Good morning, ladies and gentlemen, and welcome to Grand Tierra Energy's Results Conference Call for the second quarter, 2025. My name is Michelle, and I will be your coordinator for today. At this time, all participants are in a listen-only mode. Following the initial remarks, we will conduct a question and answer session for securities analysts and institutions. Instructions will be provided at that time for you to queue up for questions. I would like to remind everyone that this conference is being webcast and recorded today, Thursday, July 31, 2025, at 11 a.m. Eastern Time. Today's discussion may include certain forward-looking information, oil and gas information, and non-GAAP financial measures. Please refer to the earnings and operational update press release we issued yesterday for important advisories and disclaimers with regard to disinformation and reconciliations of any non-gap measures discussed on today's call. Finally, this earnings call is the property of Grand Tierra Energy, Inc. Any copying or rebroadcasting of this call is expressly forbidden without the written consent of Grand Tierra Energy. I will now turn the conference over to Gary Guidry, President and Chief Executive Officer of Grand Tierra. Mr. Guidry, please go ahead.

Thank you, Operator. Good morning, and welcome to Grand Tierra's second quarter 2025 results conference call. My name is Gary Guidry, Grand Tierra's President and Chief Executive Officer, and with me today are Ryan Elson, our Executive Vice President and Chief Financial Officer, and Sebastian Morin, our Chief Operating Officer. On Wednesday, July 30th, 2025, we issued a press release that included detailed information about our second quarter 2025 results, which is available on our website. Ryan and Sebastian will make a few brief comments, and then we will open up the line for questions. I'll now turn the call over to Ryan to discuss some of our financial results.

Thanks, Gary. Good morning, everyone. Granteer delivered another quarter of strong operational and financial performance, highlighted by record company production, the lowest per barrel operating cost since early 2022, and enhanced liquidity through a number of initiatives and credit capacity. During the quarter, we achieved record production of approximately 47,200 BLE per day, an increase of 1% from the prior quarter, and 44% higher than Q2 2024. This continued growth reflects strong performance across Colombia, Ecuador, and Canada, supported by successful drilling campaigns and water flood execution. Grand Tierra generated sales of $152 million, down 8% from the second quarter of 2024, primarily as a result of a 22% decrease in Brent pricing, which was partially offset by 43% higher sales volume due to higher production and lower South American oil differentials. Oil sales decreased 11% from the prior quarter, primarily due to an 11% decrease in Brent price, again, partially offset by lower South American oil differentials. On a per BOE basis, operating expenses decreased by 17% when compared to the second quarter of 2024 and 16% when compared to the prior quarter, primarily as a result of lower workover activities and lower lifting costs associated with inventory building Ecuador, power generation, and equipment rentals. This was the lowest operating cost per BOE achieved since the first quarter of 2022. During the second quarter of 2025, grantier incurred a net loss of $13 million compared to a net loss of $19 million in the prior quarter and compared to a net income of $36 million in the same quarter last year. Funds flow from operations were $54 million or $1.53 per share, up 17% from the second quarter of 2024 and down 3% from the prior quarter. Rent price decreased by 11% per barrel compared to the prior quarter and our cash netback only decreased by 1%, illustrating the resiliency of our portfolio. The company generated adjusted EBITDA of $77 million versus $85 million in the prior quarter and $103 million in the first quarter of 2024. A 12-month trailing net to adjusted EBITDA was 2.3 times. However, this only accounts for eight months of Canadian adjusted EBITDA and will continue to have a long-term target of one times. In terms of share buybacks, Grand Tierra purchased approximately 240,000 shares during the quarter. From January 1st, 2023 to July 28th, 2025, the company repurchased approximately 5.2 million shares, or 15% of our shares issued outstanding on January 1st, 2023. Grand Tierra's capital expenditures were $51 million during the quarter, which were lower than the $95 million in the prior quarter and lower than the $61 million in the second quarter of 2024. During the quarter, the majority of capital expenditures were incurred in Colombia on Cohenby drilling and infrastructure. In addition to the $61 million cash on hand as of June 30, 2025, the company currently has approximately $112 million in credit and lending facilities, with $47 million drawn on June 30, 2025. From a liquidity perspective, Grantier continues to advance multiple strategic initiatives to strengthen liquidity, including potential non-core asset sales, monetization of royalty interest optimization of free cash flow and evaluation of prepayment structures all initiatives are progressing in line with our expectations as part of these strategic initiatives we have announced that we have signed a mandate letter with the syndicate of banks for a 200 million dollar prepayment facility backed by crude oil deliveries we are progressing towards full documentation with closing expect in the third quarter of 2025 and funding anticipated shortly thereafter. Also of note, as part of the completed semi-annual redetermination process, the company received confirmation from its lenders that the borrowing base under its Canadian credit facility remains unchanged at $100 million Canadian. This outcome reflects ongoing strength and stability of the company's Canadian asset base. The revolving credit facility continues provide $50 million available commitments with a maturity date of October 31, 2026. The next redetermination will be on or before November 30, 2025. Granteer also employs a disciplined and risk-managed hedging strategy designed to protect cash flows, support capital planning, and enhance financial stability across commodity cycles. The company utilizes a diverse mix of oil and gas hedges with structures that provide downside protection while preserving upside exposure. This proactive approach contributed to a $14 million derivative hedging gain during the quarter. The company also maintains a rolling 12-month foreign exchange hedging program to further mitigate currency volatility. Grantair implemented a robust hedging program to manage price volatility across its operations. For the second half of 2025, the company has hedged approximately 50% of its South American oil production and 60% of its Canadian oil production. For the first half of 2026, hedge coverage stands at roughly 33% for South America and 50% for Canada. The pricing levels of these hedges are in line with the company's planning assumptions and provide downside protection while preserving upside exposure. Grandier has also hedged approximately 40% of its Canadian natural gas production for the second half of 2025. In addition to help manage foreign exchange risk, the company began a 12-month COP to USD hedging program in April 2025, covering approximately $10 million USD per month. We also continue to optimize our portfolio with the signed disposition of the UK North Sea assets for approximately $7.5 million, which is expected to close in the third quarter of 2025. Overall, Grand Tierra's second quarter performance continues to demonstrate our commitment to capital discipline and operational excellence by delivering record production and reporting lower operating expenses per barrel will also enhance our liquidity position through a number of initiatives to add financial flexibility heading into the second half of 2026. I'll now turn the call over to Sebastian to discuss some of the highlights of our current operations.

Good morning, everyone, and thank you, Ryan. Operationally, Grand Tierra delivered another strong quarter, building on the momentum from Q1 and continuing to advance key initiatives across our core areas in Colombia, Ecuador, and Canada. Starting in Colombia, total working interest production averaged approximately 25,100 barrels of oil per day during the quarter, driven by successful development drilling at Cohimbi and Costiaco, and continued improvements in water flood execution in Costiaco, Cohimbi, and Accordionero. At Cohimbi, the remaining two wells from our five-well North Pad program were brought on to production. drilling cost was approximately $3 million per well, representing a 47% reduction from the previous operator's historical costs. Injection of 8,000 barrels of water injected per day in the newly delivered North Pad began in June. Already we are seeing a strong water flood response, with gross production increasing by 2,600 barrels of oil per day in the northern area of the field. At Cosiaco, we completed and brought on stream the Cosiaco 63 and Cosiaco 64 development wells. Both wells were stimulated and placed on production with initial results exceeding expectations. Cosiaco 63 is currently producing 800 barrels of oil per day with a 48% water cut, and Cosiaco 64 is producing 1,300 barrels of oil per day with only a 13% water cut. The final well in the program, COSIACLA 65, was spud in July and is expected to be on production in August. At Accordion Arrow, we achieved record total fluid production of 89,400 barrels per day and water injection of 85,000 barrels per day during the quarter. Field production averaged 14,200 barrels of oil per day, up from 13,800 in Q1. This improvement reflects continued gains in pump-upsizing, enhanced surface capacity, and real-time water flood surveillance. Moving to Ecuador, we continue to execute our strategy and fulfill our commitments. Civil works are underway in preparation for drilling two high-impact exploration wells at the Conejo Prospect on the Tarapa block, with spud expected in late Q3. These will be the final wells under our exploration commitments in the country. The results will help guide further development plans and infrastructure alignment in the region. In Canada, the Simonette-Motany program continues to outperform. The first two lower Motany wells were completed and brought on stream in early April and are currently exceeding management's type curve expectations. The third well in the program was drilled and cased successfully in July. The rig was moved to the next location on the pad and is now drilling the fourth well in the program. The well is expected to reach total depth in August. Both of these new wells are expected to be stimulated and put on stream in Q4. Across the portfolio, we remain focused on capital efficiency, reservoir optimization, and unlocking further value from our diverse asset base. The success of our drilling programs, enhanced field performance, and reduced operating costs position us well to deliver free cash flow and strengthen our financial position through the second half of 2025. Looking ahead, we remain focused on continuing to ramp base production at Cohembe North and Costiaco from our Q1-Q2 development programs, which are delivering very positive results, optimizing accordion aero production with continued water flood enhancements and facility optimizations, initiating the high-impact Conejo exploration wells in Ecuador to unlock additional value from the Oriente Basin, completing and bringing online the third and Simonette Montney Wells while optimizing existing field production, maintaining capital and operational cost discipline while targeting free cash flow generation in the second half of the year. I will now turn the call back to the operator, and Gary, Ryan, and I will be happy to take questions. Operator, please go ahead.

Thank you, ladies and gentlemen. We will now conduct the question and answer session for securities analysts. If you have a question, please press the star key followed by one one on your touch tone phone you will then hear an automated message advising that your hand is raised your question will be pulled in the order they are received please ensure you lift your handset if you're using a speaker phone before pressing any key and one moment please for our first question the first question will come from David Round with Stiefel. Your line is now open. Great. Thank you. Thanks for making the time,

guys. Can I start with a broad question on production, please? I know we just touched on a few of the key highlights. I just want to dig into it a bit more if possible. So firstly, I guess I'm interested in how production has gone so far this year versus where you thought you'd be at the start of the year, whether there were any positive, negative surprises there, and any highlights just to bring out. And I know we just briefly mentioned sort of, you know, Castiaco, Accordionero. I suppose, are we able to just kind of elaborate on current contributions and expectations, I guess, for H2 and beyond for, I suppose, the key moving parts, so Suriente, Ecuador, and Simonette? I don't know if you're able to just elaborate on some of the specifics there.

I think at a very high level, all of our fields have been performing as expected or beyond expectations. We have the normal interruptions both in Colombia and Ecuador with blockades, but we have a very good team that manage those, the impact. We've seen also some infrastructure issues. There's one that's just finishing up in Ecuador at the moment with a very heavy rains, pipeline interruption. But in general, the answer to your question is from a field and asset performance, everything has performed as expected or outperformed. And that's both in Canada, Colombia, and Ecuador. On the specifics, maybe, Sebastian, you could say a few words about rates.

Yeah, so on rates, I think we continue to be very excited. We did an ESP conversion over on Tarapa V7, which has, again, highlighted the quality of the basal tenna in Ecuador. And so that well is currently doing 1,800 barrels of oil per day, and the decline is extremely flat. So we've had some significant wins as well within the portfolio, especially as we continue to develop in Ecuador. And then at Cohembe, the pressure response that we're seeing is really encouraging. And so we see that ramping up through Q3 and Q4.

Okay. So just then a very quick follow-up on that point. So actually, if I think about all three of those areas I mentioned, Simonette, Cohembe, and Ecuador, I mean, should we be assuming ramp up on all those assets over the second half of this year?

Yes.

Okay, fine. Just a second question then, and I appreciate it's not final, but just on the prepay, can you say anything, even in broad terms, about how that might work or just sort of indicatively what that might cost, or are we too early on that one?

Yeah, no, at a high level, we'll be committing to essentially selling oil for future prepayments. It's going to be over about a four-year term, so it's quite long-term in nature, not a huge grind on our cash flows. So just think of it as a loan that really advertises over four years settled with oil payments. terms will be very very competitive and we're quite excited about it and so it's similar to what we've done in the past it'll just be a longer tenor okay great

thank you I'll hand it back thanks and the next question will come from Ann Milne with Bank of America your line is open thank you good morning

congratulations on your results I have a few questions relatively short hopefully the first is could you provide us with an additional any additional updates or your thoughts on other asset sales for this year I believe you mentioned the UK North Sea seven and a half million I think there were a couple others on the list list there that would be the first question yeah

the answer to that question is we have several things that are ongoing and we We have non-disclosure agreements in place. So we're really not talking about those, but we are very actively looking at our portfolio to divest of non-core assets and in some other areas to dilute our interest. And so you'll see more of that here over the third quarter.

Okay. Very good. And then in terms of your guidance that you had previously given, I look quickly at your presentation here versus what you had last quarter. I do see there is a comment that you're looking to generate $20 million of free cash flow this year, but yet for your $65 a barrel assumption in terms of the guidance, there was zero free cash flow. Could you just tell us what you're thinking? And then since you've sort of front-loaded your CapEx for 2025, will some of this come from lower CapEx and this additional new production that's coming online from a number of your fields?

Yeah, great question. The biggest driver on that end is just lower CapEx. The team's done a great job of executing the program, and we continue to look at how do we optimize that in the second half of the year. So the number one driver is obviously, you know, oil price is somewhat supportive right now at $70 and very, very tight differentials in Colombia and Ecuador. But the main driver will be on the CapEx side.

And then just tell me if I'm missing something, but do you break down EBITDA by country in the presentation here? I don't think I saw it, but I'm not sure. We don't.

We don't. In our press release, we have more details by country as far as netbacks and whatnot, but not EBITDA.

And then I guess the final question would be Colombia. There have been a lot of, I guess you could say, pipeline disruption and other types of disruptions. And I think there were some export taxes that I know they affected. EcoPatrol, do they affect Grand Tierra? Could you tell us what the operating environment in Colombia, what impact it might have had on either the operations or, and I know you sort of hinted at that in some of your comments, or on any sort of financial metrics you have?

Yeah. On the export tax, we've been unaffected. The main thing that's impacted us is pipeline disruptions in Ecuador. As Sebastian mentioned, there were some significant landslides, and obviously it's on our pipelines, but there was some disruptions in Ecuador on the pipelines. And so that more impacted our Ecuador production in the first part of July, but all the pipelines are back in operation, and we're in its normal operations.

Okay, great. Thanks very much. Thanks for answering these questions.

Thanks, Anne.

And the next question will come from Joseph Schachter with Schachter Energy. Your line is open.

Morning, Gary, Ryan, and Sebastian. First question for me. You've got a range of, you know, 47,000 to 53,000 for production this year. your average for the first half 47. What needs to happen to get to 50? What needs to happen to get

to 53 in terms of your forecast? Yeah, thank you, Joseph. I think the answer to that is we have the capacity. We have the production capacity. It's no disruptions, and we're working through that. Yes, the answer is we're at the lower end of our guidance, but we're still easily within our guidance. And our target is to be at the upper end. We're going to do our best to ramp. I think Ann asked the question, or David around asked the question. Yeah, we have most of our capital deployed. We've had some excellent results in Cohimbi, excellent results in Costa Rica. The water flood is going in the right direction in Cordonaro. So all of that's there. The exciting one as well as Ecuador. We're just going through our field development plan approvals with the government, and these are some fantastic reservoirs. As Sebastian alluded to, the performance is very clear that we're going to be doing some water flooding, quick response. So not only the second half of the year, but the next few years. We're quite excited about where we're going with our capital and capital allocation with some fantastic reservoirs. Second question for me.

In your Canadian side, where you have the central 12,500 BWEs a day, 49% working interest, how much of that do you operate and where do you see any potential growth for you in that central area? Does that include things like the Belly River? How do you see upside from that part of the portfolio?

Yeah, I think to go back on sort of the transaction questions that we were talking about, there's a ton of opportunity in central. And the nice part is we do have a lot of linking infrastructure. And so the team is actively working the central portfolio. And, you know, I won't talk to a specific formation because there's many of them. And, you know, starting from the NISQ to the Glock. And the team's been working on how do we optimize that portfolio. And so I think that's kind of the approach that we're taking, is where it makes sense to have some synergies, especially on third-party processing fees and so on and so forth, to optimize, again, on cost, but also in terms of profit.

Okay. Super. Thanks for that input. And sure looking forward to seeing Q3 and Q4 with the results. So thanks very much.

Thanks.

And our next question will come from Peter Bolle with Jeffries. Your line is open.

Hi, thank you for the call and the opportunity for two questions. First question is, after recently increasing your hedges for 2026, is the strategy to continue increasing hedges even further, or are you comfortable at this level? And the second question is just regarding some report or media that there was an MOU signed for potential entry into the Azerbaijani market. Could you share any updates there or any expected timing if you are contemplating a market entry there?

Great. Thanks. Yeah, on the hedging front, yeah, you know, what we've been communicating is that we're putting more of a structured plan. And so our objective is to hedge 30 to 50 percent six months out and then 20 to 30 percent the following six months on a continuous basis. so we will as a month rolls off we will add hedges for the following month that rolled off and so we do have a continue continue more systematic hedging program

yeah your question on Azerbaijan yes in fact we did sign an MOU and and we're working with the governments of Azerbaijan with SOCAR that the national company on progressing that to a production sharing agreement. And what I'll say, what I will say about what we're doing in Azerbaijan, this is the one thing in our portfolio that we've been trying to add for the last five or six years, looking in specific basins around the world where you have an order of magnitude opportunity greater than we have currently in terms of Colombia, Ecuador, Canada, where you can find multi-TCF-type fields. You can find a couple of hundred million barrel oil fields. And so it's a very large block of land and a very prospective part of the country onshore, and we're very excited about it. You'll hear more about it when we go to a definitive agreement with a production sharing agreement, hopefully in the third, fourth quarter here. And so, yeah, we're very excited about Azerbaijan.

Thank you.

And our next question will come from Garrett Fellows with JH Lane Partners. Your line is open.

Hey, guys. Thanks for taking the question. So, I mean, you listed a few other ways of raising capital here, the royalties, non-core asset sales. I guess I'm curious why we felt the need to do the forward sale sort of loan agreement now if, you know, if the assumption is that this was to de-risk the $184 million and more payment next year. You know, why do we need to pay a full year of interest on it? Or maybe there's something else going on that I don't know. Thanks.

Yeah, no, it's a good question, and I think part of it is, you know, the number one concern I think people had with the company was addressing next year's maturity, and so we think we're proactively addressing the maturity. And with respect to the interest, you know, the way we've structured things, there's actually going to be a very low negative carry on the transaction, so again, de minimis negative carry just with investments that we can do and some tax efficiency that we have. And so, we thought now would be the time to proactively address that and with very minimal cost.

Okay, great. And then, I guess, quickly on Azerbaijan, you know, could you walk us through the kind of cadence of how this project progresses? Let's say you have a signed MLU or a signed production sharing agreement in the back half of the year. How does this project progress from there?

Yeah, it's a five-year first phase, very low cost in terms of the reward that's in front of us. And so there's no pressure in terms of timing. We have a full five years from the time the Congress ratifies a PSA. And so timing that we see, there are discoveries on the block. It is very close to infrastructure. Gas, there's a very, very prolific price for both domestic and European exports. There's room and pipelines, and so that explains our excitement about having big structures in a very prolific oil and gas basin, and it really is just applying modern technology that will apply over the next years to come, and so that is the timing. It's a five-year program, and we'll disclose more about it, but a low cost of entry that we see in terms of the reward that's potentially there.

Got it. But just in terms of when you could actually start producing after the PSA is signed?

Depending on a proven discovery within that same year.

Okay. Great. Thank you guys very much.

Gentlemen, there are no further questions at this time. Please continue.

I would once again like to thank everyone for joining us today. We look forward to speaking with you over the next quarter and update you on our ongoing progress.

This concludes today's conference call. Thank you for participating, and you may now disconnect.