Good afternoon, ladies and gentlemen, and welcome to Enel Chile Third Quarter and nine months 2022 Results Conference Call. My name is Victor, and I'll be your operator for today. At this time, all participants are on a listen-only mode. After the speaker's presentation, there will be a question and answer session. To ask a question during the session, you will need to press star one one on your telephone. During this conference call, we may make statements that constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Such forward-looking statements reflect only our current expectations, are not guarantees of future performance, and involve risks and uncertainties. Actual results may differ materially from those anticipated in the forward-looking statements as a result of various factors. These factors are described in Enel Chile's press release reporting its third quarter and nine months 2022 results. The presentation accompanying this conference call and Enel Chile's annual report on Form 20-F included under Risk Factors. You may access our third quarter and nine months 2022 results press release and presentation on our website, www.enel.cl, and our 20-F on the SEC's website, www.sec.gov. Readers are cautioned not to place undue reliance on those forward-looking statements, which speak only as of their dates. Enel Chile undertakes no obligation to update these forward-looking statements or to disclose any development as a result of which these forward-looking statements become inaccurate, except as required by law. I would now like to turn the presentation over to Ms. Isabela Klemes, Head of Investor Relations of Enel Chile. Please proceed. Buenas tardes. Good afternoon, and welcome to Enel Chile's third quarter and nine months 2022 results presentation. Thank you all for joining us today. Joining me this afternoon is our CFO, Giuseppe Turchiarelli. Our presentation and related financial information are available on our website, www.enel.cl, in the investor section and in our app, Enel Investor. In addition, a replay of the call will be soon available. At the end of this presentation, there will be an opportunity to ask questions via phone or webcast chat through the link, Ask a Question. On this occasion, media participants are connected only in listening mode. In the following slides, Giuseppe will open the presentation with our key highlights, later passing by market and strategy outlook, and finally to our business economic and financial performance. Thank you all for joining us today. Now let me hand over to Giuseppe. Thank you, Isabela. Good afternoon and thanks for joining us. Let me now start with the highlights of the period on slide three. As we mentioned during our last call, the rainfall and the snowing period in Chile were better than last year. As a result, we can see better hydro production during the third quarter. Therefore, we maintain our expectation of a good hydro contribution for the Q4. Argentinian natural gas was confirmed for early October until the end of April 2023. These associated with better hydrology in supporting a slight decrease in spot prices, which are still pressured by commodities given the international scenario. We have been taking several management actions to offset this pressure and take advantage of the natural resilience of our assets, proving that our strategy is reliable and resilient. The gas optimization is helping us to slightly mitigate the international headwind. We complete the process of the coal phase-out in our operation in Chile. During the third quarter, we added around 0.2 GW of additional capacity, fully renewable, reaching +0.4 GW in the year-to-date figures. Regarding our economic performance, we face temporary headwinds over our margin related to the commodity pressure and hydrology during the first half of this year. Thanks to the managerial action we have put in place and the positive hydro production in the third quarter, the scenario has changed, translating into margin recovery. As a result, we keep our view for the year-end, confirming our guidance for this 2022. Finally, last week we had an important update on our asset rotation strategy. The antitrust body approved the sale of our transmission assets, so now we are passing to the stage at which the buyer will make a tender offer for the total shares. We expect to cash in the sales of the assets by the end of the year. Now let's move to slide five to briefly talk about the market situation and how we have developed our recovery plan. Our company this year has been facing a challenging scenario due to the sharp increase in the commodity prices, transmission constraints, and critical hydrology conditions in the first half of the year. Nevertheless, we have been able to develop several managerial actions that have helped us to cope with headwinds, contributing with around $240 million year to date, as better detailed in the slide. The improvement of rainfall in the third quarter led to an important recovery in our hydro generation. Moreover, our new connected renewable projects, including those that obtained the COD this quarter, are part of the improvement in the period. Active natural gas purchases in the period due to the increased availability of Argentinian gas and LNG cargo from different players, have allowed us to optimize the operation of our combined cycle power plant and furthermore, to carry out gas trading activities. Now, let's move to slide six to talk about just transition, energy transition strategy, given the coal phase out that we have been carrying out. Decarbonization is one of Enel Group's strategic pillar. The decision to close the plant ahead of the time was taken in the context of the agreement to shut down coal-fired power plant, signed with the Chilean government through the Minister of Energy in June 2019. Therefore, we decided to anticipate the phase-out of both units of Bocamina and Tarapacá. Enel Chile has taken a great step forward in its process of decarbonization by increasing renewable energy and with the disconnection of Bocamina plant. Bocamina shutdown is part of the implementation of the just energy transition strategy, which means incorporating technological, social, and environmental solutions, and placing the workers of the plant, its contractor, and the community at the core of each decision. We are analyzing several alternatives for land use, and 100% of the coal facility employees have the option to be relocated within the company or take a retirement plan. This is the true meaning of all the inclusive and just energy transition, ensuring that no one is left behind. Let's now look at how we are consolidating our renewable leadership on slide seven. During the last year, we have focused most of our efforts on developing a diversified renewable matrix in line with our decarbonization strategy, aiming for a clean energy matrix. As you can see, our renewable capacity continues to increase. This quarter, we have connected 225 MW of solar capacity. In this period, we received the authorization to start the commercial operation of the Azabache photovoltaic plant, the first hybrid renewable plant in Chile, being associated with the Valle de los Vientos wind facility. Additionally, we received authorization to start commercial operation of the Sol de Lila photovoltaic plant, which incorporates state-of-the-art bifacial photovoltaic technology for greater efficiency in capturing solar radiation. The renewable potential of the country continues to represent an attractive opportunity, and we continue consolidating our leadership, contributing to the transition from the current energy matrix towards one based on 100% renewable generation. Now on page eight, let us look at our electrification strategy. One of the key elements to face the climate change is the decarbonization of the final consumption through electrification. Transforming today's power grid into a smart and resilient grid are mandatory, and combined with the renewable growth, will be essential to reach the net zero goal. Furthermore, the quality and digitalization of our networks are at the core of our grid strategy, and we continue working to improve all the main indicators, as you can see in this slide. Additionally, we have carried out different projects and partnerships aiming to decarbonize the energy consumption of our clients. Let me go through some examples of the period. Regarding e-buses, two e-buses projects are being developed for the metropolitan region public transportation, Santiago Poniente and Santa Rosa. With this, we will reach 20 e-buses depots in 2022, with an estimated consumption of 77 GWh per year. Related to the e-City segment, we signed partnership with the Chilean Football National Association to develop projects in stadium with a focus on LED lighting, water heating, video surveillance, and analytics as part of our circular city approach. Finally, in industry, we are developing a project for two PV plants for the forestry and paper company CMPC with a total of 1 MW. This project is part of our effort to provide solutions to our clients, supporting them to reaching their decarbonization strategy. Let me now detail our economic and financial performance of the period on slide 10, where I show the main adjustments of the period. In nine months and in the third quarter 2022, we applied an adjustment in EBITDA due to the impairment made to the cost of the year, which amounted $60 million and $1 million, respectively. This adjustment had an effect at the bottom line of $41 million in the nine months and $0.4 million in the quarter. In the same period of last year, we applied an adjustment due to the coal stock and the voluntary retirement, which amounted $48 million in the nine months and $10 million in the quarter. At the bottom line, this effect amounted to $3 million and $7 million in the nine months and the quarter respectively. The Q3 2022 adjusted EBITDA increased 201%, reaching $242 million, mainly due to the better hydro in the quarter, the gas optimization activity, and support of the new renewable projects connected since last year. These effects have also impacted the nine months 2022 adjusted EBITDA performance, which increased 18%, reaching $543 million. In terms of adjusted net income during the nine months 2022, this increased by 140%, reflecting the higher EBITDA of the period and the lower financial cost coming from the factoring of PEC accounts made in the first half 2021 to improve the liquidity of the company. In this quarter, the net income reached $117 million due to the same reason mentioned before. Nine months 2022 CapEx reached $750 million, 13% higher than nine months 2021, mainly due to the construction of new renewable capacity. In the third quarter, our CapEx reached $234 million, 15% higher than the same period of the previous year. FFO accounts for a negative $340 million, presenting a significant reduction in the nine months 2022 versus last year, driven by the stabilization mechanism effect in the nine months 2022. This quarter, FFO reached $124 million, reflecting the stabilization mechanism as well. Now, let's review more about CapEx on slide 11. During the nine months of 2022, the cumulative CapEx reached $750 million, of which 93% was linked to the SDG goals, mainly related to our renewable growth. Customer CapEx totaled $52 million and was mainly focused on grid segment in order to improve quality and digitalization, improving the experience for our customer and build new connection. Asset management CapEx reached $112 million, and was mainly focused on maintenance and repair activities to ensure the continuity and resilience of our operation, thus reducing unavailability risk. In terms of generation business, larger CapEx was deployed into maintenance of hydro and thermal facilities. The latter, as a consequence from the greater usage of this facility in the last year. Development CapEx reached $452 million, representing an increase of 7%, mostly related to our renewable expansion plan, reflected in our project under construction, as a clear signal of our commitment for decarbonization goals. Let's now move to slide 12, where we have the summary of the third quarter adjusted EBITDA breakdown, accounting for $242 million. The variation was mainly related to an increase in our PPA sales of $120 million in the Q3 2022, primarily explained by the higher devaluation of the Chilean pesos against dollar. Renewable growth, mainly due to the new capacity, adding $13 million EBITDA of the period, $94 million due to the better hydrology in the period. Gas optimization activity that generate $104 million of margin. All effects that I've just mentioned in the generation side were offset by a negative $76 million related to variable costs, mainly due to a higher thermal generation cost related to the commodity prices and higher regasification costs due to higher volume, and by the hedging commodity coverage instrument in the period. A higher spot price in the system in the Q3 2022, mainly due to the higher commodity price. Following from this slide, let me talk about the other element that explain our EBITDA. Grid accounted a negative impact of $5 million, mainly related to the provision of regulatory fines in network business due to the non-compliance of quality services indexes from previous year, partially offset by tariff indexation in both distribution and transmission line. Other effect in the period was the hedging instrument associated with the bond debt, which had negative impact of $50 million. OpEx and other effects accounted -$28 million, mainly related to the higher inflation costs affecting personnel and maintenance costs. Let's move now to slide 13, where we have the summary of nine months adjusted EBITDA breakdown, accounting for $543 million, 18% higher versus 2021 figures. This variation was mainly related to $310 million higher PPA sales in nine months 2022, primarily explained by the higher foreign exchange of the Chilean pesos against dollar. Renewable growth contribution mainly due to the new capacity, added $33 million in EBITDA, and better results in the third quarter that had an impact of $68 million. Gas optimization activity that generate $103 million on margin. All the five that I just mentioned were offset by a negative $76 million in variable costs, mainly related to a higher thermal generation cost due to the commodity prices, and higher regasification costs in the period, due to the higher volume. Partially offset by a more efficient thermal generation in the period, and the commodity coverage instrument in the period. A negative $163 million due to the highest spot price in the system in the first nine months of 2022. The remaining variation of our EBITDA comes from $32 million due to the greater remuneration and demand, mainly explained by $14 million mainly to the release of the final transmission tariff technical report issued by the regulator in the first quarter of 2022. This final tariff allows us to reduce the provision we have made since the beginning of the new regulatory cycle that started in January 2020. $22 million on tariff indexation in both networks of business. The recovery of the demand in the period, which increased 7% in nine months 2022, compared to the nine months 2021, reaching pre-pandemic level. This effect was offset by the hedging instruments associated with the bond debt, and the higher generation business OpEx in the period by $50 million, mainly reflecting the higher personnel costs and operational maintenance activity. These effects were offset by higher capitalization of the period. All the above lends us confidence that we will reach our adjusted EBITDA goals for 2022. In the last call, I have explained that our generation business is quite seasonal. That is mainly related to the fact that from June to August, we have the start of rainy period in Chile, associated with the starting of snowing. At the beginning of our spring, during October, we started to have higher hydro generation in the country, associated with the melting season. All these effects associated with the long position of natural gas supply resulted in the higher generation hydro capacity, and the gas optimization activity allow us to confirm this year the adjusted EBITDA guidance. Let me now give you more details on generation KPI on page 14. Net electricity generation increased by 20% to 16.5 TWh in the 9-month period of 2022, mainly resulting from a higher dispatch of our CCGTs, a greater hydro production due to the improved rainfall, coupled with a higher generation from other renewable sources, especially solar production, mostly related to the additional capacity of new projects. Similarly, net generation increased 36% to 6.6 TWh during Q3 2022, highlighting the improved hydro production and also a greater generation from other renewable sources. Our energy sales increased 14% as of December 2022, mostly related to higher sales to free customers, primarily due to the new contract, coupled with greater sales to regulated customers. During the Q3 2022, physical sales grew by 7%, mainly as a result of higher sales to regulated customers. Now, on slide 15, let's go through the main driver of our group net income. Our nine months adjusted net income amounted to $150 million, representing an increase versus last year figures of 146%. The main variances are coming from higher adjusted EBITDA, which increased $82 million or 18%, already explained in the previous slide. Higher D&A impairment and bad debt by $32 million versus last year results, mainly related to higher depreciation amortization in EGP assets, primarily explained by the exchange rate effect in the period and the initial commissioning of the new solar power plant. Higher depreciation in the distribution and transmission segment, related to the new project and higher amortization of intangible assets related to the new commercial system recently upgraded at Enel Distribución. Also, we had a higher provision of bad debt in the distribution business, mainly due to the increase in overdue debt in the retail clients and municipalities. Financial results and equity investments recorded an improvement of $64 million in the nine months 2022, mainly due to the lower expenses related to the factoring executed last year in generation business on account receivables that arose from the Tariff Stabilization Law. Income taxes decreased by $25 million, mainly related to higher tax credit to the monetary correction in the period, offset by higher earnings before tax results of the company due to the better EBITDA and financial results. The adjusted net income of the Q3 2022 reached $117 million, which represents an increase of $128 million in the quarter, mainly explained by the same effect of the nine months. Moving to the FFO of the nine months 2022 on slide 16. The nine months 2022 FFO amounted a negative $343 million in the period, mainly explained by the cumulative stabilization mechanism effect in our receivable accounted in nine months 2022 for $338 million, reducing the cash conversion of the period. Let me highlight that $67 million are related to the stabilization mechanism approved in 2019, and $271 million are related to the new mechanism approved this August. According to the mechanism of the law recently approved, the $271 million represent a temporary effect that we expect to recover within the first half of the next year through a financial instrument that should be guaranteed by the Chilean government. The working capital in the period account for a negative impact of $340 million, mainly due to $239 million related to the delta payables in September 2022 versus December 2021, mainly coming from CapEx execution profile in the year. Most of this impact shall also be recovered within this year. $107 million due to higher EHE, mainly due to the energy spot prices, most of it to be recovered by the end of the year. Temporary effect of $40 million related to lower collection in energy distribution, mainly associated to the fine-tuning of commercial system updates, and these effects were partially offset by the factoring executed in nine months 2022 of $90 million. Income tax reached $54 million. With regards to the variation versus 2021 figures, I would like to recall that last year's numbers were impacted by FX losses, resulting in lower payment of tax. Finally, the financial expense amounted to $155 million related to the debt cost payment in the period. For what concerns last year's figures, this includes expenses related to the past factoring instrument that I've just mentioned. Moving to our debt on page 17. Our gross debt increased by $1 billion, amounting to $6 billion as of September 2022. Due to the increase, the company loan provided by Enel Finance International to Enel Chile for $700 million and third-party loans for $300 million in the Q3 2022. This was partially offset by $21 million amortization of Enel Chile local bonds. Our debt maturity remained comfortable with an average of 4.7 years, and the fixed rates are close to 70%. We are working to increase the fixed rate portion and the average life of our debt as part of the debt optimization strategy using the proceeds of Enel Transmission sale. For the current year, we have around $400 million debt at Enel Chile level with EFI that has a maturity in December. We are currently evaluating whether to amortize or not this debt as part of our debt optimization strategy. Despite the increase of our debt, its average cost decreased to 3.9% as of September 2022, from 4.4% as of December 2021, as a result of financial management carried out in the nine months. In the period, 17% of our total gross debt is currently SDG linked. We confirm our plan to continue to pursue this kind of debt in line with our sustainable business strategy. In terms of liquidity, we maintain an adequate position in order to cope with possible events in the next market related to the overall economic situation, including the international conflict in Eastern Europe. Now, I will point out some closing remarks on slide 18. As we mentioned during the call, we completed the coal phase out process and converted the first coal-free conventional utility in Chile. As all know, this year the international market has been particularly impacted by non-recurring events or externalities, and we have taken several management actions to offset this impact. The asset rotation transaction is ongoing as expected, and the deal should be closed by the end of December. This decision will help the company to deleverage and destress business debt EBITDA ratio. To conclude, we are confident that we will reach our 2022 main guidelines. Let me now hand over to Isabel. Thank you, Giuseppe. Before starting the Q&A section, we want to invite you to participate in our Investor Day 2022, which will be held on November 28th, in which we will update the strategic figures for the period 2023 up to 2024, 2025. As anticipated, we will receive questions via phone or chat in the webcast on this occasion. The Q&A section is open. Operator, please, you may start. Thank you. As a reminder, to ask a question, you need to press star one one on your telephone. Please stand by while we compile the Q&A roster. Our first question comes from the line of Javier Suárez from Mediobanca. Your line is open. Hi, good morning, and thank you for the presentation. Three questions. The first one is again on the FFO year to date, where there has been a decrease of something like $600 million versus previous year. You explained the effect is basically 50% coming from the stabilization mechanism and then 50% from working capital absorption. You mentioned during the presentation that you are expecting to recover the impact on the stabilization mechanism during the first half 2023. Can you again help them to understand how this recovery is going to be implemented? On the working capital absorption that should be at least partially recovered before the year-end. Which are the managerial actions that are going to be taken for that reduction? A little bit the thing that I'm trying to understand is where this $100 million should be by the year-end in terms of working or cost absorption. That is the first question. The second question is on the debt evolution. The debt, the cost of debt has been reduced this year, but obviously there is a scenario of higher interest rates, a global scenario of higher interest rates. How do you see that level of debt impacting your company for the next year, for example? Any indication on how w hat you see cost of debt in 2023 could be helpful. Then the third question that is related to the second one is on the management of your capital structure. In a scenario of more higher interest rates down the road, do you see a necessity to modulate CapEx or to be more selective on CapEx and to allocate in a different way CapEx on dividend, et cetera. Any comment on capital allocation would be welcome as well. Thank you. Okay. For what concern the FFO, the first quarter and the recovery that we see or at least we expect by the end of the year, we have basically three main items that we have taken into the consideration. The first is the payables. As I said, in September figures, we see an impact of $229 million because the CapEx profile has a certain level over the year. Let me say that around 30% of our CapEx are concentrated in the last quarter. Once we close the year, you shouldn't see such a big difference. The reason because I believe that we are able to recover it. The second one is the GAT. As of today, we have an impact, a significant impact that it will be recovered as soon as we're gonna sell our energy. We believe also that the higher GAT will be absorbed according to our projection. The last one is the collection and distribution that we are putting in place several action in order to recover the detail that we had coming from the changing in our commercial system. We believe that this all this action will allow us to reach around $300 million FFO positive, really, positive FFO in at the end of the year. This is for what concern the first question. For what concerns the second one, let me say that as soon as we are going to get the proceeds from the Enel transmission sales by the end of the year we are able to rebalance our balance sheet in terms of debt. We believe that we are able to have an average interest rate around 4%. That will continue to be our target this year and next year. We're gonna see in more detail the number as soon as we are going to have our capital markets day in this year. For what concerns the CapEx modulation, all the CapEx that we have this year are already committed and are basically related to the project already in execution. Clearly, as I said before, in one month from now, we're gonna have the new capital market date, so we're gonna present the strategy for the next year. According to this strategy, you can see, you know, our projection for the following year. Okay. Many thanks. Thank you. One moment for our next question. Our next question comes from line of Francisco Paz from Santander. Your line is open. Hi, Giuseppe, Isabela. Thanks for the presentation. My question is the following, and it's a really open one. Given the end of the operation of the coal unit with the exit of Bocamina II, what will be the main focus of Enel Chile investment plan? If you can give some further information about that. Okay. Thank you, Francisco. Okay. Thank you. Okay. Thank you. Okay. Thank you. Thank you, Francisco. Well, clearly, the close of Bocamina II is one of the pillars that we have in our strategic plan together with the renewable expansion. Again, we are finalizing our industrial plan that is gonna be presented in the capital market day. It's just a matter of one month before to show everybody our strategy. In general, I mean, the decarbonization strategy is going to be still. It's gonna be still the pillar of our company. We are going to present all the details in one month from now. Okay. Thank you. Thank you, Francisco. One moment for our next question. Our next question comes line of Ezequiel Fernández from Balanz. Your line is open. Ezequiel, your line is open. Thank you. I was disconnected for a second there. Good day, everybody. Thank you very much for the materials. Very complete as always. I have three questions. I would like to go one by one, if you don't mind. The first one is related to gas provisioning during the next two quarters. What can we expect from Argentine gas? If you are confident on getting as much as you did this year, maybe a little bit more? The second one is, how do you feel about the possibility of seeing any of the LNG vessels bound for Chile being redirected to Europe? Thank you, Ezequiel. Okay. Well, I mean, this year, we were able to optimize our gas activity thanks to the availability of our sources. We believe that considering the good performance in terms of rainy season, we believe that in the last quarter, we are able to make some additional optimization and additional optimization that we are going to finalizing in during this week. The margin, I mean, something difficult to say right now because we didn't close yet the sales, but we expect a very good result also in the last quarter. Well, the optimization of the gas means all our sources. We have different kind of sources. As you know, we have the LNG contract with Shell. We have the availability of other sources like third parties or Argentine gas. Anyway, we are trying to figure out which is the best way in order to exploit the maximum advantage from this availability. Again, I believe that we are able to do some very good deal in the last quarter. As of today, I cannot tell you know, margin or any other information. Okay. Thank you. My second question is related to the PEC 2.0 stabilization program. We understand that it has two parts. One is the surcharge that's gonna be borne by all Chilean power demand, regulated and unregulated customers. There is this hike to the energy component of power bills that is going to be enacted just for the larger consumers connected to the distribution networks. I was wondering if that increase for the larger consumers has already been enacted or not, but it should be enacted next year. Okay. Well, consider that the law foresees a different kind of tariff for different kind of clients. For what concerns the large customer, they're going to pay basically the full PPA starting from the next year. Basically, there is a different kind of cluster with different kind of increase per customer. For what concerns the customers that are higher than 700 MWh, they're going to have the regular price or the price coming from the PPA since 2023. What I can tell you is that, in general, if you compare the two different kind of mechanisms, now the perimeter of the receivable is going to be reduced significantly in terms of around 40% of our customers. This is the reason because we believe that this new mechanism is going to impact the lower way, but always important because of the exchange rate scenario that we see this year. Anyway, as I said during the presentation, the good point for what concern this new mechanism is that there is a guarantee from the Chilean government, and the receivable that is going to be accumulated because of the mechanism is going to include also the interest associated to the late payment. So at the end of the day, what we are doing is to identify the proper instrument, financial instrument, in order to factorize this amount without, theoretically, without any kind of effect in terms of financial expense. Okay. Great. Thank you very much. My third question is related to the carbon taxes, and a lot of the presidential hopefuls last year were campaigning on hiking the carbon tax. So far we haven't seen anything. I don't know if you have any updates on that front. Look, as of today, we don't have news about that. Clearly we are monitoring the issues that could potentially impact on our company. You know, so far we don't have any specific update to communicate. Okay. That's great. Very clear. Thanks. Thank you. Thank you. I'm not showing any further questions in the queue at this time. Now I'll turn it over to Isabella for any closing remarks. Hi. We have actually two questions coming from the web chat here. The first one, Giuseppe, is coming from Andrew McCarthy from Credicorp Capital. He's asking, "Why was the commercialization margin for gas so high in the third quarter of this year versus prior quarters? How sustainable is that going forward?" Actually also on the same route, there is also a question from Rodrigo Mora from Moneda. "Hi, good afternoon. Could you please give us the physical sales of LNG in TBtu during this nine months of 2022." That's it, the two questions, Giuseppe. Okay. Well, for what concern the first question, of course, the margin that we are able to reach every quarter is depend of the market scenario in terms of price. Let me say that the high margin that we got in the third quarter basically coming from the fact that we were able to use our regasification system. Basically, we were able to use our capabilities to divert the sales in respect to different markets. The price of course is depend on the client and the scenario that we find in the international level. For what concern the question related to- To Rodrigo, yes. To Rodrigo. For relating how Yeah. Okay. The volumes. Yes, on the third quarter. The volume, we are talking about 20 TBtu. These are the volume that we sold to our customers. As we do not have any more questions, as the operator coming from the system or for the webcast. Actually, we have one more question that just has arrived here. The question, Giuseppe, that we have. Mm-hmm. It's from Pamela Salgado. Pamela is asking us, "How has energy decoupling affected Enel Green Power's EBITDA, the curtailment? Energy decoupling understood as the difference between the sale price and the purchase price." Thank you, Pamela, for your question. I pass to you, Giuseppe. Yeah. Well, Enel Chile has energy bonds, where having some commitment PPA has to cover it with its own production or buying the energy on the market, on the spot market, from third parties. Now, we of course buy the energy on the spot market according to the variable cost that we have for our power plants and the commodity scenario that impacts significantly in the spot price. Every month and every day, let me say, there is a different kind of situation. As of today, we are in the position in which we are short, if you look to compare just the sales versus the renewable production. Of course, we have enough gas capacity to cover whatever it is the remaining amount of energy. Again, sometimes depending on the hour and depending on the season that we are, it could be more convenient to buy from the market rather than to produce with our power plant. Basically, we have an impact, but the impact depends on different kind of factor. One of the most important, of course, is the fuel. Okay. Thank you, Pamela Salgado from BCI for your question. Just checking if we're receiving additional question. No for now. As there is no more questions, I conclude the results conference call. Let me remind you that the investor relations team is available for any doubt you may have. Many thanks for your attention and see you soon on our event on. This concludes today's conference call. Thank you for participating. You may now disconnect. Everyone, have a great day.