20 24. We would like to inform you that this event is being recorded. All participants will be in listen only mode during the presentation. After the Company's remarks, there will be a Q and A session. Questions can only be submitted in writing through Zoom. Should any participants need assistance, please send us a chat message before proceeding. Please read the disclaimer on the second page of our presentation. Let me mention that forward-looking statements are based on Pampa Energía's management beliefs and assumptions and information currently available to the company. They involve risks, uncertainties and assumptions because they are related to future events that may or may not occur. Investors should understand that general economic and industry conditions and other operating factors could also affect the future results of Pampa Energía and could cause results to differ more materially from those expressed in such forward-looking statements. Now I'll turn the video conference over to Lida. Please go ahead. Hello, thank you, Raquel. Hello everyone, and thank you for joining our conference call. I will make a quick summary of Q3. You might find more details in our earnings release and financial statements. Today we are having our Q&A with our CEO Gustavo Mariani, our CFO Mr. Nicolás Mindlin, and Horacio Turri, our head of E&P. Let's start with the quarter's figures marked by the solid outperformance from gas upstream and power generation, which helped to overcome the winter peak. This is the year's most critical period. Gas production increased 8% year-on-year with a growing contribution from shale. Our CCGTs achieved high load factors supported by strong gas and capacity availability. Our balance sheet remains solid with extended maturities and improved liquidity, bringing net debt to its lowest level since 2016 when we acquired Petrobras Argentina. Adjusted EBITDA amounted to $279 million up 14% from last year driven by increased gas deliveries through the new pipeline under Plan Gas, higher spot prices and excellent dispatch and availability performance in our power generation segment. Tariff increases also boosted contributions from TGS and Transener, lower gas exports, power and gas B2B sales and petchem margins partially offset these gains. The quarter-on-quarter decrease is explained by warmer September temperatures, gas pipeline curtailments and higher operating costs. It is worth noting that 75% of the quarter's EBITDA was dollar-linked and E&P leading the share. Excluding most regulated peso businesses, the dollar share goes up to 85%. Capex in Q3 is set to 59% lower year-on-year mainly because of the shale gas ramp up and PEPE IV construction in 2023 partially offset by final payments for PEPE VI ongoing development in Rincón de Aranda. Moving on to power generation on slide 4, we posted an EBITDA of $112 million in Q3. This is a 23% increase year-on-year mainly explained by the operating outperformance and higher legacy prices partially offset by lower industrial demand, increased operating expenses and the divestment of Mario Cebreiro. Q3 dispatch rose 19% year-on-year driven by our CCGTs at Genelba, Barragán and Loma supported by greater gas and power availability, lower water levels at Pichi Picún Leufú, full hydro and the divestment of Mario Cebreiro partially offset increase, take-or-pay capacity payment especially from PPAs contributes most of the EBITDA. It is driven by capacity availability and in Q3 we reached 96% up from 94% last year, helped by fewer thermal outages. A quick review on PEPE VI expansion, the civil works were completed, all windmills are installed since October and the project now is 89.98% advanced. Between September and October 50 MW were commissioned. Additional were commissioned by CAMMESA, reaching 113 MW operational out of the total plan 140 MW. We are now conducting the final tests and full COD is expected just next week or before the end of the month. PEPE VI energy will be sold under B2B PPAs. Now going on slide 7, our E&P business posted an EBITDA of $122 million in Q3. This is 8% down year-on-year largely due to higher operating costs related to Rincón de Aranda, reduced exports to Chile and lower industrial sales due to the economic downturn. These factors were offset by increased gas production from the latest round of shale gas, the beginning of Rincón de Aranda pilot plan and increased gas treatment cost raised the total lifting cost by 16% year-on-year. However, lifting cost per BOE slightly rose to $6 per BOE. Higher output lowered the gas lifting cost by 2% to $0.8 per MMBTU. Total production averaged nearly 88,000 BOE per day and 8% higher than last year. When we zoom in, crude oil represented only 6% of the output and 16% of the E&P revenue while gas accounted for 90% of our production. Gas production in Q3 rose 3.3% year-on-year. As you can see here, the deliveries have been increasing throughout the year to date thanks to the new gas pipeline and peaked during the winter. However, bottlenecks due to the delays in the commissioning of compressor plants. Warmer September and most significantly soft demand from industries and Chile impact the volumes. Still, deliveries stay above take-or-pay levels that we do in the winter, way above in Q4. Demand is expected to ease with warmer weather. El Mangrullo contributed 57% of the quarter's production and Sierra Chata provided a growing share of 29%. Sierra Chata's production grew 18% year-on-year and reached a new all-time high record of 5 million cubic meters per day in July. Without connecting or drilling any wells this quarter, El Mangrullo experienced the same thing. No new wells tied in and a 7% increase year-on-year. The average gas price for the quarter was $4.40 per MMBTU 6% down due to the lower exports to Chile and sales to industries, partially offset by better retail prices due to tariff increases. As you can see right below, increased local gas deliveries were directed to retail and thermal power generation on Slide 10. Before we move on from E&P, let me briefly summarize what we presented during yesterday about Rincón de Aranda. Production is currently at 1,000 barrels per day. This is primarily crude, low water, low gas content. The development plan targets a production plateau of 45,000 barrels per day by 2027. This is aligned with the ongoing pipeline expansions. We are building facilities, securing evacuation capacity in Vaca Muerta Sur and planning to drill seven pads annually for the next two years. This is why we procure four drilling rigs right now. We estimate to invest over $700 million in 2025 with a total of $1.5 billion in Capex between 2025 and 2027. Quick note on petrochemicals, we posted $2 million on EBITDA in the Q3. This is an 88% drop year-on-year due to higher costs and peak demand due to the economic downturn partially offset by higher volumes and prices of reforming products. Though the spread to official FX shrank the export dollar helped Petchem to stay afloat this quarter. Okay, so moving to Slide 12 we show restricted group figures that reflect the bond parameter. In Q3 free cash flow reached $80 million supported by improved working capital with days of sales outstanding at 48 days just 6 days delay. Besides the robust operating cash flow the last year's Capex was shale gas ramp up. This year capital spending was mainly maintenance. For maintenance at $74 million in September we issued a $410 million international bond maturing in 2031 and to improve the debt profile partially redeeming at par the 2027 notes. Overall, this resulted in a net cash increase of $272 million, raising our cash position to $1.2 billion by the end of September. This is a 23% increase compared to last year September and $150 million more compared to June of this year. This slide shows our consolidated financial position, including our affiliates out of ownership. But let's keep it on restricted group figures. On top of the $1.2 billion cash that we described before, we posted a gross debt of $1.7 billion, up 5% year-on-year and 93% is in dollars. However, the net debt recorded $539 million, down 20% year-on-year and 0.8 x the last 12 months EBITDA, the lowest ratio and amount in the last eight years. So this concludes our presentation. Now I will turn the floor to Raquel. She will poll for questions. Thank you so much. Thank you so much, Raquel. The floor is now open for questions. If you have a question, please send it to us through the chat. We will read and answer them in order received. If you have one also, please make sure your name and company are correctly displayed to introduce you to the audience. If participants need assistance, please send us a chat message or raise your hand. To begin, first question comes from Bruno Montanari from Morgan Stanley. First question he asks is, can you talk about the initial performance of Rincón de Aranda and how should we think about the path of drilling in the coming quarters through the end of 2025? Good morning, Bruno, and all the audience. Regarding Rincón de Aranda, as I mentioned before, we have two rigs actually working, two high spec rigs plus one spudder. Our forecast is to drill from today to the end of 2025, seven pads of four wells each, so we will be drilling around 28 wells in the period November 2024-December 2025. In terms of our forecasted production, we are expecting to hit 12,000 barrels by April-May 2025 and 18,000 barrels by September of 2025. Thank you. Horacio, next question is for you too I think. Regarding evacuation capacity. Can you remind us Pampa's and Argentina's gas evacuation capacity today and how that should evolve into 2025 and after? And how about oil? How are the discussions related to having stake for oil evacuation in Vaca Muerta soon? Hi, Bruno, Gustavo. First of all, I want to thank Horacio who's coming right from the airport. He's not our millennial E&P director, but he's been very kind to rush from the airport to the office to take the call regarding evacuation capacity. Producers don't own evacuation capacity for natural gas. So the ones who owns the transportation capacity are either the distribution companies or the big industries. If your question relates to the situation of the gas evacuation capacity of the Neuquina Basin this year, early in the winter one of the compression plants of the Gasoducto Néstor Kirchner became online though increasing its capacity from 11 to 16 million cubic meters of natural gas per day, and the second plant I think is supposed to be online anytime soon, despite the fact that during the summer is not needed. It will be needed and used next, next winter and it will be for sure ready by then. By that moment the evacuation capacity of the Néstor Kirchner will be a total of 21 million cubic meters per day. And the situation will not improve until a new infrastructure project is online. So the other change that happened this year was with the inauguration of the Norte, the reversion of the north pipeline. So now the pipeline that used to bring gas from Bolivia and the north of Argentina to the center of Argentina is reversed and the Neuquina Basin can supply to the north and eventually export gas to the north of Chile and to Brazil. But just to keep in mind, that is not additional production from the Neuquina Basin is gas that used to go to the Litoral to the east of Argentina and now it's able to go to the north. Relating. Oil. We, as we mentioned, I think. If. I recall correctly in the previous call, we are part of the consortium that has been formed for the project Vaca Muerta Sur for several weeks or more than weeks. There are currently daily meetings to discuss the documents. We are very optimistic that this project we will finish the documentation and we will sign the final agreement among the different players of the industry probably by month end and that the project will be launched before year end. Thank you, Gustavo. Third question from Bruno is regarding Argentina's LNG project. How have discussions about LNG projects evolved? Is Pampa still interested in being directly involved and if so, in which portions of the projects would the company be more interested in the floating units, the land facilities, or perhaps only the infrastructure part? Definitely we are very interested in the LNG projects that are being discussed currently in the country. Our interest is basically because we want to monetize our very competitive dry gas reserves that we have in Sierra Chata. And we see the export of natural gas through an LNG facility is the only way to do so in a significant number in the long term. We believe Floating units makes more sense than the land facilities. Basically because of the fact that given capital restrictions and high cost of capital for Argentina, it makes more sense to hire to rent the facilities than having to own them and all that. But so far we are giving priority to the all evacuation. So today we are focused on the Vaca Muerta Sur. That's our priority. The LNG project can come once we have the Vaca Muerta Sur on the way. Thank you. Next question comes from Alejandro Demichelis from Jefferies is regarding Exxon's process. How do you see the situation of the Sierra Chata block and a potential change in the partner there? Hello, good morning. So we do not have information about the process relating to this asset. I think in the only official statement from Exxon did not specify whether this asset was included in the package or not. So that's the only information we have. But the important thing about this is that we are the operators of the area and we will continue to operate the area in the same way. So our plans are not changing because of the results of this process. Thank you, Nico. Next question comes from Marina Mertens from Latin Securities. First one is regarding Energía Base or spot energy prices. The latest increases granted to the Energía Base scheme outpace devaluation improving legacy asset remuneration. Do you expect this trend to continue? Hi Marina. Yes, we expect this trend to continue as the remuneration of the legacy assets, despite the improvement, are still at very low levels. So yes, we do expect this trend to continue marginally. Not something huge but similar to what has happened in the past few months. That the increases were a few points above the average inflation. And we expect this trend to continue until the deregulation that we expect to be announced at some point next year. It's finally published. Thank you. The second question from Marina says there has been news about a potential urea plant in Bahía Blanca. Given Pampa's focus on developing Rincón de Aranda in the coming years, can we expect a start date or a go or non go decision on the urea project? You are totally right that today's focus for Pampa is definitely Rincón de Aranda which is a major challenge and a significant capital deployment. Having said that, as we mentioned a few times, despite its size and given the free cash flow generation of the other two segments of Pampa's gas production and power generation, we don't expect a significant impact on our ratios, on our net indebtedness because of the development of Rincón de Aranda. So Pampa having the debt profile that we have and the cash position that we have, we feel totally comfortable to move ahead with a project the size of the urea project once we are convinced that it makes sense. When we will be convinced or when we will know if it makes sense or not? It will not be before one year from now. In the next six months the team will be working on designing and preparing the documentation so that we can request from the EPC providers the price for a turnkey project to build the urea project. We don't expect to receive that the soonest will be around one year from now because we need to prepare the documentation that will take us now. We hope to be ready by some point in the first quarter of next year and then the EPC providers will require like another six months to prepare their bid. So the go no go decision will happen probably at some point in the second half of next year. Thank you. Next questions come from Daniel Guardiola from BTG Pactual. First one was about a Sierra Chata situation, but we already answered that. So second question is about Oldelval. He asks for an update on the entry date for the doubling capacity and how many barrels of capacity are guaranteed in this pipeline. Considering there will likely be spare capacity, how many barrels do you expect to transport by doubling in 2025? All right. The Oldelval Duplicar project is expected to come online by April of 2025. We have already secured 6,000 barrels in this first stage of Oldelval and on top of that we already have agreements with other producers in order to make use of their idle capacity for an additional 6,000 barrels. So we will be then in a position to have by April of next year 2,000 barrels of evacuation capacity which will match our production forecast. On top of that we have enough treatment facilities by September of 2025 in order to produce 18,000 barrels which we expect to be in a position to make use of idle capacity of other producers in the original Oldelval Duplicar project and move those additional 6,000 barrels through that pipeline. At the same time we are working with Oldelval still in the first steps of what might be an additional increase in the total transportation capacity. That adds up to approximately 120,000 additional barrels out of which we will be in a position to eventually contract 12,000 barrels additional capacity. Thank you. Next question from Daniel was about Rincón de Aranda's plants, but we already answered that. So the fourth question is about power generation. What would be the EBITDA impact in Pampa's units? If Pampa decides to adhere to the Secretariat of Energy plan and we would like to know if this plan would involve additional CAPEX commitments. Have you considered increasing the company's footprint with new generation plans? What is the current state of Argentina's energy matrix? And when do you see, when do you foresee an energy shortage? Okay. Regarding the impact on EBITDA of this incentive that the government has published a few weeks ago, we estimate that it's an impact of around $10 million per year. Regarding CapEx, obviously it requires in all of the equipment some additional CapEx that we're still working on. We haven't replied yet to the request from the Secretary of Energy. So this is a work in progress. But yes, it requires additional CapEx. In terms of EBITDA, it's around $10 million per year. Regarding increasing our footprint in power generation, it's a possibility, but today there is. We've been doing so on renewables and we are, as Lida explained, about to complete the PEPE VI wind farm with 140 MW of capacity in terms of thermal generation. We presented last year a proposal for a 300-megawatt thermal plant in Genelba, but that was for the auction. That was. Finally this administration decided to cancel or postpone and today, given the regulatory environment in terms of thermal generation, there is no possibility to increase because the deregulation has not happened yet. And you also ask about the situation of the energy matrix or the energy generation. I think Argentina has enough capacity in place to supply the system. Most of the time there are a few weeks during the year, so there are probably six weeks a year with very extreme weather conditions. Those could happen. In summary, in Argentina they could happen either in December or in February or March, January because of the holidays, usually there is no problem. But in those months, in the weeks with prolonged very extreme weather, their requirements of the system might put the system to a limit. As long as we are able to import, as we have been importing electricity from Brazil mainly and from Uruguay, we should be okay unless something unexpected happen. And during winter it's same situation with a little bit less stress. So there are a few weeks a year with a stressful situation and that needs to be addressed. Other than that, the system is okay for its current requirement. Thank you. Next question from Daniel says, "Could you give us an update on the gas transportation and transmission tariff schemes? Basically TGS already requested to extend the date. Right now it's no longer RTI. The name is RQI. Right. Like for the next five, it's RQI and basically they're requesting to extend the due date of December 31st to more because the processes of the delay behind against the electricity utilities. Electricity utilities. However they did have a schedule public hearing for Transener on November 4th and it was postponed with no date and we are expecting a new date. I am talking about Transener and then TGS. What we've been doing lately actually is focusing on extending the license and actually I think last week we had. That's all the other week we had the two. No, two weeks ago. Right, yeah. The license extension. Probably hearing that this, that was a very key part of the process to get the license extended. The processes are pretty good. The idea is to have the RQIs or RTI sooner than later. Thank you, Lida. Last question from Daniel is about what is the current status of Pampa's and its subsidiaries' receivables with Gamesa and in what time frame are the invoices being paid? They're basically paid on time as has been the case since early this year. We are paid. Last six months we have been paid with three or four days of delays. So right on time. Both from CAMMESA and from Enarsa. Thank you. Next questions come from Ignacio Sniechowski from InvertirEnBolsa. First one says, "Do you see any chance of renewing Mendoza's hydro concessions? The government has not yet decided what to do with those concessions, although we believe that the intention of the government is that they will remain in private hands or operated by private operators. So. Once they decide how they move forward, we will be able to give you a more straight answer. Definitely we do have interest in hydro concessions. It could be the Mendoza or it could be any other hydro concession in the country because if they are auctioned again by the government, that could be all of the concessions will be for an opportunity, a potential opportunity. Thank you boss. Next question from Ignacio is about Vaca Muerta Sur project. So we already answered that. And the last one, it's about OCP Ecuador. What are the negotiations or extension plans for the concession of OCP? So finally we've been informed that the government has decided that the asset should be returned to the state at the end of the concession on November 30 with plans to launch a new bidding process later on. So now we are collaborating with them and following all the contractual steps needed for the return of the asset to the government. In this initial phase that they are proposing. Thank you, Nico. Next questions come from Gustavo Faria from Bank of America. First one is about Rincón de Aranda. So we already mentioned. Answer that. And the second one is regarding the reversal of the Northern Gas Pipeline. How do you see the upsides from gas from local market and exports to Brazil in terms of production and pricing? And what are the pending developments to increase the gas exports from Argentina? Okay. Regarding the opportunities of exporting gas to. Brazil. We've been developing contacts with Brazilian traders. The issue here is what's going to be the final transportation tariff to go from Neuquén to eventually the end consumer in Brazil. That's going to be basically the big question mark on whether the Argentinian gas is going to be competitive in Brazil or not. But luckily we do have an alternative for the gas flowing through the northern pipeline, which is the Chilean generation market in the mining sector of Chile, in the north of Chile. So it would be a competition of these two markets for the Argentinian gas flowing north, which accounts approximately from four to five million cubic meters per day. So in a nutshell, we do have two markets, one which is the Chilean market, which seems pretty anxious to get some of the Argentinian gas as well as the Brazilian with the. In this case, a question mark of how competitive the overall transportation tariff is going to be. Thank you, Alessia. Next question comes from Raul Singh. Can you please provide guidance related to gas production for 2025 and onwards? Yes, we are forecasting to end 2024 with a production of on average of around 13 million cubic meters per day, reaching peaks of around 16 million cubic meters per day. Next year we see the average production of Pampa increasing a little bit to 13.1-13.2 million cubic meters per day and reaching peaks of around 14.3-14.5 million cubic meters a day, including exports to Chile. So that's more or less the answer to question. Thank you. Next question comes from Florencia Mayorga from MetLife. After refinancing 27 and leverage at 0.8 x, which are the next steps for the group? Hello Florencia. After the refinancing of the 27th, I think it was a very good deal for the company and the country issuing debt with the minimum coupon for an Argentine company in the last five years. We are very comfortable with our level of debt and our debt profile considering all of the projects that the company has in the pipeline nowadays. We do not see a necessity to go to the markets in the short term. Although we do not rule out taking action in the coming months to extend the maturity of the remaining 27 if we see a very favorable window in the market. Thank you, Nico. Next question comes from Matías Castagnino from Adcap. First one says, with the proposed government reforms allowing free contracting in the term market, how does Pampa plan to position itself competitively? Thank you for the question. Our competitiveness. We are very optimistic. We are eager for this regulation to happen because we believe Pampa has many strengths to manage itself in this, in a free market for two big reasons. One is because Pampa is an integrated company, so the fact that we produce the gas that our thermal plants will burn give us significant competitive advantage. The second is related to our portfolio of power generation plants, and not only we have several combined cycles, extremely efficient in terms of thermal efficiency, but they are also well located in terms that the cost of gas transportation because they are located at wellhead is insignificant or inexistent and that give us a competitive advantage vis-à-vis other power generation plants that need. That needs expensive transportation capacity and even they need new infrastructure to be built. Another thing is that we have a very seasoned team with a lot of expertise. Our commercial team in power generation is well trained with a lot of expertise. We are one of the biggest players on the matter. We are very comfortable to face that expected new environment. Thank you. Next question from Matías is regarding hydro concessions. So we already answered this. Now Sebastián Lacunza is asking regarding LNG projects which we already answered. And the next question says is Pampa's seeking to sell legacy plants into Tucumán? First of all, we don't have power plants in Tucumán, and secondly, we are not seeking a buyer for any of our power generation assets. Thank you. Mono, I don't know if you have. If we have more questions. There's one from Matías Castagnino. I think it's a follow up says how much upside can you have from the deregulation the segments EBITDA in the following years? I guess he's talking about power, right? Yeah, but that's too soon to tell. Let us read the new regulation and do the math and yeah, I come back to you. But we don't know what is it going to look like yet. So we don't have any more questions. Thank you everyone for your questions. And now I will turn to Lida for final remarks. I know, thank you so much for speeding up to get here. I don't know if you have any remarks that you wanted to add. I think we covered it all pretty well. Right. The next call is next year, so we don't see you all until the next year. Beforehand we will. If you have any questions or doubts or if there's any unanswered questions, just let us know. Contact us at investor.pampa.com. We're always happy to help you. I bid you good day. Bye. Thank you for joining. Bye. Thank you.