Chevron Corp (CVX) Q2 2026 Earnings Call Transcript

Okay, we're ready.

Can I stand by? Good morning. My name is Katie, and I will be your conference facilitator today. Welcome to Chevron's second quarter 2026 earnings conference call. At this time, all participants are in the listen-only mode. After the speaker's remarks, there will be a question and answer session, and instructions will be given at that time. If anyone requires assistance during the conference call, please press star, then zero on your touchstone telephone. As a reminder, this conference call is being recorded. I will now turn the conference call over to Head of Investor Relations of Chevron Corporation, Janine Wei. Please go ahead.

Thank you, Katie. Welcome to Chevron's second quarter 2026 earnings conference call in WebCAT. I'm Janine Wei, Head of Investor Relations. Our Chairman and CEO, Mike Wirth, CFO, Emer Bonner, and President New Energy's Jeff Gustafson are on the call with me today. We'll refer to the slides and prepared remarks that are available on Chevron's website. Before we begin, please be reminded that this presentation contains estimates, projections, and other forward-looking statements. A reconciliation of non-GAAP measures can be found in the appendix of this presentation. Please review the cautionary statement and additional information presented on slide two. Now, I'll turn it over to Mike.

Thanks, Jane. Amid geopolitical uncertainty and market volatility, Chevron delivered a strong second quarter, driven by our consistent strategy, capital discipline, and strong execution. Global upstream production grew more than 5% quarter over quarter, underpinned by exceptional reliability across key assets. In the U.S., we achieved a new upstream production record of nearly 2.1 million barrels of oil equivalent per day and record refinery throughput of over 1 million barrels per day. At the same time, we maintained financial and capital discipline, achieving our structural cost reduction target six months early, with $3 billion of annual run rate savings since 2024. As synergy benefits have also been delivered, also six months early. We continue to capture strong capital efficiencies in U.S. shale and tight, and expect to spend 25% less CapEx per barrel of oil equivalent in 2026 compared to last year. And we strengthened our balance sheet. to underpin long-term investment to deliver reliable energy the world will need for decades to come. This month also marks the one-year anniversary of the HESA acquisition. We pulled value forward, capturing 50% more synergies than initially targeted, with $1.5 billion realized six months ahead of schedule. The HESA assets are generating strong free cash flow, which has been roughly double the incremental dividends and accreted to shareholders on a per-share basis. This reflects the quality of the combined portfolio. Guyana is a world-class asset with significant resource depth that is expected to extend high-margin oil growth into the 2030s. In the Bakken, we're leveraging best practices from our shale and tight business to drive performance improvement, drilling laterals that are on average 28% longer, optimizing workovers, and applying advanced chemicals. And we're also maintaining similar production with one less rig. Further, we're benefiting from the talented HES employees who bring deep expertise in offshore, unconventional, and exploration. The entire organization is stronger because of this combination. I'll now hand it over to Jeff, who will share an update on power.

Thanks, Mike. The U.S. is undergoing a structural shift in electricity demand as AI accelerates, and reliable power is becoming the critical constraint. Chevron is well-positioned to address this challenge. We bring a combination of assets and capabilities we believe few can match. A leading U.S. natural gas portfolio, extensive experience with large-scale behind-the-meter power, proven project execution capabilities, and strong partnerships that provide access to critical equipment and leading customers. This reflects Chevron's strategy in action. We're leveraging advantaged assets, customer relationships, execution capabilities, and partnerships to deliver reliable, affordable energy while creating long-term shareholder value. While many data center power projects have been announced, few have secured long-term customer commitments for behind-the-meter power, and only one is at multi-gigawatt scale, Project Kilby. This demonstrates our ability to execute at speed and scale. We recently signed a 20-year take-or-pay power purchase agreement with Microsoft for 2.67 gigawatts of firm, behind-the-meter capacity supporting its co-located data center complex. We're now focused on execution, with permitting and EPC activities progressing towards a final investment decision later this year. Kilby is expected to deliver mid-teens returns and long-duration contracted cash flows that are independent of commodity price cycles. Importantly, Kilby provides a repeatable model. We're already in advanced discussions on additional opportunities with existing and potential customers for future projects. We've engaged closely with local stakeholders throughout development and have been encouraged by the strong support we've received in West Texas. I'll now turn it over to Emer to discuss the financial results.

Thanks, Jeff. For the second quarter, Chevron reported earnings of $12.1 billion, or $6.11 per share. Adjusted earnings were $12 billion, or $6.06 per share. Cash flow from operations excluding working capital was nearly $20 billion. dollars. Organic capex was 4.4 billion dollars for the quarter. We now expect to finish the year at the lower end of our guidance range of 18 to 19 billion dollars and our net debt coverage ratio improved reflecting the strong cash generation in the quarter. Adjusted second quarter earnings were 9.2 billion dollars higher versus last quarter. Adjusted upstream earnings increased due to higher realizations, higher liftings, and favorable timing effects. And we're partly offset by higher DDNA and tax-related expenses. Adjusted downstream earnings increased primarily due to higher refining margins and favorable timing effects. Chevron generated $19.7 billion of cash flow from operations excluding working capital and $15.4 billion of adjusted free cash flow in the quarter. We reduced debt by more than $8 billion, further strengthening our balance sheet and financial flexibility. Net debt to CFFO at the end of the second quarter was 0.6 times. Following the large build in the first quarter, working capital unwinded by $2.9 billion as commodity prices decreased through the quarter. On production, we had our second highest quarter ever, maintaining strong operating momentum across all our key assets and growing production by over 200,000 barrels of oil equivalent per day. Reliable operations defined the quarter. In the US, we achieved records for total production, Permian production and throughput at multiple facilities in the Gulf of America. International production was also strong at nearly 2 million barrels of oil equivalent per day. TCO in Australia operated at or near full rates and the impact from the Middle East conflict remained isolated to the partition zone representing about 1% of second quarter total production. Costs always matter, and they always will. We achieved $3 billion of structural cost reductions over the past 12 months, reaching our target six months ahead of schedule. Thanks to the hard work and relentless focus across the organisation, more than 70% of the savings came from efficiency gains, underscoring the quality of the improvements delivered. Through these reductions, we have largely offset inflationary effects, while we continue to grow across key assets like the Permian Gulf of America and Guyana we're never satisfied and never done and we will continue to look for ways to lower costs to drive lasting value our plan is clear execute safely and reliably deliver on our objectives and continue to expand our opportunity set for the future our second quarter performance demonstrates strong execution and results that can be seen in our bottom line we remain confident in the 2030 objectives we outlined last November including annual production growth of two to three percent adjusted free cash flow growth averaging greater than ten percent per year and more than three percent improvement on return on capital employed all the flat commodity prices that are lower than today we also continue to develop robust growth options for the next decade building new resource options across regions and asset classes. Achieving the power milestone, sacking multiple exploration successes and securing strategic exploration agreements and MOUs in the Mediterranean, Africa and the Middle East are examples of the strong set of opportunities we have for the future. We'll focus on executing with excellence in the near term, meeting or exceeding our guidance through the end of the decade and creating even more value in the decades that follow consistent with our long-standing financial priorities we intend to reward our shareholders today tomorrow and long into the future I'll now hand it off to Janine this concludes our prepared remarks additional guidance can be found in the appendix to this presentation as well as on the slides and other information posted on chevron.com we're now ready to take your questions.

We ask that you limit yourself to one question and we'll do our best to get to all of your questions. Katie, please open the line.

Thank you. If you have a question at this time, please press star 1 on your touchtone telephone. To allow for more questions from more participants, we ask you limit yourself to one question. If your question has been answered or you wish to remove yourself from the queue, please press star 2. If you're listening on a speaker phone, we ask you please lift your handset before asking your question to provide optimum sound quality. Again, if you have a question, please press star 1 on your touchstone telephone. Our first question comes from Devin McDermott with Morgan Stanley.

Hey, good morning. Thanks for taking my question. So, Mike, Emer, the goals you laid out with the corporate reorganization plan last year was more than just cost. It was also the sport best-in-class operations, and I think the strong results this quarter clearly show that's paying off. So on the theme of operations, I wanted to start on TCO, which looks like it was one of the key drivers of tire production quarter over quarter. So I think we talked about performance there, any learnings as far as it relates to quantifying or de-risking the de-bottlenecking opportunity. And while we're on the topic, Mike, maybe you can just address the current situation of the CPC pipeline, any levers that Chevron has to mitigate any disruption.

Sure. Devin, thanks for the comments about our reorganization. And you're right. It wasn't just about efficiency. it was also about performance. I'll speak to TCO performance in the pipeline in Eamer. Maybe you can cover the bottom ranking question. It was a strong quarter. You'll see in the production waterfall, we're up 170,000 barrels a day versus first quarter. Really stellar operating performance in the second quarter. Each month was among the highest months we've ever seen at TCO. The affiliate distributions in the quarter of roughly $3 billion, most of that is coming from TCO, and I want to affirm our $6 billion guidance. At $70 Brent, obviously, we're likely to have a higher number for Brent this year, which would translate into even higher affiliate distributions. The team has been working incredibly hard on recovering from some of the first quarter issues, but really the most exciting thing is the ability to optimize across the entire field now. The low-pressure production performance of the field has been strong, and through this integrated control center to take each generation of topside facilities and look at the way to best optimize those, not only individually, but collectively across the capabilities we have in all of the kit. The pipeline question, you've seen the media reports. There has been some activity in the Black Sea that we've seen primarily related to the Ukraine-Russia conflict. It has had over the last number of quarters intermittently some impact on activity in and around over a SISC. I can tell you that today both of our SPMs are in service there. The third SPM has been down for a while, undergoing some refurbishment activities. We'll be open here in the third quarter, so all three are available later in the third quarter. But the pipeline is flowing. We've been loading ships this week, and mitigation is the usual things. We can ship some across the Caspian. We can ship some on rail. We've got storage that we can use to buffer some of these ups and downs. But as you know, CPC is the primary route to market for that production for us and others on the pipeline. We're clearly a big shipper on it, but not the only shipper. And we work with governments in the region, the U.S. government, Kazakh government, obviously other governments, to be sure that that pipeline stays flowing. It's critical to the world at a time when we need the energy. Emyra, maybe you can talk about – specifically about the de-bottlenecking of FGP and the third-generation plant.

Sure. So, Devin, the de-bottlenecking efforts, as Mike said, were focused on the third-generation plant that we started up last year, and its original oil capacity is 260,000 barrels of oil per day. So the team there, they conducted a turnaround the fourth quarter of 2025, and during the turnaround they changed out some of the internals in a major column in that system it was very low capital a job or modification and since the fourth quarter last year they have been testing the performance of that unit and its interaction with the rest of the utilities and the system in 3GP very extensively so testing different operating conditions and we are very comfortable to say today that we have successfully increased the nameplate oil capacity from 3GP or the third generation plant from the original 260,000 barrels of oil per day to 320,000 barrels of oil per day. So what that means for the overall total field processing capacity, it now takes the total field processing capacity to slightly above a million barrels of oil per day, and so we're really encouraged by that and confident that we can sustain that level of performance. The efforts by the team are consistent with our track record of looking for the technical limits in plant and increasing the capacity, so they'll continue to focus on safely and reliably, optimizing the plant and the production, optimizing through the integrated operation center from the reservoir through to the market. So we're really, really pleased with that.

Thank you. We'll go next to Neil Mehta with Goldman Sachs.

Yeah, thanks, Mike and Emer. I just want to spend some time on the shale and type part of the portfolio. And Mike, maybe you can give us how you're thinking about the different components there. The 25% less CapEx per barrel oil equivalent in 26 compared to last year is a good data point. It sounds like capital efficiency is moving in the right direction. Spend a little bit of time in the Bakken as you evaluate whether this is core or non-core, and then spend some time in Bakken where it's done. Maybe a quick tour around the world would be great on shale and type.

Okay. Well, let me give you a couple of comments and then have you talk about capital efficiency and the Permian in particular. You know, we're producing on the order of 1.7 million barrels a day out of our shale and type portfolio. One of the things I'm really pleased with in the new operating model is we've brought all these assets together under common management. Previously, we had them reporting in geographically, and we attempted to, you know, coordinate across those assets. But it's not the same as having one organization responsible for operating all of them, for applying technology. to all of them to optimize activity across all the Shailen-type portfolio. And, you know, as you know, we've got multiple large assets in there, you know, a million barrels a day in the Permian, 400 in the DJ, 200 in the Bakken. Argentina, you know, smaller than that, but growing. And really out of the largest piece, the U.S. piece, we've got assets that we're working at Plateau to generate free cash flow, which is the lesson I think that the industry learned over the prior decade when it generated no free cash flow, essentially, and all the cash went back into growth. At the scale that we operate at now, we could grow these assets further, particularly in the permanent we chose, but we are working for efficiency, productivity, and to generate free cash out of them. In the Bakken, we're getting to know the asset better. Actually, the person who runs all of our shale and tight came from Hess and is very familiar with the Bakken. And I cited some of the things that we're doing in the Bakken differently already in terms of lateral length and drilling efficiencies, you know, same production with one pure rig. So we're getting to know that asset better, as was the case with the DJ when we integrated it. It turns out that oftentimes the things you don't know, you can't underestimate. And we like what we see in the Bakken. And we've got to sort through this midstream thing that we get asked about on every one of these calls, and we'll let you know as we've got our thinking and plans together for that. But it's really, you know, been great to see the benefits across the entire portfolio that we've been able to derive by bringing them under common means. One of those being continued capital efficiencies, just when you think, you know, there won't be much more and you might have climbed the improvement curve and started to level out, you know, we continue to be surprised yet again that there is more there. And I think some of that's a result of being able to really focus on the performance of these assets as opposed to being driven by growth. So, Eimear, maybe you can talk a little bit more about the capital efficiency particularly.

Yeah, thanks, Mike. So, I mean, the Permian has been operating for the last five quarters at over a million barrels per day. So they are seeing huge efficiencies with this focus on sweating the assets. So not growing production, growing free cash flow. You know, our capital is now – we expect it to be below $3.5 billion this year. So that's a 25% improvement in capital efficiency, so capex per barrel of oil over 2025. It's one of the reasons why we feel confident today to say that we expect to finish the year at the low end of our capital budget, range of $18 to $19 billion. Maybe a few examples. We have talked before about the drilling efficiencies and the completion efficiencies. But Permian is also seeing the highest reliability it's seen since 2024, and so there's a lot of new initiatives including optimizing artificial lift, real-time facility optimization, a new approach to ops and maintenance through an asset tiering lens. All of those things are delivering really stellar reliability at surface as well as all of the drilling efficiencies and collision efficiencies that we've talked to you about before. So we're really encouraged by what we've achieved and by bringing all of the shale and tide assets together to run them all as one and as we couldn't we really couldn't do it without I'm bringing all these assets together because they're all learning from each other thanks Nate thank you we'll take our next question from John Royal with Piper Sandler hi good morning thanks for taking my question so my questions on the power business and I appreciate the update and the detail on on Kilby my question is more about how you view the long term for Chevron and the power business.

It sounds to me from Jeff's commentary that you're uniquely positioned to serve this market, and you mentioned potential future projects beyond Kilby. Can you talk about how much power could contribute to your business mix longer term, and how can we think about how it fits into the next decade plus of Chevron's growth story?

Yeah, sure. John, thanks for the question. We're very happy with the milestone that we achieved in June with Microsoft, high-quality customer 20-year firm PPA it really serves more than just that project though we do see a larger business potential here you know Kilby is a good proof point it demonstrates that there's durable very high customer demand it demonstrates that there this model this behind-the-meter power model works for customers and it also shows that we bring capabilities which are differentiated, you know, in this market. In my comments, I spoke about the structural shift in power demand. Demand far exceeds supply. The grid cannot keep up with the demand from hyperscalers and others, and we see that persisting for years. Our capabilities are deep. Our large natural gas portfolio, you know, our experience in natural gas markets across the country, our behind the meter power experience around the world in very remote areas where you don't have grid options you must be behind the meter and you must do so at a very high reliability our complex project development and execution capabilities these are very large large very large-scale projects our customer relationships partner relationships and other other stakeholders to put all of together takes a long list of capabilities and we bring those here. When we look to the future, you know, turbine availability is tight. We have some deep relationships with GE Vernova and other manufacturers. We're already talking to them about their cues. I think the Kilby announcement strengthens our position in these discussions and demonstrates that we're not just talking about potential projects, but we've converted an opportunity into an executable project. So we'll pursue additional opportunities. We already have some of those discussions well underway with existing and new customers and partners, but we'll also be disciplined as we move this forward, and we'll always focus on value over growth.

Thank you. We'll take our next question from Doug Leggett with Wolf Research.

Thanks. Good morning, everyone. Mike, I wonder if I could take a little bit of a longer-term view. The U.S. has perhaps become, you know, it's backing everybody's focus as a safe source of energy supply, and you paused your growth trajectory in the Permian some years ago to inflect the free cash flows. My question is, you've got a lot of things going on in the portfolio today. Guyana's inflecting the free cash flow. where you've put a lot of stuff in the portfolio beyond your current plan. Where does the Permian fit? Could we see that go back to growth in the post-2030 outlook?

Yeah, Doug, thank you. Listen, actually it was just last year that we took the Permian to plateau, not years ago.

Yeah, I guess so.

And if you look at it, it has continued to grow. And we can, you know, I can have Janine follow up with you offline, mind, but it actually has crept up and is still growing. But the, you know, the point here is we really want to turn the organization to focusing on the efficiencies and productivity that Eimer talked about earlier, and we're seeing that in the Permian. We're seeing that in other assets as well. Could the Permian grow? 100%. But we've learned the lessons that at some point you want to see free cash out of these these assets, and we're seeing that in significant quantums. We're working hard on technologies that can change the equation. And we've talked in the past about advanced chemicals. We can talk about it more. We've talked about AI, and there's a lot of interesting things going on with AI. We maybe haven't talked as much about simulation technologies, but we're working on both incremental and potentially novel improvements to stimulation, when you're leaving 90% of the molecules in the ground, there's a huge incentive to figure out how to unlock all of that. And so as we work these technology levers and see performance improvements, it changes your options. You can extend the plateau and hold a plateau. You can create more value in a plateau. You can create more value in growth. We have, you know, thousands of well locations today. As we use technology to unlock horizons or benches that may not be economic using today's technology, that inventory of drillable locations goes up. And so this is an asset that is incredibly advantaged given our long history there, given our royalty position there, and we are going to work it to create value, not for a year or two, not growth for a year or two, but value long, long, long into the future, and I expect we will unlock options like those I've described over, you know, the coming years. Let me just talk a little bit about growth, because that's really what, you know, kind of your question gets at, and I get this from others. You know, there's kind of three buckets that I think about our growth opportunities in. One are the things that are in hand. So our massive shale portfolio and the ability to further improve that. Guyana, which we've talked about. The Eastern Med, where we've got a project underway to expand Leviathan. We're moving towards FID on another project in Aphrodite. Argentina, where we're continuing to see policy move in a good direction, and there's enormous resource potential there. West Africa, we've got a lot of captured opportunity today that creates growth options, not just for the next few years, but well into the next decade. The second bucket are announced business development advancements in some of our explorations. So new entries into Libya, Suriname, Namibia, our continued leadership position in terms of acreage in the Gulf of America, all the new exploration acreage that we've added over the last few years. And then the third bucket are what I'll describe as special situations that we have some control over. Venezuela is one of those. We're in negotiations right now to try to improve the fiscal terms and enable more investment in Venezuela. A second one of those would be the Iraq situation, where due to the circumstances LUCOL found itself in, it has stepped away from West Kyrna too. You know, the Iraqi prime minister who was here recently, We've signed some agreements with them, and there is significant potential at West Karnatou, Nazaria, and in Iraq. And then the, you know, the TCO concession, which I didn't address in my response to Devin, but, you know, we're into our, you know, well into the negotiations on that. Obviously, massive resource potential there, a field we know well. And so, broadly speaking, we have a lot of growth options in hand, and we will pursue those that are the strongest. We will remain capital disciplined, and, you know, the Permian is one of many options we've got out over, you know, into the next decade for growth. Thanks, Doug.

Thank you. We'll take our next question from Arun Jaram with J.P. Morgan.

Yeah, good morning, Mike and Emer. Jeff. Mike, I wanted to get your perspective on Iraq. You know, you look to be close to an entry to operate West Karna 2 and Nazaria. I'd love to see how you think that this Iraqi opportunity could compete for capital in your portfolio, how you view overall commercial terms, cost of supply, and how you think about managing some of the above-ground risk.

Sure. So, obviously, potentially huge resources, third-party data on West Kernetoo alone is, you know, gross oil potential well into the billions of barrels. It's one of the largest oil fields in the world. We're advancing discussions to align on the key commercial and economic principles for future contracts. It's a new form of contract. This month, we signed some follow-on agreements that significantly advanced the commercial discussions at both West Kernetoo and Nazaria. And so, you know, we see a very encouraging set of signs from the Iraqi government. The terms look like they will be competitive within our portfolio. We still have work to be done to nail down all of the details. And then, you know, there's a cross-border pipeline concept that would allow alternative routes to market, north through Iraq, potentially either through Syria or Turkey, or perhaps even both, to get to the Mediterranean. We've got a framework established to evaluate that. We've talked to a number of interested parties that would participate in that. We would have a share in it, but many others would also have a share in what we're talking All this needs to get to final agreements, but it's advancing at pace. The Prime Minister, in particular, has been personally engaged and very supportive. We appreciate the leadership from him that's made this progress possible, and we look forward to continuing the discussions in the coming months. As we reach any final determinations, of course, you'll hear about it when we do. Thanks, Rune.

We will take our next question from Steve Richardson with Evercore.

Hey, good morning. This is probably a good one for Eimer, but I'd love to just dig in a little bit on the achievement of the 3 billion cost savings schedule and the 70% kind of from efficiency I was wondering if you could maybe just give us a sense of where you're seeing out performance versus the plan, what have been some of the surprises and what are maybe some of the chunkier elements of what you're seeing as you're attacking these costs and then your confidence level on kind of as you mentioned you know sticking these costs and not falling back into a kind of inflationary trap if you will yeah thanks Stephen so yeah we're absolutely thrilled to be able to share today that we achieved the 3

billion of structural cost reduction ahead of schedule it's testament to all the teams around the organization they've been relentlessly focused on on this so achieved great results and 70% of the results are associated with efficiency gains and maybe what I point to there is we went through a massive restructuring rewiring of the organization last year so that is impacting the results by 35% of the 70% that I reference and then the balance is associated with a combination of technology, you know, achievements, improvement initiatives across the organization and other things. So maybe a couple of examples to demonstrate our confidence in the sustainability of these You know, the first thing I would maybe point to in the new ways of working are rewiring. we've pulled a lot of our work into centralized functions and we have a technical center that allows us to do things across the organization like centralized and standardized engineering work orders for example and so that is something new and we're seeing results there another good example would be the way that we are looking at maintenance reliability we talked earlier about how the Shielan type business. They're running as one, all together, learning from each other, and they have predictive maintenance that they have in place on all of the assets that is delivering results, much more proactive in detecting anomalies and ensuring minimum loss production. And then maybe a final one that I would talk to is around one of the improvement initiatives that's inspired by benchmarking and rigorous benchmarking, and that is a turnaround optimization and what the teams were doing to tighter control scope prioritize sequence learn from each other those are the examples so I call it these examples because they're things that are now built into the business and we're very confident that you know we'll continue just with this focus that we have costs always matter they always will we're never satisfied and we're never done and and we've a very strong culture across the organization and paying attention to this always. So thanks for the question.

We will take our next question from Baraj Burkattaria with RBC.

Hi, thanks for taking my questions and thanks for the presentation. I just wanted to follow up on CPC again. This is obviously a very significant pipeline that serves your asset and also a number of your peers. I suspect there's a number of governments involved trying to solve this issue. But could you just kind of clarify if CPC pipeline is closed for an extended period of time, how much of that, you know, 1 million barrels a day of liquid could be evacuated by the alternative routes? And then related to that, in the Middle East, there's a lot of discussion at the moment around building alternative evacuation to reduce the risk from the strait. I'm just wondering if anything incremental is being discussed here. I know the geography is obviously very challenging, but any thoughts on that would be helpful.

Yeah, Baraj, clearly with the CPC being the primary evacuation route, if it were to be shut down for an extended period of time, that will create issues for all the shippers on that line. And that's a number of different projects in Kazakhstan, a little bit that comes in from Russia as well. You know, I mentioned our alternatives before. I don't think we've quantified those, and I don't intend to. But, you know, you've seen creativity in the Strait of Hormuz over the years. We've had to use some creativity at times with CPC. But I will say the commitment to keeping it open from all the parties that rely on it and all the governments that rely on it is very, very high. And I have a great degree of confidence that that commitment is real and that we'll see the CPC, I won't say never interrupted, but I don't think that the scenario that you pose is a highly likely scenario that they'd be an extended shut-in. On your second question about the straight, I'm not sure I fully understood it. I mean, I think, you know, you're probably aware of the kinds of things that have been done, the shuttling through the strait, the loading outside the strait, the pipelines. You know, there are a number of different workarounds that, you know, have helped continue to establish some degree of flow through the strait. Those are the short-term actions. And then the, you know, kind of the medium-term actions, I talked about one of them, the pipeline that we're evaluating to move to the Mediterranean. and there are other ideas like that that are being advanced by others. Thanks.

We'll take our next question from James West with Mellius Research.

Hey, good morning, Mike. So I wanted to – you very eloquently shifted a question on the Permian earlier to really walking around the world demonstrating the optionality that you've put in place in various markets that are now turning into signed agreements and action. I wanted to dig in a little bit deeper. I wouldn't ask you to walk back around, but on expiration in particular, that I'm thinking, you know, Libya, Namibia, Greece. Where are you kind of most excited? Where do you think you have the best upside potential? And where do you think maybe we as the market are kind of missing what you're up to?

Yeah, thanks. Thanks, James. You know, I'll start by saying that this is the largest and highest quality opportunity set that we've had in years, probably in my time in this role, you know, that we haven't had this deep an inventory of opportunity. We're building quality through choice. We increased our acreage by 35% over the last year or so. We closed on $10 million net acres just this year in South America, in the Mediterranean, and in the Gulf of America primarily. We've got a strong presence in Guyana, which I won't spend any time on because I think that's pretty well understood, but there's still exploration potential there. West Africa, you know, the deep water of both Nigeria and Angola is relatively underexplored, and we're actively working on that. And I'm very optimistic that, you know, large basins like that that have a proven petroleum system will offer more opportunity for us. We've got another well we intend to put down in Namibia where we've seen success. So West Africa is a place I'm very excited about. The Mediterranean is interesting. You know, we've got some success we've had off Egypt. We're a partner in a well that one of the operators has talked about on their call this week where there's been a working petroleum system that's been established, which is important in exploration to understand that. So there are opportunities there in the Eastern Med that we like. The Middle East, again, I think kind of speaks for itself. You know, in Iraq, we've got both operating fields and associated exploration prospects that come with them that our exploration team, I would just say their eyes get wide open when you start to look at some of these structures and the analogs that are in the area around them. And so we're going to be disciplined in the way that we advance through that portfolio. We're going to be using these new tools, and this is an area where AI will definitely change cycle time. It will change our ability to see things that previously we may not have been able to see, and I expect that it will change outcomes. And, you know, the last thing I'll just say is we're already seeing some results. Over the last year and a half or so, we've had, you know, five different discoveries or successful appraisal wells in the Gulf of America, in the partition zone, in West Africa, and I mentioned the well off Egypt that, you know, we're a partner in recently. And so we're already seeing the early signs of this portfolio yielding different outcomes. We'll be talking about this a lot more in the years to come.

We'll take our next question from Sam Yargolan with Wells Fargo.

Hi. Thanks for taking the question. Europe is exceptionally toned, and Australia typically has a volume ramp. And we typically have a little bit of a volume uplift in the second half of years, starting in the third quarter. Can you just talk about your available LNG position to you to kind of solve this European shortage?

Yeah, Sam, we do see some seasonality in Australia. And so, you know, cooler weather is better for LNG facilities than hot weather. Most of our Australian LNG is termed up with customers in Asia. We do have some spot cargos that we move, but, you know, it's far away the smaller portion of our production there. West Africa, we move LNG up into Europe more steadily on some shorter-term, you know, contracts and a fair amount of spot out of West Africa. And then we've got a growing position here in North America where we've got 4 million tons per annum that will come in over the next few years. And that is primarily going into Europe. And so, you know, I would say Australia is probably the longest putt, if you will, furthest away. We've got it pretty well termed up. And Asian spot markets have been very strong as well. And so you see JKM and TTF both are, you know, have been firming. And I think the demand in both North Asia and Europe is likely to continue to be pretty strong here over this next period of time. And so we'll do the, you know, we'll make the best sales into each market and continue to operate at a high reliability, which I'm really pleased to say our Australian assets are operating at.

We will take our next question from Manav Gupta with UBS.

Good morning. A lot of questions on CPC. I was hoping I can talk a little bit about CP-CAM, big jump in earnings, obviously global product inventory. Everybody talks about refined products is depleted, but so is the polyethylene side depleted. Multiple global crackers are also struggling, and you have a very unique portfolio, but most of it is in North America. So if you could talk about the leverage that CPChem has in this environment of elevated polyethylene margins.

Yeah. I mean, I think you've mostly answered the question yourself there. You know, CPChem's primary footprint is in North America. There's some production in the Middle East, which obviously is constrained right now, given the circumstances with the strain. But CP Chem cracks ethane primarily and primarily in North America. Those margins have been under a lot of pressure the last few years. They've been buoyant, to say the least, over the last few months, as we've seen naphtha out of the Middle East constrained, which mostly flows into North Asia. for NAPLA crackers, which are normally the price-setting mechanism out there in the marketplace. And ethan crackers are lower cost. The margins tend to be better. And in an environment where you get production tightening up the way that it has, CPQM, you know, is advantaged in this kind of an environment. We'll see how long it lasts. I can't predict when things in the straight will settle down, and we'll start to see those flows again. But very pleased with the performance in CPChem right now.

We'll take our next question from Jean-Anne Salisbury with Bank of America.

Hi, good morning. Can you discuss your decision to license your surfactant technology versus keeping it in-house? How did you view the pros and cons there, and how large could this revenue stream be?

Hey, Jean-Anne, I'll take this one. Yeah, no, we're really excited about this. Look, the rationale was really just to explore another pathway for innovation. Advanced chemicals is such a focus for us with regards to improving recoveries, as Mike talked earlier, for our entire Shield and Tight asset class. And we have a lot of work underway deploying pilots, trying different chemicals, and, you know, an opportunity to work with a partner that has manufacturing capability, distribution capability and pumping service, quite frankly, allows us to co-innovate with them and accelerate scaling this technology with speed. So, I mean, that's overall the rationale. We have a lot of NOJV volumes, and therefore, having a partner like CEL allows us to benefit from those volumes, offer this to our NOJV partners, and it's a win-win. And overall, we see it as a way to accelerate our progress on doubling shale and tight recovery across the shale type this. And so that's the rationale.

And you asked about the materiality. The contribution from recoveries will be much larger, I think, than the licensing revenue. We'll get licensing revenue from a company our size. The real opportunity is on the application of the chemicals.

Thank you. We'll take our next question from Betty Zhang with Barclays.

Hi. Good morning. Thank you for taking my question. Probably a question for Imer on the long-term CapEx. You mentioned earlier that Permian is falling below 3.5, and a lot of that is driven by capital efficiencies, which I would imagine will also put downward pressure on that Permian CapEx going forward. But at the same time, you have power that's floating in as well.

So could you just remind us what's driving the range for that long-term CapEx and whether we could be seeing that number trending lower as well yeah in terms of the the long-term range that we shared last year at our investor day and so we provide a range of 18 to 21 billion obviously this year our budget is 18 to 19 billion but that that range represents you know the opportunities that we have over the course of the next five years within that we had expected to have a power project within that capital range and so the one that Jeff talked about project Kilby is reflected in both the organic capital outlook and range and the affiliate capital outlook and range and so at the end of the day we're going to be capital discipline Mike talked about all the growth options that we're stacking up around the world both power and on the upstream the upstream side and so we'll continue to be to be disciplined but we believe that that range gives us enough for the options that we have on the table today thank you we will take our next question from Nitin Kumar with Mizuho Securities hi good morning and thanks for taking my question where I shift gears a little

bit. Obviously, refining had a good quarter given the macro environment. Mike, I was wondering if you guys would be willing to talk about what do you see as the outlook post the war? Are you seeing any evidence of demand destruction as things remain tight? What's your view on the cracks here?

Yeah. So I'll be brief here because I want to get everybody a chance on the call. You know, middle distillates are really the tight spot right now. Initially, it looked like jet, now diesel. European diesel demand was weaker in the second quarter, which I think is what really kept global inventories from drawing further than they did. That may not hold up as we get into the third quarter. You've got restocking of heating oil ahead of winter that is, you know, kind of upon us or soon to be upon us. That lands on top of the export ban from Russia. Refinery outages in Russia. of the obvious constraints that exist in the strait, and then MoGas inventories are low as well. And so products are tighter than crude around the world, and that's why cracks have widened I think the question is, when does, you know, when do we get crude flows reestablished, and when do those cracks come back in? Hard to say. So I think, you know, we're going to see some upward pressure on product pricing here, you know, into the third quarter and perhaps beyond that. Demand destruction is not obvious to me at any significant scale. China's a black box, and so that's the big question is what's really going on in China. It's difficult to shift demand as rapidly as their crude purchases have come off. I think they've got some flexibility to do so. Other Asian markets that have seen actual physical constraints, There's likely some demand destruction in some of those markets, at least in the short term. But in terms of longer-term structural demand destruction, I would say it's hard to find evidence of that at this point.

We will take our next question from Bob Brackett with Bernstein.

Good morning. If I think about Project Kilby, you talked about expected mid-teens returns, and that's really a ring fence around the taker pay and standing up that power gen. Are there additional opportunities to create value given that you're sitting there at the county with plenty of acres and plenty of wells? Is that additional add-on value potentially?

Yeah, thanks, Bob. There could be. There could be expansion potential on the Kilby site after the first phase, after we ramp up to this 2.67 gigawatts. None of that has been agreed or negotiated yet with Microsoft, but obviously their demand needs continue to increase, and we'll work with them to see if we can supply those while meeting our returns thresholds. I talked about the potential to scale this business further. We don't see Kilby as a one-off. This is a very durable macro demand environment. Really, the depth of our capabilities are unique and differentiated here. Microsoft certainly saw that with Kilby. And there are others who are interested in where can we grow beyond this, both in West Texas and perhaps other parts of the U.S. But look, as we go forward, we're always going to be disciplined with this. We were very disciplined on Kilby. We had a firm requirement for what we needed to do for our shareholders, both returns in value. We're going to hold to those going forward, and we'll provide additional information as new growth opportunities emerge.

We'll take our next question from Jason Gabelman with TB Cowan.

Yeah, hey. Thanks for taking my question. I wanted to ask on Venezuela. Well, I imagine you're getting to the point where the amount that they owe you is going to be fully repaid. And I wonder if that point, contractual terms shift to the new fiscal framework that they're developing, or is there something in place right now that you would lift under? And then more broadly, how are the contract negotiations going to unlock additional volumes there? And how do you think about both incremental investments and incremental production growth over the medium term? Thanks.

Okay, Jason, I'll maybe try and hit this one. On debt recovery, we are continuing to recover our debt. We expect that by early 2027 that will be fully recovered. In terms of our JVs, today we are operating three JVs and very successfully we've grown production over the last few years from 40,000 to 250,000. With the existing model that we have in place we have grown the production from those three JVs 15% over the last six months to 280,000 barrels of oil per day, and we're anticipating that we will be able to grow up to 50% between now and the end of 2028. So everything with Venezuela operationally is going well and consistent with what we had communicated. With regards to the opportunities, obviously we've been in Venezuela for 100 years. We've stayed there because of the potential in the country and the assets. We love the assets, the heavy oil that's there, we have a lot of experience in this space so we are actively working with the government to look at other opportunities will be disciplined at the end of the day the terms that we're discussing are confidential and but they have to be and they have to be competitive and and they have to compete in our in our portfolio for capital but I want to leave you with we're very encouraged with where we are with the venezuela on the additional opportunities thanks for the question thank you our final question comes from phil philip jungworth with bmo thanks good morning uh can you update us on your latest

thoughts just around future investment across argentina and the vaca murta uh emir i think you worked down there in may and we saw some reports around uh over 10 billion development but it's always been a large contributor to other shale and tight. Just hoping you can update us on the potential here and what gives you the confidence now to push forward.

Yeah, thanks, Philip. Well, we are really excited about the opportunity in Argentina. We've obviously got history there, three development areas that we are an operator in or in a non-operated position. We're producing 80,000 barrels a day from Argentina, 75% oil cut, so we like the products from Guacamerta, and we're leveraging the lessons from the Sheiland type asset business that now includes Backend and DJ and Permian to really look at how to deliver on the growth that we shared in our investor day, which is to grow 3x by 2035. I think the engagement that you might be referring to was with the Minister of Economy and we had a discussion around the RIGI framework that has recently been extended to oil and gas and so we have applied for the El Trapial an application for that asset and this framework gives us 30 years of fiscal stability incentives like accelerated depreciation and tax incentives and so that makes Argentina look much more competitive from a growth option for us so again we'll continue to be disciplined no change in the near term

but obviously a lot of opportunity to grow thanks Philip I think that's the last question we have we'd like to thank everyone for your time today we appreciate your interest in Severan and your participation in today's call please stay safe and healthy Katie, back to you.

Thank you. This concludes Chevron's second quarter 2026 earnings conference call. You may now disconnect.