GeoPark Ltd (GPRK) Q3 2026 Earnings Call Transcript

If you do not have a copy of the press release, it is available in the Invest With Us section of the company's corporate website at www.geo-park.com. A replay of today's call may be accessed through this webcast in the Invest With Us section of the GeoPark corporate website. Before we continue, please note that certain statements contained in the results press release and on this conference call are forward-looking statements rather than historical facts and are subject to risks and uncertainties that could cause actual results to differ materially from those described. With respect to such forward-looking statements, the company seeks protections afforded by the Private Securities Litigation Reform Act of 1995. These risks include a variety of factors, including competitive developments and risk factors listed from time to time in the company's SEC reports and public releases. Those lists are intended to identify certain principal factors that could cause actual results to differ materially from those described in the forward-looking statements, but are not intended to represent a company list of the company's business, a complete list of the company's business. All financial figures included herein were prepared in accordance with the IFRS and are stated in U.S. dollars unless otherwise noted. Reserves figures correspond to PRMS standards. On the call today from Geopark is Philippe Bayon, Chief Executive Officer. Ayemi Caballero, Chief Financial Officer. And now, I will turn the call over to Mr. Philippe Bayon. Mr. Bayon, you may begin.

I would like to highlight two important developments that reflect the progress we are making in transforming GeoPark into a more diversified energy company with multiple platforms for long-term growth. Earlier this week, we announced the successful completion of our strategic entry into Venezuela through the body block following the effectiveness of the 25-year production participation contract with PDVSA. This milestone was achieved well ahead of the original contractual timeline and reflects the execution capabilities of our teams and the constructive collaboration we have built with PDVSA. With the contract now effective, our focus shifts to the safe and disciplined operational takeover of Vare, which we expect to complete before the end of the year. We have already assessed approximately 300 to 400 wells for potential reactivation, establishing a foundation for the initial redevelopment phase. The transaction adds a large-scale, long-duration redevelopment opportunity to our portfolio with significant potential to restore production by leveraging existing wells and infrastructure. It also marks an important step in our strategy to build a more diversified regional platform. We also announced recently the award of Corralera Noreste Block in Argentina. Adding approximately 26,900 gross acres to our position in northern Vaca Muerta. This is a very important expansion to our unconventional portfolio with material resource potential and a strategic location adjacent to an expanding development area. We will approach this opportunity through a phased appraisal program, applying the same technical discipline and investment criteria that guide our capital allocation decisions across the company. Together, these developments reflect the progress we have made in expanding our portfolio beyond Colombia while preserving the strong operating foundation that has supported Geopark's growth over the past two decades. Turning now to our third quarter results, we delivered solid operational performance with stable production in Colombia and accelerating growth in Argentina. Consolidated production averaged 27,973 barrels of oil equivalent per day, increasing approximately 3% compared with the prior quarter. In Colombia, production remains stable at approximately 25,900 barrels of oil equivalent per day. Our Janos 34 block continued benefiting from water flooding and polymer injection projects, while Janos 123 delivered higher production supported by ongoing development activity. At CP05, we also achieved encouraging exploration results, including the Milano 1X Discovery, which has been testing at around 1,000 barrels of oil equivalent per day, reinforcing the remaining potential of our Colombian portfolio. Argentina continues to demonstrate the progress of our development program. Production increased by 51% quarter over quarter to approximately 2,100 barrels of oil equivalent per day, following the successful completion and start-up of five wells at Pad 1030 in Loma Jarrillosa Este. These wells underwent 180 hydraulic fracturing stages and gross fuel production exceeded 5,000 barrels of oil equivalent per day following their startup. We are now preparing for the next phase of development with a focus on transitioning towards a more continuous and efficient drilling and completion program. From a financial perspective, the third quarter was more challenging. Despite our good operations performance, although Brent prices remain relatively strong, averaging $91.4 per barrel, our results were significantly affected by wider crude oil differentials in both Colombia and Argentina. In Colombia, the Vasconia differential widened from a discount of $1.43 per barrel in the second quarter to $6.67 per barrel. In Argentina, the Medanito differential shifted from a premium of $1.79 per barrel to a discount of $3.50 per barrel. These movements, together with the impact of our existing commodity hedging contracts, reduced our combined realized price to $56.20 per barrel of oil equivalent compared to $67.20 per barrel in the prior quarter. Our commodity risk management contract resulted in a negative impact of $36.4 million on revenue compared to $41.2 million in the second quarter. In response, we have continued to actively manage our hedge portfolio to improve future price protection and participation in stronger market conditions, including optimizing our fourth quarter positions and extending coverage into 2028. At the same time, operating costs increased to $20.70 per produced barrel of oil equivalent. Compared to $17.90 in the prior quarter, mainly reflecting higher energy costs, increased well-intervention activities, and the appreciation of the Colombian and Argentine currencies, we recognize the importance of addressing these pressures. Our teams are implementing operational efficiencies and cost optimization initiatives, including energy price hedges, designed to mitigate price volatility. As a result of these factors, quarterly revenue reached $116.2 million and adjusted EBITDA totaled $45.8 million, representing a 39% margin. While financial performance was below the prior quarter, our operational results demonstrate the resilience of our portfolio and the progress of our development program. We remain focused on improving margins and cash generation through disciplined execution and active cost management. During the third quarter, we invested $72.2 million, primarily focused on development activities in Vaca Muerta and continued production and infrastructure investments in Colombia. Operating cash flow was also impacted by lower profitability and working capital requirements. As expected, during this phase of elevated investment, free cash flow remained negative. This reinforces the importance of maintaining a disciplined approach to capital allocation and preserving liquidity as we advance our development plans. At quarter end, GeoPark held $253.4 million in cash with net leverage of 1.6 times the last 12 months adjusted EBITDA. Following quarter end, we successfully completed our liability management transaction, including a $550 million senior notes issuance due in 2033. This transaction extended our debt maturity profile, addressed our near-term refinancing requirements, and secured long-term funding for a substantial portion of our planned investment program in Vaca Muerta. It represents an important step in aligning our capital structure with our growth strategy and provides greater financial flexibility as we move through this investment phase. Looking ahead, we continue to expect full-year production and adjusted EBITDA to remain within our guidance ranges, supported by growing production contributions from Argentina and Colombia and the optimization of our fourth-quarter hedge positions. Our priorities remain clear. Complete the safe operational takeover of the body block, accelerate development in Vaca Muerta, sustain the performance of our Colombian assets, and maintain discipline in the allocation of capital. When I look at the progress we have made over the past year, I see a company that has significantly expanded its growth opportunities while continuing to build on the operating strengths of its Colombian business. We recognize the challenges reflected in this quarter's financial results, and we remain focused on the actions needed to improve profitability, generate sustainable cash flow, and create long-term value for our shareholders. Finally, I want to recognize our employees for their commitment to safety, operational excellence, and disciplined execution, and thank our partners and shareholders for their continued support. Thank you again for joining us today. With that, we are ready to take your questions.

We will now begin the question and answer session. If you would like to ask a question, please press star 1 to raise your hand. To withdraw your question, press star 1 again. We do ask that you pick up your handset when asking a question to allow for optimum sound quality. If you're muted locally, please remember to unmute your device. If you would like to submit a question via the webcast, you may do so by clicking the Q&A button in the bottom right corner of your screen. Now please stand by while we compile the Q&A roster. Your first question comes from the line of Jacob Roberts with TPH Research. Your line is open. Please go ahead.

Good morning. I wanted to start on Venezuela and some of the numbers that were referenced in the September call and then also this morning, but roughly we're looking at 300 to 400 reactivations, I think 100 workovers, and then 30 potential neutral horizontals by 2030, I think with the neutral starting in 2028. So now that the CPP is effective, you're taking over before year end, can you walk us through the cadence across those three buckets year by year to reach that 2030 exit rate?

Thanks, Jacob, and good morning again, everyone. And good news, I found the unmute button, because I didn't at the beginning of the call, so apologies for that. I think you may have missed my first sentence. So, absolutely, Jacob. In terms of body, the body block, we signed the contract, and we had up to 120 days to make that effective. We actually took only 65 days, roughly, to make that happen. So we're well ahead of schedule, which is great. And currently, we're, I mean, with our teams and working with PDVSA to take over the operation before year end. So, a lot of activity, a lot of preparation, a lot of work being done in terms of supply chain, people, and the likes. But I'd like to ask Martin, you know, to take us through some of the details, especially around reactivations, workovers, and everything else, and how we're viewing that. Martin.

Absolutely, Felipe, and good morning, Jacob. So I'll put a little bit of color into where we are and reiterate what Felipe was saying. Safely taking over the operations is our top priority. And that's something that we're planning and feel comfortable on doing before the end of this year. The first phase of the three phases that we presented is reactivation, followed by drilling, and then steam injection. So for the first year, we're going to be doing reactivation, and eventually we'll start doing drilling next year. What we have, and when we look at the numbers, out of the... 300 to 450 reactivations we're going to be doing by 2030. One-third of those would be done next year. So we're talking about 100 to 150 reactivations that we're going to be performing. That's basically OPEX. When we move to the next category, which is workover, so you spend a little bit more time on that and more money. Out of the 100 workovers that we said by 2030, it's going to be about a fourth. So 25% of those will be done in 2027. And then when we talk about drilling, by 2030, we did say 30 wells, that's about... 12 to 15 wells per year, and we will start drilling operations in 2028. So from drilling perspective, it's zero for 2027. Now, I do want to take a few more minutes to talk about two things. One is readiness, and the other one is our relationship with PDVSA, which is very, very good. On readiness, Right now, we have more than 50% of the contracts that are critical to takeover operations already awarded, and we're awarding the remaining in the next two to three weeks. So we feel confident about that. And which are those contracts? That's rigs, chemicals, artificial lift. Tubulars and engineering, because on the reactivation, it's not only reactivating wells, but we are aware that as we go into some paths, we will have to do some engineering to understand integrity of facilities. So that one, we feel very good about it. And actually, we had a... A visit with PDVSA in which we got really high ranking, and that's part of the requirements to get the effective approval. The other one I want to talk about, readiness teams on the ground. We have teams both in Caracas and in El Tigre for the past month and a half. We have offices in both places, and we already have an understanding on the names of the PDVSA employees that are going to be joining the VARE block development. And finally, I just want to say once again that we feel that... The reason why we have been able to accelerate this timing that Felipe was saying to be effective is not only what Geopark is doing, but our relationship with PDVSA, and we continue to work on many fronts, including identifying which of the wells that we're reactivating jointly with them. So I feel very good about what's coming in Venezuela.

Thanks, Martin. Thank you. That was great detail and super helpful. And then for my second question, I wanted to move to Argentina, and I apologize for my pronunciation here, but in the Corollera Noreste, we just don't have access to much well data. And so I'm wondering if you could talk about the technical case of the asset and specifically what data your team was looking at, what you're seeing in terms of rock quality, all those kind of details, and then ultimately what you're expecting out of the asset to make it competitive with the current Wacomerta blocks.

So absolutely, Jacob, and before handing over to Rodrigo, I'll just give you a bit of context, which I think is relevant. The first thing is that the award is official now for Corralera, so that's great. We're in the process of closing, so it will take some weeks probably to get everything sorted in terms of the contracts and everything else. And as probably you're aware, and we've announced this to the market, we have four years initially to do a lot of work to de-risk the area. And I know Rodrigo will go into some detail, but briefly, if you think about the neighborhood, obviously this is different from where we have the other two blocks that we're operating right now, but there's probably around 80,000 barrels of production being done by other companies in the area. This is around 27,000 acres gross. So that would take us, in terms of geopark, adding the existing two blocks and this one to 39,000 acres, which is great. And we've identified, remember in Loma Jarrillo and Puesto Silva, we have two landing zones. In this one, we see two to four landing zones. So, good news, we have the acreage. We have the possibility of starting the work. We have four years to start this de-risking. So, in that sense, we can phase things accordingly in terms of capital efficiency and logistics and everything else. So, Rodrigo, if you can provide us a bit more detail, that'd be great.

Sure. First of all, this asset we consider complement our current portfolio in Argentina because we have 12,000 acreage, as Felipe mentioned, three years of development in the current asset. This new asset can provide, before the activity that we have to do to evaluate the subsurface potential, another 27 acreage that allow us to continue developing the area with the drilling rigs and also with new wells. The asset is located in the oil window, so that is very important for us. It's located in the north of the basin, in what we call the new hub near to infrastructure, so that is good. Chevron, PlusPetrol, TechPetrol, and YPF in the north actually are developing and conventional in the area, so that's why we believe we are in the bright neighborhood. The information you asked about, the information we have, the previous operator did a well. With the well, we know that the reservoir is there. What we are going to test during these four years is the potential and the productivity of the well. One of the uncertainties that we have is the water cut that we are going to produce. The well type that we are looking for here is similar like El Trapial. In the south, it's Chevron producing from El Trapial. Very good result from there. So what we are expecting is trying to achieve that well type. We are talking about more than 1 million barrels per well in that case. The landing zones that we are going to test during these four years is the T7 and the Veracium. Those landing zones are tested by the neighborhood but not tested by the previous operators. That's why we are going to introduce something new in the equation here. You asked about competitiveness. So the plan that we have today is preliminary, as with the information surrounding. We are talking about more than 120 wells for the development. We are thinking about conventional well at the moment, so 3,000 lateral length, because the polygon of the block allows us to think about that. We have more than $120 million of potential reserves in the future, and the wealth cost is between $14 and $15 million, as you can see in many of the other operators in the area. So it's preliminary. We have to test the potential of the reservoir, but that's the bed that we have in Baca-Morota today.

Thanks, Rodrigo.

And thanks, Jacob. Great, Tom. No, thank you, guys. I appreciate the time.

Your next question comes from the line of Alejandro Demicheles with Jeffries. Your line is open. Please go ahead.

Good morning, guys. Thank you very much for taking my questions. A couple of questions, if I may. The first one is, Felipe, you mentioned your focus on the cost structure now, that all of the team is looking at that. Maybe you can kind of... Indicate how you've seen this evolution of cost, both in Argentina and also in Colombia, and also with the new acreage that you have coming up in Venezuela. And the second question is a bit of a follow-up on what you discussed on Venezuela. Now you have closed the deal. There's still some kind of milestones that may trigger or may not actually trigger, call it an extra amount of shares for your controller. So could you kind of explain what those milestones are and how you see those kind of evolving?

Thanks, Alejandro. And if I may, I'll probably start with the second question, and then I'll ask Jaime and Martin to help us with the first one. So in terms of the body block, you know, and how do we view it? As I was mentioning before, Alejandro, we still need to start operations, which is great. We want to do that. Before year end. And, I mean, all the attention focus is on that. You know, how do we, as Martin was explaining, conduct operations in a way that's safe, that's efficient. And again, we're going to start, even though we've done assessments of the area, of the wells, we've gathered the data. It's one thing when you go in and get to the field and start putting the wells into operations and restoring production. So that's going to take us some time, and Martin was clearly explaining. Focus is going to be on reactivating the wells. The good news, the well stock is very ample. You know, we've looked at the 300 to 400 of the 1,100 wells, and next year it's going to be 120 or something in that range. So from that point of view, I think, Alejandro, we're good. In terms of the milestones, you know, that may trigger or not, and probably Jaime can go into some more detail, we did announce the issuance. of the shares related to Bari, to the Bari block, and we announced a potential additional of shares that could be triggered by milestones, mainly related to some tax events that could happen in Venezuela. So, Jaime, do you want to talk a little bit about that?

Yeah, sure, absolutely. So the muscles that Felipe refers to, they're basically linked to the tax conditions in Venezuela, particularly around corporate income tax that applies to the different types of fields that you have in Venezuela. The specific circumstance is that there is an ongoing discussion between the Venezuela Executive and the Congress around what are the most appropriate conditions to reactivate the industry going forward. And in that context, there is the possibility that the corporate income tax that is applicable to a field such as FIRE gets a downward revision. So currently, our business case has the assumption that we're going to be paying a 50% corporate income tax over time, and there is the possibility that this could be reviewed downwards over the next few weeks. What we have agreed with Grupo Dinisti as part of this transaction is that if these revisions occur by the 1st of December of this year, we would have that adjustment. Importantly, the revision needs to be absolutely clear in scope. It needs to be very clear that it applies to VARE in its integrity, and if we have that condition met, then we would apply this clause that That implies an additional shared grant to the group of GDCC.

Thanks, Jaime, and if we can go to the first question from Alejandro on cost.

Sure. So, Alejandro, sorry, and I didn't actually say hi. So, on cost, I would start by saying that, of course, the company continues to have a very astringent view around, you know, operating costs, and we are very conscious that over this quarter and the last, we've had a significant increase in our unit costs, right? I think the way to think about it is if you think about our earlier guidance for this year where we were in the $13 to $15 per barrel range, and now we're at $20, how do we describe the $5, $6 of difference? And fundamentally, what's happening is two-thirds of that variation is associated to Colombia macro factors that are largely outside of our control. It's energy costs, which represent about $1.5 per barrel, and the FX impact associated to a stronger vessel that represents about $1.5 per barrel. The other element, the other one-third, is more activity. We're having more activity levels in Janos 34 in particular, and Martín is going to explain that in a moment. I want to focus on what's going on in energy and in FX and what we're doing about it. Basically, in energy, due to the gas shortages in Colombia, which imply significant imports, we're having a material increase in the cost associated to electricity coming from the grid. There's a number of sources. I don't want to go into a lot of detail here, but basically That expansion of imports associated to gas reflects in spot prices in the grid. In GeoPark, we've had historically a significant exposure to spot pricing because it's proven to be most cost effective over the long term than fixed prices. That was the reality in the past, right? As we go into this transition in the Colombian energy grid, that's changing, and we're moving to a place where spot pricing is becoming very volatile, it's expected to grow over the next few years significantly, and we're making that transition from spot price to fixed price. And that gives us a better outlook going forward. There's three specific things. The first one is... We're basically going to move from a place where about 60% of our pricing is fixed, coming from Pell, which is the grid that hits Llanos, to a place where only about 45% is going to be bought from Spots. The second thing that's going to kick in is Pell grid rates. It's a commission with a new government that governs energy matters in Colombia already made an intervention that represents about a 30 percent discount on energy rates that we're getting from the grid. That's kicking in as well this quarter. And the last thing that I want to highlight is some energy hedges that we have contracted. Those energy hedges basically guarantee us a fixed price. The rates that. The spot pricing that we paid over 3Q. And all of that starts to kick in in 4Q. That gives us a better outlook. Now, as we look into the longer term, well, 2027 is moved to a place where about 75% of our demand is And we will keep With regards to FX, What's going on between the Colombian peso and the dollar? Essentially, what we're doing is we are ensuring that we have downside protection. If we have an extreme scenario where the exchange rates go below 3,000 pesos per dollar, we're protected against that. We have hedges that protect us against that. So if you will, the downside exposure is already limited. The The other thing that we're doing is we're reviewing our entire call space. To see where we can have opportunities to improve efficiency and mitigate that exposure that we have. Having said that, to the extent that the FX rate stays at the current levels around 3,200 pesos, 3,300 pesos per dollar, we will continue to have that increase, if you will, dollar-based exposure. So with that, I'm going to hand it over to Martin. Talk a bit more about the activity drivers.

Yeah, I'll build on Jaime and Alejandro. Thanks again for joining our call. So, if we think about Colombia... Jaime was saying, you know, 1.5 energy, 1.5 exchange rate, and that's dollars per barrel. And the remaining is maybe operations. And for Colombia, if we think about channels 34, and that's where most of the OPEX increase has happened, I'll talk a little bit about channels 123. But in Channel 34, the first half of the year, we had a failure rate that was outside of the ranges we used to have. That means more pooling jobs than expected. That has changed. We are not having that in the second half of the year. And the other component from that incremental in pooling jobs is... And proactively, we have done what we call deepening, which is basically to put the well, the pump at a lower depth or a bigger pump and produce more fluid so that we can arrest the declines. And we still have some of those candidates early in the year. So that's when you think about the pooling reason for the OPEX being higher. So what are the things that we're doing in Colombia to arrest part of these incremental OPEX? And I'll say it's mainly two big buckets. The first big bucket is water management. So that's why workovers are so important in Channel 34. Some of those workovers are doing water shutoffs or they're doing incremental production or both, and we continue to do workovers. We're actually doing about eight more workovers than expected, agreed with our partner, and they're delivering good value. When you look at channels 123, water management means simplifying and reducing water tracking, and so we've done that. In the past nine months, we have two paths, and we have reduced the water tracking between paths by engineering some of the facilities so that we can treat the water and inject it in the same location. So that's... Another of the things that we've done. And then the other component is for Colombia, what else can we do on energy efficiency? And one of the things that we're doing is, like Jaime was saying, not only hedges, but can we switch a little bit the feed of our machines from diesel to other sources? So that's giving us some savings. Year to date, we got savings of around $7 million that are being contra-arrested with the effect of exchange rate and energy. And I don't want to forget about Argentina. And yes, Argentina is contributing with around 5,000 barrels of the total production that we got. And for the quarter, it was, like we mentioned, around 28,000 barrels per day. But Argentina, when we took over operations a little bit over a year ago, the OPEX was high 20s, low 30s. Between $29 and $32 per barrel. I don't remember exactly, but that was the order. And now we are below $10 per barrel. And that's because of all the work, and you guys have followed us on the facilities and the investments. I'm very proud of what the TILIC has done, incident-free, and now we are not tracking crude. The crude goes into a pipeline. We're not tracking water. The water goes into a disposal well, and we're also piping the gas. So all of those things, plus the upscaling that we did in Loma Jarichosa battery, is helping us keep the OPEX on the trend that we have in mind, and it's our plan.

Thank you, Martin. Thanks, Jaime.

Thank you very much for...

And we now have a few questions from the webcast. Daniel Guardiola from BTG asks, Given Felipe's experience operating large oil and gas assets across Latin America, which do you believe represents the greater execution challenge today? Scaling up a relatively new unconventional development in Vaca Muerta or rehabilitating a mature, underinvested asset And how does that assessment influence where you allocate management attention and capital?

Thanks for the question. And Daniel, thanks for following us always and for the interest in the company. So I'd say that the two are different, and they actually give us probably different challenges and different opportunities. If you step back for a second and you think about Geopark. And I think with the current portfolio, now that we've made BARE effective, the CPP contract effective, we're in reality with a platform in Latin America that has conventional oil in Colombia with heavy crude as well, unconventionals in Argentina, and extra heavy oil. In Venezuela. So three different types of crude, three different operations. The good news, over the last year, in Vaca Muerta in particular, and with the team that we've managed to assemble, with a lot of people with many years of experience around unconventionals, We're actually advancing well, you know, in terms of activity, in terms of intensity. And as we've described before, Vaca Muerta is going to be a highly intensive capex development over the next few years. So it's about execution on drilling and factory mode drilling, which starts in December. And the good news, we've already drilled five wells. And that was done earlier in this year, in March, April. So all that information, all that experience, all the things that we found in the subsurface have been incorporated into the plans going forward. And the other good thing that we probably haven't talked too much about, we actually just finished a very high-quality 3D seismic survey in the area that's going to provide a lot of data going forward. And so... I'm very specific in terms of the challenges that that And tiles, or that brings with itself in terms of vaca muerta. And we're on track with the investment and the ramp up of production. So that's good. And as Martin was highlighting, over the last year, a good reduction in lifting costs, which is always, always important. And in terms of body, you know, and when you step back again, a field that has, or a block that has close to 16 billion barrels oil in place. Where we've at least identified that over the next 25 years, we can produce some 600 million barrels. It has plenty of opportunities, you know, and it's around reactivation. So challenges there would be around getting the pulling rigs and the small rigs, I mean, the 350 horsepower, 550 horsepower in the field on time, starting the reactivations, getting the right people. And as Martin was highlighting, we've already awarded around 50% of the services that are required. And we're very comfortable. You know, a lot of those companies are companies that we've operated with before or that have a lot of experience in La Faja, which is great. And the other thing, Daniela, I'll step back. I think, and you rightly point out, different challenges, different natures of the developments. We have very, very good teams for both Vaca Muerta and Vare. So I'm very confident with that. And in parallel with that, we'll keep on taking care of Colombia, you know, so we're not forgetting what has brought us here and what's enabling us to take this step. So personally, I'm very thrilled. I'm very optimistic. I mean, there will be things down the road. There will be probably surprises, but I think the opportunity set is one that's very high quality and, again, puts us in the range of a regional platform for investors and for people that want to be with GeoPark for the long term. Thanks for the question.

Daniel's second question is, given the significant losses recognized this year and your substantial hedging commitments through 2028, how are you balancing downside protection against the opportunity cost of capping upside, particularly as production ramps up in Argentina and Venezuela?

Thanks, Daniel, and I'll link it to the... The first question you made, so clearly Argentina and Venezuela are providing additional volumes going forward, so there will be increasing production in Vaca Muerta as we drill and we finish some of the facilities. By the way, over the last couple of weeks, we've already done the initial tie-ins to regional oil pipelines and gas pipelines. So evacuation is something that we're in a much better place right now with reduced trucking. So there will be volumes. And again, as we take control of operation in Venezuela of the body block, we'll start seeing production increase. And I mean, we've told before, in terms of gross numbers, probably around 15 to 20,000 barrels in terms of body. And if you step back, you think that our volumes that are hedged for next year are roughly 22,000 barrels average for the year. So there will be incremental volumes coming in. That will be, to some extent, able to be exposed to higher prices, should they remain. And I think it's important just to step back for a second, you know. A year ago, when we made the decision to enter into two blocks in Vaca Muerta, we very specifically said we need the hedging to ensure that we can fund the CapEx and pay our debts. And we knew that this quarter 3Q in particular was going to be tough and that we were going to be in a sort of a tight spot. But I think it's delivering the strategy going forward. And again, I think we're in a good place in that sense, being able to deliver investments going forward. So thanks for the question.

And the final question from Daniel is, given Grupo Galinsky's role in originating the bear transaction, should we expect additional investment opportunities in Venezuela to emerge through the controlling shareholder? If so, how would Geopark approach funding these acquisitions and what safeguards would be in place to ensure the future transactions do not result in further dilution of minority shareholders or create potential conflicts of interest?

Thanks, Daniel, and great question. And first of all, I just want to acknowledge that working with Grupo Gilinski over the Venezuela opportunity was fundamental to get to where we are today. You know, very, very quickly and in a way that was very efficient. Get the opportunity in front of Geopark and then being able to close on the deal with Grupo Gilinski. And the one thing I'd say, Daniel, is that any opportunity and all opportunities coming forward for the company will be managed through Geopark. So everything will be done using Geopark as a vehicle in Venezuela, or should there be other opportunities going forward? But I just want to reinforce one point. I think that over the last 12 months, we've managed to assemble a very competitive portfolio. And right now, I think our focus is mostly on execution, you know, on delivery of what we've managed to build as a very, very competitive, high-quality portfolio. Thanks, Daniel.

And returning to our audio questions, your next question is coming from the line of Joaquin Robet with Balenz Capital. Your line is open. Please go ahead. Joaquin, are you there? I believe Joaquin has also sent a question. Oh, are you there, Joaquin? We'll move on to our next text question. It comes from Vincente Falanga with Bradesco. What is the company's expectations regarding the timing of the tender process for shares? Is the offer proportional to all shareholders? That's the first question from Vincente. And then he follows up with, in the release, Geopark said it could already assume operations before year end. What will be the key short-term operational milestones for the first 100 days?

I intend to answer your questions. I'll take the first one. Basically, the timing of the tender process is governed by the contract, the PSA, that we agreed with Grupo Gininski, and it basically provides for a 90-day period post-closing to perform the tender, and that initiated last Monday, and it's going to go through the next 88 days, if you will. The offer is proportional to all shareholders, excluding Grupo Jirinski. So it's available to all the shareholders of the company outside of Grupo Jirinski, and in the event of an oversubscription, tenders are going to be awarded on a pro rata basis. Over to Martin.

Yeah, Vicente, thanks for your question. So, in relation to, okay, what are the short-term operational milestones, I'll give a little bit more information of what I described before, but I'll say that it's mainly around safely taking over the operations. It's mainly around incorporating equipment. To the block, and that's so that we can reactivate wells and incorporating equipment is the rigs, we're targeting between one and two rigs to start, and then we will continue to ramp up. And equipment is also well heads, tubulars, and so forth. And the other component in the first 100 years, 100 days, sorry, is make sure that we are just like we did in Argentina. The teams are bonding and that we continue to have a good relationship with PDVSA in our way forward. So how are we going to measure that? I'll say that our key performance indicators for the first 100 days are going to be incident-free operations, so safety again. And then it's going to be around production levels. I mean, where are we on production versus what we got when we started the operations? And then we will move into efficiencies. But I'll say that in the first 100 days, it's going to be about reactivation and safe operations.

Thanks, Martin.

Your next question comes from Joaquin Robay from Balance Capital. And they ask, after the recent bond issuance, how much additional funding do you need through 2027, including Vaca Muerto, Corollera, and Barre? If there is a remaining funding gap beyond the VTOL facility, how do you plan to cover it, and how much of that financing is already committed?

Hi, Joaquin. Thanks for your question. So, first, I'd say that we're very happy to have secure investor support to our growth plans recently with these foundations. You know, the 2033 tenor provides ample room to deliver our growth plans that are, you know, that revolve around the portfolio transition that Felipe has described. So, from that angle, it's very strategic that we are getting that investor support, and we really appreciate it. Now, when we go into the numbers, you know, when you look at the net proceeds of the recent issuance, once we refinanced the 2027s, which we already did, so that's taken care of, and the 2030s, everything that was standard, our net proceeds sum about $170 million. So, that $170 million need to be added to our existing cash position, which, you know, as you would have seen in the three-year results, was in the order of, you know, $250 million. And on top of that, we have a number of available committed lines undrawn, which include VTOL, but there's more to that. We have a couple of other lines, including a club line with a set of international and Colombian banks that is in the amount of $150 million, plus a number of revolving facilities in China, which are available to the Vaca Muerta operation, which together, those lines in Argentina amount to about $150 million. So, where I'm going here is that, basically, when you add all that up, we're talking about available financing in the order of $600 to $700 million, which provides ample leeway for what we're trying to do in Baca Muerta. To put that in context, of course, as we look at market conditions over the next year and how Vaca Muert is progressing, we're going to be seeing what is the most efficient use of those lines. And I would characterize the Vittorio line and the contingent line with the club deal as contingent lines. They're safety nets. They're not part of our core plan, but they're available. So I think our decisions around funding Bacamuerta are going to depend a lot on how market conditions evolve over the next, you know, 12 months or so. But 2027 is funded, you know, in aggregate, including all the requirements, not only of Bacamuerta, but of Vare and Corralera. Thanks.

Thank you, Jaime.

And our final question is from Andres Pautista. Pau Tasso from Argentaria. I am surprised by the level of Vasconia differential over the quarter and the transport cost. What are the main drivers that affected them during their quarter? What do you foresee for the remainder of the year and first half of 2027? Mitigation measures you are taking to counter the impact on realized prices.

Hi, Andres, hola. So I'm Vasconia. So the first thing that I would say is that we were also surprised with what's happening in Basconia. This is completely unprecedented. It's completely unexpected, right? And we need to start from there, right? It's a very, very atypical market situation that we have never seen before. It doesn't affect just your park. It affects all the Colombian operators that use the Basconia reference. And it's not just affecting Pasconia, it's affecting basically all the heavy oil crudes that go to the Gulf of Mexico refineries, you know, essentially. So this is an industry issue, which actually has no point effects on Medanito, but it's primarily right now about Colombian crude that's going to the Gulf of Mexico, and that's the connection with Pasconia. So basically what's happening, it's multiple factors, but I would summarize it around three things. Basically, with the sustained high prices that we have seen over this year, it provides an incentive to otherwise not profitable heavy oil to be produced. So basically, we're getting new supply from Canada, from Mexico, into the Gulf of Mexico, which is in turn depreciating, if you will, or taking off competitiveness of Colombian crude. That's one of the factors. The second factor is that freight costs... Have gone significantly high, you know, across the Caribbean, and actually it's a worldwide phenomenon associated to that Hormuz disruption, what's going on in the Gulf. Basically, as the conflict has sustained, you know, for now more than six months, it's all reflected in freight costs, and those freight costs are affecting the Lasconia differential and the transport costs associated to that crew. So that's the second important component, I'd say. Now, when you think about is this structural or temporary, our view is this is not structural. This is linked to the current oil market conditions and disruptions. And to the extent that those geopolitical situations unwind, this is going to go back. This is going to go back to normal because the fundamentals are still there. The crude hasn't lost its quality. The crude hasn't lost its appeal for the Gulf of Mexico refineries. So, that should normalize. The question is, how long is it going to take? And we don't know. We don't know how long is it going to take. So, what are we doing about it? We're doing two or three things. The first thing is, we're actually... We're optimizing our hedging positions, you know, and there's been a number of questions around hedging. We've left space within our hedging policy to do a specific, you know, like, if you will, surgical interventions in our hedging positions, and we're doing that in the fourth quarter. Basically, what we've done is we've taken part of the volume that we have hedging for two, and we released the ceilings that we had associated to that through a rollover mechanism. Basically, what we're doing is we are taking the existing positions into the future at better pricing conditions because the futures curve has improved, and we are giving ourselves more room to capture a higher pricing in 4Q. That should, to a large extent, offset what's going on with Baskonia, provided that stays, you know, within reasonable levels. And we're going to see how that evolves over the next. You know, 45 days. That's been one intervention. The other intervention that we're doing is revisiting our commercial strategy along with other operators that use Tabasconia reference. You know, we're not alone. If you look at basically all the Colombian operators used either directly or indirectly Tabasconia reference, and we are in discussions with them around how to navigate this situation. In terms of whether there's possibility of blending groups together, aggregating supplies so we get better conditions, and things like that. And more technical things, such as working with blacks in terms of ensuring that the basconia marker is adequately priced or, you know, if there are opportunities around that. So those are the sort of things that we're doing right now, which...

Thank you, Jaime, and thanks, Andres, for the question.

This concludes the question and answer session. I would now like to turn the call back over to Mr. Bayon for closing remarks.

Thank you, and thanks again for being here with us today, for your interest in Geopark. We're very excited with the moment we're in, in terms of our strategy that was laid out almost a year ago, when we decided to protect what we have and get back to growth. Growth does come with some pains, you know, and we've had to increase our level of activity, our CAPEX, and we've addressed some of those issues during our release and during this call today. We are on track in terms of Vaca Muerta. You know, there's going to be intensity ramping up as we drill more wells and we have factory drilling mode. And we're absolutely thrilled with getting control of operations in body block before the end of the year. And again, thanks for being here today. Thanks for the questions. And hopefully we'll be able to see you in the next results conference call.

This concludes today's call. Thank you for attending. You may now disconnect.