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Good day, ladies and gentlemen. Welcome to Enel Chile's second quarter and first half 2026 results conference call. My name is Carmen. I'll be your operator for today. At this time, all participants are in a listen-only mode. After the speaker's presentation, there will be a question-and-answer session. Please submit your written questions via the webcast chat. Please be advised that today's conference is being recorded. During this call, we may make statements that constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Such statements may include Enel Chile S.A.'s current expectations, intentions, plans, beliefs, or projections. Forward-looking statements are based on management's current assumptions and expectations, do not guarantee 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 on its second quarter and first half 2026 results. In the presentation accompanying this conference call, Enel Chile's annual report on Form 20-F on the risk factors. You may access our second quarter and first half 2026 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 undertake 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.

[Foreign language] Good afternoon. Welcome to Enel Chile's 2026 second quarter and first half results presentation. Thank you for taking the time to join us today. My name is Isabela Klemes. I'm the Head of Investor Relations. Joining me today are our CEO, Gianluca Palumbo, and our CFO, Simone Conticelli. Our presentation and related financial information are available on our website, www.enel.cl, in the investor section, as well through our investor app. In addition, a replay of the call will soon be available. At the end of this presentation, there will be an opportunity to ask questions via webcast chat through Ask a Question link. Media participants are connected in listening mode. Gianluca will begin by covering the key highlights of the period, our portfolio management actions, and recent regulatory developments. Simone will provide an overview of our business, economic, and financial performance.

Thank you for your attention. I will now hand the call over to Gianluca.

Thank you, Isabela. Good afternoon, everyone, and thank you for joining us today. Let me start with the main highlights of the period. First, let me turn to portfolio management. During the first half of 2026, hydro generation was lower than last year, reflecting weaker rainfall conditions across the system, despite a strong El Niño expectation. This impact was partially offset by higher renewable generation, availability of Argentina gas, and active portfolio optimization initiatives, helping us maintain operational flexibility and support our supply commitments. Looking at our medium-term strategy, we continue to advance our portfolio diversification initiatives. Construction of our battery energy storage projects remains on track with approximately 0.5 GW currently under construction. In addition, we signed a new renewable PPA buy that will provide greater flexibility to our supply portfolio, strengthen diversification, and support long-term value creation. Let's now move to the country and regulatory context.

During the quarter, the Electricity Tariff Protection Bill was approved by both the Chamber of Deputies and the Senate. The bill includes a securitization mechanism to address the VAD 2020-2024 tariff settlement process, providing greater visibility on the recovery of regulatory receivables. At the same time, the proposal extends the VAD 2024-2028 regulatory period through 2030, aiming to prevent delays in upcoming tariff review cycles. In addition, the initiative established a dedicated framework to plan investments aimed at enhancing the quality of service for customers by strengthening network resilience. This is an increasingly relevant topic considering the challenges faced by the electricity system in the recent years. Finally, let me turn to business performance. Despite a more challenging operating environment in the quarter, our first half's results remained resilient, supported by active portfolio management and diversification initiatives.

We also maintained a sound liquidity position, allowing us to support our CapEx plan while providing financial flexibility. In the next slide, we will go deeper into each of these areas and provide further details on the key drivers behind these results. Throughout the presentation, we will discuss each of these topics in greater detail and explain the main drivers behind our operation and financial performance. Let's now move to slide four, where I will provide more detail on our sourcing strategy, hydrological conditions, and the progress of our battery energy storage projects. Let me begin with our hydro generation. Hydro generation during the first half was below last year level, as shown on the left-hand side of the slide.

This was due to poor rainfall recorded year to date, even though observations from specialized entities indicate that Pacific Ocean conditions have transitioned into El Niño conditions and are continuing to intensify. For 2026, our hydro generation outlook remains at around 10.7 TWh, reflecting an expected recovery in the second half of the year. Over the past few weeks, we have seen a significant improvement in hydrological conditions, together with encouraging snow accumulation levels. As a result, we are increasingly confident that our hydro generation target is achievable. Moving now to gas and thermal activities. In thermal generation, we continue to optimize our fuel management strategy, adapting our sourcing and generation portfolio to evolving system conditions. As a result, thermal generation increased by 5% year-over-year, reaching 3.6 TWh during the first half of 2026.

As you already know, we secured an Argentina firm gas supply agreement covering fixed volumes from January 2026 through April 2027, strengthening fuel availability during the period. During the first half of the year, lower hydro availability and safety operational requirements across the power system increased the need for thermal generation. To support system reliability, security of supply, and cost efficiency, we also secured additional short-term LNG volumes for the second half of 2026. In parallel, we will continue to advance our LNG portfolio optimization strategy, further strengthening flexibility across our sourcing portfolio. Let me now comment on our sourcing agreements. We continue to strengthen our commercial sourcing portfolio through a new long-term buy PPA. This contract will add up to 1 TWh per year of non-solar energy, starting in the second half of 2026.

The agreement has a duration of 15 years and will further enhance supply diversification, while supporting long-term customer demand. This agreement is an example of our flexible make or buy strategy. As we have consistently highlighted, we remain focused on capturing opportunistic and value-accretive sourcing solutions that enhance portfolio diversification and strengthen the value proposition that we offer to our customers. Finally, let me focus on our projects under construction. We continue to advance our BESS projects. Las Salinas, Valle del Sol, and Azabache represent a combined capacity of more than 450 MW, reinforcing system flexibility and supporting greater renewable integration across our portfolio. Overall, our active portfolio management approach and diversified sourcing strategy continue to strengthen security of supply, improve cost efficiency and operational resilience, and support our operational commitments. Now let's move to slide five, where we will review our generation mix and energy balance.

Let me now turn to our generation mix and energy balance. As shown on the left-hand side of the slide, net electricity generation decreased compared to the first half of 2025, mainly reflecting lower hydro generation during the period. Hydro generation declined by approximately 1.1 TWh, reflecting weaker hydrological conditions throughout the first half of the year. This impact was partially offset by higher generation from renewables sources, as well as a stronger contribution from our efficient gas-fired combined cycle plants. Moving now to energy balance. Physical energy sales remained broadly stable during the first half of 2026. Our diversified sourcing portfolio allowed us to maintain a solid commercial position, with total sales reaching 14.8 TWh, broadly in line with the 15.1 TWh recorded in the same period last year.

The difference compared to the previous year was driven by a decrease in free market sales, partially reflecting lower demand, mainly from mining customers, among others. During the period, lower hydro generation was offset through a combination of higher thermal generation, strong renewable output, and portfolio management initiatives. On our portfolio mix. The flexibility of our portfolio continues to be one of the key strengths. Although hydro generation was lower, the contribution from combined cycle generation increased from 2.9 TWh to 3.2 TWh, while renewable generation increased from 2.7 TWh to 3.0 TWh. As a result, 67% of our production remained emission-free, demonstrating the resilience and diversification of our generation portfolio. Regarding spot performance.

Regarding energy purchases, during the first half of the year, we increased our net spot market purchases mainly during non-solar hours, while purchases from third parties remained at a level like those recorded in the first half of 2025. Now I would like to move to slide six, where I will discuss the latest developments related to the regulatory framework for the distribution business. Now, let me turn to the latest regulatory developments affecting the distribution business, particularly the Electricity Tariff Protection Bill. During July, the bill received final approval from both chambers of Congress and was sent to the President for promulgation, representing an important step toward addressing pending regulatory matters in the distribution sector. The proposal is relevant for three main reasons. First, it addresses the VAD 2020-2024 settlement. Second, it extends the current tariff cycle by two years to establish a VAD 2024-2030.

Third, it creates a dedicated framework to support grid resilience investments aimed at increasing the quality of services. Regarding the VAD 2020-2024 settlement, the bill establishes a mechanism to normalize and recover outstanding regulatory balances accumulated in the recent years. This mechanism is expected to help distribution companies monetize regulatory receivables over time, while avoiding an immediate impact on regulated customers. For Enel Chile, this process is expected to result in an estimated cash inflow of approximately $70 million, improving visibility of future cash recovery. Moving now to the VAD 2024-2030 tariff framework. The proposal extends the VAD 2024-2028 tariff period through 2030, aiming to prevent delays in upcoming tariff review cycles. For the time being, several implementation details remain under discussion as the legislative and administrative process continues.

We look forward to providing further updates and greater clarity as those discussions progress, including during our upcoming quarterly earnings call. Finally, regarding resilience investments. The bill also introduces a dedicated framework to support investments aimed at strengthening grid resilience by improving quality of service. This is particularly important given the increasing need to reinforce distribution networks and improve the system's ability to respond to extreme weather events and operational contingencies. The proposal is a step in the right direction, despite key implementation details remain to be defined. Overall, we see these regulatory developments as a positive for distribution business, because they provide greater tariff certainty, enhance visibility on regulatory receivables, and support future investments in grid resilience. With this, I will now hand over the presentation to Simone.

Many thanks, Gianluca, and good afternoon, everyone. Let me start with our key financial highlights of the period. As shown on the slide, in the first half 2026, EBITDA reached $685 million, up 4% year-on-year, driven mainly by stronger gross margin performance in our integrated business, while second quarter EBITDA was lower than last year, reflecting weaker hydrology and lower gas sales. Net income reached $272 million in the first half, increasing 11% year-on-year, while second quarter net income grew 54%, supported by lower depreciation, amortization, and impairment expenses, as well as lower financial expenses. Cash generation remained particularly strong. First half FFO increased 24% to nearly $500 million, while second quarter FFO increased 28%, demonstrating the resilience of our business and the discipline of our cash management.

We will go into more detail later in the presentation. Let's move to the next slide to talk about the investment made during the quarter. During the first half of 2026, we invested $328 million, more than doubling our CapEx versus last year. Our capital allocation remained highly focused. Nearly two-thirds of total investment were directed to renewable and BESS, while around 22% was invested in strengthening and modernizing the distribution network. The remaining investment were allocated to maintaining the reliability and availability of our thermal fleet. Let me provide some additional details on our investment allocation. In the renewable segment, our investment were focused on the development of BESS project, in line with the objectives set out in our strategic plan, the optimization of hydro facility performance, and the improvement of fleet availability.

In the thermal segment, the priority continues to be the maintenance and performance enhancement of the power plant fleet. Regarding grids, we continued advancing on the resilient program to strengthen the distribution network and ensure service continuity and readiness. Looking at the CapEx breakdown by nature, first, development CapEx, equal to $196 million, represented 60% of the total spending and were mainly allocated to BESS, which accounted for 80% of the spending, network, representing 13%, mainly related to reliability, quality of services, and digitalization, and hydro plants, which represent 5%, mainly driven by performance enhancement project. Second, asset management CapEx totaled $102 million, accounting for 31% of total CapEx, mainly allocated to the maintenance of Atacama, Quintero, and San Isidro CCGT, the maintenance of renewable fleet aimed at ensuring plant availability, and some activities for the corrective maintenance and digitalization of grids.

Finally, customer CapEx totaled $30 million, mainly invested in low and medium voltage connection project and initiative to support load increase. Now, let me walk you through the key drivers behind our EBITDA performance during the second quarter of 2026. Our EBITDA reached $262 million in the second quarter 2026, a decrease of $32 million compared to the second quarter 2025. The variation is mainly explained by the following factors. Starting with PPA sales, we have a negative impact of $14 million, mainly due to the expiration of old high-prices regulated contracts. Moving to sourcing, we recorded a positive impact of $5 million, mostly thanks to optimization of regasification costs. Energy and transmission resettlement from previous periods and commodity hedges. These effects were partially offset by a higher volume of spot market purchases, mostly due to weaker hydrological conditions.

On the other hand, we recorded a $36 million reduction of the gas margin, reflecting the high impact of gas trading and optimization activity of the second quarter 2025. Turning to grids and other, the $14 million positive variance is due to the one-off effect in personal costs recognized in the second quarter 2025 related to the incentivized early retirement plan, and the optimization of the O&M processes of our renewable facility. These effects were partially offset by the reduction of grids results, reflecting 2025 positive effect of the previous year remuneration recovery. Now let's move on to the next slide to review the EBITDA evolution during the first half of this year. As shown on the slide, EBITDA increased from $659 million to $685 million, despite ongoing challenges in the energy market.

Starting with the integrated business, we recorded an increase of $38 million, mainly due to gas optimization initiative led by the agreement with Shell that contributed more than $100 million to EBITDA growth, demonstrating our ability to unlock value from our gas portfolio under volatile market conditions. Lower natural gas costs that impacted positively on our variable thermal production cost and lower spot energy purchase costs. These positive impacts were partially offset by the expiration of old high-price regulated contracts and the net impact of transmission cost settlements. Moving to grids, we recorded a decrease of $12 million, mainly due to the positive one-off insurance provision recovery and other one-off positive effects recorded in 2025. The increased maintenance activity aimed at strengthening the resilience and security of the grids, partially offset by an increase in grids margin, also supported by favorable foreign exchange rate effects.

Now let's move on to the next slide to review the net income evolution. In the first half of 2026, our net income amounted to $272 million, an increase of 11% compared to the last year's figure, mainly explained by, first, the already illustrated EBITDA improvement by $26 million. Second, the decrease of depreciation, amortization, impairment, and bad debt expenses by $38 million, mainly due to positive effect from impairment charges recorded during the first half of 2025, along with the recovery of value from certain generation assets previously impaired, partially offset by higher depreciation and amortization associated with the commissioning of new renewable generation capacity. Third, the negative variation for $34 million of financial result, mainly explained by negative foreign exchange differences and lower capitalization in the generation business. Finally, the increase of income taxes for $5 million, mostly due to the improved results.

Focusing on the quarter, net income improved by $38 million, mainly as a result of lower depreciation, amortization, and impairment expenses by $52 million, mainly driven by impairment-related effects on generation assets across comparable quarters. Lower financial expenses by $17 million, thanks to positive foreign exchange effects and increased interest capitalization related to the advancement of BESS projects, partially offset by a $32 million reduction in EBITDA, largely due to lower PPA sales and gas trading performance. Now passing to the next slide, let's analyze the FFO composition. In the first half of 2026, FFO reached $499 million as a result of the following factors. First, EBITDA totaled $685 million, as previously explained. Second, we recorded $32 million of PEC receivables.

Third, the net working capital decreased by $43 million, mainly due to positive effects of payment optimization related to development CapEx, partially offset by seasonality of energy payments and the increase in Enel Distribución receivable. Fourth, financial expenses amounted to $141 million, also including the settlement of hedging derivatives. Finally, income tax payments amounted to $120 million, mainly related to the generation business. Moving to the comparison with the results of the first half of 2025, the 2026 FFO was $96 million higher, mainly thanks to the EBITDA increase for $26 million, a decrease of PEC receivable recovery by $237 million, largely explained by the factoring transaction related to PEC 3 executed in April 2025. The positive net working capital variation of $300 million, mostly due to higher commercial debt related to the newly developed capacity and the positive effects of energy payment optimization.

The higher financial expenses for $59 million and the lower income tax payment for $66 million, net of the negative impact from higher monthly payment tax rates in the generation business. Now let's take a look at our liquidity and leverage position. Our gross debt reached $3.8 billion at the end of June 2026, decreasing by 1.4% compared to the gross margin as of December 2025. This reduction was mainly driven by $150 million of debt amortization related to the inertial debt, partially offset by a $15 million drawdown under the CAF credit facility to support net working capital needs, and $9 million of additional IFRS 16 lease liabilities. The average terms of our debt maturities decreased from 5.8 years recorded in December 2025 to 5.5 years by the end of June 2026, and the portion at a fixed rate was 85% of the total debt.

The average cost of our debt reached 4.9% as of June 2026, in line with December 2025. Regarding liquidity, we are in a comfortable position to support our capital needs for the upcoming months and cope with the next year maturities. As of June 2026, we have available committed credit lines for $640 million and cash equivalent for $276 million. Thank you all for your attention. I will pass the floor to Gianluca for the closing remarks.

Thank you, Simone. Now on slide 15. To conclude, our first half 2026 results once again demonstrate the value of our diversified generation and distribution platform. Despite less favorable hydrological condition, our results remain resilient, supported by disciplined portfolio management, increased renewable generation, and greater fuel flexibility. Second, recent regulatory developments represent an important step for the distribution business. Approval of the Electricity Tariff Protection Bill supports ongoing efforts to address tariff settlements and establish a framework for the future network modernization and resilience investments. In addition, despite the intense winter weather conditions, our grid operations have remained resilient and performed in line with the expectations. Our execution to date confirms that we are on the right track, supported by enhanced operational readiness and a strong focus on service continuity. We will provide a more comprehensive update on our performance during the Q3 call once the season concludes.

As Chile continues to advance toward a more electrified and sustainable economy, we remain well positioned to support this transformation through our integrated presence across generation, distribution, and energy infrastructure. Finally, our strong liquidity position, robust cash generation, and disciplined capital allocation continue to underpin our growth strategy. These strengths allow us to advance key initiatives aimed at strengthening our commercial platform and sourcing portfolio, including battery energy storage projects and new long-term power purchase agreements. At the same time, we will maintain financial discipline and preserve balance sheet strength. Looking ahead, we remain focused on execution, operational excellence, and long-term value creation, supported by a flexible portfolio and a solid financial position. Thank you for your attention. I will now hand it over to Isabela for the Q&A session.

Thank you, Gianluca. Let's move on the Q&A section. We will be taking questions via chat through the webcast. The Q&A session is open. Let me check here. Well, thank you very much for all the questions you have submitted to us. Since a few topics are common, received to both analysts and also via email, I'm going to start with these common questions. I will try to group them together for ease of the discussion. Any remaining details on these topics will be covered as we move through our Q&A session. Our first question is coming, well, for several analysts like Andrew McCarthy from LarrainVial and Fernan Gonzalez from BTG. I'm joining the question. Could you provide an update on the recent approved Electricity Tariff Protection Bill and its implications for the distribution business?

In particular, how should investors think about the VAD 2020-2024 settlement, the extension of the current tariff cycle through 2030, and the new framework support investments aimed at improving services quality and grid resilience? Also, Andrew is requesting if we have any projects ready to submit in terms of the resilience investments. Gianluca, please.

Okay. Thank you for the question. I would like to take a few extra moments on these topics, considering that for us, it is one of the most significant regulatory developments for Chilean distribution sector in recent years. From our perspective, there are three key elements. First, the VAD 2020-2024 settlement. The bill established a mechanism to address pending balances from the previous tariff period, improving visibility on the recovery of the regulatory receivables accumulated in the recent years. For Enel Distribución, this represents approximately $65 million-$70 million. Subject to final implementation process, we currently expect the securitization and factory process to be completed by the end of this year or in early 2027. Second key element is the extension of the tariff cycle. The bill extends the current VAD period through 2030.

While we are still assessing some of the implementation details, we believe this should bring greater regulatory predictability and help us avoid new tariff settlement delays. Third key element, and probably most importantly looking ahead, is the new investment framework for service quality. As I mentioned on our last call, there is a broad consensus across the sector that improving service quality requires a clear mechanism to recognize the investment needed to strengthen and modernize the distribution network. The new framework moves in that direction, opening a potential path to support future investment in grid resilience and service quality, but subject to regulatory approval and tariff recognition. Concluding, while several implementation details still need to be defined, we clearly review this as a positive development for the industry.

For now, we don't have any specific project to share with you, we are working on it.

Okay. Thank you, Gianluca. Now let's go to the second question. This one is also recovered of several analysts. Gianluca, this is also for you. How is Enel Chile evolving its portfolio and sourcing strategy to capture future growth opportunities while maintaining flexibility in an increasingly complex power market? In particular, how do battery storage, long-term energy contracts, and portfolio optimization contribute to management volatility, supporting your commercial growth and creating value?

Okay. Thank you for your question. We are evolving our portfolio to add flexibility, improve resilience, and capture new growth in a more volatile power market like we had in the last months. First, battery storage, or BESS, is now a key part of the portfolio. As we know, it helps us capture more value from renewables, reduce curtailment, shift energy to higher-value hours, and add flexibility while making the system more resilient. Second, long-term contracts remain obviously key pillar of our commercial strategy. They give customer stability and help us manage spot market volatility, while a diversified sourcing structure lets us adapt to market conditions and customer demand. Finally, portfolio optimization ties it all together. Therefore, by combining renewables, storage, thermal flexibility, and contract management, let me say, we manage price volatility, optimize sourcing, and support growth.

The goal is not only to protect margins, but to create extra value from the flexibility in our portfolio.

Thank you, Gianluca. Another one also from Andrew McCarthy, from LarrainVial, and the same from Fernan Gonzalez from BTG Pactual. Could you elaborate on the recently announced long-term PPA purchase? What is the strategic rationale behind this agreement, and does it imply any change in Enel Chile's growth strategy, particularly regarding the development of BESS, Gianluca?

Okay. Many thanks for another more interesting question. As indicated during the presentation, this agreement is fully consistent with our long-term strategy and should not be interpreted as a change in direction. First of all, it strengthens our portfolio diversification. Second, enhances our sourcing flexibility, and supports future customer demand. More importantly, this is an important point, it reflects our disciplined make or buy approach, under which we continuously assess both organic and contracting opportunities in order to optimize value creation and risk management. I wanted also that, to be clear, this agreement doesn't imply any change in our BESS strategy. Our battery storage project continue to progress according to plan, and remain a key pillar of our growth strategy, thereby supporting renewable integration, system flexibility, and portfolio resilience. Overall, this is another example of our disciplined execution, keeping us on the right track.

Okay. Thank you, Gianluca. Now, another one from Andrew McCarthy, LarrainVial, another analyst that we receive also here. They are asking now, Simone, this is for you. More details on the hydro generation expected for 2026. One of the question is, we have seen weaker hydrological conditions than initially expected in 2026. Is Enel Chile's full-year hydro guidance at risk, or will the recent rainfall over the last week sustain your projections?

Okay. Thank you, Andrew, for the question. Let me introduce a little bit some color about our budget. The budget is composed of two parts. The first five months, we included in budget in a very dry scenario. Why? Because we are coming from a very dry year, we have been very conservative. For the second part of the year, starting from June, in budget, we are considering a neutral scenario. We set the hydro production at the level of the average production over the last 13 years. So far what happened? Until May, we were well in line with our budget. We are not surprised by the very dry year. We expected first front of rains during June, the rain arrived with a little bit of delay, starting from the 10th of July.

Now we are comfortable in confirming our guidelines for the hydro production because we expect a neutral year. In this moment, all the forecasts say that the year could be neutral or wet maybe. We are confident with our budget.

Thank you, Simone. Let me check. We are receiving more questions. Also on the hydro estimates and also gas, Simone, this is for you. Giving weaker hydrological conditions, evolving system reliability requirements, and tighter gas availability from Argentina during the winter season, how comfortable are you with your fuel position for the remaining 2026? Do you have sufficient gas secured to support thermal generation requirements? Should we expect any additional fuel sourcing or portfolio optimization initiatives during the second half of the year?

Talking about our sourcing strategy in general, specifically sourcing gas strategy, we try not to depend on just one source of gas. We prepared last year, and we have two groups of contracts. Some contracts for natural gas from Argentina, and then the historical contract with Shell for LNG. In any case, we have a very solid portfolio of gas contracts, and then the LNG contracts are firm ones. I mean, firm in terms of volume of transportation at fixed price. This is the core, the core part of the portfolio can fuel our thermal power plant. On the other side, our strategy is to keep on adjusting the portfolio based on the evolution of environment.

In this present week, we also closed a contract for the delivery of another cargo of LNG that will be delivered in the second half of 2026. Based on this, based also on other activities that in case needed, we can put in place, we are very confident that we can go on and fulfill all our needs, not just in the base scenario, also in a stressed one.

Thank you, Simone. We have seen some questions from Alessandro Di Vito from Mediobanca. The first one, I will divide. The first one is: Is the company confirm its 2026 guidance?

Another time, let's look at the first half results. The first half was a quite tough period in terms of external input, very dry season with some problem for the system related to gas. Also the price went up in the last part of the half. In any case, our results for the period were well in line, or even a little bit better than expected. This is a proof of the resilience of our portfolio, our preparation. Looking ahead, we can confirm our guidance. We have no element to change our guidance for the remaining part of the year, we are focusing on the management of our operating activities during the coming season.

Thank you, Simone. Another question coming from, now let me go again with hydrology, now coming from Isabella Pacheco from Bank of America. How do you expect El Niño to impact your operations and financial results this year? Could you give more color on how it has affected Enel Chile in the past and if there is any contingencies, measures, initiatives you are taking?

Thank you, Isabella. We have a little bit talked about hydrology, our budget. What I can comment that El Niño as a phenomenon is not included in our budget in terms of hydrology, extra hydrology. Considering the current situation, we could have also a positive surprise in the next part of the year in terms of production. We are not considering it, thinking about our guidance and everything. From a operative point of view, we are well prepared to manage this kind of phenomena that can intense phenomena. The meteorologists say that the El Niño phenomenon is very probable that we'll have a peak of activities in the last quarter of the years.

I think that we have already shown our preparation during the first half, thinking about the distribution area, but also the generation area is ready to manage intense phenomena in the second part of the year.

Okay. Thank you, Simone. Now going to a question made by Fernan Gonzalez from BTG. The question is: Would you be willing to voluntary renegotiate regulated PPAs with the CNE? If so, under which terms?

Okay. Hello, Fernan. Thanks for the question, really, it's a little bit too early to talk about our posture about this new piece of regulation. We are waiting for operative deployment of the regulation, we are keep on monitoring the regulation, how it will evolve.

Okay, thank you. Let's see. We are receiving more questions. Just a second here. Also another one is from Alessandro Di Vito, Mediobanca. Can you remind us which is now the total stock of the PEC receivables and the updated trajectory of the recovery?

Okay. Thanks, Alessandro. Talking about the PEC. As you know, the last PEC to be recovered is the PEC 1 that will be recovered through the tariff. The deadline to recover all the receivable is end of 2027. This year, we open with a stock of more or less $100 million. So far, we have recovered a part of this. We should recover more or less $40 million during the year and the last $60 million in the next year.

Okay. Thank you. Another one also from Alessandro, following up: Could you provide some granularity on the returns you are observing on batteries in Chile? Could you also share the evolution you are observing on unitary CapEx for battery packs? Gianluca?

Yes. Thank you, Alessandro. We are not opening the returns as it too strategic. That said, we are not disclosing specific return metrics for battery projects beyond what has been communicated publicly. In terms of CapEx, we consider an average of more or less $0.9 million per megawatt. Nevertheless, each technology is consistently evolving and is affected by commodity prices and global geopolitical conditions. Batteries remain a very attractive opportunity in Chile, primarily because they improve portfolio flexibility, allow us to capture value from intra-day price spreads, reduce renewable curtailment, and optimize the use of our renewable generation fleet. Batteries are a strategic part of our growth and flexibility strategy, and we continue to see compelling opportunities supported by improving technology economics and the need of a Chilean power system.

Okay. Thank you, Gianluca. Another one that we also received. It's about the gas. Did you see some risk related to lower gas supply in Chile?

Thank you, Rodrigo. We do not see a risk related to gas supply. Due to our contract structure of gas contract, we cannot disclose further details due to strategic reasons.

Okay. Thank you, Gianluca. Moving on, we have one coming from Jay Samani from Scotiabank. Any insights on why you are seeing lower demand from mining companies given copper prices? Does the decline in free customer sales change management's confidence in capturing incremental demand from mining companies? Simone?

Okay, thanks, Jay. Regarding the lower mining consumption, really, we do not see the structural phenomena, just some adjustment of some customer, but related to very specific topics. In general, mining is, for us, a very important sales segment. In any case, our sales portfolio is spread all over many kind of customers. We can say that we are quite resilient just in case some segment have some problem and has to reduce the consumption.

Okay. Thank you, Simone. As we do not have any further questions, I would like to conclude this results conference call. Let me remind you that the investor relations team remains available to address any questions you may have. Thank you for your attention, and we look forward to seeing you soon again. Bye-bye.

This concludes our conference. Thank you for participating, and you may now disconnect.

This conference call may make statements that constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Such statements may include Enel Chile S.A. current expectations, intentions, plans, beliefs, and projections. Forward-looking statements are based on management's current assumptions and expectations, do not guarantee future performance, and involve risk 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 the Enel Chile's press release on its first quarter 2026 results. In the presentation accompanying this conference call, Enel Chile's annual report on Form 20-F on the risk factors. You may access our first quarter 2026 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 these 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.

[Foreign language] Good morning, and welcome to Enel Chile's 2026 first quarter results presentation. We greatly appreciate you taking the time to join us today. My name is Isabela Klemes. I'm the Head of Investor Relations. Joining me this morning are our CEO, Gianluca Palumbo, and our CFO, Simone Conticelli. Our presentation and related financial information are available on our website, www.enel.cl, in the investor section, as well as through our investors app. In addition, a replay of the call will soon be available. At the end of presentation, there will be an opportunity to ask questions via webcast chat through the Ask a Question link. Media participants are connected in listening mode. Gianluca will kick off the presentation by covering key highlights of the period, our portfolio management actions, and providing updates on the regulatory context.

Following that, Simone will offer an overview of our business economic and financial performance. Thank you all for your attention, and now let me hand over the call to Gianluca.

Thank you, Isabela. Good morning, and thank you for your participation. Let's start the presentation with our main highlights of the period. Let's begin with portfolio management. During the quarter, hydrological conditions were favorable, which helped us reduce portfolio risk and supported a stable operating performance across the business. We will come back to this point in more detail later on. At the same time, through EGP Chile, we started the construction of three battery energy storage projects in the northern part of the country. These BESS projects will add around 0.5 GW of additional capacity and will play a key role in strengthening the flexibility of our portfolio while supporting our commercial strategy. In addition, Enel Generación Chile signed a new LNG supply agreement with Shell.

This agreement allows us to better valorize surplus gas volumes already available and to optimize LNG and Argentine gas supply for our generation business. Importantly, this initiative is fully aligned with our long-term business vision for Chile. This is particularly relevant in the context of the growing deployment of Battery Energy Storage Systems, which are essential to ensure a more flexible and efficient portfolio. Let's now move to the country and regulatory context. Starting with the VAD 2020, 2024 process, tariff resettlements have been postponed until July 2026. At this stage, the regulator is working on alternative solutions to fund this payment with the objective of avoiding any impact on regulated customers' tariffs. Turning to the VAD 2024 to 2028 process. During the quarter, the regulator published the preliminary technical report, volume 2, in January 2026.

Over the next few months, we are awaiting the publication of the final report. Let's now turn to business profitability. The first quarter of 2026 delivered consistent financial results. EBITDA showed a solid improvement compared to previous years, plus 16% during the period. The extraordinary general meeting approved a capital increase of CLP 360 billion at Enel Distribución Chile, reinforcing the company's balance sheet and overall financial flexibility. In addition, the annual general meeting approved the final dividend, fully in line with our commitment to shareholder returns and value creation. In the next slides, we will go deeper into each of these areas and provide further details on the key drivers behind these results. Let's move to slide 4 to talk about hydrology and the progress of our battery energy storage project. Let me begin with our hydro generation.

Hydro generation during the quarter remained broadly in line with last year's levels, as shown on the left-hand side of the slide. For 2026, we are forecasting hydro generation at 10.7 TWh. This assumption is based on a conservative view on hydrology, fully consistent with the average evolution observed over the last 13 years that allows us to confirm our 2026 guidance. This is the case, even though the probability of an El Niño event has increased in recent weeks, with potential impacts mainly expected in the second half of the year. This level of performance is supported by our well-diversified hydro portfolio, together with continuous operational optimization. Moving now to gas activities. On gas sourcing, we have signed contracts with Argentine gas suppliers with a longer tenure compared to previous years.

These contracts secure firm volumes at more competitive prices, providing stable supply until April 2027. In parallel, in the context of high gas prices and the more flexible demand outlook for our thermal fleets, we concluded a negotiation related to our long-term LNG agreement. This approach is well aligned with our view of a gradual ramp-up of battery storage in the coming years, supported by a solid and reliable gas supply from Argentina. Finally, let me focus on battery storage. We continue to strengthen our generation portfolio through the development of battery energy storage systems. These investments will increase the flexibility of our portfolio and support the long-term resilience of our generation mix. In addition, they will continue to optimize our sourcing strategy.

In this context, approximately 450 MW of new battery capacity are currently under development and will gradually start operations from 12/12/2027 ahead, in line with our planned investment schedule. Now let's move to slide 5, where we will review our generation portfolio and the energy balance. Let me start with our generation portfolio. We entered 2026 with a solid and well-diversified portfolio. In fact, our total net installed capacity stands at 8.9 GW, of which 78% comes from renewable energy sources and BESS. Therefore, this structure enhances flexibility and supports a balanced and resilient energy mix. Moving now to our energy balance. During the first quarter of 2026, net production remained stable compared to the same period last year. This performance reflects the flexibility of our generation portfolio.

Higher contributions from wind, solar, and efficient natural gas combined cycles more than compensated for the slightly lower hydro generation. Physical energy sales amounted to 7.5 TWh, fully in line with the level recorded in the first quarter of last year. This confirms the stability of our commercial positioning, supported by our diversified sourcing mix. Energy purchases during the quarter, we maintained a similar purchasing mix compared to last year. This included 1.3 TWh of net spot market purchases and 0.8 TWh sourced from third parties. Now I would like to take a moment to share with you some key topics related to the distribution business, which we will cover on the next slide. Let me start with the tariff review shown on the left-hand side of the slide. We are in the 2024 to 2028 distribution tariff review process.

In January of this year, the regulator released the second version of the technical report. The remaining technical steps are expected to lead a final tariff determination in the second half of 2026. Overall, the review is progressing in line with the regulatory timetable. Turning now to the VAD 2020-2024. The settlement of the outstanding debt with distribution companies, which was originally scheduled to begin earlier, has been postponed to July 2026. For Enel Distribución, the amount to be received is around $65 million, while at the distribution sector level, the total amount involved is approximately $900 million. We remain confident that the process will progress toward the prompt resolution, considering its relevance for the sector and the need for orderly completion.

Turning to distribution reform, we continue to see constructive and positive engagement from stakeholders, together with the growing and broad consensus on the need to further evolve and modernize the distribution framework in Chile. This is particularly important in the context of electrification and considering the long-term nature of distribution investments. Finally, a few words on grids and execution. We continue to reinforce specific parts of the network, while at the same time expanding digitalization and remote control solutions across the network. These actions allow us to restore service faster, improving customer experience, and strengthen the flexibility and resilience of our networks. Overall, execution and distribution remains solid, with a clear and continued focus on service quality. With that, I will now hand over the presentation to Simone.

Many thanks, Gianluca, and good morning, everyone. I will begin my presentation with an overview of our key results for the period. As shown on the slide, during the first quarter of 2026, EBITDA reached $423 million, with a 16% increase compared to the same period of last year. The improvement was mainly driven by a better integrated margin performance. First quarter net income amounted to $162 million, representing a 7% decrease compared to the result of first quarter 2025, mainly due to higher depreciation following the commissioning of the new renewable plants and lower capitalization of interest. Finally, first quarter FFO reached $122 million, representing a 12% increase compared to the same period last year.

The improvement is due to a combination of several factors, which will be commented on the following slides. Now let's move to the next slide to talk about the investment made during the quarter. First quarter investment amounting to $111 million were mainly allocated to the development of BESS project, increasing the value of our power plant fleet, and the reinforcement of our distribution network. Let's review the allocation in more detail. 41% or $46 million were invested in renewable and storage. 31% or $34 million supported thermal power projects. 20% or $31 million was directed toward grids investments. In the renewable segment, we have focused our effort on the development of BESS project, as announced in our strategic plan, on the enhancement of hydro capacity performance, and on the improvement of fleet availability.

In the thermal segment, the priority has been the maintenance and performance enhancement of the power plant fleet. Finally, regarding grids, the focus remain on the resilience program to strengthen the distribution network and ensure service continuity under adverse weather condition. Passing to the nature of investment, first, asset management CapEx totaled $58 million, accounting for 52% of the total CapEx. The main activities have been the maintenance of Atacama, Quintero, and San Isidro CCGT, the maintenance of renewable fleet aimed at ensuring plant availability, and some activities for the corrective maintenance and digitalization of grids. Second, development CapEx amounted to $40 million, mainly invested in batteries development, which represented 75% of total, and digital meters and grids remote control equipment. Finally, customer CapEx totaled $13 million, mainly invested in low and medium voltage connection project and initiative to support load increase.

Let's now go on to the next slide, which provide a closer look at the EBITDA performance. In the first quarter of 2026, our EBITDA reached $423 million. The increase of $58 million compared to the same period of 2025 is mainly explained by the following factors. Starting with the integrated business, we recorded an increase of $67 million, mainly due to, first, lower natural gas costs that reduce the variable production cost of our thermal power plants and the spot energy purchase costs. Second, the positive impact of the optimization of gas sourcing, which allowed us to improve LNG and Argentine gas supply for our thermal fleet, extracting value from our gas contracts portfolio, as previously commented by Gianluca.

These positive impacts were partially offset by the termination of certain high-priced regulated contracts and higher provision related to energy and transmission charges adjustments booked in 2025. Going to grids, we recorded a decrease of 18%, mainly due to the positive impact of issuance provision on 2025 and the impact of the higher O&M expenses associated with the anticipation of the 2026 winter plant activities, partially offset by a higher contribution from complementary distribution activities, mainly related to the new customer connections. Now let's move to the next slide to review the net income evolution. Net income amounted to $162 million in the first quarter of 2026.

The difference compared to the first quarter 2025 is mainly due to the $58 million improvement in EBITDA, thanks to the more efficient sourcing, partially offset by higher depreciation and amortization, mainly related to the commissioning of new renewable capacity in the generation business and higher financial expenses, partially due to lower interest capitalization in the generation business. Now, passing to the next slide, let's analyze the FFO composition for the first three months of 2026. In the first quarter 2026, FFO reached $122 million as a result of the following factors. First, EBITDA totaled $423 million, as previously explained. Second, the increase of net working capital amounted to $161 million, mainly due to seasonality of energy payments and gas optimization agreement, for which the payment was registered in April.

Third, financial expenses amounted to $93 million, also including the settlement of hedging derivatives. Finally, income tax expense payments amounted to $48 million, mainly related to generation business. Passing to the comparison with the results of the first quarter of 2025, the 2026 FFO was $13 million higher, mainly thanks to the EBITDA increase for $58 million, the lower increase of net working capital for $27 million, mostly due to lower CapEx payment related to the new development capacity, the positive effect of energy payment scheduling, partially offset by the increase of account receivable following the LNG agreement settled in April, the higher financial expenses for $62 million, and the higher income taxes for $9 million, reflecting higher monthly payment tax rates. Now let's take a look at our liquidity and leverage position.

Gross debt amounted to $3.9 billion as of March 2026, remaining broadly flat compared to December 2025. The slight increase reflects the seasonal cash and working capital requirements, which were temporarily funded through a $50 million drawdown on the CAF credit line, partially offset by a $9 million reduction in IFRS 16 lease liability. The average term of our debt maturity reached 5.4 years by March 2026 versus the 5.8 years seen in December 2025, and the portion at a fixed rate was 85% of the total debt. The average cost of our debt reached 4.9% as of March 2026, in line with December 2025 figures. Regarding liquidity, we are in a comfortable position to support our capital needs for the upcoming months and cope with next year maturities.

As of March 2026, we have available committed credit lines for $640 million and cash equivalent for $454 million. Thank you all for your attention. Now I will pass the floor to Gianluca for the closing remarks.

To conclude, our resilient and diversified business model supported solid and stable results in the first quarter of 2026, even in a volatile operating environment. A well-balanced portfolio combined with disciplined execution continues to provide resilience, allowing us to navigate changes in market and climate conditions with confidence. Electrification is clearly emerging as a key driver of demand growth in Chile. This trend is supported by structural developments across mining, industry, transport and electromobility. In this context, we remain closely engaged and well-positioned to support the country's electrification process, leveraging our integrated offering of clean energy, infrastructure and services. At the same time, we continue to closely monitor regulatory developments and their potential impacts. Our solid financial position and flexible business model continue to support the execution of our investment plan and our ability to meet financial commitments.

This financial strength allows us to continue investing in renewables and battery storage while maintaining financial discipline and delivering sustainable returns to our shareholders. Let me hand it over to Isabela for the Q&A session.

Thank you very much, Simone and Gianluca. We now start the Q&A. As a reminding, we are receiving questions from our chat on the application. I will start now, Gianluca and Simone, with the first question. We actually received this question from several analysts, including Andrew McCarthy from LarrainVial. I will do the questions, okay? The first one is, congrats on the results. Apart from the gas valorization agreement, which is a positive one-off in your results, could you please indicate which other one-off negatives you have incurred in your first quarter 2026 figures? Basically, I'm interested in knowing the recurring EBITDA booked in the first quarter 2026.

Actually, on the same, we also received a question regarding what we have mentioned in the EBITDA, regarding the provisions recorded in the first quarter 2026 related to energy and transmission charges. Simone?

Thank you. Thank you for the question. You are right, in this quarter, we have more than one non-recurrent effect. The first one is the impact of the agreement with Shell. That is a positive impact, but then was partially offset by some problem with the transmission line that impacted in our efficiency. On the other side, this impact can be around $50 million, and then around $60 million of adjustment coming from the previous year. The main part from 2023, it was related to an adjustment of the ancillary services, booked in this year after quite a long discussion with the system, we finally take the final decision, and this has an impact of -$30 million. To make a synthesis, if you normalize all these non-recurrent effect, our results is around $360 million-$370 million for the quarter.

Thank you, Simone. We are receiving several questions. Let me go to the second one. The second one is coming from Javier Suarez from Mediobanca. Javier has several questions that I will split here. The first one is, can you update on the key factors on the ongoing negotiations with regulator of the distribution regulatory framework? Also on the same page on distribution, he also is asking why, in other words, what is the reasons for the postponement of the settlement to July 2026 relating to VAD 2020-2024? Gianluca, is this yours?

Yes. Okay. Let me start for the first part on the distribution regulatory framework. The VAD 2024-2028 process is still ongoing, so the methodology remains based on the reference model company with a regulated real post-tax WACC, as you know, of 6%. We believe there is still room for improvement in the CNE proposal, and we are actively participating with the distribution association in the observation and the discrepancy process. The final technical report is expected by June 2026, and the tariff decree in early 2027. Regarding the postponement of the VAD 2020-2024 settlement, the estimated impact is around $765 million.

The recovery mechanism was defined by the SEC in February 2026, but collection was postponed by three months. In this moment, our current planning assumption is collection from July 2026, while the Ministry of Energy is also evaluating alternative mechanisms, including potential debt factoring.

Okay. Thank you, Gianluca. Now, another question from Javier. The other question from Javier, Simone, this is for you. Can you give more details on the profitability of the BESS project in Chile in terms of IRR?

Yes, thanks for the question. First of all, let me make a initial comment saying that Enel is developing new BESS, following the strategical goal to balance our portfolio. First of all, we see this BESS project like an improvement of our portfolio and a way to have some energy shift that can result in a better match between the demand and the production curve. Looking at the BESS project as a standalone project, what we can say is that we launch this kind of project only if the return is at least 300 basis points above our WACC. Also that we make also some stress test trying to change the market condition to see the resilience of this kind of project also to some more stressed and critical scenarios.

Okay. Thank you, Simone. Move on. The other question is coming from Fernan Gonzalez. This is also for you, Simone, from BTG Pactual. The question is: Why did energy purchase cost in the generation segment increase so much if volumes were similar with last year and its spot prices were significantly below the first quarter 2025 levels, even in the non-solar hours? Simone.

Okay. In such a way, we answer at the beginning indirectly to this question, because this negative impact from adjustment from the past, entered as sourcing cost. You are looking also at the impact of this negative adjustment.

Okay. Thank you, Simone. Moving on, we're receiving a lot of questions. The next one is coming from Andrew McCarthy, another question from Andrew from LarrainVial. Good morning. Energy losses in the distribution segment continued to deteriorate during the first quarter 2026. Can you comment on what is driving that, how you expect to evolve, and what can be done to reverse the trend? Gianluca.

Okay. Thank you for your question. Energy losses increased mainly due to tariff adjustments and some change in customer behavior, which have led to a rise in not technical losses, such as the debt. In the first quarter, losses were also impacted by lower than expected demand and a more competitive market environment. That said, our loss levels remain below the regional averages, and we have a clear plan to reserve the trend. We are strengthening our loss reduction strategy through this plan. First of all, improved inspection targeting using better analytics. Second, expansion of micro and macro metering. This is an action to help the balance, micro balance. Increased field action and controls, considering the better analysis that we will do. Finally, enhanced coordination with authorities to address illegal connection. That is one of the problem that we have.

Looking forward, we expect losses to gradually decline, targeting around 5.7% by 2028, supported by these operational and technological improvements. That is very important for us.

Okay. Thank you, Gianluca, for the question. I'm checking here other questions. Okay, the other question is coming from Felipe Flores from Banchile Citi. The question is: My question is related to the capital increase in distribution. Will this be subscribed by Enel fully using cash? How does the company plan to finance it? It's already covered? How much would take to recover the money? Gianluca, if you can give some color on the capital increase.

Yes, of course. Okay. The capital increase is intended to strengthen Enel Distribución financial position, and it's expected to be supported by controlling shareholders in line with its long-term commitment to the business. From a financial perspective, it will be covered through group level financial resources, ensuring obviously efficiency and flexibility. In terms of returns, this is not a short-term recovery investment. It supports the long-term sustainability of the business through improved financial structure, lower financial costs and the ability to execute the investment plan under regulatory framework. This is the last question that I can add in this case. Okay.

Okay. Thank you, Gianluca. I'm checking here. We have receiving another question. Some of them, some of them, we have already talked about that is related the capital increase and also on the postponement on the VAD. I'm continue checking here. Another one was a question also, Gianluca, regarding the VAD 2020-2024, that potentially is gonna be a new pack. Gianluca has already answered this. That is one of the proposals that could be done in order to have the payment on the VAD. Let me just a second. Okay. We have other questions that is coming from Juan Felipe Becerra, that is relating.

He ask Simone, if you can give more details on the gas optimization contract on Shell. We have already included, if you can check also. Now, he has another question. Does this optimization imply lower contracted volumes or changing pricing terms with Shell? Regarding the three BESS projects highlighting the presentation, can you provide more details on the expected timeline for each project to reach COD and enter in EGP capacity? Simone?

Let's start talking about the Shell agreement. This is an agreement that has the goal to optimize our portfolio. As you know, we have a very valuable portfolio of gas contracts. Part of the contracts is for LNG. Part of this contract is for gas from Argentina. What I want to stress is that the total amount of volume of gas that we can manage is higher of our needs, even stressing the needs of our power plant during a dry year. What we have done in this agreement is try to rebalance the amount of the LNG contract to make coherent our portfolio. We did it in a very right moment in such ways. We have also positive impact on 2026 results.

On the other side, talking about the BESS.

Yeah, this is.

Okay.

Go to Gianluca.

Gianluca.

Regarding the three BESS, to complement, the answer, regarding the three BESS projects highlighted in the presentation, let me know that, we could you provide more detail on expected timeline. In this case.

Yes. The question, Gianluca, was regarding the BESS. What we are expecting the COD on the BESS side. Also what Gianluca was saying that we are expecting, it's included in our business plan that we have recently presented. Gianluca, if you want, now your mic is up.

Oh, okay. I understand.

Going back again. Thank you.

Okay. During 2025, we focused on engineering, permitting and project preparation. With the regulatory framework now in place, we are starting construction in 2026 and expecting the COD during the third and the fourth quarter of 2027. Our strategy also included additional BESS investment, like we presented in the last Capital Markets Day, in 2027 and 2028, reinforcing storage as a core pillar of our portfolio. This is our pillar in our optimization of our portfolio.

Thank you, Gianluca. Another question is coming from Jay Samani from Scotiabank. This is for you, Simone. Where do you see Enel Chile next avenues for growth, given that lower demand from unregulated customers? He's mentioned about the termination of the PPA, regulated PPAs. How is Enel Chile position itself for long term, and can we expect the company to maintain the current earnings level for growth? He's asking about our business plan.

Can you repeat me the first part of the question, please?

Yes. Jay is asking you, where do you see that Enel Chile is going? What are the strengths of our plan? He's also mentioned that we have seen the results, not the reduction of the regulated PPAs, he's asking what we are seeing the long term, no? We are seeing more regulated customer coming on, new auctions, and how we are positioning ourselves in the long term.

Okay. Enel will confirm its strategy. In this moment, clear we see a reduction in the volumes of regulated contract, but this is related in how the auction now will rise in the market. What we have to stress is that we want the full last to auction also at a valuable price on the market. We have a very good portfolio in term of price in the short term. Also, we can stress the fact that the pricing of our portfolio, the average price in the next three year, we will maintain the same value, even if the price on the market is going down. For the full following year, we will keep on looking to a good mix among short-term opportunity and also long-term contract. That can be new, regulated auction, but also, long-term contract with the big customer.

Okay. Thank you, Simone. We have a last question that is coming from Isabella from Bank of America. She's asking: What is the minimal cash position you are operationally comfortable with? You currently have a cash position of around $454 million. Do you plan on using your credit lines this year, or will you refinance your short-term debt?

Thanks for the question. You know that our business has a strong seasonality with some needs in terms of financing in the first and in the second quarter, and higher cash production in the second half. We have an internal model to define the comfortable minimal cash position to cover the networking capital needs. For the future financial needs, we plan to refinance using a long-term financing that in this moment is under negotiation.

Thank you, Simone. We do not have any more questions coming here from the chat. Any other doubts that you may have, the investor relations team will be fully available to execute other calls and to go into more details. Thank you very much for connecting today. Have a nice holiday. Thank you.

This concludes our conference. Thank you for participating, and you may now disconnect.

Good morning, ladies and gentlemen, and welcome to Enel Chile Third Quarter and 9 Months 2025 Results Conference Call. My name is Carmen, and I will be your operator for today. 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 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 9 months 2025 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 9 months 2025 results press release and presentation on our website at www.enel.cl, and our 20-F on the SEC's website at 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.

Good morning, and welcome to Enel Chile's 2025 Third Quarter and 9 Months Results Presentation. We greatly appreciate you taking the time to joining us today. My name is Isabela Klemes, and I'm the Head of Investor Relations. Joining me this morning is our CFO, Simone Conticelli. Our presentation and financial related information are available on our website, www.enel.cl in the Investors section as well as through our app investors. 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 webcast chat through the link Ask a Question. [Operator Instructions] Simone will kick off the presentation by covering key highlights of the period, our portfolio management actions, providing us updates on the regulatory context and an overview of our business economic and financial performance for the period. Thank you all for your attention. And now let me hand over the call to Simone. Simone?

Thank you, Isabela. Good morning, and thank you for your participation. Let's start the presentation with our main highlights of the period. Let's begin with portfolio management. We observed a high-level performance of our thermal generation fleet, which helped offset lower hydrological conditions during the quarter. This outcome reflects our ability to adapt to evolving market dynamics and maintain operational stability. In addition, our gas optimization activities continued to support our margin, reinforcing their strategic role in balancing our portfolio and mitigating exposure to spot market volatility. On the distribution side, we achieved successful implementation of the comprehensive winter plan aimed at strengthening grid's resilience and improving service continuity under challenging climate condition. Indeed, our performance in the period was one of the best in Chile. The winter plan included the deployment of emergency crews strategically positioned in high-risk areas, extensive vegetation management action and the installation of new telecontrol units to reduce restoration time. Additionally, targeted measures were implemented to support vulnerable customers, ensuring continuity of supply during adverse weather events. Now let's move on the Chilean regulatory context. With reference to the VAD 2024-2028, a key milestone was the publication in the last weeks of the consultant report followed by the preliminary regulatory technical report. I will give you more details about it. Furthermore, in October, was also released the preliminary regulated energy tariff report for the first half 2026. Now the generation association, of which Enel is a part of, is working with authorities regarding the outcomes of the report. Looking ahead, 2 regulated energy auctions are scheduled for the fourth quarter 2025. Let's now turn to business profitability. We closed the first 9 months of 2025 with a stable EBITDA compared to the previous year despite the difficult context and significantly lower hydrology, demonstrating the resilience of our operations. Our FFO remained positive, driven by the recovery of $261 million of receivables generated by the PEC mechanism. This inflow significantly strengthened our cash position for the year. As a result, we maintained a strong liquidity position, enabling us to support our development plan and to mitigate operational headwind associated with the market and climate uncertainties. In the next slide, we will take a closer look at these topics to provide further insight, but let me anticipate that these achievements demonstrate our focus on operational excellence and sustainable growth. We remain committed to delivering long-term value to our shareholders while advancing in the energy transition and strengthening the resilience of our business. And now let's move to Slide 4 to talk about the energy market situation, especially regarding hydrology and gas opportunities. On the left side of the slide, you can see our hydro production over the last 10 years. For 2025, we set our target at 10.7 terawatt hour based on the last 10-year average. Although 2025 has been a particularly dry year, our hydro production has remained in line with our strategic plan. This was possible, thanks to the flexibility of our hydro plants with access to hydrological basins. For this reason, we are keeping our hydrology guidance unchanged. To manage this dry scenario, we relied also on the flexible and competitive thermal fleet, supported by a strong and diversified LNG and Argentine gas supply. This helped us respond quickly to market needs and reduce exposure to hydro volatility. As a result, we increased thermal production, used competitive gas and seized favorable trading opportunity, adding $74 million in margin during the first 9 months of 2025. Regarding gas business, in October, we completed a gas sales to Europe with margins similar to those recorded in the second quarter 2025. Looking ahead to 2026, we are evaluating options to secure competitive gas from Argentina through firm contracts in line with the past year strategy. And now moving on to Slide 5, let's review our generation portfolio and energy balance. During the first 9 months of 2025, net production decreased by 9% compared to the same period of 2024. This decline was driven by lower hydro dispatch during the first 9 months of 2025, reduction in renewable energy production due to the maintenance of 2 solar plants, higher curtailment levels also caused by transmission line limitations. These effects were partially offset by higher contribution from the efficient CCGT. The same factors impacted the third quarter generation that amounted to 5.4 terawatt hour, lower by 1.1 terawatt hour versus the same period of 2024. Energy sales reached 22.7 terawatt hour, mainly due to the lower sales to regulated customers following the expiration of regulated contracts. The regulated contracts volume reduction is also the main cause for the decrease of the third quarter sale from 8.4 to 7.6 terawatt hour. And now I would like to take a moment to review an important milestone in the resilient program of our distribution business. We are pleased to share that we successfully implemented a comprehensive winter plan aimed at strengthening the stability of our grids and guaranteeing service continuity during the most challenging months of the year, particularly for our most vulnerable customers. First of all, we deployed 376 emergency crew across our service territory. These teams were mobilized to respond to outages and restore power. One of the most impactful initiatives was the execution of more than 115,000 tree trimming actions, which significantly reduced feeder failures in areas exposed to severe weather. We also modernized the grids, installing new telecontrol unit. This helped us to isolate faults and reducing service interruption time. In parallel, we implemented several infrastructure upgrade that enhanced network reliability and quality of service for more than 193,000 customers. Supporting vulnerable customers remain a priority for Enel, so we assisted more than 3,000 electro-dependents, ensuring continuity of supply through targeted measures. Among them, more than 2,000 were equipped with digital meters, while almost 2,900 receive makeup power solutions, such as generators or battery systems. Finally, we strengthened the collaboration with municipalities to improve coordination during extreme weather events. This joint approach has enhanced emergency response capabilities. All these efforts translated into tangible improvements in the performance of our distribution network with results that clearly demonstrate the effectiveness of the winter plan. And now let's take a look at Slide 7, where we highlight key updates on the energy regulatory context. In 2025, we saw key changes in the regulatory framework. The distribution cycle for 2024, 2028 is under development. In September, the consultant final report was published. Then in October, the CNE released its preliminary technical report with changes in maintenance and technical standards. Company have until the 10th of November to submit comments. The final report is expected in 2026. In parallel, we are currently awaiting settlement of outstanding debt related to the PAD decree for 2020, 2024, published in April 2025, that is expected to be settled in 2026. Passing to generation business on the 4th of October -- on the 14th of October, the CNE published the preliminary technical report for the first half of 2026. It includes a correction related to the inflection effects. We are reviewing the impact and waiting for the final report. Passing to the stabilization mechanism as of September 2025, we have $149 million PEC 1 receivable to be fully recovered by the end of 2027. Going to other relevant topics in August came into effect a resolution on BESS remuneration that authorize the BESS to provide ancillary services. In the last week, changes have been introduced in 2025 regulated auctions, increasing the volume of the 2027-2030 auction from 1.7 to 3.4 terawatt hour per year. The offer deadline is now the 14th of November, launching a 1.5 terawatt hour per year short-term auction for 2026. The offer deadline is the 2nd of December. Finally, regarding subsidies, the third electricity subsidy round run from the 3rd of June to the 15th of July, covering the period from July to December 2025. Around 341,000 annual distribution customer benefit of it. A bid to expand the subsidy is still pending in the Congress. And now I will start reviewing the highlights of our financial performance over the period. Before we review the results, a quick reminder. As of January 1, 2025, Enel Chile changed its functional currency from Chilean pesos to U.S. dollars. For comparison, 9 months and third quarter 2024 figure are short using the average exchange rate of these periods. I will enter into details of our financial and economic performance in the next slide. So let's move to the next slide to look at the progress made on CapEx. Our total CapEx reached $245 million during the first 9 months of the year, maintaining a focus on grids and power plant fleet performance. Let's review the allocation in more detail. 41% or $101 million was directed towards grids investments. 31% or $76 million supported thermal power projects. 27% or $67 million was invested in renewable and storage. Regarding grids, the focus remain on the resilience program to strengthen the grids and ensure service continuity under adverse weather conditions. In thermal segment, the priority is the maintenance and performance announcement of the power plant fleet. In the renewable segment, we have centered our efforts on finalizing the PMGD program, enhancing hydro facility performance and maintaining fleet liability. Now let's move on to the breakdown by nature. Asset management CapEx totaled $139 million, accounting for 57% of total CapEx, mostly used for the maintenance of Atacama Quintero and San Isidro CCGT, the improvement of renewables fleet availability and corrective maintenance and digitalization of grids. Development CapEx was $60 million, mainly driven by investment for grid reliability enhancement, digital methods programs and telecontrol deployment and for the completion of 2024 investment program for PMGDs. The 2025 development CapEx for battery-related project will be recorded starting from the next quarter. Finally, customer CapEx totaled $46 million, mainly invested in low and medium voltage connection projects and initiatives to support load increase. Let's now turn to the next slide, which provides a closer look at our EBITDA performance. During the last quarter, our EBITDA totaled $345 million, representing a decrease of $63 million compared to the same period of 2024, mainly explained by the following factors. Starting with the generation business, we recorded a decrease of $89 million in PPA sales, mostly due to the termination of some high-price regulated contracts that impacted on volumes and average price of regulated portfolio, partially offset by the negative impact of exchange rate hedges recorded in 2024. Regarding sourcing, its contribution remained in line with the same period in 2024. This result was mainly achieved, thanks to our optimized sourcing strategy and the issuance provision, mainly coming from GasAtacama, which effectively offset higher cost in the energy spot market mainly due to the higher purchase volume. Gas trading contributed positively with a $5 million margin increase, mainly fueled by expanded trading activity in the third quarter of 2025. Turning to grids. We recorded a positive impact of $17 million, mainly driven by regulatory provision reflecting the settlement adjustment for the previous year and higher OpEx recorded in the third quarter of 2024 due to the extreme weather events that occurred in May and August. These effects were partially offset by the increase of OEM expenses, mainly associated with the implementation of the comprehensive winter plan. And now let's move on to the next slide to review the main impacts on EBITDA during the 9 months period. Our EBITDA reached $1,004 million, remaining flat compared to the same period of 2024. Starting with the generation business, we recorded a decrease of $244 million in PPA sales, mainly due to the termination of high-price regulated contracts, partially offset by the negative impact of exchange rate hedges recorded in 2024 and the positive price effect due to the indexation of the free market contracts. Regarding sourcing, we recorded a positive effect of $192 million despite the $34 million negative impact related to the transmission line restriction following the February blackout and the additional second quarter issues. The result was obtained, thanks to lower spot and third parties energy purchases costs, energy settlements from previous periods, already anticipated insurance provision and finally, lower transmission costs. In the first 9 months of 2025, gas margin contributed for $27 million, also thanks to the increase of the gas trading activity versus the same period in 2024. Passing to grids, we recorded a positive impact, primarily driven by the provision reflecting the higher tariff expected for the 2024-2028 regulatory period and tariff indexation, some settlement adjustment from the previous year, higher OpEx recorded in the period 2024, mainly due to the extreme weather events, partially offset by the increase of OEM expenses, mainly associated with the implementation of the comprehensive winter plan. We also recorded an increase of generation costs due to the new developed capacity and the maintenance activities. Finally, in 2025, specifically in the second quarter, we recorded the personnel cost one-off effect, mainly for the incentivized early retirement plan to support the company organization aimed at improving internal skills and performance. And so now let's move on to the next slide, where we will review the net income evolution. Our 9-month 2025 net income reached $352 million, a 21% decrease compared to the last year's figure, mainly explained by higher depreciation, amortization, impairment and bad debt expenses for $84 million, mainly due to the commissioning of new renewable capacity amounting to $32 million, the impairment related to our decision not to proceed with the new PMGD solar project initially planned for development in this area. And finally, the $12 million increase of grid's bad debt provision, mainly due to the higher billing resulting from tariff increase and long overdue customer debt. Regarding financial results, we recorded a negative variation of $38 million, mostly explained by the lower capitalized expenses on renewable projects by $61 million, partially offset by lower financial expenses for $29 million resulting from lower average outstanding debt and lower average interest rate. The latter was partially offset by a $20 million reduction in corporate income tax expense, mostly explained by lower results. Focusing on the quarter, net income decreased by $74 million, mainly due to a $63 million decrease in EBITDA, a $29 million increase in depreciation, amortization and bad debt, primarily due to the operation of new renewable capacity and an $11 million increase in financial results, mainly due to the lower capitalized expenses on renewable projects. The latter was partially offset by a $23 million reduction in corporate income tax expenses mostly explained by lower results of the period. And now let's move on to the FFO analysis on the next slide. Let's analyze the FFO composition for the first 9 months of 2025 and the main effect compared to the same period in 2024. Our FFO reached $615 million, representing an improvement of $248 million compared to the previous year. This is due to the following factors. First, EBITDA totaled $1 billion, remaining flat compared to the same period last year, as previously explained. Second, the recovery of PEC receivable in 2025 contributed for $285 million, mainly thanks to factoring executed in April 2025 related to PEC 2, 3 and recovery to the tariff of $31 million of PEC 1 receivable. It is worth mentioning that we offset a positive FFO variation of $248 million versus the 9 months 2024, thanks to the end of accumulation of PEC receivable started in October 2024. Third, the increase of net working capital impacted for $329 million, mainly due to the 2024 development CapEx payment, lower collection in our distribution business and other seasonality effect. The increase was higher by $255 million versus previous year, mainly due to the negative effect of energy payment scheduling and the voluntary compensation paid in 2025 regarding the extreme climate event from May and August 2024. These effects were partially offset by lower CapEx payments related to renewable capacity. Fourth, the income taxes impacted on FFO amounted to $231 million, mainly due to the tax payment in the generation business. Income taxes paid in the 9-month 2025 were higher by $63 million compared to the 9 months 2024. This difference is mainly due to the increased tax payment in the generation business, driven by both higher results and higher monthly payment tax rates. Finally, financial expenses were $130 million, mostly due to the debt related costs. This represents a reduction of $52 million compared to the 9 months 2024, mainly driven by a lower average debt this year. And now let's take a look at our liquidity and leverage position. Our gross debt is $3.9 billion at the end of September 2025, in line with the gross debt as of December 2024. The average terms of our debt maturities decreased from 6.2 years as of December 2024 to 5.5 years as of September 2025, and the portion at the fixed rate is 87% of total debt. The average cost of our debt reached 4.8% as of September 2025, decreasing from 5.0% in December 2024, in line with our efforts to optimize the financial costs. Regarding liquidity, we are in a comfortable position to support our capital needs for the upcoming months and cope with the next year maturities. As of September 2025, we have available committed credit lines for $640 million and cash equivalent for $373 million. And now I would like to share the following closing remarks. In the coming months, significant regulatory updates are expected that will clarify tariffs and market mechanisms. These represent an essential step to refine our long-term strategy and to assure that our investment decisions remain aligned with regulatory developments. We are implementing proactive initiatives to address portfolio dynamics and climate challenges. This includes action to strengthen our generation and distribution businesses, improve risk management and enhance our ability to respond to extreme weather events. The measures are designed to safeguard service continuity and maintain system stability. Our solid financial position and flexible business model allow us to follow with our business plan, even through market uncertainties, while continuing to invest in strategic renewable and BESS project and deliver sustainable returns for our shareholders. Finally, we are preparing for our 2026 Investor Day scheduled for the first quarter 2026, where we will share a comprehensive view of our strategy and the actions that will drive long-term value creation. And now let me hand it over to Isabela for the Q&A session.

Thank you, Simone. Now let's move on to Q&A session. We will be taking questions via chat through the webcast. The Q&A session is now open. Okay. So Simone, the first question is coming from Rodrigo Mora from Moneda. Rodrigo has 4 questions, so I will be talking one by one, okay? So the first one is, what is the amount that Enel Chile must return to customers due to the miscalculation of the CNE included in the first half 2026 PNP report?

Okay. Thank you, Rodrigo. Just to give some context. So in the first half of October, the CNE explained that they have changed the formula for the calculation of the PNP. And so this change in the formula will have some impact. We have calculated the impact for Enel in an amount that is between $40 million and $45 million. So we have to expect a negative provision in terms of mainly financial costs. So the impact will be mainly in the financial items. And -- but in your question, you talked about customer, but in any case, just comment that the customers were impacted just for a small amount because just the 2% of the total amount of the changes was transferred to customer in the tariff. So this amount will be accrual by Enel in 2025, and then we will pay back. In this moment, the process is not so clear. But in any case, we expect in the first half of 2026. But the amount, we will have not impacted directly for the total value of the customer.

Okay. Thank you, Simone. So the second question now is on Enel distribution. So what is the amount on to Enel's distribution Chile in connection to the VAD 2000, 2025, please?

So talking about the remuneration period of 2020, 2024, we are really not finalizing the last steps of the process. So the amount was ready to be defined. And what we are waiting is that the sector will say when we have to receive back the missing part. And the amount, in this case, is around $50 million, $55 million. There are 2 possibilities. If you want to be prudent, you can imagine that this the cashback can start middle of 2026, even if I remember interview of the new Minister of Energy that say the process can also be faster and start earlier.

Okay. Thank you, Simone. So now let me check here. We have the third question. So the third question of Rodrigo now is on generation side on the LNG strategy. So could you please explain about your strategy regarding LNG and Argentina gas firm or interruptible? For the year 2026, how many ships do you plan to buy?

So as you know, for us, the gas business is very important business because we need gas for our thermal power plant, but also because we find during the year some creative opportunities to make margin to our gas contract. We have basically a long-term gas contract for LNG. And more or less, the volume for this contract for any addition in more than 32 teraBtu per year. And so in 2026, we'll keep on using this contract. In these very days, we are working -- we are negotiating Argentinian supplier to the new contract for Argentinian gas. And so in this moment, I cannot talk about this negotiation. The negotiation is ongoing as well and has not been finalized.

Okay. Thank you, Simone. Now the last question of Rodrigo is regarding CapEx also on generation business. Regarding CapEx for generation, could you please give us an update for 2025? And actually, we also received the same question from balance as well.

So very well. Talking about this year's CapEx, as you know, we follow the plan with one exception that was the CapEx for the development of the new system because we recorded a little delay for this project and it was due to strategic reason. I mean we have the new piece of regulation related to BESS. I mean the regulation for the participation of BESS in the ancillary service market. And then we keep on starting the evolution of the market and the penetration of the BESS in the Chilean production system. So we started a little bit late in the project. And in the first 3 quarters, the amount of CapEx for this project was reduced compared to the expectation. But the projects have been already started are ongoing. And so you will see in the last quarter -- in total, talking about AGP and generation investment for more or less USD 150 million, USD 160 million. And a part of this investment will be the BESS, at least $50 million. And then we keep on growing also in investments on thermal fleet and how strategic is the thermal fleet. And of course, in case of low water in the system, our efficient CCGT plants are called to produce. And so we have to keep on these plans at the highest level of efficiency and performance.

Okay. Thank you. And we have a final one. Sorry, Rodrigo. We have 5 questions from Rodrigo Mora. So the last one is on distribution side, okay? On distribution, could you outline the measures being taken to address the increasing energy losses?

Okay. Talking about losses in energy, we have discussed the losses getting higher in the last 2 years, started from 2023. And so in this moment, the percentage of losses is a bit higher than 6%, which is the reason -- can be many reasons, but the most important reason is the increase in the target. So the final customer. And so a little bit a change in EBIT related also to this increase in tariff. What we are doing? From one side, we are increasing the activity to recover these losses. And so we have recovered more than expected in the initial planning related to losses. And on the other side, we are making other action, for example, launching flexible payment plans for the customers that want to pay the new bill. We have a new smarter special tool. We work on formulas to localize where the losses are originated and we can intervene. And finally, we are working with the regulator to try to find changes also in the regulation that can help to contain this phenomenon.

Okay. Thank you, Simone. Now move on. We have questions from Javier Suarez from Mediobanca. Thanks for the question. So the question is, is the company Enel Chile confirm its latest guidance?

So the answer is simple, it's yes, but just some context. This was a very tough year in terms of hydrological situation. So finally, the season was drier than expected. But in any case, we show our flexibility as a company. We leverage on our very profitable gas contract. We use the flexible and efficient CCGT. And so we have those effects. So we maintain high production. Also our hydropower plant can use reservoir. And so also the production for Enel did not decrease so much. And given all this action and the flexibility the company built in the past year, we can react to this adverse climate conditions and achieve -- we can confirm the results for the year.

Okay. Thank you, Simone. So move on. The next one is also from Javier Suarez, Mediobanca. It's about the FFO. So could you explain the dynamics of FFO during the 9 months of this year? And your expectation by the year-end?

Okay. Talking about the FFO, talking about our business, the FFO usually is concentrated in the second half of the year and particularly in the last quarter. And the main reason is that EBITDA is higher in this period and so on. This year, in the first 9 months, and this week, we had a very high level of FFO. And this was -- thanks to the not ordinarily cash-in from tech regulatory process. So we cash in around USD 300 million recovering cash credit from the past. Looking ahead, the cash flow from ordinary business will be higher compared to the first months in the last period. And also, we will have more efficient management of the net working capital because in the last part of the year, the CapEx are focused in the last part of the year. So also the net working capital can be managed in a more efficient way. And so we expect to improve the performance of FFO in this last quarter, which is more or less the dynamic.

Okay. Perfect. So now the next question is coming from Fernan Gonzalez from BTG Pactual. So Fernan is talking about the BESS, not the storage that we are implementing. So I will read here. I saw that BESS Las Salinas, 200 megawatts and BESS Acebache, 58 megawatts were declared under construction at the CNE. So these projects involve additional solar capacity or just the energy storage. There are still an additional 200 megawatts of BESS capacity to meet your announcement plan. Will this be added to exist in solar PV in the North?

Yes. So talking about the strategy on BESS, we have launched 3 projects this year in line with what was expected in the plan. And these projects are hybrid projects. So we are going to implement BESS system in solar power plant in the North. And while we do this, in general, the BESS can be profitable also like a stand-alone device. But the profitability is higher if you use the BESS system to [ improvise ] our power plants and why? Because the project in faster. You need less environmental document to be produced, considering that you are building the BESS in your plant and also we have some savings in terms of cost and electrical infrastructure. And so I think that I have answered the question. At this moment, we are not increasing the solar capacity. You are just equalizing solar project.

Okay. So let me check here. So we have another one from [ Thomas Peruchi ], Balanced Capital. Well, part of the question was already answered. So I'll just keep the one that wasn't here. So thank you for the presentation. And he has one question. If I'm not mistaken, you had a target of -- for 2025 of $500 million for expansion projects, mainly relating to batteries to storage. How has that changed by now, given that you are expecting a resolution on ancillary services before moving forward? And was the resolution in line with your expectations? Do you think we will be enough to unlock high investment in storage?

Okay. So in our current power plant, we put more or less 600 megawatts of new capacity. And you are right, 450 average in BESS projects. This well project should have been launched at the beginning of the year and were launched during the second launch. And so you can expect a movement of the COD. The recent COD was in 2026 in the second half. And then the new COD will be in 2027, and this will have an impact. But in any case, we start from a fleet of around 9 gigawatts of production and so this change is not a huge change. Talking about regulation. So in August, the 4th of August was largely in new regulation that say that BESS can participate in Chile service mark. It means that this is a very good news for the country because the BESS very means important element that can stabilize the system at a very low cost. And so usually because for the system, it is also reducing the cost for the participant. In terms of revenues, it's not a huge increase, but it's in line with what we expected. Talking about the current BESS that we have, the BESS that we have already installed, it means that amount USD 5 million and USD 7 million per year. But in any case, it's an important step because a permit to meet the BESS project is little bit more profitable than considered in the beginning. And it means that they are profitable also imagining a higher penetration of BESS project.

Okay. Perfect. So we have the last question that is from Edward Palma from Itaú Asset. So the question is, do you have any news for unregulated PPA contracts?

In this moment, no, we don't have any news related to this stock.

Okay. Perfect. Let me just check if we have no more questions. Okay. As there are no further questions, we formally conclude our conference call. The Investor Relations team is at our disposal for any further inquiries. Many thanks for joining us, and have a great rest of the week. Thank you.

And ladies and gentlemen, this concludes our conference. Thank you for participating. You may now disconnect.

Good morning, ladies and gentlemen, and welcome to Enel Chile Full Year and Fourth Quarter 2024 Results Conference Call. My name is Carmen, and I'll be your operator for today. [Operator Instructions] Please be advised that today's conference is being recorded. 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 and reporting its full year and fourth quarter 2024 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 full year and fourth quarter 2024 results press release and presentation on our website at 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 date. 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 becomes 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.

Good morning, and welcome to Enel Chile's 2024 fourth quarter and full year results presentation. Thanks to you all for joining us today. My name is Isabela Klemes. I am the Head of Investor Relations team. Joining me today are CEO, Giuseppe Turchiarelli; and our CFO, Simone Conticelli. Our presentation and related financial information are available on our website, www.enel.cl in the Investors section and on our app Investors. In addition, a replay of the call will be soon available. At the end of this, there will be an opportunity to ask questions via phone or webcast chat through the link Ask a Question. Media participants are connected only in listening mode. Giuseppe will start the presentation by covering key highlights of the period. He will then discuss our portfolio management actions, provide updates on regulatory context and share our guidance achievements. Following that, Simone will offer an overview of our business economics and financial performance. Thank you for your attention. Giuseppe will now take over the call.

Thank you, Isabela. Good morning, and thanks for joining us. Let's start the presentation with our main highlights of the period on Slide 2. Our hydro portfolio performed exceptionally well with hydro generation increasing by 12% compared to last year. This performance was a result of a higher reservoir level at the beginning of the year, influenced by El Nino phenomenon observed in 2023 and a solid rainy season during 2024. Also on hydro, we are pleased to announce that the Los Condores hydro power project has finally been connected to the system. The plant is already in full capacity mode generation. All the tests were concluded and we are now expecting to receive the COD in the next weeks. As we reviewed last quarter, the force majeure climatic event on August severely impacted our distribution concession area. In this presentation, I would like to provide you with some updates on the additional measures we have been taking to prepare for the future climate events, while we do not see changes in distribution regulations. Regarding the August event, I would like to emphasize that Enel Distribucion was the first distribution company to request and agree on a voluntary compensation plan for its clients impacted by the force majeure event in August. Also, I will give you more color on how we are in terms of VAD 2024-2028 process and the tax situation, considering the publication of PNP the regulated consumer tariff during January this year. Regarding the business profitability, I'd like to remind you that we changed the company's functional currency during the fourth quarter. This led to a non-cash impact of $657 million at the EBITDA level. As we have emphasized before, this will not affect the dividend distribution for our shareholders. Throughout the presentation, we will discuss adjusted EBITDA and net income, excluding this impact. Taking the adjustment, I'm pleased to announce that our adjusted EBITDA and net income results were fully in line with the 2024 guidance, reaffirming the confidence in our strategic plan. In terms of FFO, we see an important improvement versus last year, coming mainly from our EBITDA and the PEC factoring executed in the fourth quarter. I will provide more detail on this later. Now let's review some updates regarding our generation sourcing, beginning with the hydro and natural gas situation, as outlined on Slide 3. The positive hydrological condition during 2023, which led to a greater water availability from the beginning of 2024, coupled with the higher than expected rainfall recorded in 2024, allowed us to increase our hydro production. This resulted in a 12% increase compared to the 2023 period, equivalent to 1.5 terawatt hour of additional hydro generation. The hydrological situation in our reservoir continued to be comfortable year-to-date compared to the last year figures despite experiencing a La Nina phenomenon. However, for the year, we have chosen to adopt a conservative strategy and set our hydro condition target for our hydro fleet close to the average of the last 10 years, equivalent to 10.7 terawatt hour. To strengthen and diversify our portfolio, we have strategically secured contracts with a variety of Argentinean natural gas provider for 2025. Unlike previous years, this agreement covered the entire year, not just the winter and summer period. This approach enhanced our visibility of both prices and quantities, providing us with a more stable and predictable supply for the year. Furthermore, while Argentinean gas remain highly competitive, our strategy continue to be anchored to our long-term and firm LNG contract with Shell. This dual sourcing strategy ensure the security of our required volumes and offer the flexibility to explore trading opportunity in both internal and external market. This proactive measure position us strongly to navigate market and climate fluctuation and capitalize on opportunity. Let's continue discussing our generation sourcing with a focus on the development of our portfolio on generation assets now on Slide 5. I would like to start emphasizing that in 2024, we successfully completed the expansion of our renewable portfolio across the country, increasing our exposure to battery energy storage. This milestone represents a crucial step in our strategy to diversify and make our portfolio more flexible. Our ongoing efforts to advance battery regulation for ancillary services are vital for boosting market competitiveness and reducing system costs. In 2024, we received authorization from the National Electricity Coordinator to begin commercial operation of a total of 693 megawatts. This includes 385 megawatts of solar, 202 megawatts of battery storage and 106 megawatts of wind capacity. Additionally, we successfully connected 404 megawatts of renewable capacity in 2024, bringing our total capacity to 8.9 gigawatts. Today, almost 80% of our total capacity is renewable and BESS. As anticipated in the fourth quarter, we connected Los Condores hydro power plant into the grid. The plant is already operating in a testing mode until we receive approval for the coordination to commence commercial operation. The good news is that we are generating at high levels. To date, we have received approval for the 11 testing procedure requested by the system coordinator and have sent a letter formally requesting approval for commercial operation last week. Therefore, it is reasonable to anticipate authorization by March this year. Now on the next slide, we will review the performance of our generation KPI. Net electricity generation totaled 24.6 terawatt hour as of December 2024, exceeding by 2% the production during 2023, mainly due to higher hydro and renewable generation resulting from the improved hydrology this year and the operation of new projects. During the fourth quarter of 2024, net generation decreased 8% to 6.1 terawatt hour, mainly due to lower thermal dispatch during the fourth quarter 2024, lower other renewable production and slightly better hydrology recorded during 2023. Our energy sales totaled 33.4 terawatt hours during 2024, 8% higher than the level recorded in the previous year, resulting from higher sales to both regulated customers and free clients. Our commitments with our clients were fulfilled with a higher portion of our renewable generation, coupled with an efficient portfolio of purchases to third-parties. Regarding the latter, in terms of our balance during 2024, we increased our purchases from third-parties by 2.3 terawatt hours as part of our continued efforts to diversify and optimize our energy sourcing. During the fourth quarter 2024, physical energy sales grew by 6% to 8.1 terawatt hours, mainly due to higher sales to regulated customers. Now I would like to take a few minutes to talk about the extraordinary weather events of last August. I would like to provide updates on the extreme weather events that impacted our concession area in August 2024 and discuss our preparation for future events. Just to recall, on August 1 and 2, an extraordinary and unpredictable storm with winds of up to 124 kilometers per hour impacted the metropolitan region, causing extensive damages. This storm severely affected our electricity distribution network, resulting in widespread power outages and making system restoration extremely challenging. We requested the local regulator to declare the August 2024 storm as a force majeure event, but it was rejected. In response, we filed a reclamation remedy with the Santiago Court of Appeals to overturn the Superintendencia de Electricidad y Combustibles' decision, SEC. On September 30, 2024, the Santiago Court of Appeals accepted our reclamation remedy requiring the SEC to provide substantial information about our claims. As anticipated on November 2024, the SEC report recommended rejecting our claim. We are now awaiting the court's file resolution, which remains pending and we stand confident in our position. Still related to the event in August, last January, the SEC imposed a $20 million fine on Enel Distribucion. This fine is the largest ever imposed on electricity provider in Chile for service disruption, among other issues identified by the SEC. Enel Distribucion booked 100% in December 2024 of the fine, but filed an administration remedy, reiterating that August climate event was an unforeseen and resistible force majeure under Chile current legal and regulatory framework. We are awaiting the SEC formal response to our appeal. On February 4, 2025, Enel Distribucion as part of a voluntary collective procedure became the first distribution company in Chile to reach a voluntary agreement with the National Consumer Services, SERNAC, to establish an extraordinary compensation mechanism for residential customer affected by the prolonged power outages. The agreement includes a total voluntary agreement of approximately $80 million, benefiting around 800,000 customers. This amount is divided into first, compensation of interruption; second, compensation for claims; and third, compensation for the loss of food, medicine and similar items. This agreement is separated from the legal compensation that are pending the resolution of the force majeure and aggravated abnormal state reclamation remedies. The impact of this voluntary agreement program was also recorded in our 2024 financial results, as Simone will show you later. Despite several regulatory and legal discussions surrounding the August event, we have introduced many initiatives to improve the response of all parties involved in the future climate event. We believe that climate changes will make such events always more present. Therefore, it is essential for all parties to act promptly and effectively to ensure the proper functioning of the networks. Let me provide you with some examples. We agreed on operational emergency guidelines with the municipality to better coordinate with our operational teams during climate events. We signed a collaboration agreement with the electro-dependent group to ensure back-up for medical devices and to provide training on the correct use of the KIP. We accelerated the rollout of the smart meter program for electro-dependent clients. And we conducted through preventive aerial inspection of the grid in preparation for the upcoming winter, particularly to identify any potential additional damage from the August events and to address any further needs for preventive training. Part of these actions were already included and presented as part of Enel Distribucion 2025 autumn and winter season plan, which was submitted to the SEC on February 19, 2025. In the distribution sector, we remain committed to promoting reform and modernizing the regulatory framework to enhance asset resilience. This effort will enable us to optimize the value of our distribution network, fully meet our clients' needs and ensure long-term sustainability. Talking about regulation, let's take a look at the main update on the next slide. A supportive regulatory framework is crucial for attracting investments necessary for the energy transition and providing resilience against increasingly extreme frequent events to climate change. Therefore, we continue to advocate for a new model based on real assets that addresses factors such as proper remuneration rates and incentives mechanisms for resilience, quality and performance improvement. We appreciate the consensus among academia, the electrical industry and the Congress on the urgency of the distribution reform and hope it will soon be part of the legislative agenda once the legislative member return in March. The process for the 2024-2028 VAD has started using the same methodology applied for the 2020-2024 cycles, the reference model company. The delivery and official publication of the consultant final report are expected by the end of March. And we estimate that by the second quarter of 2025, the regulator will publish the preliminary technical report on this new cycle. We expect an improvement in remuneration for this new process, considering the newly approved Valor Nuevo de Reemplazo, VNR, and all the economic and technical assumption of the December 2022 included in the report. We believe that this factor will be confirmed in the various stages of this process. Regarding the PEC, since October of the last year, we have not accumulated additional receivables as the client tariff now reflect the real contract price. In December 2024, the decree for the first half of 2025 PNP was published and the regulated tariff was updated. In this process, the average residential consumer in the metropolitan region of Santiago experienced an average increase of around 12%, mainly due to the integration of the client protection mechanism MPC into their tariff. This mechanism allows for the gradual repayment of accumulated debt to the generator and establish a transitional subsidy for the most vulnerable clients. On the other hand, clients with consumption higher than 350 kilowatt hour per month that have been paying for this mechanism since last year saw a decrease of approximately 3% compared to the tariff from the last year. Related to the PEC accrual as of December 2024, we had an account receivable related to the PEC already net of factoring and including the adjustment and interest of around $500 million, showing a reduction of around 40% versus 2023. This reduction is mainly due to the factoring executed last October 2024. We expect to execute a new factoring during the second quarter of 2025 of around $250 million. Let's move to the right side of the slide where we will review the key points of the government's proposed law to expand subsidies, which currently benefit around 1.8 million families. The new proposal aims to extend coverage to approximately 4.7 million families, targeting the 40% most vulnerable households in Chile. In January 2025, the Chamber of Deputies approved the government's proposed tax with some changes. The proposal, which will now move to the Senate for its second legislative stage includes various instruments to fund the subsidies. The key instruments to fund the subsidy are as follows; allocating the additional VAT revenue that the treasury is collecting due to the increase in the tariff, implementing a temporary surcharge on the green tax emissions, increasing it from the current $5 per ton of CO2 emitted. Also in this project, the Chamber of Deputies has approved the following; increasing the amount of compensation that the distribution company must pay to clients in case of distribution power outages and for what concerns the small and medium companies replacing the price of electricity currently provided through the regulated contract with a price that includes a reduction coming from the electricity prices of PMGD in order to offer a tariff discount to this client limited to 500 gigawatt hour per year. At Enel, we support the government efforts to assist the most vulnerable families amid potential economic challenges. While this solution aims to provide necessary support, it is important to ensure that they do not disrupt the market as occurred since 2019. For a sustainable approach, it is essential to consider a measure that preserve long-term investment, competitiveness in the energy sector. We believe that allocating additional VAT revenue could be a viable and sustainable option among the proposed measures. I will now conclude with our commitment and deliverable on Slide 9. Let me point out that we have reached our main financial targets for the year 2024. Our results adjusted for the non-cash effect of the change in functional currency show an EBITDA of $1.4 billion and a net income of $0.6 billion. These achievements reflect our ability to generate value in a resilient and flexible manner. Even in a challenging environment, a more efficient portfolio mix driven by improved hydrology condition allowed us to meet our EBITDA and net income commitments of our guidance announced during 2024 Investor Day. Simone will provide details on our performance on EBITDA and net income in the following slides. The action taken during 2024 have ensured the fulfillment of our leverage and net debt to EBITDA commitment, allowing us to recommend maintaining the committed payout in our guidance. This recommendation was also endorsed by the company Board of Directors and will be submitted for approval at the 2025 Annual Shareholder Meeting. Now I will hand over to our CFO, Simone Conticelli. Simone, the floor is yours.

Many thanks, Giuseppe, and good morning, everyone. I will start my presentation with a summary of our main results for the period. First, to better evaluate our company's earnings performance, we present the 2023 and 2024 figures adjusted by the following one-time effects. For 2024, full year and fourth quarter EBITDA and net income have been adjusted by the non-cash effect of the change in the functional currency, respectively amounting to $657 million and $468 million. For 2023, the full year and fourth quarter net income exclude the capital gains obtained from the sale of Arcadia executed last year and amounting to $163 million. And the full year FFO exclude the taxes paid on capital gains obtained from the sale of Enel Transmision amounting to $310 million. Considering this adjustment, let's pass through the analysis of economic and financial performance, starting with a quick overview of the key figures, which I will detail in the following slides. Adjusted full year 2024 EBITDA and net income recorded significant improvements when compared to the previous year indicators despite the negative impact of the force majeure event of August 2024. This is mainly explained by a more efficient sourcing mix boosted by a better hydrological situation and an increase in our energy sales and better pricing. These results demonstrate the resilience of our business and the solidity of our strategy. Furthermore, the full year 2024 figure show an important FFO increase versus previous year, mainly due to a better EBITDA and the PEC's factoring operation with a significant impact on the fourth quarter. And now on the next slide, let's review the progress on CapEx. Our total CapEx reached $583 million during 2024, 19% lower than the previous year, considering the conclusion of several renewables and storage projects over the 2023-2024 period. 61% of the total CapEx amounting to $355 million was mainly related to renewable and storage deployment CapEx and 22% equivalent to $130 million was related to grids. Asset management CapEx reached $203 million, which represents 35% of our total CapEx. It increased around 77% compared to 2023 figures, mostly due to the following facts in both businesses. In the generation business, an increase of $58 million was mostly related to maintenance activity in the Atacama CCGT power plant and also in the solar and wind assets. In the distribution business, an increase of $30 million due to climate event emergency and maintenance activities related to the line failures. Finally, the development CapEx reached $318 million, a decrease of 40% compared to 2023 figures, mainly due to the conclusion of renewable and BESS projects. So let's move to the next slide where we have a summary of the fourth quarter EBITDA breakdown. During the fourth quarter 2024, our adjusted EBITDA reached $424 million, excluding, as anticipated, the one-time and non-cash effects of the change of functional currency. The $5 million increase compared to the same period of 2023 is primarily due to the following effect. In the generation business, we recorded a $71 million increase due to a significant contribution from PPA sales. This growth is mainly related to pricing FX, primarily due to contract indexation in the free market and higher volumes, especially in the regulated market. Additionally, we recorded an increase of $33 million due to positive performance in our generation. This is mainly explained by lower production costs resulting from reduced thermal generation dispatch, partially offset by higher commercial costs. The positive performance of generation business was reduced by $68 million, mainly due to the reduction of gas trading margin given the 2023 outstanding results. Regarding grids, we recorded a $9 million positive impact mainly due to an increase in remuneration associated with the rise in the Valor Nuevo de Reemplazo, VNR. However, this margin was more than offset by the impact of last year extreme weather events, including the force majeure event on August. The impact amounted to $41 million, including fines and clients voluntary compensation program. So let's move to the next slide to review the full year EBITDA breakdown. In the full year 2024, our adjusted EBITDA reached $1,421 million, not considering the impact of functional currency change. The increase versus 2023 amounts to $320 million, primarily due to a significant contribution of $321 million from PPA sales in the generation segment, mainly explained by higher volume, especially in the regulated market and pricing effect related to the contract indexation in the free market. The positive impact of $227 million from the generation sourcing activity, mostly due to lower variable production costs resulting from lower thermal generation, thanks to the remarkable hydrology during the year. And lower price in spot market purchases, partially offset by higher purchases from the third-parties. The reduction of gas trading margin compared to 2023 outstanding performance amounting approx to $0.2 billion. Finally, regarding grids, we recorded a $31 million positive effect for the full year, primarily due to the increase in the remuneration linked to the publication of VAD 2024 regulatory report, the increase in the Valor Nuevo de Reemplazo and the tariff indexation, partially offset by higher technical losses and the negative impact of inflation on our costs. These results were more than offset by the impact of extreme weather events that amounted to $62 million for the full year, including fines and clients' voluntary compensation program. And now let's move to the next slide where we will review the net income evolution. Our full year 2024 net income amounted to $622 million, 22% higher than last year figure, mainly explained by the already commented EBITDA improvement. So now let's comment the additional effects for this year. Referring to depreciation, amortization, impairment and bad debt, we recorded higher cost for $81 million, mainly resulting from higher depreciation in Enel Green Power due to new added renewable capacity and Chilean peso devaluation in the period. An impairment made in December 2024 related to Las Salinas expansion projects, higher bad debt accrual in grids due to a worsening in clients' payments behavior and higher tariffs. Regarding financial results and equity investment, we recorded a $75 million negative variation versus last year, mainly explained by positive exchange rate differences in 2023 and higher financial expenses, mainly due to FX variation and higher amount of PEC receivable also in 2023. Finally, on income taxes, we recorded a $39 million increase mainly due to better results in the period. Focusing on the quarter, our adjusted net income decreased by $37 million. This is mainly explained by, first, the difference of impairment accounted in the period for $29 million; second, the higher financial expenses for $10 million, mainly due to lower interest recognition related to PEC 2 in the fourth quarter 2024, partially offset by positive exchange rate differences in 2023. These effects were partially offset by lower tax expenses of $2 million, mainly due to lower EBITDA in the fourth quarter 2024. And now let's move to the FFO analysis on the next slide. Let's analyze the FFO composition for 2024 period and the main effects when compared to 2023. It is worth mentioning that the 2023 FFO figures have been adjusted by $310 million related to taxes paid on capital gains from the sale of Enel Transmision Chile in December 2022. 2024 FFO reached $1,209 million. It means an improvement of $332 million versus 2023 as a result of the following factors. First, the adjusted EBITDA amounted to $1.4 billion with the already explained positive variation of $320 million versus 2023 result. Second, the cumulative negative impact of the stabilization mechanism amounted to $310 million, which was more than offset by the execution of the IDB factoring related to PEC 2 and PEC 3 amounting to $697 million. If we compare the 2024 total FX of the PEC net of factoring versus 2023, we see an increase of $393 million. Third, the increase of net working capital equal to $153 million, mostly due to CapEx payment related to renewable development in the second half of 2023. Compared to the last year figures, the impact of working capital on FFO was negative for $233 million, mainly due to CapEx payment related to 2023 renewables, collection impact from distribution business and cash in from the sale of Santa Rosa building received in 2023. Fourth, the income taxes that negatively impacted our FFO by $205 million, primarily due to tax payments related to generation business and to the sales of Arcadia asset. Comparing income taxes paid in 2024 versus paid in 2023, we see a negative effect of $174 million. The difference is mainly due to the tax payment of Arcadia transaction in 2024, higher tax payment in the generation business and lower recovery from previous periods. And finally, the financial expenses amounting to $241 million, mainly due to the debt-related expenses. Compared to the last year, our financial expenses decreased by $25 million in 2024. This decrease was mainly due to the financial expenses related to PEC 1 in 2023. So now let's take a look at our liquidity and leverage position. Our gross debt decreased by 11% to $3.9 billion as of December 2024 compared to December 2023. This decrease was mainly due to the optimization on the use of cash from the PEC 3 factoring, which took place in October 2024 and the operational cash generation during the year. The average term of our debt maturities slightly increased to 6.2 years as of December 2024 versus 6.1 years in December 2023 and the portion of gross debt at fixed rate was 89% of the total debt in December 2024. The average cost of our debt reached 5.0 as of December 2024, slightly above the 4.9% recorded in December 2023, primarily due to the Enel Generacion Yankee Bond maturity in April 2024 for $400 million at 4.25%. And finally, regarding liquidity, we are in the comfortable position to support our capital needs for the upcoming months and cope with 2025 maturities. As of December 2024, we had available committed credit lines for $690 million and cash and cash equivalents for $385 million. With the financial debt analysis, we close our comment on the company figures. So thanks, everybody, for the attention. And now I will leave the floor to Giuseppe for the final remarks.

Thank you, Simone. To conclude my presentation, I would like to give you the following closing remarks. Despite the very challenging context related to the crisis events registered in August, Enel Chile resilient business model allowed us to obtain robust results for the year, enabling us to fulfill our commitment to all our shareholders. This year, we have delivered a robust economic and financial performance, aligned with the target and strategic pillar presented on our last Investor Day. This gives us confidence that Enel Chile is more than preferred to operate in a volatile environment and to take advantage of a new opportunity. For 2025, we will continue to advocate for utilities reform and the modernization of the regulatory framework to enhance asset resilience. This will help us optimize the value of our assets across both businesses and ensure long-term sustainability. Finally, to conclude, on April 28, we will hold our Annual Shareholder Meeting, during which the final and extraordinary dividend to be paid in May 2025 will be proposed, including the interim and eventual dividend, the total amount will be CLP 4.24 per share. Now let me hand over to Isabela for the Q&A session.

Thank you, Giuseppe. Thank you all for your attention here. We will now begin with our Q&A session. We receive questions via phone and chat in the webcast. The Q&A session is open. Operator, please. You may start.

[Operator instructions] Our first question is from Alessandro Di Vito with Mediobanca.

I have 3 or 4. First one is we saw a couple of days ago that you had a big blackout in Chile and it looked like it was a systemic event. So I wanted to understand whether distribution companies like yourselves will be liable for potential penalties or it was more like a systemic event. So no fault on networks. This is the first question. Second question, I was looking at the hydro output. Your assumption for 2025 of 10.7%. I understand that we come from that the estimate is based on our 10 years average, but we come from 2 exceptionally wet years. So would you argue that this estimate could be conservative? And maybe it would be interesting to understand if you had moved some -- maybe a portion of the extra 2024 hydro resources for production in '25. The third question is more related to batteries because we saw that you started operation of 200 megawatts of batteries. I wanted to understand whether these were standalone batteries or they were part of a hybridized renewable plant? And if they are standalone batteries, I wanted to understand which IRR do you see on battery projects in the country? And in general, how do you see the ramp up in standalone battery capacity in the country for the coming years? And the last one, last question is if you confirm 25 gallons that was included in the latest DV.

Thank you, Alessandro, for your question. I will pass to Giuseppe.

Okay. Well, let's start from the blackout for what's concerned is massive interruption of the electricity supply that has been caused by the transmission system and disconnection, which unfortunately affected also our distribution company. We are not liable for any penalty because we are not responsible as distribution company for this interruption. Of course, there will be several analysis that has to be made by the coordinator and the SEC. So we're going to see, which will be the results. But as of today, our information is that everything is coming from an interaction in the transmission line. So we don't foresee right now any kind of penalty for our distribution cost. For what concern the hydro output for 2025. As you see in the presentation, we made maybe conservative assumption using the 10 year average historical data. This is our current approach since several years because we believe that the hydrology is pretty volatile. So we prefer to take this kind of conservative approach. Is too early to understand whether there will be an extraordinary -- rainy season or weather condition we're going to see in the following month as soon as the winter season will start so basically in May. We are confident to match this hydro production we're going to see and we're going to give you more information in the following months, not before May or June. Talking about the battery, the battery that we have already in operation and the battery that has been presented in the last Capital Market Day are hybrid so basically we are going to build up together with solar or wind project. And for what's concerned, the IRR is double-digit of course, the IRR depends on each project and the characteristics that the project has and the location that the project have in the system. And finally the guidance, yes, we confirmed the 2025 guidance that we present in the last Capital Market Day.

Operator, do we have more questions coming from the line?

Yes, let me bring the next one to our stage and it's from Martin Arancet with Balanz Capital.

I have three questions. First, regarding the distribution business, you mentioned a fine of almost $20 million and the voluntary compensation program. If I'm not mistaken, the government was also assessing the possibility of revoking the concession. I was wondering if that's off the table or if the government is still working on assessing that possibility. My second question, well, regarding CapEx, if you can share with us possibly the CapEx plan for this year and my third question, probably a follow up of a recent question. I was wondering, what is your strategy, your commercial strategy with batteries? Is it just to take advantage of arbitrage opportunities due to low marginal cost during solar hours or if you think that you could add the cost of batteries to new PPA prices to give a 24/7 solution.

Thank you, Martin. I will pass over to Giuseppe and then to Simone.

Okay. Well, talking about the concession. Well, first of all, let me remind that the revoking of the process of the concession has not yet started. What happened is that the Minister of Energy tasked the SEC, the Superintendent, with preparing a technical report on Enel Distribucion concession and according to the authority, this study could take between 6 and 18 months. As of today, I would like to point out that we have not received any notification or communication in this regard. So no administrative process is pending for the forfeiture of any distribution electricity concession and under the local laws, the President of the Republic must declare the forfeiture of the electricity distribution concession through an administrative act and the SEC, the Superintendent is mandated by law to carry out all necessary steps regarding the expiry of the operational concession. But again, it's really important to underline that the law excludes the forfeiture of the electricity distribution concession in case of force majeure duly verified by the Superintendence. And as of today we don't have, as I said, any further update on that. Talking about CapEx and, the BESS -- the business model, I mean the BESS we used to have in terms of business model. Let me remind you the business model first of all, as of today we have 2 revenue stream in our business model for the BESS. The first one is the energy shifting. So basically we charge the BESS during the solar hour and we discharge during the night. So we take advantage of the spread that we have in terms of prices. You probably know that in Chile there are in general in all the countries, but specifically in the North there is a very important variances between solar and non-solar power. And the second revenue stream for the BESS is the capacity payment. Capacity payment foreseen by the regulation that guarantee a certain percentage of the revenue for the base. Let me say in general, I would say that is around 30% capacity payment, 70% energy shifting. Important point for what concerns the BESS is that this year is supposed to be issued a change in the regulation. We hope it's going to be issued by the end of this year, probably in the mid, we hope based on which there will be a new regulatory stream for the BESS because they are going to be entitled to receive ancillary services remuneration. So I believe that the BESS business model is very, very good as of today in Chile. And by the way, the system requires this kind of technology so everything is going well.

Yes, just a small follow up on that. Well, you shared that arbitrage is currently like the most important revenue stream, I was wondering if you have, I don't know, an estimate on how that could change with these ancillary service charge if that will be relevant close to arbitrage revenues or what's your expectation there?

Well, the ancillary services remuneration is a very good complement to remuneration of the battery because of course there will be a moment during the year or in the following year in which the arbitrage is less convenient than what we see right now. And having the 3 states is a very good complement in order to guarantee the remuneration of the battery. Clearly it's not going to be a third -- it's going to be a third remuneration, but not in the same moment.

And now from the CapEx, I will pass over to Simone.

Thanks for the question. Talking about 2025 CapEx. As we commented during the presentation of the plan, we are focused on obtaining the BESS mix in terms of generation, just to reduce the cost of generation. So we expect a very intense year in terms of CapEx in general, we are going to invest something less than $800 million and more or less $0.5 billions are related to development CapEx in new power plant. We are going to focus on new BESS project, 3 BESS projects with a total of more or less 450 megawatt. This kind of base that Giuseppe described. Hybrid projects and the investment are more or less all in this year, in 2025, but the BESS will arrive at beginning of next year. So improving our mix of Production starting from 2026.

Operator, do you have more questions to the line?

[Operator Instructions] All right, It's from Emanuele Oggioni with Kepler.

I have two left. One is on the regulatory framework you mentioned in a very detailed slide. The next steps as expected, my question is about the related to your target of roughly USD 150 million of EBITDA for 20 -- along the plan basically yearly in '26-'27 if the current expectation based on the regulatory framework the evolution of the regulatory framework could confirm or not or improve or not the current targets including the business plan? This is my first question. And the second one is on the renewable side and the additional capacity. If you remind us the expected additional capacity in '25 if there is some delay or something to flag?

Thank you very much. Giuseppe?

Okay. Well the Enel Distribucion Industrial Plan 2025 to 2027 has been made according to the view that we had at the end of last year. That is supposed to be confirmed in this preliminary report that is going to be issued at the end of November by the consultant. So everything is in line. There could be some smaller improvement and that we are going to see in the next month, but I mean it's really to say whether we are going to have any upside. But the amount that we put in terms of EBITDA for distribution companies in line with the most conservative expectation that we have about the new regulatory cycle and for what concern the renewable capacity, all the CapEx, I will give you the floor to Simone. All the CapEx are devoted to capacity that is going to be in operation next year. But Simone, please.

So talking about the CapEx and complementing about the CapEx, the new project will involve the company basically for the larger part in the second half of 2025 and the plants are expected to reach the COD just in the first half of 2026. As of today, we don't see any specific reason for a delay. In any case, the impact of these plans I want to highlight that are not for this year. it will improve the EBITDA for 2026.

Operator, if you don't have more questions come from the line I go to the to the chat questions that we received. We received several questions. So a lot of the questions coming from the outages from Chile from last February '25, so received questions related to it from Francisco Paz, Santander; Andrew McCarthy, LarrainVial; Fernan Gonzalez, BTG. So the questions are all more or less all the same. Okay. So I will read one of these. Regarding the massive power outages in Chile the Minister of Energy puts Enel Chile as one of the companies pointing out in the problem in this case for the delay connected some power plants in the system in order to establish the electricity service in the country, particularly the hydro power plant Rapel. Do you think you can see fines for the delay in connecting your plants? How long did it take to activate the plants versus what was requested from the authorities? And we also received questions about potential impacts on the distribution business related to the breakout. So if you see an impact on the distribution as well. So Giuseppe.

Okay, so in response to the failure of the National Enel system, NLH and Green Power immediately mobilize all its things procedure and protocol to control and restore the operation of generator across the country. Specifically for what concerned one of our plants, Rapel at our plant which had several attempts to connect to the nationalistic system. We emphasized that there was no technical unavailability of the plan. External factor on conditions that prevented regular start-up are being analyzed. Additionally NL team immediately mobilized all teams procedure protocol to control and restore the operation for all the country in particular our generation control room center was operational for corresponding communication with the national electricity coordinator. And talking about I saw other questions and talk about the possible findings. As I said before is too soon to foresee any impact related to it. The incident is under investigation by the system operator and there are a lot of issues regarding the system operation that must be clarified before assigning any accountability to any company.

And on distribution you have...

As I said before, distribution is not involved in terms of responsibility. Actually we made a lot of effort in order to restore the electricity to the final customer but not having any kind of responsibility, we don't believe there will be any kind of liability for the company.

Okay, thank you, Giuseppe. And now changing the subject, received some questions on the extraordinary effect the one-off effect on the functional currency. So questions coming also from Francisco Paz, Santander; and [Indiscernible] from HSBC. So regarding the change of currency in the reporting of results going forward we will see any additional adjustments to the one observed in ENEL generation in the next period. Also please could you give further details on the impact on the effect no change the function of Corinth to USD what are the mechanisms behind this move? Simone?

So thanks for the question. I will give some detail about this change of currency. First of all, highlighting that given the international financial reporting standards, the change of currency is not like a choice of the management it's something that we have to do. I mean what I have said that the currency should reflect relevant transaction, event and condition of the company. So what happened between 2024 and 2025 to the 3 companies that changed the currency? It's important starting from Enel Generacion cause the impact on Chile is related to the change in Enel Generacion Chile, Enel Generacion Chile has 2 main forms of revenues and flows. One, the regulated contracts and the other one is the contract on a free market. The first, the regulated contracts are exposed to the exchange rate among between the U.S. dollar and the CLP. On the other side, the free contracts are strictly linked to U.S. dollar. So which was the trigger for the change? On one side the regulated contract volume decrease at the end of 2024, of course, some old bid from the past expired. On the other side, linked to our policy to keep on selling on the free market. We increase the volume in the free market contracts. And so as a result the volume for 2025 is now higher. Looking at the free market contract and this is the reason why we had to change the currency. Talking briefly about Pehuenche is similar Pehuenche had in the past until 2024 a contract that was a big contract with same condition as regulators contracts and now changed a little bit strategy because it's going to sell energy to spot price. And this kind of contract are basically strictly linked to U.S. dollar. Talking about Enel Chile. Enel Chile receives the dividends from its affiliate company and so the change in Enel Chile changed the flow and so we had to change also in Enel Chile. And this is the story. Now the impact until 2024 we have to make some research related to exchange rate risks. To hedge this exchange rate, we denominated some liability in dollar and following the IFRS principle you had to create this reserve that was negative reserve. Given the trend of the exchange rate in the moment in which in the last quarter of 2024 we decided to change the currency in this very moment we have to discontinue this kind of activities and so take this reserve and bring them to the P&L and this is the impact that you see in the P&L at level of EBITDA at level of net income. And finally, to finally answer the question, all the changes were recorded on 2024 and so we will not have any other impact starting from 2025.

Thank you, Simone. So moving on to the questions now we have question in terms of the gas trading. So the following question is coming from Andrew McCarthy, LarrainVial; and also Andres Navarrete from BTG. So the question is where and when do you see the most likely gas commercialization opportunities this year? And could you give us some color regarding the gas contracts from Argentina? Size, price range, take or pay agreement and also why will there be an extraordinary shareholder meeting on April and end of April for the Enel Chile?

Okay. So during February we have already traded a star plus volume for 2025 around 6 terabtu taking advantage of the current market condition and we are always looking for new opportunity to improve our financial results. This trading opportunity was already included in our guidance figures. However, at the moment we cannot share more detailed information due to the confidential conventional strategic nature of this operation. About Argentina gas, we have contracted about 30 terabtu distributed in the year 2025 with a competitive price lower than GNL prices due to competitiveness, what I can say is that is lower than 2024 prices of USD8 per million terabtu. Extraordinary meeting, the extraordinary shareholder meeting will be held to amend the bylaw in order to reflect the new function and regarding the currency changing the capital currently expressing in pesos to move to dollar to implement the functionality currency changes from a statutory perspective, it is necessary to amend the company's bylaw to redenominate the share capital from China based on 2 years.

Okay. Thank you, Giuseppe. So moving on the questions, we have questions coming from Fernan Gonzalez from BTG; and also Felipe Flores from i3 Capital. The first one is about the fines. So if the $20 million fines were already booked in 2024 numbers. Then Fernan have some questions regarding distribution. What makes you think that the debate around the distribution reform can begin in March? The Minister has said that some of your this is already have been said. Then he's asking about if our plans in terms of a strategic plan, the guidance in CapEx and also EBITDA would be changed considering the last updates in terms of the distribution segment. And now so if we keep our plan to invest the free cash flow in the distribution segment in this period or if we're seeing any change to regulatory restrictions.

Okay, well, first of all, as I said in the presentation, all the fines, all the other extraordinary items like the compensation to the client are already booked then the closing 2024. As I said in the past, the distribution business is very important for our strategy. We believe that there is a lot of value in the company. So we confirm our CapEx and our strategy in this segment. There is no reason as of today to change our strategic plan for Watcoms and the distribution company. So we are focused to spend most part of our cash flow in order to improve our grids in terms of resilience and quality.

Okay, thank you. Giuseppe. Simone, Just another question came in regarding the CapEx and EBITDA for Enel Distribucion. We have already said, but just to complement according to the guidance that we gave to the market.

Yes. So we can confirm the guidelines given to the market. You have seen that we expect an increase in terms of EBITDA in 2025 compared to 2024 and the reason of this delta is mainly related to the very negative impact of the climate event on 2024 that amount for more than $60 million impact. On the other side, as you know, the evolution of the regulation is giving us a little bit more space. And so these are the 2 reasons. This plan, in our opinion, as of today is quite solid and so can be confirmed.

Okay. Thank you, Simone. Thank you, Giuseppe. Just checking if there is any more question. As we do not have any more question, I conclude the results conference call. Let me remind you that the investor relations team is available for any doubts that you may have. Many thanks for your attention and see you soon. Bye-bye.

And thank you all for participating and you may now disconnect.

Good afternoon, ladies and gentlemen, and welcome to Enel Chile Nine Months and Third Quarter 2024 Results Conference Call. My name is Carmen, and I will be your host for today. [Operator Instructions]. Please be advised that today's conference is being recorded. 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 nine months and third quarter 2024 results. The presentation accompanying this conference call and Enel Chile's annual report on Form 20-F, included on the risk factors. You may access our Nine Months and Third Quarter 2024 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.

[Foreign Language]. Good afternoon, and welcome to Enel Chile 2024 third quarter and nine months results presentation. Thanks to all joining us today. My name is Isabela Klemes. I'm the Head of Investor Relations. Joining me today our CEO, Giuseppe Turchiarelli; and our new CFO, Simone Conticelli. Simone is a nuclear physicist and holds an MBA from Luiss University of Rome. He joined the Enel Group in 2006, working in the administration, finance and control of Enel S.A. From 2018 to 2022, he worked in Chile as the CFO of Enel Generacion Chile. Before becoming CFO of Enel Chile, he held the position of CFO at Slovenské elektrárne another company within Enel Group. Our presentation and related financial information are available on our website, www.enel.cl in the Investors section and our app investors. In addition, a replay of the call will soon be 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. Media participants are connected only in listening mode. In the following slides Giuseppe will start the presentation with our key highlights of this period. He will then cover updates on our portfolio and regulatory contexts. Finally, Simone will provide an overview of our business economic and financial performance. Thank you all. And now let me hand over the call to Giuseppe.

Thank you, Isabela. Good afternoon, and thanks for joining us. Let's start the presentation with our main highlights of the period on Slide 2. During the first nine months, our hydro portfolio performance was very robust with hydro generation increasing by 20% compared to last year. This improvement was due to higher reservoir level at the beginning of the year, influenced by the El Nino phenomenon observing the previous year and a solid rainy season this year. This resulted in an efficient generation portfolio mix for the period. We are pleased to announce that the Los Condores project is nearing completion. After several years of construction, the project has reached the pre-commissioning tests. We expect Los Condores to be connected to the grid by the end of the year. As everyone knows, an extreme climate eventually impacted the Central and Southern part of the country, including our construction area in the metropolitan region. Further in the presentation, I will give you more detail to you regarding the unforeseeable and predictable climatic events that affected our distribution segment. On the regulatory side, we have some important news to share. The factoring related to the PEC 3 receivable was successfully executed last week. We have carried out a factoring totaling $630 million. The PNP Decree for the second semester was published on October 5, which will result in a lower PEC accumulation for the year end. And the draft bill for the electricity subsidies for vulnerable customers is still under discussion. Today, the Energy Commission is renewed to evaluate government proposal. I will give you more color on these topics during the presentation. Regarding profitability, and let's announce that our EBITDA and net income results were better than last year's figures, fully confirming our guidance for the year. We achieved a positive FFO, even though during the first nine months of this year, we recovered only a small portion of receivables related to the PEC. As I mentioned before, much of the recovery of the PEC 3 receivable was made through the factoring executed the last week. So we will see them in the presentation of the full year results. And finally, for the 2024 nine-month results, we present a strong and sound level of liquidity, I will provide more details on this later. Now let's look at some updates on the hydrological situation on Slide 3. In addition to the positive hydrological conditions during 2023 that allow us to have greater water availability this year higher-than-expected rainfall recorded during 2024 has allowed us to increase our hydro production, exceeding 20% in the same period of 2023. Therefore, during the first nine months of 2024, we have accumulated 1.6 terawatt hour of additional hydro generation compared to last year. The hydrological situation in our reservoir is also very positive year to date compared to the last year's figures, particularly in the South. In fact, with the water accumulation in our reservoir to date, we have sufficient availability to supply our energy demand until the end of this year, even with the possibility of La Nina phenomenon in November and December. It is worth mentioning that there's no melting season has already started. Unfortunately, there has been a rainfall and a rapid increase in December during the south, generating increases in the affluent flows of the river. In fact, we had to carry out these charges in Penta power plants a few days ago and on October 24 in the Ralco in the Pangue power plants as well. Of course, this manual were coordinated and previously informed to the competent authority and the communities. Based on this fact, we have updated our hydro generation estimate to approximately 15 terawatt hours for 2024 and 3.3 terawatt hours for the fourth quarter of which we have already produced 1.3 terawatt hour. Let's move to the next slide to review how we continue improving our portfolio on generation assets. We continue consolidating our renewable capacity through a diverse portfolio of projects distributed across various country regions. This year, we increased our exposure to battery energy storage, the best system. In recent months, we received authorization from the national electricity coordinator to begin conventional operation of 101 megawatts associated with the two projects El Manzano BESS located in the metropolitan region of Santiago, and La Cabana BESS, located in the south of Chile. Considering this latest authorization from the coordinator in 2024, we initiated the commercial operation of a portfolio equivalent to 511 megawatts and 1,735 mega since 2023. In this 9-month period, we reached a total net installed capacity of 8.7 gigawatts, of which 6.8 gigawatt renewable, representing 77% of the total. A good news, the Los Condores hydropower plants had significant updates in this period. We have concluded the filling of the tunnels and started the pre-commissioning test. We expect to be connected by the end of the year. Now on the next slide, we will review the performance of our generation KPIs. Net electricity generation totaled 18.6 terawatt hour as of September 2024, exceeding by 6% of the production during the first nine months of 2024, mainly due to higher hydro and renewable generation, resulting from the improved hydrology this year and the operation of new projects. During the third quarter of 2024, net generation decreased 8% to 6.5 terawatt hour, mainly due to better hydrology recording during the same period of 2023 and lower thermal dispatch during the third quarter of 2024, partially offset by greater wind generation. Our energy sales totaled 25.3 terawatt hours as of September 2024, 9% higher than the level recording in the first nine months last year resulting from higher sales to both regulated customers and free customers. Our commitment with our clients were fulfilled with a higher portion of our renewable generation, which also led us to lower energy purchases in the stock market. During the third quarter of 2024, physical energy sales grew by 8% to 8.4 terawatt hour, mainly due to higher sales to regulated customers. In terms of our balance, during the first nine months of the year, we increased our purchases from third parties by 2 terawatt hours as part of our continued effort to diversify and optimize our energy sources. Now I would like to take a few minutes to talk about the extraordinary weather events of the last August. I would like to present this slide to discuss the extreme weather events that impacted the country and not just our concession area, which impact was higher than the earth quake occurred in 2010. On August 1 and 2, the metropolitan region of Santiago was severely hit by an extraordinary and unpredictable storm, with winds of up to 124 kilometers per hour. Significantly exceeding the forecast and warnings issued by authority and technical expert. This storm caused the fall of more than 2,000 trees, over 1,000 utility poles and large ranges, which destroyed part of our electricity distribution network, causing widespread power outages. The damage is comparable only to death caused by the earthquake already mentioned. And [indiscernible] Chile deployed all available resourcing going much further than required by Chilean electrical legislation. And it adopted extraordinary special measures to restore power to its customers as quick as possible. Reaching this amount of queue was only possible as part of Enel Group. We have requested support and received more than 100 technicians in this type of event coming from different parts of Latin America and Europe. Furthermore, it is worth noting that for this weather event, we spare no expense to recover and normalize the power supply which made possible. This is reflected in the number of field crews, 383 crew at the peak of the event versus 100 is considered in the reference model company of the current tariffs. Establishing the system was extremely difficult. And we have already submitted to the local regulator and the core debt resistibility and unpredictability of this event. Therefore, we really faced a major climatic event, the severity of which exceeded all the possible measures to be adopted under the Chilean legislation and will appear clear to all the different stakeholders in Chile once the pertinent data will be disseminated. As Enel, we have been working on proposing different kinds of regulatory model to meet the regulatory and physical system more relating to future weather event. We clearly understand the diffusion to modernize and digitalize the Chilean electrical for the solutions. Now I would like to talk about some regulatory framework, milestone in the next slide. As you may recall, during last call, we indicated that in January this year, the Ministry of Energy presented the bill related to the energy stabilization mechanism, which the power of continuing the PEC mechanism in mitigating the projected sales increase for Enel customers. At the same time, they also aim to improve the client protection mechanism known as the MPC mechanism to allow gradual repayment and accumulated debt to the degenerator and establish a transitory subsidy for the most vulnerable client. This new law was discussed and approved by the Chilean Congress in April. It came into force at the end of April. Following this, the first half and the second half PNP decrease were published and the regular -- regulated tariff was updated. After the communication of the second half Decree, all clients, including that, with the consumption of less than 350-kilowatt hour which are basically households, are paying the regulated PPA real price. The consequence of this is that no further debt will be accumulated during the tariff stabilization. An outcome that has not been achieved since 2019. This shift map a critical step towards financial stability, reflecting a significant change in managing tariff-related obligation. After the issuance of the sovereign guarantee decree as well as the complementary set of rules and regulation to the new law, the factoring was executed. We were able to factor $630 million last October 2024. As of September 2024, we had an account receivable related to the fact already net of factory and including readjustment and interest of around $1.1 billion approximately. So taking into this new factory realized in October, we are expecting to the end of the year with accruals in the range of $500 up to $550 million. Let me go to the right side of the slide, where we will recall the main topic related to the proposed law the government is introducing to increase the subsidies, which currently cover 1.2 million families to reach approximately 4.9 million families, representing the 40% most vulnerable families in Chile. Now Congress is discussing with executive authorities, potentially increasing this benefit to increase the number of the family, supported by these subsidies. Currently, the Energy and Mining Committee of the [indiscernible] is deliberating on the matter, which including general terms doubling the green tax emission from the current $5 per ton of CO2 emitted, for reference last year, we paid around $15 million related to it, allocating the additional VAT revenue that the treasury is collecting due to the increase in the tariffs, doubling the fines imposed by regulator and allocating them to support the subsidy fund, applying new charges to the small and medium distributed energy units known as PMGDs. As Enel, we support the government efforts to find alternatives to assist the most vulnerable family in the country, especially in light of potential economic change. However, we have observed that over the year, government solution have often disrupted the market. The same company that has been impacted by various regulatory measures since 2019 are once again being called APAB to support these subsidies mechanism. To maintain Chile reputation as a quality marketplace, it is crucial that such measures are reconsidered. Otherwise, we risk severally impacting long-term investments, competitiveness, and the health of energy sector. Among the proposal measure, we believe that allocating the additional VAT revenue is the most viable and sustainable option. To conclude, regarding distribution EBIT 2024-2028, there have been no significant developments since our last call. Our perspective on the next steps. In the process is detailed in the annex of our presentation. Now I will hand over to our CFO, Simone Conticelli.

Many thanks Giuseppe and good afternoon, everybody. First of all, I would like to tell you that it's a pleasure for me to join Enel Chile. And now let's move to economic and financial performance. During this nine-month period and the third quarter of 2024, our results continue to demonstrate a solid economic and financial performance. Let me begin with a quick summary of the main figures which I will detail in the following slides. Both nine months '24 and third quarter '24 EBITDA and net income recorded important improvement when compared to last year's indicator. This is mainly explained by a more efficient generation mix, thanks to better hydrological situation, coupled with an increase in our energy sales and better pricing. Regarding the FFO the nine-month 2024 figure show a slight reduction versus last year, particularly in the third quarter, mainly explained by a temporary negative effect from tax factoring operations and higher tax payments in 2024, primarily related this to Arcadia transaction in October 2023. This trend is expected to deliver during the last quarter of this year. Now on the next slide, let's review the progress on CapEx. Total CapEx reached $406 million during the first nine months, 16% lower than last year considering the conclusion of several renewable and storage projects over the year 2023 at beginning of 2024. 62% of the total CapEx amounting to [$253] million was related mainly to renewable and storage CapEx deployment and 22% equivalent to $92 million was related to grids. Asset management CapEx reached $133 million, which represent 33% of our total CapEx. It increased by around 50% compared to the last year figure. The reason for this increase can be found both in the generation and distribution business. In the generation business, this increase of $29 million is mostly related to maintenance activities in the Atacama CCGT power plant and in solar and wind assets. In the distribution business, the increased approx $16 million is due to climate events, emergencies and maintenance related to fall in the low and medium voltage lines. Looking about development CapEx, they reached $227 million a decrease of 32% compared to the last year figure, mainly due to the conclusion of renewable projects. And now let's move to the next slide, where we have a summary of the second quarter EBITDA breakdown. In third quarter 2024, our EBITDA was $405 million, which is $63 million higher than the same period in 2023. Referring to generation business, we have an increase of $68 million, thanks to a significant contribution from PPA sales. This is mainly due to higher volume, especially in the regulated markets, as mentioned by Giuseppe and pricing effects mainly related to contract indexation. Going to gas trading. We had a $11 million margin increase coming from additional trading activities in third quarter 2024. Particularly the sale of LNG cargo to Europe. Referring to the margin is higher by $5 million, mainly due to the increase of remuneration linked to publication of the VAD 2020, 2024 regulatory report. This margin was totally offset by the extreme weather events, including the force majeure events of August 1st and 2nd that affected our distribution segment. This generated $16 million of additional OpEx and other expenses mainly related to an increase in dispatch for center facilities and generators rent and operation. Let's move now on the next slide to review the main impact on EBITDA during the nine month figures. Our EBITDA reached $1 billion, an increase of $300 million, representing a 46% improvement compared to the last year. I will start explaining the positive effects. First, we had a great contribution of $250 million in PPA sales, mainly related to higher volumes, particularly in the regulated market and PPA pricing in the free markets, mainly due to indexation in line with the assets explained previously in the quarter. Second, industrial sourcing had a positive impact of $123 million, this is mainly explained by lower variable production cost due to lower thermal generation because of the remarkable hydrology of the deal. Then, that's a positive contribution of $70 million related to commercial sourcing mainly explained by lower prices associated with purchases in the stock market. This effect was partially offset by higher purchases from third parties and the impact of PPA renegotiation that benefited us in 2023. Then we have another positive effect of $23 million loan from grid margin. This is mainly due to the grid remuneration linked the publication of VAD 2024 regulatory report. As we have seen in the quarterly analysis, this positive effect was offset by the impact of the weather events. The aforementioned that positive that were partially offset by a negative impact of $115 million associated with the notable gas trading activities carried out during the first nine months of 2023, amounting to approximately 29 terabytes and a negative net effect of $16 billion, mainly due to higher OpEx associated with new renewable projects. recognition of Transantiago business in buses in 2023 for NLX. Negative impact of inflection across all the businesses. Let's move on to the next slide where we will review the net income evolution. Nine months 2024 net income amounted to $446 million, 62% higher than the last year's figure, mainly explained by the EBITDA improvement. Let me drive you through the additional aspects for this nine-month period. Returning to the depreciation, amortization and bad debt we have a higher cost for $47 million, mainly resulting from higher depreciation in green power due to the new renewable capacity coming into operation and Chilean peso devaluation in the period. Higher bad debt accrual increase due to the rise in credit losses associated to the higher tariffs. Regarding financial results and equity investments, we reported a $63 million negative variation versus last year, mainly explained by positive exchange rate differences in 2023, higher financial expenses, mainly due to FX variation and lower financial income linked to lower average interest rates, partially offset by higher interest related to the tax receivables. Talking about the income taxes, we recorded an increase of $42 million, mainly due to the better results in the period. This was partially offset by a lower cost related to representation of Arcadia assets held for sale in 2023.. Focusing on the quarter, our net income increased by 3%. This is mainly explained at high pricing EBITDA contribution, lower tax expenses of $50 million, mainly due to lower cost for the electrification of Arcadia assets held for sale in 2023 and lower cost due to monetary production. These positive effects were partially offset by, first, an increase in D&A and bad debt of $12 million due to higher depreciation mainly linked to operation of new renewable capacity in EGP. And an increase in bad debt mainly due to a rise in credit losses associated to the higher Second, highest financial expenses of $60 million, mainly due to positive exchange rate differences in 2023 and lower interest recognition related to PEC 2.0 in third quarter 2024 versus third quarter 2023. And now let's move to the FFO analysis on the next slide. Let's review the composition of our FFO for the period and the main effect versus 2023. First, let me highlight that the 2023 FFO figure has been adjusted by $310 million due to tax paid on capital gains for the sale of Enel transmission in 2022. Our FFO in this nine-month period of 2024 reached $366 million, nearly align in the same period of 2023. Excluding the 2024 tax payment for the sale of Arcadia asset last year, an FFO would have shown an improvement versus last year. EBITDA in this nine-month year amounted to more than $1 billion, showing a variation of $380 million compared to the last year's figure. This is mainly due to higher PPF sales and positive performance in commercial and industrial sourcing as I previous explained. We have also already talked about the cumulative impact of the stabilization mechanism, which amounted to $313 million. This negative effect was partially offset by the execution of the IEB factor related to PEC 2, PEC 3, which amounted to $83 million in the nine months period. When we compare the total aspect of PEC net of factoring for the nine months of 2024 versus 2023, we see an increase of $270 million this year. However, this is only a temporary aspect as we have already received an additional USD 630 million. Working capital in the nine-month period showed a negative balance of $74 million, mostly due to CapEx payments related to 2023 renewable. Compared to the last year's season, working capital impact on FFO was positive for $84 million, mainly due to the higher cumulation of VAT tax credit in 2023. Income taxes negatively impacted our FFO by $169 million this period, primarily due to tax payment in the generational business in 2024 and taxes paid on the sale of Arcadias. Comparing income taxes paid in the first nine months of 2024 to 2023, we see a negative effect of $163 million. This difference is mainly due to the tax payment of our value operation in 2024, higher tax payment in generation business and lower recovery from previous years. To conclude the financial expenses as a net negative impact of $166 million on the nine-month 2024 FFO, mainly due to the debt related to expenses. Once compared to last year, our financial expenses decreased by $12 million in the first nine months of 2024 compared to 2023. This decrease, it may be due to the financial strength related to PEC 1 in 2024. Now let's take a look at our liquidity and leverage position. Our gross debt increased by 8% to $4.8 billion by the end of September 2024 compared to December 2023. This higher debt was mainly due to accumulation effect and seasonality of generation business. This increase in gross debt should reverse during the last quarter of 2024, considering the factor under the PEC 3 mechanics, which took place on the last October 24 allowing us to pay an important amount in short-term credit lines, taking advantage of our debt flexibility. The average sale of our debt activity slightly decreased to 5.7 years by the end of September 2024 versus the 6.1 years that's seen in December 2023. And the portion at the fixed rate was 75% of total debt. The average cost of our debt reached 5.0% as of September 2023, slightly above a 4.9% recovered in December 2023. Mainly due to the energy generation reactive bond maturity in April 2024 for $400 million at 4.25%. All in all, we can see a significant improvement in our leverage generations. In this September, our net debt-to-EBITDA ratio was 2.9, demonstrating solid decreases versus last quarter figure. Regarding liquidity, we are in a comfortable position to support our capital needs for the upcoming months and cope with the next year. Thank you all for your attention. And now I pass the floor to Giuseppe Turchiarelli for closing remarks.

Thank you, Simone. To conclude this presentation, I would like to give you the following closing remarks. Better hydrology and incorporating new technology such as optimization in hydro facility and the development of battery in our portfolio have helped us to improve our margin. Also, our trading capabilities were also important in adjusting our sales portfolio, contributing to important margin in the period. As a result, we have delivered a more than solid operating and financial performance during the year. We received around $713 million through various factoring activities related to the fact. Larger part of which came from the last week operation, which reached $630 million. The proceeds will primarily repay short-term debt, strengthening our balance sheet. As I mentioned, taking this new factor in realizing in October, we expect to end the year with accrual in the range of $500 million up to $550 million. Finally, to conclude, we want to embark you to the event of November 21, where we will present the new strategic plan for 2025, 2027 to the financial community. More information will be provided in the coming year. Let me now hand over to Isabela.

Thank you, Giuseppe. Let's now begin with our Q&A session. We will receive questions via phone and chat in the webcast. The Q&A session is open Carmen, please, you may start.

[Operator Instructions] One moment for the first question. And it comes from the line of Javier Suarez with Mediobanca. Please proceed.

Hi. Many thanks for the presentation and for taking my questions as well. I have three questions. The first one is on the guidance. If you can elaborate on the latest guidance that you provided to the market in terms of EBITDA net income and also net debt, we should consider this guidance confirmed and the implications of the fact that the company is increasing their higher guidance to 13 terawatt hour this year, when previous guidance were 12 terawatts hour. So any light on existing guidance could be appreciated. Second question is on the recovery of regulatory receivables under the destabilization mechanism. So the question is, can you update us on your latest expectation for the timing for the recovery of the pending amount. I think that on the previous conference call, you mentioned something like $200 million in 2025 and the remaining portion in 2026 and '27. Is that guidance is still a good one. And the final question is on the -- your latest expectations on the publication of the new distribution tariff. I think that you mentioned during the conference call that there is no significant update. So if you can give us a latest thought on when the final report should be unveiled.

Okay. Thank you, Javier, for your questions. I will hand over to Giuseppe.

Yes. Okay. Let me say that for what concerns the guidance, as you probably remind last year, we present a range of EBITDA between 1.3, 1.5, and we confirm it. Of course, we're going to be in the upper side of the range, but we are confirming our guidance. Same confirmation for concern, the net debt-to-EBITDA ratio, we're going to be below 3x, that is basically our target. We feel comfortable with this duration. And for work content hydro, as you see in the presentation, we are expecting to close the year with approximately 13 terawatt hours of hydro production. Let me say that already in October, we had 1.2, 1.3. So we are in line -- everything is in line with our forecast that people send in the call. So this should be the production that we're going to have at the end of the year. For what concern back with Simone. Well, okay, maybe just to find -- to finalize my part for what concern there in 2024, 2028 distribution tariff process. We don't have any kind of update. We expect to have some news at the beginning of the next year, when the CNA, the regulatory model will show the feedback for the technical consult record. So we are waiting for this report.

Okay. Thanks for the question. Let's talk a little bit about PEC. As you know, at the beginning of the year, the debt was quite high, $750 million. And then this increased first three quarters, of course, each quarter, we accumulate something like $100 million of new debt. And in the first three quarters, we received a factoring process, just more or less $80 million. And so at the end of September, the situation is that we have debt about [$1.1] billion. The important message that already Giuseppe gave you is that, in any case, the increase in time change the situation. starting from a few weeks ago with the PPD of second half. So we are not accumulating more or less any other tax receivable. And so from now on, the PEC amount should decrease each month. Now as we have already commented, we received a cashing of $630 million, so the 24th of October. And given this cashing at the end of the year, our position should be in a range around $500 million and $550 million. This amount should be cashed mainly in the next two years. The larger amount, more or less [$200] million in the first year, plus in '25. And the most of the remaining in 2026. We expect just a small part to be cashed in 2027. And particularly, we are talking about the sector one mechanism. As you know, these mechanics consider that as part of the total debt will be cashed in through the tariffs. And so we had to wait before the end of 2027.

Thank you, Simone. Operator, do you have more questions on line? .

We do not have any other questions. Back to you for webcast.

Okay. So Giuseppe and Simone, I will start with some questions that we have received from the analysts and investors connected. So the first one is coming from Francisco Paz from Santander. Francisco is saying thanks for the presentation. The question is the following. We have observed a positive water availability during this year and the previous one, which has helped the company to reduce cost pressures and increase hydro generation. Going forward and in the context of uncertainty for water availability in the long term. What do you assume is the reasonable estimate of hydro generation in the medium to long term for the company in an motor?

Well, let me say that we are clearly happy to have this two year with a very good hydrological condition. We do not consider this 3-year as a proxy for the following year. So we used to project in terms of hydro condition the last 10, 11 year average. So in general, we are soon to have around 10, 11 terawatt hour per year. These are our estimation as soon as we're going to see a different kind of path in terms of hydrology, we are going to change our estimation. But as of today, we keep our estimation around 10, 11 terawatt hours per year.

Okay. Thank you, Giuseppe. So we have some questions now from Andrew McCarthy from LarrainVial. So the first question is also related to the hydro generation, but I think we have covered now the question. So the second one relating to the fact, the factory, now so when do you expect to sell more factory receivables? And how much do you expect to receive?

So I think that we have answered also in the previous question, but I will focus on the specific questions. Thank you. We are keep on selling the PEC debt going with the new decreases that we, and we are expecting to have cash for around $200 million or something more by the end of 2025. This is the first block of the effect that we are going to cash in.

Okay. Thank you, Simone. So we have another question from Andrew that also their investors analysts have sent to us. So do you see more gas commercialization opportunities for the first quarter?

Well, at this moment, we don't expect any additional sales of cargo for the rest of the year. Clearly, we are always looking at mainly opportunity to increase our profitability but as of today, we don't have any in front of us in [indiscernible] in front of us.

Okay. So the last question from Andrew is, do we expect the distribution business to return to normalized operating profit in the fourth quarter of this year or should there be more negative impacts from fines or compensation to clients for services interruption that occurred in 2024.

For what concern, the distribution business, of course, we are still evaluating all the period that we need in order to put our grid to the original status. We are waiting also in discussion for what concern the possible fines or compensation, and we're going to give you more detail during our Investor Day.

Okay. Thank you. We have some questions from Ignacio Sabella from Itau. So the question is also very similar to the ones that we have already answered. But just to focus on the PEC 2. Now so how much we expect the receivable accumulation regarding the factory going forward. Simone, just to rephrase as we have several questions on this.

Yes. As we have commented on this one, that the two segment of customer with the consumption below 350 and with the consumption higher of 650 are started to pay. Basic the sales price we call the cost of the system and then also a component that is needed to recover. So from now on, we expect no significant increase or accumulation of debt.

Okay. So a question from now coming from Martin Arancet from Balanz. Also on PEC, but he is asking more details about the usage of the funds from the factory that we received in October.

Okay. Thank you for the question. As we have commented, the 24th of October, we received a payment of more or less [630]. This cash in was received by Enel Chile. And Enel Chile used the money to reduce the debt position in the short term. And part of the mine was invested also in the short term as the market interest rate. Clear, we keep on looking ahead to have further opportunity to optimize also the long-term debt. And on the other side, you know that the financial stability is one of our core growth for our strategy while, of course, we can leverage on that to graph eventual proximity that can come up in the market. And so this increase of our financial stability is a very positive effect that can enable us to do more in the future.

Okay. Thank you, Simone. So we have one more from Martin. He's asking, if I'm not mistaken, the government is preparing a technical report to evaluate if a non-distribution has taken the proper steps to return service to clients after the extreme weather event conditions. Could you give us any color on the time line of this report, your expectations? And also your options if it has a negative outcome.

Okay. So let me first mention the fact that the process of revoking the concession has not yet started. The Minister of Energy tasked the sector is preparing a stemming report on energy distribution concession. According to the authority, the study should take between 6 and 18 months. And once it's going to be ready, it will be delivered to the President of the Republic for review and only the President of the Republic of Chile through a decree can start the process. So we are waiting for the record that should be issued by the SEC or let's understand whether this technical mode see any possibility or any suggestions in order to revoke or to suggest the blocking of the concession. Just to be clear, below the current law exclude any possible revocation of the concession in case of force majeure. This is the reason because we believe that any record from the SEC should give this kind of suggestion because it is clear from the situation that has been occurred in August that the force majeure is clearly part of the bank, let me say. And what we're going to do in case of negative outcome. Well clearly, we're going to start with all the legal action locally and international. So we're going to start really defending our interest in terms of concession.

Okay. Thank you Giuseppe. We received all the questions also from [Rodrigo Mora], but were the same on distribution and also on gas commercialization. So Tomas Gonzales from Scotiabank. Some questions we have answered, but I go to the dividend. And also, he is asking regarding the dividend, do you plan to pay our interim dividend before the year-end? Any possibility to increase the payout in the future is mentioned because of the funds of the PEC.

Okay. Talking about Enel, soon, the business policy of Enel [indiscernible] to increase to the year the dividend. In this moment, this cash in is in line with the possibility to stay in the policy. And in the very short term, so we will reach in the future until the 70% of the dividend. And so this money are very good news. No, will permit stay with our in policy. But in my opinion, and this is a matter for the Board of Directors and for the assembly of owners of the company. But in my opinion, there will be no big changes regarding the dividend policy.

Okay. So let me check here. We have other questions. Okay. So we have one from Martin [Poso]. So he's asking us. Can you give more detail about the impact the company might have with the increase of the green taxes in case the new project law is approved. Can you give you more details Simone.

Well, let me remind you that last year, we paid $50 million in green taxes. And we have a very good mix in terms of plant fleet. Our CCGT is tied with a very competitive contract. And the green tax at the end of the day, represents a very low percentage of our thermal power plant. We have several options in order to compensate this taxes. But at the end of the day, as I said before, we are -- the law is under discussion is at the beginning of the discussion, actually. And the amount of the taxes are almost. Yes, very, very low.

Okay. Thank you, Giuseppe. So one more from Rodrigo Mora from Moneda. He's asking about Los Condores project, okay? So he's asking if we could give more color about the status of testing of Los Condores. And the energy generated expected to this plant. So just if you can give more on how we are in Los Condores, and then Simone the generation of Los Condores?

Okay. Well, Los Condores project is in a very good shape right now because we already started the pre-commissioning test. We are going ahead and we are pretty sure to have the first synchronization in the following month. It should be before the end of the year, we expect we could have a very good surprise in the following weeks. But let me say just to be conservative by the end of the year.

Okay. Thank you. Simone, on the generation, please.

Talking about generation of this new plant, we can give a range of production expected for the next year and should be on 150 and 200 gigawatt hour for one year.

Okay. Thank you. So we have one from [Andres Barberis]. So the question is on Andres. Thank you for the presentation. I have a question regarding the regulated sales. We observed a year-over-year increase of 606 gigawatt, is this increase driven by higher demand in your current CPAs? Or is due to a start of a new regulated contract?

Basically, increase in sales are connected to a new cons that start recently this year actually. And it was a regulated standard that we won in 2017. So it's a matter of perimeter. So we have a new PPA entering our portfolio.

Okay. Thank you, Giuseppe. So Carmen operator, do we have any more questions online.

Yes, we do. We have a follow-up or moment, please. Okay. Thank you from the line of Javier Suarez with Mediobanca.

Sorry for coming back again. Is on the guidance, you mentioned that the guidance for the EBITDA in 2024, is now seen at the upper end of the range, the previous range, $1.3 billion to $1.5 billion. If you can confirm that if you can share with us also on the guidance for the net income.

Okay. I confirm you on that if you're going to be at the upper range. So around closer to 1.3 rather than 1.3. So upper range. And for what concern the net income similar situation, I mean, we are going to confirm the guidance at the upper range that we presented last year.

Okay. Thank you. If there is no more questions, I would like to conclude our conference call. The Investor Relations team is available to answer any questions you may have. Many thanks for your attention. Have a great rest of the week and see you soon at our Investor Day. Thank you.

Thank you. And with that, we conclude today's conference. You may now disconnect.