberto and Frisomar, I think you gave us a lot of details on the problems that occurred at Friday, Poland, TBMT. I just want to understand, Could you give us a a big picture of what was expected and what was the surprise? What worries you more considering these issues? Francois Mori gave us a lot of details, but I just want to understand what's left in terms of issues that was not resolved when we consider NUP three at Friday, the problems, the boiler, and then well 44 at TBMT. My second question is looking forward Brent discounts, What do you expect? What what do you expect in terms of Brent price discounts perhaps for the next quarter? And finally, Roberto, on the strategic side, could you tell us about the Abacore process? Have you felt any any change given all of these changes that are happening at Petrobras regarding the Abacore process and what would be the next steps. And also on the strategic side with Wahoo, after the success with BP and Total, What about BP's interest in acquiring your stake at Wahoo? Thank you, Christian. Thank you for the questions. I will answer all three, and Francois Mar is here with me. So if Francois Mar wants to add to the first question, no problem. Regarding operating problems, if we can call them that. Let's start with Frady. We had m u p three that had a hydrate formation last year. We were able to open the field for fifteen days or a little more than that. If I'm not mistaken, that was in February. But then the well started presenting problems again, so we decided to shut it down again to try to resume production sometime in the coming days or months. This well is not producing at all. We try to have the the well producing through another path, but it didn't work as we wanted. These wells have redundancy. So we try to use the redundancy, but it didn't work out as we expected. So now we still are trying to open the well using its original path, and that's why it's taking a little longer. So regarding Friday, this is one point, and it's out of the ordinary. Regarding POVU, what is out of the ordinary is the VW FPSO. It is underperforming because of the boiler problem. We had a ten day downtime because of that boiler. And, candidly, we've been struggling to have VW perform as expected both in terms of production and in terms of maintenance of the FPSO. We don't see a problem regarding that from the from the safety standpoint. But but we it's it's a kind of a dispute. We want to bring the FPSO at the level of excellence that we are used to having. That's what we are pursuing. So that's something that we have to address. How do we address it? With a tieback. Regarding Tiburon Martello, we have one well that is down. Well number eight, Tubaro Martello eight. This well had been producing from the very beginning of the the field, and the pump failed. It produced for seven years, and then it finally failed. You know, we need to carry out a workover. However, the workover requires that rig that we acquired last year, and that rig is going through an overhaul. And that caught us a little by surprise. But m UP three and well, number eight at TBMT, these are routine for us. These are operational and expected things. We like to report it because we wanna be transparent with the market, but this is our day to day. What is it kind of an outlier is the performance of the FPSO at Volvo. Volvo is performing sometimes under 90% in some months, and that is too low. And I would say that this is going to be treated FPSO at Povo because we know we are going to have the FPSO for another sixty days. And then we'll start using the FPSO at TBMT, which is showing excellent performance since we acquired the FPSO. Regarding Brent oil price, today, we are operating Friday at a discount of 1.5 to $2 for Friday. And for Povu and TBMT, we are running at levels of 3.5 or $3 discount, around that range. We might have one offload of 500,000 barrels before July, and it should be should have a a greater discount because that oil had a little bit more water. The maximum acceptable is 1%, and this one has a three to 4% water content. So the discount will be a little higher. We've been using this oil. We've been using this oil blend for the offtake. So we always sell the oil with 1% water content. But now with the transfer of the FPSO, we might have to sell it all at once, and there will be a greater discount, but still a one digit discount. Nothing out of the ordinary, but a little higher. So this is what we expect in terms of Brent oil discount. So things are unfolding well. They are normalized, and we are almost back to IMO 20 and pre COVID times. So I think that we are at good discount levels. Regarding Evercore, so far, we haven't seen and we haven't identified any change when with Petrobras. We know the bid will happen in July. Today, it is expected to happen in the July. Now we don't know whether this is going to be pushed forward or not. That's not under our control. But I would say that it is expected to happen in July, perhaps in the first fifteen days of July. We haven't noticed any change in Petrobra's attitude regarding this process. So we still we don't have anything to report. In regarding Vivi, we submitted a proposal to them, a binding proposal for the acquisition of the field, and they are now in their decision making process. Things are a little slower. Sometimes it's a little frustrating, but the truth is our proposal for strategic strategic reasons had a longer a longer our proposal had a longer term, so they have more time to make an internal decision. It's not really I believe this decision. It's the decision of the of the partners of I believe this Indian companies. So this is where we stand. I I can't really predict what they're thinking, but, yes, they do have a proposal from us. And if they are interested, they'll sell. Excellent. Very clear. Thank you very much for all the details, and congratulations one more time. Yep. Thank you, Christian, for the questions. Our next question comes from Pedro Suarez with BTG Pactual. I have three questions on my end. The first regarding the new drilling in the ocean. If you can comment on the decision making process. Of course, it includes a number of things. But I would also like to know regarding price evolution, whether it makes you comfortable to proceed with this new drilling. Perhaps you can give us an expectation of of the oil production from that well and the CapEx involved. That would be quite helpful if you can give us some color whether it makes sense with all of the macro conditions, if it makes sense to perhaps expect more such drillings along this year. The second question is regarding offtakes. You explained in the release why you had a reduction in the first quarter. In the second quarter, looking forward, should we expect a more gradual evolution, perhaps not increasing too much in the second quarter or perhaps to increase in the second quarter to enjoy more favorable prices? Perhaps if you give us if you could give us some color on that. And the third, as a follow-up question regarding the lifting cost and everything that impacted TBMT and Polvo. I believe that TBMT will still feel some of these effects for a while. What can we expect regarding the company's lifting cost in q two or until you complete the Porfutubaru Martello tieback? Should we expect the lifting cost to remain at this level or perhaps with the Frade additional production, it could be closer to the third quarter of last year? You know, could you give us some color on what you expect? Thank you. Please hold. You may proceed, sir. Please hold. The executives may proceed. Ladies and gentlemen, please stand by. Ladies and gentlemen, please stand by. Ladies and gentlemen, please standby. The executives may proceed now. Alright. Thank you, Pedro. I'm sorry. Can you hear me? Yes. We can hear you. Pedro, I apologize, but you were asking about the offtakes and how many offtakes we would have in the second quarter. Yes, I asked about the evolution of offtakes, if it would make sense to imagine something more gradual towards the end of the year or if you expect higher volumes. And finally, related to the first question regarding TBMT OVO issues, imagining that TBMT will still have some problems for a while until the rig arrives on-site to carry out the workovers. Does it make sense for us to expect lifting costs close to what we've seen in the last two quarters? Or perhaps with the 30% stake of Friday, there might be an upside and perhaps a stronger reduction in lifting cost even before the workover is carried out and the tieback is completed? Alright. As regards the decision making of Oval and Friday. Hello? I can hear you. Oh, okay. Sorry. The phone was ringing. Well, of course, it takes into account the price, the fact that the Brent oil price is at a more constructive level worldwide now. But we have to remember that this well costs $13,000,000, even less than $13,000,000 even today. We were considering something around 10 to $11,000,000, and it is a well that can add production 2,000 to three to 3,000 more barrels a day. So when you do the math, the well is repaid very quickly. The return on investment is very fast, and that is why we we take this into account. Francois Marr and his team in the last few months have been evaluating the reservoir. They did a geological reservoir. Our reservoir engineering team worked on that to decide on this infill drilling. We are drilling on the Eocene reservoir. So it's almost an infill drilling, but it's a new region of the same reservoir that hasn't been drained yet. And all of that gave us a lot of comfort regarding that well. Now looking forward, our goal is to have that well operational, and then we'll handle the workover of Tubarao Martello Well Number 8, the one that had a fail in the ESP. Then we'll have Tubarao Martello Well Number 10 operational again, That one that has been operating for a while. And then we should start with Frade. We're still in doubt whether we should drill another such well before Frade's campaign, but we haven't decided on that yet. The reservoir people will look into that in more detail. But it is possible that we'll drill another similar well before Friday, but we want to see how this well that we're drilling will behave. Regarding the offtakes, we imagine that for the second quarter, between three to 4,000,000 barrels sold, that's what we expect. And it's going to be more than than the first quarter. So that's the second part of your question. The company is effectively producing more, so we are going to have more offtakes. In this first quarter, in particular, we had 2,000,000, also because we wanted to replenish our inventories. Because last year, our inventory went down as it happens in all months of December. The fourth quarter is always very strong. So we'll resume the offtakes in selling between 3,000,000 to 4,000,000 barrels. As regards to lifting cost, we expect a reduction starting in the second half of the year. Of course, now we have our lifting cost of Tubaro Martello, TBMT. We have a scheduled downtime of the FPSO at Friday. We have to certify some vessels with cleaning that we need to carry out. So the FPSO is going to be shut down for approximately eight days. It's happening as we speak. So in this quarter, we'll still have that that that stoppage. Although, we probably will have some production from the well that is being drilled. So as of the third quarter, we should see a reduction because of the tieback, $50,000,000 a year that will leave our OpEx. So we should see a reduction in our lifting cost. Very clear, Roberto. Thank you. Thank you for the answers. Thank you, Pedro. Our next question comes from Andre with Itau. Hello, Roberto and team. Thank you for taking my questions. I have two questions. One has to do with the Polvo tieback. It is expected to be finished by July. Can you tell us about the process? How it is evolving? If it is going as planned? And what are you learning with this tieback project that can be applied to the Friday tieback? You did some information on that, but I'd like to understand, what the process is like and if it's according to plan and what do you expect looking forward? My second question is regarding m and a. You have the follow on offer. You have a lot more firepower today. But when we look at Abacora, the news are indicating more losses than expected originally. So could you give us an idea of what you expect in terms of the M and A market? There are new entrants and perhaps market players being a little more aggressive. What can you expect? Thank you, Andrea. Francois Mar will speak a little about the TBMT tieback, and then I'll speak about m and a's. Andrea, this first tieback project is indeed being all it's bringing us a lot of lessons learned. We are trying as much as possible to optimize resources. I have to remember when we talk about tie back, people talk about twenty four months to execute. And since the beginning, we tested the market, and we wanted to do it in a lot less twelve to fourteen months. And the results so far overall has been very good. Delivered to the plan and had some positive surprises. The suppliers are performing well, and that will help us with flexibility with our suppliers for the Wahoo tieback. We are at an advanced conversation stage with with some suppliers, and that will give us even more comfortable for the Wahoo project. So things are unfolding really, really well. I would even say that the the project has been easier than we imagined. Francois Marble never let me say that, but the project is being executed according to plan on schedule, so the process is well under control. As regards to m and a's, we had a follow on. We are financially sound for sure. And what I think is we we didn't do the follow on only for Abacara. We had the follow on because we have a market of mature fields out there that is a very relevant market. Albacora is not our only target. It's not our only everything or nothing. What we have seen, generally speaking, is that there are many companies that are capitalized. However, they are still very much focused on Petrobras processes. Our goal is to have bilateral projects that perhaps don't include necessarily Petrobras. From that standpoint, the market for us remains intact. We have a lot of investment possibilities, and we are working on them. Wahoo, for example. In the past, I used to say, I want to buy a 100% of Wahoo, and this is what we are pursuing. And this is a totally bilateral process. It's capital intensive, not only for the acquisition, but for the investments that come next. And there are some other investments. I cannot give you a lot of detail on that, but we are very positive. It's a positive moment for the company and for all of us. And, Roberto, you mentioned buying outside the scope of Petrobras. What about your partnership agenda? You don't have a lot of partners, and you want to remain as operator. So what do you think in terms of partnerships for new assets with existing players in Brazil or new entrants in the market? We don't have any problems regarding partnerships. So we actually like partnerships. What I think is important is that the partnership of be with people, with players, and partners who think like Pedro Rio. In the case of Alba Cora, we have a partnership foraged with a Spanish group. This is public information. So we signed a partnership with them in which we would have 50% stake and be the operators, and the partner would have the remaining 50%. So we like this kind of idea of partnerships. We're open to partnerships. But in some situations, as is the case of Wahoo and Frade, it made more sense for PetroRio to acquire a 100% of the assets to handle the turnaround. And the same applies to to Barreel Martello. But in the future, we might have partners in these fields and even in large processes like Albacora. No problem with that. We we don't refuse partnerships at all, but we need partners that think alike. Perfect. Very clear. Thank you, Francois Martin and Roberto. Thank you for the questions. Our next question comes from Regis Gatos with Credit Suisse. Hello, Roberto Milton from Saint Laurent. Thank you for taking my questions. Perhaps I have follow-up questions on topics that were addressed before. Perhaps the answers will be shorter because of that. But first, we always discuss cash position, net debt. The company still has commitments if you want to acquire the remaining stake of Wahoo or to handle drilling campaigns. So my question is, how do you see today the firepower, the power in your balance sheet? You mentioned into 1,000,000,000, perhaps $1,500,000,000. How much would PetroRio have for new acquisitions to have all the m and a strategy. Another topic has to do with the timing of projects. Which one of these projects share resources, particularly rigs? I just want to have a sense of what needs to be done in parallel, what what can be done in parallel, what needs to be done sequentially. Perhaps you can use the same rig for Friday and for the tieback between Povlo and Tubaro Martello. That would be my second question. And the third follow-up question is regarding to BMT tieback, the risk of delays. Any chance that the delay will extend beyond the end of the contract with BWFPS. So if that happens, what is the alternative? And, also, if you have other players that were initially focused on offshore and and are now turning to onshore, are you thinking of going the other direction in the inverse direction, or do you prefer to embrace even bigger projects in ultra deep waters similar to major oil company projects with larger larger projects. Well, from the standpoint of cash, firepower, m and a's, today, we have a capital structure of 370, $360,000,000, but this is a short term debt. So let's imagine that we get this debt and turn it into long term debt, which is a discussion we are having as we speak, whether it makes sense to issue a bond of 400 to $500,000,000 because that would be a more structured five year term debt. With that, we would have money available because it's hard when you have twelve month loan. It's cheap loan, but you can't fully count on that because the banks may enter those loan facilities. So let's imagine we issue bonds and we have that kind of money, then I believe the company would have firepower to invest $1,000,000,000. We are now already very well prepared. And if we want to make adjustments to our capital structure and if we want to push our debt more to the long term, so it's a possibility we are considering. Then we're talking about a firepower greater than $1,000,000,000 or a little more than that. And that will take us to a whole new league for big fields to be acquired, important fields to be acquired. And I'd like to remind you, in the case of Albacora, our goal is to have a partner. We are not resistant to have partners. And as for synergies, It's very different when you talk about shallow waters and deep waters. Shallow waters in the case of TBMT and Polo Foam. For shallow waters, we have a rig, but that rig only handles workovers in TBMT, and the fixed rig handles workovers at Volvo. And it is the same team that operates both rigs. So here, we cannot have at the same time. We cannot cannot complete a well at TBMT and another one at Pova at the same time. We can't do it at the same time. At least that's not we are thinking right now. We would need to increase our crews and give more muscle to our crews. We still believe it's better to do it sequentially for now. And in deep waters, that's a whole new game. That's more in line with Friday and Wahoo. The same rig that will handle the drilling campaign at Friday, will handle the drilling campaign at Wahoo to sequence. We'll drill first at Friday and then Wahoo. We could do both in parallel. Friday, the deep water cluster together with a shallow water cluster. That would not be a problem. We are not doing it now right now because of the focus. It is our first time handling such a big project. In the case of Povo, Tubaro Martello tie back and the workovers, we need to handle that first and then Friday later. We didn't want to do them both. It would be easier to do something in parallel in shallow waters and in deep waters, but it was not our decision. We will continue to work in shallow waters until the end of the third quarter. And then in in the end of the third quarter, most likely in the fourth quarter, we will start the campaign at Frade in deep waters, and then we'll start drilling at Frade and then move on to Wahoo and so on and so forth. You asked about delays. Delays in the Thai bed project. Yes. Today, what do we have to do? All of the materials have been commissioned. They're all being built. We even included a photo of the assembly line being built. The studies are ready. So what I can tell you is that today, it is very hard that there will be delay in delivery of materials and equipment. Things have been done. COVID around the world is going away. There are things being manufactured in in The UK and Portugal. COVID seems to be a little more under control. We are not seeing any plants stopping because of COVID, so it seems that everything is pointing to on time deliveries. We'll receive our flexible lines in the May. It is one of the photos in the release that coil with a flexible line around it. That is one of the most important items, umbilical lines. So we'll get that in the May. We have to we have to clear it in customs and install them. We have the vessel, the Sapura vessel, and it is contracted, and it is recovering lines that we have there. In that deal with Domo, we kept some lines and some lines have to be recovered at Tubara Wazul, and they're removing these lines with this vessel. So the vessel is in house. So we just need to receive the whole equipment and install the all the flexible lines. So the possibility of delay is unlikely. Having said that, our contingency plan would be to sit and negotiate a tariff with BW. If we come to the conclusion that we need to spend more time with the FPSO at Volvo, we'll negotiate a tariff with BW that is compatible with the situation. I don't expect it to be a $100,000 a day as we pay today, but yes, there's this possibility. Having said that, I, again, stress, a delay is very unlikely. As regards moving to onshore hedges, no. We don't have that in our radar. That is not in our radar. I believe that onshore can be profitable, can be interesting, but it is a different type of company. It's a different mindset. Francois Laurin and I have had that kind of conversation over and over. It's a different type of operation. This is a sing and acting operation, while offshore is more of a planning reservoir engineering operation. These are two very different things, And we believe that here at PetroRio, we still have a lot of room to grow in offshore. At the moment, it doesn't make sense to look at onshore. At the moment, we see some companies rehearsing to move from onshore to offshore. That's something they should look into very thoroughly and carefully because we are talking about two different beasts here. We are we are not thinking about going onshore. Petrobras is divesting in that area. We know a little bit about it, but we didn't get excited about that because we believe that it is a totally different type of operation. It requires a totally different skill. And as regards ultra deep waters, we already operate in deep waters. We operate in mature fields. So we might have a mature field in deep waters or in shallow waters. As time goes by, mature fields will be in ultra deep waters. Not now. Today, ultra deep waters are immature fields, that's why they are not part of our scope of action. But our goal is to operate in mature fields. When we find mature fields in ultra deep waters, we'll look into those. Now giving up return to do more business, I don't see that happening at Petrojillo. It's not our idea. Idea is to maintain return on investment, and that's why we focus on mature fields. We don't tackle exploration and nothing different than the operation of mature fields. So this is what we know what to do. It's a one trade pony. That's what we do. We operate mature fields, and we'll continue to do that with the level of return that we have today. This is our mindset. Thank you. Very clear. Very well explained, and I think that the risk of delays is mitigated. Thank you very much. Thank you, Jesus. It's been a pleasure. Our next question comes from the webcast by Felipe Bravo. Good afternoon. Thank you for the call. At the beginning of the presentation, Roberto mentioned that the lifting cost fell below the company's expectation. However, a simple calculation of OpEx suggests an annualized cost of around $160,000,000 versus an expectation of $180,000,000 $190,000,000 expectation. In addition to foreign exchange, what other factors explain this performance? Hello, Felipe. Thank you for the question. Good point. Here, today, our running rate and if you multiply it by 12 or by four quarters, we would get close to a 160. But we've been guiding the market, guiding people to something close to a 170,000,000. There's 10,000,000 difference from a 160 to a 170. Well, a 180, a 190 that would include contingencies contingencies. But the number we are pursuing is a 117,000,000. And this delta, 10,000,000 delta, relates to shutdowns. We're going to have a shutdown at Friday, as I mentioned some time ago, and it is happening now. And the shutdown costs $5,000,000. So it is on top of the 160,000,000, and we're going to have another shutdown at TBMT because of the tieback. It will not cost 5,000,000, but there will be another shutdown. So it will be between a 160 and a $170,000,000 naturally. Of course, there is the foreign exchange effect that helped us a little, but this is what we're thinking. Pursuing running costs of 170. Actually, we we won't end the year at $1.70 because in the middle of the year, we'll eliminate the POVO FPSO. So we'll have to make adjustments, but the running rate would be around a 170,000,000. And after that, we would have to exclude the second half of the year of the chartering of FPSO, Volvo. So the cost for the whole year should be a $170,000,000 minus this $25,000,000 around that. And for next year, something between a 110 and a 120. That would be the OpEx running rate for next year. Is laughing. He's sitting next to me, but that's the number that we have in mind. The next question comes from the webcast by mister Cesar Lanzoni. Are you considering to the possibility to issue a new bond? Hello, Cesar. Yes. We are considering to issue not a new bond, but one bond. Never issued any bonds. We have 370,000,000 in debt considered in the very short term. And, yes, we have considered the possibility of issuing a five year bond. This is the follow on. We've been thinking about this. We've been analyzing this. We've talked with many banks. I guess it started in February from February to present. We had spoken with more than 30 players getting their feedback, understanding the rates, the costs, the fees, and we're looking at the possibility of issuing a bond, and we're considering it. There's a possibility of an education of the market regarding PetroRio, and it's all maturing more and more. We expect to be able to do this in the coming months. This concludes today's question and answer session. I would like to invite the executives to proceed with their closing statements. Well, I would like to thank all of you for joining us. I want to apologize for the technical glitch we had in the middle of the call, but but, technical glitches do happen. Thank you very much for joining us, and I hope to see you in the next quarter. Thank you very much. That concludes PetroRio's conference call for today. Thank you very much for your participation, and have a good day.