Earnings Call: Q3 2020

Nov 4, 2020

Good afternoon, ladies and gentlemen. Welcome to PetroRio's conference call to discuss Third Quarter twenty twenty Results. Thank you for standing by. At this time, all participants are in listen only mode during the presentation. 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 and may be accessed through PetroRio's Investor Relations website at ir.petroreusa.com.br by clicking on the banner Q3 twenty twenty 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 success. 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 Monteiro, CEO, CFO and new business officer Mr. Francois Fernandez, COO and Mr. Milano Fernandez, legal officer legal and administrative officer. Mr. Montero, please go ahead, sir. Thank you very much. Good day, everyone. Thank you for joining us in our third quarter earnings conference call. I will make a brief introduction regarding our results, and then I'm going to turn the floor to Francois Marre, who will give you more detail on our production in the third quarter. And then I will be back to speak about our financial highlights. I would like to begin once again highlighting our culture. Our culture is very much focused on efficiency, financial and operational discipline, and ours is a culture of resilience to achieve results. Our culture, our way of seeing our business model once again was a determining factor for us to achieve our results as we will see in a minute. The first highlight I would like to mention has to do with safety and health. We had another quarter with a fairly stable and safe operation, both in terms of operating safety and in terms of the health of our workforce. And this obviously minimized the impact of COVID-nineteen on our company on Petrogradium. In this quarter, we started operating Tubaro Martello, TBMT. A and P authorized the startup of the operation of TBMT. We handled this transition very efficiently, as Francois Marre will tell you, and we also resumed the project to interconnect TBMT with Volvo. And Francois Marre will be giving you more on that later. In the third quarter, we sold 2,400,000 barrels of oil, generating around $490,000,000 in revenue. Another important point as regards to oil offtakes has to do with our fourth quarter sales. During the third quarter, we already contracted the sale of 4,000,000 barrels of oil to be shipped along the fourth quarter. So this is definitely going to be a historical quarter for the company from the point of view of oil derived revenue. If we remember at the beginning of the year with the COVID pandemic, one of the pillars of our strategy was to hold back on oil offtakes. So we would not sell any very depressed market. But now we are resuming sales during the fourth quarter. And we have already confronted the sale of 4,000,000 barrels approximately with hedges locking the minimum price for these offtakes at $43.5 per barrel. And the discounts that we have received are already at twenty nineteen levels, in some cases even levels prior to IMO 2020. IMO 2020 was a treaty, perhaps we can call it an agreement among countries to reduce the level of sulfur in the diesel and in the fuel used by ships called bunker fuel. At the beginning of the year, we had a slight impact of that, but now even this impact is wearing off, not only the COVID nineteen effect, but also the IMO 2020 effect. So this will definitely be a quarter with strong revenues for the company. Now moving to the next slide, slide four, please. Here, I will speak about another three important highlights of the quarter. And again, later, Francois Mora will give you more detail on each one of them. But the three important things to mention are, our lifting cost. For another quarter, our lifting cost reduced from $13.7 per barrel to $12.8 company wide. Our production with TBMT increased by 25% on average during the quarter. And finally, our leverage metric, our indebtedness level, in other words, our net debt over EBITDA ratio decreased from 2.1 times to 1.9 time. So again, another reduction of our leverage. Overall, so far, this has been a very challenging year or a year of many great challenges. But these indicators show in quite well how the company is reacting to these challenges so far. The company is totally under control, operating according to our culture and according to our business model and achieving fairly good ratios and marks even in such a difficult and uncertain landscape. With this, I turn the floor to Francois Mar to speak about our operation, and then I will be back to speak about our financials. Thank you. Francois Mar, over to you. Thank you, Roberto. Hello, everyone. Let us move to the operating highlights starting on Slide five. As Roberto has already mentioned, one of the most important highlights was the reduction of the company's lifting cost now at $12.9 per barrel. I will detail all these figures a little more later on. PetroRio's daily production was 33,000 barrels and that is excluding the 30% working interest of Frade Field, but already including the startup of Tubarong Field. We started operating the field in the August, as well as had the start of production of Tubarong Martelu number four well. With well completion and its connection to the FPSO leading to a 40% production increase at TBMT Field. We also had the first off take at OSX-three with a record mark of 2,500,000 barrels sold in one single quarter of the company, the best mark ever for the company. We resumed the tieback project between Polvo Alpha platform and the OSX three FPSO located at Tubarao Martello with a physical progress of around 17%, and I will be giving you more on that in a minute. Another very important highlight in Q3 was the maintenance of our production and operating efficiency levels as well as the health and well-being of all our workforce operating at our units even in this COVID-nineteen pandemic scenario. This comes to show the resilience of our people and the efficiency of all of the procedures we have adopted to prevent problems. Moving to Slide six, I'll detail the performance of our assets. Overall, I would like to draw your attention to the production of Manati field. After a marked drop in production in Q2 due to a reduced demand for gas, we again have a good demand for the commodity and are practically at the limit of production at the field. The productions at Povo and Frade fields will be detailed momentarily. But by and large, with the startup of TBMT field in Q3, we had a total production increase for the company of around 25%. Moving to Slide seven, we can see on the left hand corner graphs showing the evolution and steady reduction of our lifting costs. The factors influencing this reduction in lifting cost are related to a rationalization of all of the resources we have on board. And here, I mean, our employees, third party contractors. We started this action last year and intensified it along this year. We also had an increased production at Povu Field as well as the startup of Tubarao Martelo, the startup of well TBMT four, coupled with synergies that we kept fruit in the operations of the field. All of these factors have helped us achieve this lifting cost reduction. The challenge now is to keep it at that level as now we should resume some maintenance services that were postponed for preventive reasons and to reduce people on board. To give you an idea, we were working with 50% of the normal people on board, POP. We have increased it recently and are now at around 60%, 65%. The scenario should last until the completion of the tieback of Polvo platform with FPSO OSX3, when we should see another total reduction in the lifting cost. Moving on, I will give you more detail on the operating efficiency and performance of Frade Field. Well, the field continues to have an excellent operating efficiency, 99.48%. We had few problems there. Production had a slight decline, but for natural reasons, nothing exceptional happening in the quarter. Moving to Polvo Field on Slide 9. Here, yes, we had some excitement, some unscheduled emergency stoppages at the FPSO at Polvo with an impact on operating efficiency at 94%. This was somewhat offset by an increased production at the field. So after we mastered a little more the flow process, particularly at Well 45 of the Eosin Reservoir, we had an increase in production. Now we are working to increase the levels of operating efficiency. Moving forward to Slide number 10, will give you an update on the revitalization program of Polvo Field. The producing well in the Ilocin Reservoir has been showing excellent behavior with steady pressures compared to what we expected initially. And confirming and even going beyond our expectations, the reservoir proved to be a little bigger than we thought, giving us confidence to move ahead with the project. We should complete the studies in the 2021 and we should have data to drill some wells in that reservoir. On Slide 11, I'll give you more detail on the operating performance of Tubarong Martelo Field. The field achieved a 97.5% operating efficiency in the quarter, with a good part of that under the operatorship of PetroRio. We took over the fields in the August. So the whole operational part of the FPSO and the subsurface management, including subsea and wells being handled by PetroRio's technical staff. The transition unfolded really smoothly and uneventfully, maintaining all safety and efficiency levels and showing the resilience and capacity of the company in this kind of transition. During this same period, we also finalized completion and connection of TBMT Well Number 4, which increased the production at the field by around 3,000 barrels totaling 10,000 barrels. This well is located in a reservoir that was already producing, so it should have a greater decline and we already see some signs of that happening. On the lower chart, we can have a general and schematic view of the Taipei project. So we have the fixed Polvo Alpha platform. There is a flexible line that will be connected to the FPSO OSX-three at TBMT. And here we are and here are the subsea wells at at TBMT. Well, number 10 is closer to Povo, and it is a future target for us to go ahead with the completion and connection with the vessel. This project is unfolding well. We have made physical and financial progress according to schedule and ended the third quarter with around 17%. We are a little beyond that now and the project is unfolding as planned. We expect to finalize everything by the end of the first half of next year with this I and my part and turn the floor back to Roberto. Thank you, Francois Mar. Well, from the financial standpoint, would like to draw your attention to our great revenue and EBITDA increase. Even operating in this difficult and uncertain world scenario, with the Brent oil price dropping from $60 to negative values and then going back to 45, $43, now dropping again. So you see, this has been a very volatile and uncertain year. So I'd like to draw your attention to our net revenue and EBITDA, which have a lot to do with our offtakes of 2,500,000 barrels or almost 2,500,000 barrels along the quarter, resulting in a cash position of $136,000,000 at the close of the third quarter. We had a reduction of our leverage, our net debt over EBITDA ratio and a reduction of the company's net debt from $270,000,000 to $239,000,000 And finally, I'd like to point out once again, and I spoke about this during my initial remarks, our contracted off takes for the fourth quarter of approximately 4,000,000 barrels approximately, right, with a hedged price or perhaps we can call it a minimum price of $43.5 per barrel. Please go to Slide 13. Here, I will show you our income statement and the results of the company. We can see an increase compared to 2019 in practically all line items, revenue, operating result, EBITDA, and so on and so forth. I would like to underscore two points. The first has to do with general and administrative expenses with a slight increase even over the second quarter. And a good part of that is explained by salaries returning to normal levels. You will remember that during the second quarter, we had our wages temporarily reduced during the COVID-nineteen pandemic, a 25% salary reduction across the company and a 50% reduction for the management. But now the salaries are returning to normal levels. The second point has to do with insurance. Once a year, we have to pay insurance. This is an expense that we incur in one given month, and it applies to twelve months, But it is all recognized at the moment that we actually pay for it. So we had a slight increase, a slight g and a increase, the salary effect amounting to around 3,000,000, and the insurance effect of approximately 4,000,000 in the quarter. Another thing, the second thing I'd like to underscore is our EBITDA margin. Our EBITDA margin is 42%. Here on the left bottom corner, we see a 42% adjusted EBITDA margin. And this has a lot to do with the way in which we accounted for Tubarao Martello so far. And now I'm going to go to Slide 14 because here we show how we accounted for TBMT. If we look at the right hand corner, we can see the part of TBMT's revenue, part of the TBMT result, according to our contract, was accounted for as other operating expenses, other operating revenues. In the quarter, 22,000,000. Year to date, BRL 127,000,000 approximately. And this was the chartering of OSX three that was accounted for as revenue for the company. And this was and then this was coupled with the oil that we received when we got approval by A and P. So we did what we call a price adjustment. But the fact here is that oil was accounted for by the company at a somewhat higher cost because we had already recognized part of this benefit that we have since February with the chartering of OSX three. So when we do an EBITDA adjustment and this line item of other operating expenses revenues is derived from the EBITDA, we changed this margin a bit. But what matters here is that looking forward in the coming quarters, there will be no longer this effect of other operating expenses linked to the chartering of OSX three. From now on, we don't charter OSX three anymore. So we will start to see an improvement in the margins because of TBMT. You see, this is just a technical explanation, but I just wanted to mention it because it might mislead you to think that we are losing a little bit of margin when we actually are not losing margin. It's just because of the way in which we accounted for the Tubarao Martello deal. Now moving to the next slide, I would like to speak a little about what we call funding. It's actually the company's indebtedness. Here, not much has changed compared to what we posted in the second quarter except for the loans that we paid, we repaid. We continue with the vendor finance with Chevron as the main funding source for the company. This vendor finance was renegotiated in the beginning of the pandemic. Here, we have the new amortization schedule, 15,000,000 in November, 30,000,000 in May, 97,000,000 in November under Prisma. During that period when we were thinking about that, about issuing a bond when the company went to market to try to issue a bond in The US, that market, we held back for a while on the negotiation with Prisma. We stopped working on the Prisma deal. Both parties stopped because if we were successful with the bond, we were going to prepay that debt with Prisma. But since we decided not to go forward with the bond issuance, we resumed negotiations with Prisma to transform the short term debt into a project finance. So I'd say that in q three, after that bond moment, in recent months, this last month perhaps, that was the moment when we advanced the most. I should say we are 80% ready. Like I said before, this is a big long term contract, and we're on our way to turn it into a long term project finance. And we think we should have this matter settled by year end. And then we have the prepayment of imports with ICBC, which remains in the regular amortization schedule. So nothing much here. What is worth paying attention to and highlighting is the company's deleveraging. Once again, we reduced our leverage. We are at 1.9 times net debt over EBITDA, and this does not take into account some effects. For example, in the case of Tubarao Martello, in the third quarter, we had one month operating TB and T or a little over a month operating the field and generating EBITDA. And EBITDA was impacted by what I mentioned earlier related to the way in which we accounted for the deal. But we have the whole debt, right, related to the acquisition. Another point relates to Friday, the acquisition of the 30% stake from Petrobras. We've been a lump sum to Petrobras in the past, but so far, no EBITDA was generated. So we disbursed the cash for the investment or at least a part of it has been disbursed with no corresponding EBITDA and so on and so forth. So there are some corrections that can be made here. If we were to make these adjustments, so we would have a much lower leverage level. Oh, and something else to highlight is our oil inventory. In the first nine months of the year, we somewhat postponed our oil sales. So we wouldn't sell at such low prices in the beginning of the year. But now we have this oil available to the market. So that's something else that explains why we did not generate all the EBITDA we could have generated along those period. If we were to make all of these adjustments, our leverage would be under one time. So it is an indicator that remains comfortable. The company remains comfortable with these figures. In other words, I think that this is what really matters here. It is not really about the size of the debt, but rather how comfortable the company's operation is with that level of debt. And I think we are very comfortable in that regard. Moving to the next slide, slide 16, I'll speak about the next steps. And here, I don't mean necessarily the next steps in financial terms. I'm talking about the next steps for the company. What is important, and we will continue to do it, is to keep our focus on safety, to keep our focus on health so as to protect our operation, so as to protect our employees and so on and so forth. So this is an ongoing focus of ours. Also in the next quarter in Q4, we expect to complete the acquisition of the 30% stake of Frade Field acquired from Petrobras a year ago. We are waiting for ANP's approval. We have here, as I mentioned twice today, the strong upticks totaling 4,000,000 barrels of oil to be sold along Q4. We also expect the conversion of the Prisma loan into a project finance and that will turn a short term debt into a long term debt. The tieback project of TBMT and Polvo and the connection of the new TBMT-ten well, we expect these projects to continue so that we can finalize the tieback by mid-twenty twenty one. And the company remains attentive to M and A opportunities. We see the market picking up again. During the most acute phase of COVID nineteen, our pipeline was considerably reduced. But now we see several opportunities appearing again out there. So the company will follow its DNA, a DNA of acquisitions. With this, I would like to close the presentation. We will now open the floor to questions. But before I do that, I would like to publicly thank the whole PetroRio team for their perseverance, discipline, and resilience that they have shown so far. I think that this has been a very challenging year. I guess we'll agree on that, lots of challenges. But at the same time, the company achieved marks, figures, record numbers, a record production, record profitability, and so on. And this is a big achievement by all employees of PetroRio. Thank you very much, and let's start the Q and A. Ladies and gentlemen, we will now begin the question and answer session for analysts and investors. Our first question is from mister Rodrigo Almeida with Santander. Good afternoon, Roberto, Ernesto Amar, Emiliano. I have two questions. One has to do with the sale price. When we look at the selling price that you mentioned in the press release, it is a little different when we do the reverse calculation with the amount sold. So I'd like to understand how you got to that actual price and perhaps you could break it down by field so we could understand better how each operation is performing. And my second question is related to working capital that increase in the supplier's account. Perhaps this is related to investments that are being made for the tieback project and for Friday. So perhaps you could give us more color on that. These are my two questions. Thank you. Thank you, Rodrigo. Good afternoon. Thank you for the questions. I will start with the selling price. Of course, we can give you more color on that. Regarding the third quarter, it is important to remember that we had some off takes from Frade and VolvoTBMT, but still not with the discounts that I mentioned during the presentation, not with the 2019 discounts pre pandemic and pre IMO 2020. So we still had some impact, impact by the COVID effect. We had some trades at OVO slash TBMT. So we had a discount of 6 to $7, perhaps a little more. And for Friday, the discount was around $4 discount, perhaps a little less than 4. And one thing that you have to consider, you you have to disregard gas from Manetti. I will ask Jose Gustavo to get in touch with you and perhaps give you more detail regarding that. And then you can improve your report. But but these were the offtakes and these were the discounts. So we have to get to the average Brent oil price for the month. We applied this discount and that is it. As regard working capital, I think you were very precise. We had an increase in the supplier's account, because we are starting to contract some items. Most of these items well, there are two effects in practice. You have TBMT expenses. So we add another operation that has few expenses, but there are some expenses. So that increases the supplier's account. But the bulk comes from CapEx to connect OVO and TBMT. It's unfolding well, but the CapEx has to be there so that we can be ready for the final tieback by mid twenty twenty one. Our next question will be by Mr. Bruce Barbosa. Hello, everyone. Congratulations on the results and thank you for allowing my question. If you can, could you break down the costs because half of your costs are in Brazilian reals. And what about the lifting cost? Can you break down how much of the lifting cost is specifically in Brazilian reals, BRL? Hello, Bruce. The lifting cost perhaps is a little less than 50% in reals, just under 50%, I would say. Perhaps 40% in Brazilian reals. It's around 40%, 50%. Around 40% to 50% of our costs are incurred in Brazilian reals. Understood. Thank you. May I ask a second question? You mentioned about M and A opportunities in the end of the presentation. Do you have anything in mind? Anything happening? Can you tell us anything about it? Well, of course, in addition to the Petrobras deals. There is one Albacora, which is important given its size. But in our pipeline, we have perhaps another four or five M and A opportunities. In addition to this opportunity with Petrobras. So what we see is that after COVID, our pipeline is again full as it was before the COVID nineteen pandemic and enters a little of everything in our pipeline. There are things not related to Petrobras. There are some possible deals related to Petrobras, such as the deals that you know about. We have a possibility to divest. So I should say that our pipeline has become a lot more active in the last two months. Understood. Thank you. It has also to do with a reduction in oil price. How do you see the Brent oil price in the middle the midterm post pandemic? Well, we've had two more marked reductions in the oil price. One was in 2016 and one was this year. And what we normally see that in the most acute phase of the oil price reduction, normally, the m and a pipeline, the number of deals shrink because then well, since we normally negotiate with major companies, they tend to hold still. They tend not to sell in acute phases of price reduction. This is what happened back in 2016 and now. But then when the oil price starts going up again, which is happening now, then these oil companies start thinking about selling again, thinking about m and a. This is what we are seeing. And as regards to the oil price, that is hard to say. I haven't got an expertise to speak about that because it involves a little bit of geopolitics. And it's hard for anyone to say that they are experts in predicting oil price. But we look at the future curve for our projections, the curve that is available to the market. So we look at that. At the end of the day, that's related to inventory plus expectation of production and demand in the short term. But we think that, well, we have a constructive approach to oil. We don't think that the oil price will be very, very high, $70.80 dollars per barrel. We don't know. There there is research pointing in every direction, but we tend to be constructive. We believe that the COVID pandemic will pass, and the world will go back to demanding more oil. Now how much of that will bring a structural change as some people say that will be? We don't know. But we have a constructive view of oil. Alright. Thank you very much. Our next question comes from the web by mister Rodrigo Sequeira. Could you please give us an expectation of the closing of the 30% working interest of Petrobras, such as amount to be paid at the closing, cash flow generated at the period, date of the closing and remaining oil inventory. Hello, Rodrigo. This is Emiliano. First, I would like to highlight that the transfer of rights, which is the most important event, has happened. Now A and P is analyzing the proposal of guarantee for abandonment and based on the track record of the agency, similar processes, we expect this process to be finalized by year end in 2020. Regarding the amount to be paid at the closing, we are thinking about paying 25,000,000 to $30,000,000 with an oil inventory equivalent to $10,000,000 $15,000,000. So these are the main points to answer your question. I am not the best person to answer about cash flow. Our next question comes from Mr. Rodrigo Sequeira. Two questions. Can you speak a little about the company's growth strategy and expected time for organic growth tie back Volvo campaign and Friday campaign? And can you speak about inorganic growth, M and A? New Volvo campaigns will happen only after the tieback, or is it possible to drill new wells infill drilling in the Eosan before the tieback? And when are you expecting to connect to BMT ten h? Hello, Rodrigo. I will try to divide growth into organic and inorganic growth as you did it yourself. Organic growth, what's the easiest to speak about? It will happen in the following way. We are now implementing the tie back project between Polvo and Tubarao Martello, and this should be completed by mid twenty twenty one. And together with this project, we will start operating TBMT 10 well. With TBMT 10, we can expect perhaps something a little better than what we had in TBMT 4 that we started producing recently. And why do we think it's going to be better? TBMT 10 is in a totally different reservoir. TBMT 4 is in a reservoir where we already had two producing wells, and that's why TBMT 10 well will be more productive. So these two things, both the tieback project and Tubarao Martialu number 10, these two projects will happen by mid-twenty twenty one. In the 2021, we still have to make a decision whether we will be drilling an additional well in the Eosin Reservoir at Polvo Field or whether we will move straight to Friday field. But this is a decision that remains to be made. In the coming months, we should make a decision. There are pros and cons. Volvo, for example, requires little investment, and you invest little and fast. But you have daily production of oil and reserves, which are well lower than what we have at Friday. So we haven't made a decision yet. We will be deciding later on perhaps along first quarter of next year. So in the next four months, I should say. But this tieback project plus TBMT 10 will happen now. And then in the second half of next year, we should have either Pauvo drilling another well or two new wells and then Friday. And our our thinking is that we'll start working on Friday field in the second half of next year. At the most in the end of next year. So this is our idea about organic growth. Now inorganic growth is a little harder because this is related to m and a project, and we cannot give you too much color on that given the confidentiality nature of the business. What I can tell you though is that we have some possibilities in our pipeline that we expect will be successful at least in some of them in the coming months. But again, the company is rather diversified and rich. We are looking at some possible deals, and it would be strange for PetroRio to be able to grow inorganically in the next six to eight months. Next question from mister Bruce Barbosa with North Research. Hello, me again. Well, since people are following the US elections, let me ask more questions. How do you see the market for the issuance of that bond that you considered in the past? And can you comment on the demand for capital in case of a possible acquisition? What are your plans for funding? Of course. Regarding the bond, we went to the market. The conditions we found were not ideal. They were not the conditions we would have liked. And since we were thinking about refinancing a debt, we thought it would not be worth while getting a much more expensive debt just because we would have a safer rollout. And that's why we didn't go through with the bond issuance. It was a matter of cost. Now what is important is that now the company is a 100% ready to issue. If we want to issue a bond twenty days from now, if we think that this makes sense, that there's a demand, that the market changed or whatever, we can we can update the prospectus and very quickly, perhaps in a matter of twenty days. And we can access the market again, so the company is a 100% ready to do it in terms of governance, in terms of auditing, and everything. We've we've gone through all of the stages. So we are 100% prepared. Regarding our capital structure, we always emphasize this. Our main indicator is net debt over EBITDA ratio. It's at 1.9. We had a moment when we were higher than 2.5, but we don't want to be at greater than 2.5 or 2.75. I mean, it might happen if we make acquisition. So of course, you take on debt and you don't have the corresponding EBITDA. But these are technical things. But if we look at our business, we never want to have our net debt over EBITDA ratio greater than 2.5 or 2.7. So our capital structure will fit the size of the opportunity. If it's something bigger, of course, in order to maintain this kind of debt, we'll have to go to the equity market, which is another market that we are ready to access. We have our income statements revised, revisited for 2018, 2019 and even the 2017 balance sheet and income state. It all fits the initial '18 balance sheet. So it's all aligned. It's all sorted out. And we are ready to go one way or the other way. It really depends on a timing of the market, if we think it makes sense and depending on the size of the opportunity. If it's a smaller deal, perhaps we can fund it with the company's cash flow plus a little debt that we can take on. If it's a bigger deal, then we'll think about going to accessing the equity market. It's understood, and it's very clear. Thank you very much. Next question from the web. Mister Rodrigo Siquera, what is the strategy in Manati? Can you divest just like the other concessionaire did recently, or are we thinking about buying Petrobras' working interest? Rodrigo, Manatee Field is an asset that perhaps will change its operation. Instead of extracting gas, it can become a gas storage operation. In that context, of course, we consider we have looked in the past at the possibility of acquiring more stake of Manati on always thinking about reducing costs, optimizing expenses, etcetera. But given this new possible modality, we have been thinking about the possibility of selling our stake of the asset at similar conditions, and this would make sense for the company. And this is something we've been discussing at the board of directors, but I would say that today, our trend would be to sell the asset if possible rather than buying more interest of the asset. Our next question comes from the web of mister Rodrigo Sequeira. Estimated CapEx for 2021 is around $340,000,000 which would go for the tiebacks connection of TB and T-10H, three wells in Polvo and three wells in Frade. Is that correct? Hello, Rodrigo. This is Francois Mar speaking. Let me try to clarify that. What we have today approved and certain in terms of next year's CapEx is the tieback between the fields. This is already happening, and that would cost $42,000,000. And completion in connection of TBMT 10, another 23,000,000. So that is already happening. The other projects, the Iocin reservoir wells at Povo and the revitalization, considering three initial wells to be drilled at Friday. This is still to be defined and we will decide on the sequence of these projects. So that is the current scenario. The next question is from Mr. Victor Schmidt of Fort Sale Capital. Why is it that the new TBMT well started producing 10,000 barrels a day, but then dropped to 7,000 barrels daily and then increased again to 8,000? What can we expect looking forward? Hello. Thank you for the question. It's a possibility for me to clarify. You see, TBMT 10, standard operating, adding about 3,000 barrels of oil a day and TBMT as a whole achieved 10,000 barrels. But then we started having a natural decline process. This reservoir was already producing via two wells. So the first the well started producing more, but then it follows the decline of the other two wells that share the reservoir. It's currently at around 9,000 or 9,200 barrels, and it should remain at that level for a while. This is what to be expected until we have TBNT 10 producing, and that is a new reservoir, and that should increase the production a little more. And this should happen by the end of the 2021 or beginning of the second half of next year Our next question from the web, Mr. Rafael Hagazi with North Research. Hello. Despite a reduction in lifting cost, cost of goods sold grew more than the revenue in the quarter. Could you comment on that? More specifically, on the acquisition of oil for resale and the reduction in the royalties line item even with an increased production. Thank you. Rafael, regarding the lifting cost, it is exactly that slide that I explained on Tubarao Martello. When we acquired the field according to the contract, part of the economics of the field came with the chartering of the FPSO from Domo in this quarter. Part of the economics came from that and not from the low cost because when you look at the cost of goods sold, COGS at Tubarao Martello would be taking into account the chartering of the FPSO. So in the COGS, you have the chartering, increasing the COGS, negative value. And then later, you have positive values, the rental of the FPSO. So it's just accounting, and we have to follow the contract. Since this was the agreement we had with Domo in the past, this is what we did. But the moment that we no longer have the FPSO chartered, the FPSO will no longer be chartered. It belongs to the company. It belongs to PetroRio now. So we are going to see an improvement in the margin Tubarao Martellus. So this is the difference. It is what I tried to explain on that slide. I think it was number 13 or 14. Not sure. It it was all because of the way in which we accounted for Tobaran Martello. As for the royalties, we paid 10% royalties on everything with the exception of Manati, which is 7.5% with the exception of Polvo. This last well that was drilled in the Eocene, we speak a lot about it. It's it's already producing 3,000 barrels. For that one, we pay 5 percent royalties. And it is this mix. Well, 5% of Volvo, 7.5% from Anativ. This gives us the average royalties payment that you could see in our release. Our next question comes from Mr. Bruce Barbosa with North Research. Hello again. I have a quick question regarding FRADIField. In the release, you wrote that we can expect approval in the coming months. Are we waiting for CADI to approve this. Can we expect this for the fourth quarter, or would this be for 2021? And with Prade starting production, we're going to have another strong reduction in lifting costs. Right? Again, this is Emiliano. No. We don't need Cadi's approval for that. In this case, we are waiting authorization and approval by ANP. Both A and P approvals, including the approval of the transfer of rights, has happened. And the cardi approval has happened already before. We are just waiting for the analysis of the guarantee for abandonment, which is a fundamental phase for the closing. We estimate this. We expect We add this asset, we should have more reduction in our lifting cost. When we look at Frade in the Tobarom Martello slash Bovo, Frade has a more competitive lifting cost because we don't have a chartered FPSO. So Frade should bring another little reduction in the lifting cost. So we're to have this additional reduction. And another reduction in lifting cost should happen in mid twenty twenty one when we increase production with TBMT number 10 and when we stop leasing the FPSO at Povu. Are you giving a guidance on the lifting cost considering TBMT plus the last part of Friday? No. But you can do it easily. When we get to mid twenty twenty one, our lifting cost in absolute terms should be between a little under $70,000,000 a year for Friday and a little under 70,000,140 million dollars annually for the whole operation, and then you divide that by the number of barrels of oil. And I will give you a number. Today, we're running a 100% of Friday at 63. In the Tebarao Martello plus Pulvo cluster, We're running at a lifting cost of a $120,000,000. I understood. Thank you very much. Thank you. We are now closing the question and answer session. I will turn the floor to mister Roberto Montero to proceed with his closing statements. Please go ahead, sir. I'd like to thank all of you for participating in another conference call. Thank you very much for your support to the company. My special thanks go again to Pedro Rio's employees. We see that many of them are participating in this conference call. Most of our employees are shareholders of the company. So thank you very much to all of you, and hope to see you again in three months. That does conclude PetroHero's conference call for today. Thank you very much for your participation, and have a good day.