Good morning, everyone. Welcome to the conference call for AES Brasil, referring to the second quarter of 2024. The presentation will be conducted by Rogério Pereira Jorge, CEO, and the CFO, José Simão. At the end, they will be available to answer any questions you may have. We highlighted the simultaneous translation is available at the platform. Please click on the interpretation button at the bottom of your screen and choose your preferred language. This conference is being recorded and will be available at the IR website of the company, www.ri.aesbrasil.com.br, as well as the presentation. We inform that our participants will be in listen-only mode during the presentation. Later, we will start a Q&A session when further instructions will be given. Before proceeding, I would like to reinforce that our prospective statements made are based on the information currently available to the company. Such statements may include risks and uncertainties, as they refer to future events and therefore depend on circumstances which may or may not occur. Investors, analysts, and journalists should take into account that events related to the macroeconomic environment, to the industry, and other factors may cause the company's results to differ materially from those expressed in such forward-looking statements. We'll now start the presentation, and I turn the floor over to Rogério Jorge. Mr. Jorge, you may continue. [Foreign language] Good morning, everyone. Welcome to the Conference Call for the Second Quarter of 2024 of AES Brasil. It's a pleasure to be here along with our CFO, José Simão, who will share the presentation with me. At the end, we'll have the other officers of the company supporting us in the Q&A session. Starting on slide 2, I bring the main highlights that have marked the second quarter of the year. We start highlighting that the Cajuína 2, the wind complex with 370 MW of capacity, is fully energized and started in July the test of the three wind turbines that remained. I would like to remind you that there are 65 in total in this stage. We expect it to be fully operational by the end of September. As for AGV VII with 33 MW capacity, we are pleased to announce the completion of the work at the end of July and beginning of its commercial operation. It has been already dispatched by ANEEL, and the COD has been advanced by one month. I'll address this topic later. In the operational front, we continue to focus on the execution of our strategy to recover the availability of assets acquired in M&A. The result was an increase in the average availability of all assets, 4 percentage points better when compared to the second, the same quarter of 2023. Another highlight is the contracts of our portfolio that have average prices at excellent levels. We increased their contracts with the sale of another 100 MW average in PPA of conventional energy, with the average price between BRL 185-BRL 206 per MWh for 2024 to 2030. In the financial front, I would like to highlight the net margin, net revenue minus costs with energy, which amounted to BRL 558 million in the second quarter of 2024, an 8% increase regarding the same period of 2023. In addition, the adjusted EBITDA for non-recurring periods was BRL 373 million. Simão will bring more details about that in the financial presentation. Now, on slide four, we had the evolution of the works. Cajuína has a total of 684 MW of installed capacity in Rio Grande do Norte and is divided in two phases with long-term PPAs. Cajuína 1, 314 MW, fully operational since the last quarter of 2023, and Cajuína 2, 370 MW of installed capacity. Of these 684 MW, 610 are in operation and have contributed with BRL 38 million in the EBITDA and 254 GW h of energy in the second quarter. Cajuína 2, 99% of the work has been completed versus 96% in the first quarter, including the commercial operation of 52 out of 65 wind turbines, which total 296 MW of operational capacity since the end of 2023. Such turbines already in operation are connected to Caju substation that also connects our turbines of Cajuína 1. The other 13 turbines, equivalent to 74 MW, are connected to another substation named Castanha, that was energized in June 2023. With that, in July, we start the tests of these new machines, and we expect it to be fully completed until the end of September. Phase two of Cajuína has an operation and maintenance agreement that is complete, also known as FSA, with the equipment supplier, ensuring minimum availability of 98% for the following years. Whatever is below that level will be reimbursed by the supplier. Speaking of Tucano, it is located in Bahia and has 322 MW of installed capacity, fully contracted in PPAs of long term, with an average length of 17 years and an energy supply to Unipar and Anglo American. As we already discussed in other calls, we completed the construction of this complex, and in July, we solved all the challenges faced in the commissioning. With that, the retrofit of the 2023 machine spending was completed. As the turbines are accepted by the construction team of AES, they go under FSA agreement with Siemens Gamesa, with a 5-year term and extendable for another 5 years. Today, 50 wind turbines have been accepted and are in substantial completion issued. The other 2 wind turbines are expected to have the substantial completion issued in August. This agreement with Siemens Gamesa establishes a minimum availability for machines in operation of 97% for the first year, 98% for the following years. Whatever is below that level will be reimbursed by the supplier. Finally, I would like to highlight the commitment of our team to ensure that this equipment operates in total compliance with our excellent standards, ensuring efficiency and reliability of Tucano in the future. Our last highlight is AGV 7 with 33 MW of installed capacity or 8 MW average of generation at P50. It was built close to Boa Hora and Água Vermelha solar complexes in the state of São Paulo. Until the end of July, we had important advancements in the construction. It was completed within budget. On July 30, the operational dispatch was issued by ANEEL, and the complex has a COD advanced by one month. With the operational, when it starts up, AES has completed its obligation of expansion with the state of São Paulo. Now, on slide 6, I present the evolution of a turnaround of wind parks that acquired since 2021 in the M&A. Our strategy is based on acquiring wind complexes with operational challenges. When we integrate them to our portfolio, we use our experience and dedicate our best efforts to recover them in the first years. Our goal is to restore our expected levels of availability of generation. The slide shows the availability per wind complex since the acquisition of each one of them. In Ventos, acquired in December 2020, we improved 8 percentage points the availability through years. In this scenario, the end of contract of O&M of two of three complexes that include Ventos, Miassaba and Rei dos Ventos 3, with the completion of this workforce that's now part of AES in the second quarter of 2024. Mandacaru and Salinas acquired from Cubico in April 2021. We recovered 8 percentage points in availability, reaching 88% in the quarter. Ventos do Araripe acquired from Cubico in December 2022. In the last quarter, the availability was influenced by the unavailability of two out of the two transformers of the complex, which limited maximum availability by 55%. However, during the second quarter, the operations team completed the repair, and the transformer was re-energized on July 17. In Caetés, acquired from Cubico in December 2022, average availability reached 94% in the second quarter of 2024, 9 percentage points higher than the average of 2022. In June, the average availability was 96.4%. We do not consider Alto Sertão because it has been with us for longer, but it's worth highlighting its average availability higher than 97% in the second quarter. It's also important to highlight that this evolution reflects the anticipation of some maintenance scheduled originally for the second quarter, second half of this year, and this resulted in a greater availability of assets, allowing us to make the most of favorable wind forecasts for the second and third and fourth quarter, ensuring continuous operation of the complexes. On slide 7, I'll talk about the performance of our wind plants in 2024. Looking at the wind assets on a consolidated way, including what I mentioned before, I would like to highlight again the effect of our efforts to improve performance in the wind complexes. Looking at the quarter, as well as year to date, we see an important recovery of 4 percentage points, going from an average availability of 88% to 93% in the quarter and 94% year to date. After a difficult period regarding wind speed from January to April 2024, especially in the northeast when our wind farms are located, the second quarter showed a recovery in. As of May, the average speed of wind reached 7.3 meters per second in the second quarter, the same average recorded in the second quarter of 2023. When we look at the first half of the year, we still see the impacts brought by the bad wind season of the first quarter. Until June, the average speed was lower than 7 meters per second, 6% lower than last year. The generation in the quarter was 33% higher than in the second quarter of 2023 and 21% higher in the first half. In this chart, you can see that the highest responsible for this growth were Tucano and Cajuína, whose constructions are being completed, accounting for more than 1/3 of the generation recorded. Now, looking differently from the recovery of wind and availability that is higher, the wind performance of our plants was influenced by curtailment, especially in Cajuína and Alto Sertão 2 in Bahia, Cajuína and Rio Grande do Norte. When ONS determines such curtailments, the plants cannot generate energy, even when they are available and there is wind. This may happen to several factors, mainly limitations in the transmission network. According to ONS data, curtailment totaled 92 GWh in the quarter, five times higher than in the second quarter of last year, and 109 GWh in the year to date, more than four times the volume in the same period of 2023. For Cajuína, our team estimates a curtailment that has actually been 2.5 times higher than the volume officially reported by ONS because the measurement towers of the complex had a period of unavailability for maintenance and construction. Even with the available turbines, there was no record of a wind speed in the operating system. With that, all the generation was not accounted for in official data. What I mean is that actually AES generation could have been much higher than we are showing here in this slide if it wasn't for this effect. In a scenario with no curtailment, only using ONS data, the wind generation from AES Brasil would have grown 39% on a quarterly base and 21% year to date. For the solution of these problems is the operations of transmissions that are now being completed, and that will improve the transfer limits of energy between the submarkets on northeast and southeast, which is the area that has the most of the load. According to data available in the ANEEL website, some of these constructions in Bahia, Sergipe, and Ceará will be operational in the beginning of August. Three transmission lines of 500 kV Porto Sergipe Olindina, Olindina Sapeaçu, Pacatuba, Jaguaruana, in addition to Pacatuba substation, where this transmission line Fortaleza 2 Pecém II. Ending this slide, I once again reaffirm my priority to continue to work in the recovery and efficiency of the plants, in addition to highlight the active participation of the company in regulatory discussions regarding the refund of all curtailment. Moving to slide 8, I would like to highlight the operational excellence of our solar complexes that for the third consecutive quarter have reached 100% of availability in the quarter and in the half of 2024. Irradiance increased 3% in the quarter and 7% year to date, once the region where they are located in the state of São Paulo was less affected by rainy days and cloudy days. On the other hand, generation was influenced by the reduction of the modules. At this time of the year, dust is very high due to the dry weather in the region, which increases dust and particles deposited on solar panels. To solve that, we have recently acquired 2 new cleaning equipment that are 5 times more efficient than the current process, optimizing maintenance of the modules and generation efficiency. Because they are located in the state of São Paulo, solar complexes of AES Brasil benefit from a high demand and constant demand for energy, which reflects industrialization and the number of inhabitants in the region. Also, we have a robust network infrastructure. Considering all that, the likelihood of a curtailment in our solar plants is much lower than in those located in other regions. The following slide number 9 shows the hydro scenario and the performance of hydro power plants of the company. Because we are part of MRE, the revenue from such plants is connected to the strategy of allocation of energy of the plants, both for the company as well as for other power plants in the country as a whole. AES Brasil plants account for 2% of the total physical guarantee. In 2024, we didn't follow the seasonal guidelines of MRE for all the plants as we did lately. We allocated Água Vermelha, accounting for 58% of our capacity, with more energy in the first half of the year. The remaining of our water portfolio followed the seasonality. It's important to highlight that both the physical guarantee allocated by AES, as well as the total volume by the MRE, was higher in the first half of 2024 as compared to the first half of 2023. The upper part of the slide shows a map of what the water scenario was in the first half of the year. Looking back, we faced a severe water crisis in 2021, followed by two years of rainfall above average and record highs reservoir levels in 2022 and 2023. More recently, the last rainy season between October 2023 and April 2024 was once again challenging. 74% of MLT in the first half of the year, one of the worst affluences of all years. The last wet period with low rainfall caused a decrease in the reservoir levels exactly when we expected them to recover. Although reservoirs are currently at more comfortable levels than in 2021, it's important to highlight that this scenario cannot be sustained for many levels of rainfall below average. We also see an increase in load every year above GDP growth. According to ONS, the average net load, excluding MMGD, was 75 MW average in the quarter and 75 year to date, also above the levels in 2023. We can say that this increase is due to the resumption of economic activity and also high temperatures. As a result, we see a GSF of 100% in the quarter and 94% year to date, while the average spot price remained at the bottom of January and May, going up to BRL 66 in June. Looking at the charts, we see a reduction in the volume generated in both periods. This is a consequence of the more conservative posture of ONS when compared to preservation of the reservoirs. The operator dispatched less water plants than last year, both in the first and second quarters. The only indicator about management of AES is availability, although we are subject to their authorization. In the second quarter of 2024, we had an average availability of 96%, 4 percentage points above second quarter of 2023. In the year, 3 percentage points above. We continued with our energy management strategy with a competent team that's always attentive to the changes in the industry. Before turning the floor over to Simão to talk about the financial aspects, I'll finish the operational part of our presentation showing the evolution of the contract levels in our portfolio. The green charts show the contracts of water plants, light green, and wind and solar in dark green. Blue bars show the volumes with no contracts in conventional energy and incentivized energy. Our conventional energy is fully contracted for this year in 2025, and just a small amount of incentivized energy remains that is a result of triangulation of energy between AES Operações and complex of Tucano and Cajuína. This enables the company to benefit from the spread of incentivized energy, even in cases when wind customers have purchased conventional energy. In addition, we leave approximately 15% of water energy without contracts every year as a way to protect our portfolio against GSF. This GSF hedge is adjusted every day according to the evolution of market expectations. As you may see, once the portfolio is well equalized for the short term, the focus of our team is 2-5 years forward. In the second quarter, we sold more than 100 MW average in PPAs, which increased the total contract levels in the period, with a highlight of water contracts between 2026 and 2028. In 2026, an increase of 12 percentage points. In 2027, 14 percentage points. In 2028, 15 percentage points. As for the average sales price, we have contracts between BRL 185 per MWh in 2024, with market prices close to regulatory bottom levels, and going to BRL 206 per MWh in December 2026. It's also important to highlight that the prices regulated and free are updated for inflation every year. Now I turn the floor to Simão, who will talk about the financial aspects, and then I'll come back for my final remarks in the Q&A session. Thank you. Thank you, Rogério. Good morning, everyone. I'll start with the financial analysis. On slide 12, we will see the net operating margin, which is a net revenue minus costs with purchase of energy and social charges. In 2024, AES Brasil had a net margin of BRL 558 million, which is an 8% increase regarding the second quarter. Year to date, it was BRL 1.1 billion, which is in line with the first half of 2023, a 1% increase in the semester comparison. According to the bridge order, I'll go through the sources. Water comes with an absolute value of BRL 289 million. BRL 289 million are from water, but in the variation of second quarter 2023 and 2024, water had a decrease of BRL 13 million in the margin, which is basically a consequence of a non-recurring revenue reported in the second quarter of 2023, a volume of exports of EVT that was an event of 2023 and happened in 2024. Now, the wind energy, we have an increase of BRL 56 million in the quarter, which in absolute terms leads to a contribution of wind of BRL 228 million in the second quarter. There are some factors that explain that. First, the phased entry of Tucano and Cajuína, which are newer complexes, the greenfields we deliver. Tucano and Cajuína contributed BRL 63 million in the quarter, BRL 115 million margin in the quarter in the semester. But there are also positive effects on our asset base that are already operational, called turnaround, 4 percentage points in availability, which is reported every quarter, and we have based our investment policy to recover availability of assets acquired. And we see that every quarter, their contribution is more positive. Something that brings down the positive contribution of wind is the curtailment. We see that in the second quarter, 92 GWh, according to ONS, of curtailment versus 18 GWh reported in the second quarter of 2023. Out of the 92, according to ONS, now for the second quarter of 2024, 35 GWh, an important amount, is specifically in Cajuína. As Rogério mentioned, this view of ONS doesn't match our internal estimates because this curtailment in Cajuína was around 2.5 times higher than reported in the quarter by ONS for Cajuína. So this is an important factor for Cajuína performance and its operational margin. Solar plants contributed negatively with BRL 1 million, especially because there was a 4.8 reduction in the volume of energy generated, which is a consequence of 30-year panels. But the operations team is addressing that, changing the process with more effective tools for cleaning plates. Now, on slide 13, we talk about the OpEx in the period, which are operational costs and SG&A, which added up BRL 185 million in the second quarter of 2024, BRL 357 million in the first half of 2024. Both cases I'm adjusting for non-recurring items that applied in each period. I'll go through the bridge to explain them in more simple terms. The first element is inflation. So we see an increase of BRL 7 million in comparison quarter-on-quarter, BRL 16 million on a semester basis. Basically, the application of our IPCA in our cost base, there is an accumulated IPCA in 12 months of 4.23%. When we apply that, it goes to BRL 7 million in increase of costs in the company quarter-on-quarter. An important point is our cost is indexed by inflation as well as our revenues. So it's a timely issue. In January every year, we have all agreements adjusted for inflation. The second pillar in the variation of OpEx is growth. We see an increase of BRL 7 million in comparison of quarters. In semester comparisons, BRL 14 million, and there are costs that come with operational assets. The phased startup of Tucano and Cajuína increased revenue, but there is also contribution to the cost base. That is BRL 7 million in the quarter, BRL 14 million in the semester. The recurring cost that increases the cost base of the company, ex-growth and ex-inflation, is only BRL 3 million reais reported here, and it's specifically related to insurance. That insurance premium increased, and there was a BRL 3 million contribution of OpEx in 2024. There's a simple metric to work on efficiency because in the margin, how our operational costs behave in the margin. So we went to second quarter 2023, 4.1 gig in operations, and we included 1 gig in operations to Tucano and Cajuína, and now basically have 5.1 gig in operations. When you divide OpEx by the installed operational capacity, there is a reduction of 9% in this multiple, which shows something that we comment frequently, that our discipline in cost management is translated by a simple multiple that shows that we have a healthy cost base. Slide 14, we see the evolution of adjusted EBITDA, net adjusted net income on a quarterly and semester basis. We reported BRL 373 million of adjusted EBITDA. When the increase is 7% in the semester, we reach BRL 741 million of adjusted EBITDA. Now, the change between periods. In the water source, since there is no non-recurring revenue reported in 2023, with the exports of EVT of 10.11 million, there was a reduction in the contribution of EBITDA of BRL 15 million in the quarter. Wind complexes is an increase of BRL 46 million in the EBITDA contribution due to some factors. The first of them is the entry in operation of more wind turbines of Tucano and Cajuína in the quarter comparison to assets generated BRL 24 million more. But the wind speed went back to average in May and June, differently from April. So May, June, we go back to amounts close to the second quarter of 2023, and there are more assets available. So now they're going through the turnaround process, and there are 4 percentage points increase in availability. What brought down the negative contribution is all the offsets the positive contributions is the curtailment seen mainly in Cajuína and Ventos, that are in Rio Grande do Norte. There was a reduction of 6.4% in generation due to that. So it had a significant result in the quarterly EBITDA. Now, talking about the adjusted net income, they're reporting a loss of BRL 104 million, which year to date is BRL 180 million. In addition to the facts that impact the EBITDA, I'll talk about the financial result and depreciation amortization. BRL 78 million in financial revenue in the second quarter and BRL 155 million in financial result revenue year to date, which is a reduction of 24 in the quarter. And that is a reflex of a lower cash balance, BRL 2.8 billion in June 2024, and used to have BRL 3.9 billion in June 2023, and lower CDI. Now, the year to date CDI is 10.5% the second quarter 2024 against 13.5%. The financial expenses, we added BRL 343 million, which year to date are BRL 656 million, which when compared in the quarter is an increase in expense of 21% in the quarter and 50% year to date. The higher financial expenses have to do with the interest that are transferred to fixed assets that result from the end of the construction works in Tucano and Cajuína. There was a reduction of 65%, and it offsets financial expenses. There was also an increase in depreciation amortization, which is part of the business. As we grow our operational portfolio, we also have a higher depreciation basis that has a negative impact on the adjusted net income of the company. On slide 15, we update the consolidated cash flow balances in June, March, 2024. We ended June BRL 2.8 billion, which is BRL 300 million higher than the balance in 2024. Now, go through each element in the bridge. We go from operational cash BRL 360 million with the positive contribution of all the assets, including wind turbines, as Tucano and Cajuína become operational, and the turnaround, which is pure cash generation between funding and amortizations that have a positive cash balance of BRL 430 million. These payments of new loans are not new loans. These are payments we are making for changing short-term debts of our SPEs of Cajuína, and we are changing the short-term debts for long-term debts. For example, with Microsoft, BRL 900 million, which prepaid an important part of the bridge that was under AES Brasil. We had a cash reduction of BRL 45 million, payment of dividends regarding the year of 2023. They were approved in the general meetings in April. Payment flow with partners, BRL 47 million, is to payments to minority interest of Guaimbê. We invested BRL 182 million in Cajuína, Cajuína 2, and finishing AGV 7 in the state of São Paulo. We have a cash balance of BRL 2.8 billion, and we explain what these funds are being used for. In light blue, we have BRL 521 million of this cash balance, which is restricted cash in some SPEs that we expect to complete or due to the shareholders' agreements. This is a restricted cash. We have BRL 589 million that are in the reserve account for that service. BRL 707 million is cash that will be used for repayments in 2024, and we have expected investment of BRL 388 million according up until the end of the year. On slide 16, we show our debt structure. In the second half of this year, AES Brasil ended with a net debt of BRL 9.4 million compared to with an increase of BRL 100 million reais. So the net debt is pretty much in line with the quarters. We also have in line the consolidated leverage of AES Brasil, 5.7x versus 5.6x. AES Brasil is a holding that has no covenant restrictions. Its debts are not restricted in terms of debt level. AES Operações is different. AES Operações, there is a cap for debt. We can reach a leverage of 5.5x net debt over EBITDA. We are around 3, 3.16. So there's a lot of room here as for the maximum cap. So these are the debts under AES Operações. In addition to those already mentioned, we have financially subsidized loans with BNB and FNE, not with FDNE. We have BRL 153 million out of BRL 68 million have been disbursed in July, and the rest is expected for the next weeks. They will be used for the BRF cluster of Cajuína that are being served by short-term bridge loans. And as long as the funds come to, we will prepay them. The same applies to Veleiros, which is a cluster of Cajuína that is used for Unipar. There are BRL 220 million approved, contracted with BNB, and we expect disbursement shortly next week, and we'll be able to prepay the bridge loans that are used for Veleiros. With that, the average consolidated term, there used to be 4.2 years. Today, with that counting this, is 5.2-5.1 years, and it will be raised to 6 years. And the costs from 1.30-1.1 per year will be reduced, which generates a lot of value with a better indexation of debt indicators. Now, moving from CDI, migrating to IPCA, which has a natural hedge with our revenues. This ends the financial, and I turn the floor over to Rogério. Now, moving on to the last slide of the presentation, we show the evolution of conditions precedent for the completion of the business combination with Auren Energia, announced with the material fact on May 15, which will give rise to a single listed company in the B3 market. As announced, to complete this operation, we need to comply with some conditions precedent. We show the status of each one of them. Firstly, regarding CADE, we had the final approval on July 1 without restrictions, as reported in a communication to the market on July 2. As per the request of the agreement of ANEEL, it's been analyzed by them, and we expect that the technical note approving the transaction is published until the end of August. Another condition precedent regarding the substantial completion of wind turbines, of 15 turbines of Tucano complex. As already mentioned, 50 wind turbines have been accepted by our team until July, and all these turbines will reach substantial completion in August. Since we're changing the controlling shareholders' control, we need the approval of waivers of third parties and creditors. Waivers of third parties include some suppliers, credit customers, and insurance companies. In July, we had more than 70% of these waivers, and we expect the others to be completed by the end of August. As for creditors, we engaged 2 banks to help us, one for development banks and another one with market banks. Negotiations are in progress with the development banks, and we're working with Auren to call the venture holders' meeting. We expect this to be completed in the beginning of October. We created a company called ARN Holding Energia S.A. with a capital fully held by Auren. It will include all the shares of AES Brasil that will become its fully owned subsidiary. In this incorporation of shares, ARN will issue new common and preferred shares to be delivered to shareholders of AES Brasil. For preferred shares, they will be redeemed mandatorily because they refer to the amount in current in currency that our shareholders may receive according to the option period that will be open for shareholders of AES Brasil to choose from. Among those shown in the lower part of the slide, after all conditions precedent are fulfilled, as well as the shareholder meetings of AES Brasil and our for approval. Following that, ARN will be incorporated into Auren and ARN will no longer exist, and AES Brasil will be fully owned by Auren. In replacement of the common shares issued by ARN that have received due to the inclusion of shares issued by ARN Brasil, shareholders will receive common shares issued by Auren, believing that this has corporate operation and financial benefits and a solid portfolio of generation and sale of energy to meet the growing demand of renewable energy in Brazil. We expect the closing of the transaction to happen in October, and we will certainly keep the shareholders and the market informed of the next steps. With this, we reach the end of our presentation. We can now start the Q&A session. Thank you very much for your participation. [Foreign language]. Thank you. We will now start the Q&A session. Should you wish to ask a question, please click on the Q&A icon that's at the lower part of your screen and ask your question. If you want to use the microphone, click on "Raise Hand." First question comes from Guilherme Lima from Santander. Your mic is open, Guilherme. [Foreign language]. Good morning, everyone. Thank you for the question. We've seen in the quarter the still high level of curtailment for wind. [Foreign language]. This 6.4% of curtailment level that you mentioned in the release, when compared to the potential wind generation, does that consider official data from ONS or your data that you consider as having a higher curtailment level? And if it considers your data and not ONS data, does it make sense to think about something of 15% curtailment, or do we need to adjust that with the potential generation with your data? And also, could you comment if it makes sense for us to think about the same level of curtailment for the rest of the year, thinking that Cajuína would be fully operational in the second half of this year? And what have you observed in terms of curtailment in July? And what would be the process to solve this change or this divergence of curtailment levels with ONS? Thank you. Estão me ouvindo agora? Pessoal, I'm sorry, the microphone was closed, I guess. So if you could repeat the answer. So 15% of curtailment, did you hear? No, we didn't hear anything. We couldn't hear anything. Did you hear about the 15%? No. We didn't hear your answer at all. Oh, I'm sorry. I think we had some problem in the platform. Okay, so starting in the first block, as for the source of information, the data that we brought are the data from ONS. We brought that to allow the market to compare us with the other players from a single source. According to our controls, this volume was much higher, 2.5 times higher than the official source of ONS. There are several reasons for them. We know all of them very well, and we're working with the operator. But the fact is that our data shows 2.5 times more curtailments than the official data that would lead us to 15%, as you mentioned. Now, as for the third part of your question regarding our prospective view, outlook into the future, whether that is expected to increase or not, there are positive and negative factors. The positive ones are there are several transmission works that are in the final stages, several both increase and construction of new lines. This will help a lot to increase the capacity in the northeast and southeast, north, also with some local restrictions that will increase the operator to increase the number of energy that flows without having any risk to the system. So that reduces the curtailment due to excessive generation and other factors. On the other hand, there is an increase and continuous increase in distributed generation and commissioning of renewable energy, both solar and wind. So the supply is increasing, and the distributed generation decreases the net load of the system, especially during sun hours. So it's harder to predict the behavior of the load because there's more distributed generation available, and the temperature effects, especially higher temperatures, increase load in the northeast and reduce the generation of curtailment, and there is distributed generation on the other hand. So it's hard to say whether the trend will go up or down. Finally, you asked about the refund. There is a lawsuit in court filed by several associations. We are a party in several of them. The main one had a preliminary decision that is now being appealed, was unfavorable for the generators, and now there is an appeal, and we expect to revert it and to have the preliminary decision, the injunction that allows us to receive that that was already recognized. But this is a discussion that will take a long time. In our point of view, it will take a lot of time, a lot of funds of the industry as a whole, especially generators that have a large renewable portfolio in the northeast. How would be the process to solve this difference of curtailment levels considering ONS levels in yours? Oh, well, there are several factors, Guilherme. ONS, national system operator, has all the routines defined to define what they account for, and there are several rules we're working on with them to increase the feasibility of data delivery. For example, something that's very sensitive with them, data of wind, measurements every six minutes. So if it's not available in six minutes, it's not considered. There are more than 20 items on the list that we are working on with them that will help to refine the assessment of curtailment. Most of them are related to operational procedures in terms of what they expect, what we ask for, what we do, and how to prove it. Okay, thank you. I would like to remind you that to ask a question, please click on the Q&A icon at the bottom of your screen and type your question. If you want to use the microphone, click on "Raise Hand." Please wait while we collect the question. Pergunta do Victor Cunha, Itaú BBA. Esse trimestre, nós vimos Victor Cunha from Itaú BBA. We had ANS above 56 meters for MWh. What was the position of the company for liquidity of longer term and at what price in terms of movements in the energy balance? Is ARN participating in helping to make decisions? Good morning, Vítor. This is Rogério speaking. Answering your question. What we see is a resumption of liquidity. On the purchase side, customers are interested in purchasing, especially the prices are lower now, but it's like I say, when prices are low, generator doesn't sell, and when it goes up too much, people don't buy. So there's a good average, which is 140 for conventional energy. When it goes up, it changes the market. So the prices now started to reach this range in 2025 onward for several regions. We are in a very dry year. It has everything to be one of the driest years of history. There is an increase in the load, which puts pressure on prices, and there are several changes in the pricing parameters that will put a lot of pressure and increase volatility due to the increase of risk aversion. And it's become effective now to be valid up until as of 2025, but the market is already including that in prices and will increase volatility either up or down, and that scares customers because most of them are advised by consultants. So now customers start to see an increase in prices and more volatility. They want to buy for two or three years in advance, but we take this opportunity to have an important energy volume, a 100 average, and to capture prices that's within the efficiency range for the market. Our next question comes from Mario or Beto, from Safra. Your mic is open. Senhor Mário, seu microfone está. Mr. Mário, your mic is open. You may ask your question. [Foreign language]. The next question comes from Victor Cunha from Itaú BBA. Go ahead, [Foreign language]. Good morning, everyone. Just to follow up on my previous question. There are movements in the energy balance. ARN has been participating in the decision-making, or are the decisions only made by AS in this quarter? Thank you. Thank you, Vítor. No. The portfolios remain managed by the respective companies until the closing of the deal. So these decisions are being made by AS according to our vision of the market and based on the best risk-return comparison, as we have always did before the combination. I mean, up until the closing date, we make our decisions based on the best return possible for the current portfolio. Thank you very much, says Vítor. The Q&A session has now ended. I would like to turn the floor over to Rogério Jorge for his final remarks. Well, I thank you all that had a chance to join our conference call, and I hope to see you soon again. Thank you for attending. Have a great Friday. The earnings conference call of AES Brasil has now ended. We thank you all for attending. Have a great afternoon.