Good morning. My name is Katie, and I will be your conference facilitator today. Welcome to Chevron's first quarter 2022 earnings conference call. At this time, all participants are in a 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 require assistance during the conference call, please press star and then zero on your touchtone telephone. As a reminder, this conference call is being recorded. I will now turn the conference call over to General Manager of Investor Relations of Chevron Corporation, Mr. Roderick Green. Please go ahead. Thank you, Katie. Welcome to Chevron's first quarter 2022 earnings conference call and webcast. I'm Roderick Green, GM of Investor Relations. Our Chairman and CEO, Mike Wirth, and CFO, Pierre Breber, are on the call with me. We will refer to the slides of 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. Please review the cautionary statement on slide two. Now, I'll turn it over to Mike. All right. Thanks, Roderick. Before we turn to first quarter results, I'd like to recognize the people of Ukraine. Our hearts go out to those affected by this tragedy, and we hope for a prompt and enduring diplomatic resolution. The last two years have been volatile and unpredictable, driven by the global pandemic and geopolitical conflict, creating strains on economies and markets around the world. Through it all, our objectives have been clear and consistent. In the first quarter, we continued to make progress, delivering book returns in the mid-teens, investing to grow both our traditional and new energy businesses, and returning even more cash to shareholders while maintaining an industry-leading balance sheet. Recent events remind us of the importance of energy. Looking forward, I know that Chevron is doing its part, raising this year's Permian production outlook and advancing two important renewable fuel transactions, our Bunge JV, which is expected to close shortly, and the Renewable Energy Group acquisition, which is expected to close around mid-year. While the future is uncertain, our actions are not. We're on a path to delivering higher returns and lower carbon and rewarding our stakeholders all along the way. With that, I'll turn it over to Pierre to discuss our financials. Thanks, Mike. We reported first quarter earnings of $6.3 billion, or $3.22 per share. Adjusted earnings were $6.5 billion or $3.36 per share. Included in the current quarter were pension settlement costs totaling $66 million and negative foreign currency effects exceeding $200 million. A reconciliation of non-GAAP measures can be found in the appendix of this presentation. Adjusted ROCE was over 15%, and our net debt ratio is below 11%. A third consecutive quarter with free cash flow over $6 billion enabled us to return $4 billion to shareholders and further pay down debt. In addition, during the quarter, we received over $4 billion in cash when about 3,000 current and former employees exercised stock options. This quarter's proceeds from option exercises were over 4x the historical annual average of around $1 billion per year. About 2/3 of the vested options at year-end 2021 were exercised during the first quarter, lowering the potential future rate of dilution from the outstanding balance. Over time, we expect our share buybacks to more than offset the first quarter dilutive effect. Adjusted first quarter earnings were up $4.8 billion versus last year. Adjusted upstream earnings increased mainly on higher realizations, while adjusted downstream earnings increased primarily on higher margins, partially offset by negative timing effects. Compared with last quarter, adjusted earnings were up more than $1.6 billion. Adjusted upstream earnings increased primarily on higher realizations and the absence of certain fourth quarter DD&A charges. Liftings were lower in part due to lower production in the Gulf of Mexico. Adjusted downstream earnings decreased primarily on timing effects. The all other segment was down primarily on unfavorable tax items and higher corporate charges. The all other segment results can vary between quarters, and our full year guidance is unchanged. First quarter oil equivalent production decreased 2% year-on-year due to the expiration of Rokan in Indonesia, lower production in Thailand as we approach the end of the concession, and lower entitlements due to higher prices. Permian growth and the absence of Winter Storm Uri impacts partially offset and drove US oil and gas production up over 10%. Now, looking ahead. In the second quarter, we expect lower production due to planned turnarounds at Wheatstone and Angola LNG, impacts from CPC pipeline, and the expiration of the Erawan concession in Thailand. At CPC, two of the three single port moorings are now back in service, and TCO has returned to full operations. Downtime associated with the April repairs is estimated to be less than 15% of our second quarter turnaround and downtime guidance. We anticipate a return of capital between $250 million and $350 million from Angola LNG in the second quarter. This cash is reported through cash from investing and not cash from operations. In the first quarter, Angola LNG returned over $500 million of capital. The differences between affiliate earnings and dividends are not ratable, and TCO has not yet declared a dividend in 2022. With higher commodity prices, affiliate dividends are expected to be $1 billion higher than our previous guidance. We've utilized our NOLs and other U.S. tax attributes and expect to make estimated U.S. federal and state income tax payments in the second quarter. These payments will flow through working capital accounts just like our first quarter IRS refund did. In the second quarter, we expect to invest $600 million as we close the Bunge joint venture and to repurchase shares at the top of our guidance range. With that, I'll turn it back to Roderick. That concludes our prepared remarks. We're now ready to take your questions. Please try to limit yourself to one question and one follow-up. We'll do our best to get all of your questions answered. Katie, please open the lines. Thank you. If you have a question at this time, please press star one on your touch tone telephone. You may ask one question and follow-up question. If your question has been answered or you wish to remove yourself from the queue, please press star two. If you are listening on a speakerphone, 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 one on your touch tone telephone. Our first question comes from Phil Gresh with JP Morgan. Hey, good morning. Thanks for taking my question. Mike, I wanna start with one for you on Tengiz. You know, there have been a number of events here in the quarter, from the social unrest earlier in the quarter to the CPC pipeline uncertainty and the moorings issues. You know, I recognize production seems to be back up and running to normal now, but I'm curious how you think about this in terms of the broader implications of what has been happening on the ground there. You know, it's a very important asset for Chevron, so what are your latest thoughts? Well, Phil, it's an important asset not just to our company, but you know, to the Republic of Kazakhstan and frankly, you know, to world energy markets in Europe in particular. It's a significant supplier at a time when there are concerns about supply security that you're very familiar with. You know, we're focused on safe and reliable operations as you would expect, protecting people in the environment and our assets, executing the major project that's underway and working with all the stakeholders that are involved in this. That includes partners, that includes obviously the government of Kazakhstan and our customers. The risks that I think you're referring to are risks that are present in Kazakhstan and in varying degrees in other parts of the world as well. That's part of what we do, is manage those risks on the ground each and every day. Excuse me. There are times when you know the environment feels a bit more benign, but you can't take your eyes off those risks because they can materialize at any point. You know, to this point in time, we've been able to make good progress on the project. Some impact really from the weather-related downtime at the loading buoys at Novorossiysk. You know, two of those are back in service, and the third one is slated for repair, which would give us plenty of redundant capacity there. We continue to stay very focused on every aspect of managing that. Our people on the ground are empowered to do what it takes and to be very responsive in real time. I'm incredibly proud of the work that they've done in a very challenging environment. Understood. Appreciate your thoughts. My second question would be for Pierre, on cash flows or cash balances. You know, the quarter did come in a bit lower than expected on cash flows, and I think you highlighted some timing factors, b ut you did get a bunch of cash, you know, from the stock vesting, so cash balances are up quite significantly. I was wondering, you know, I don't know if there's anything else to highlight on the moving pieces of the cash flow, but you know, even at strip prices, with your buybacks, it seems like cash balances will keep going up. Just what are your latest thoughts on managing the cash from here? Thanks. Thanks, Phil. First, let me just talk about cash in the quarter. Cash in the quarter was very strong. As I pointed out, our dividends from affiliates are not ratable, and particularly from TCO, which historically has paid dividends in the fourth quarter. We increased our guidance on expected dividends, but they were light in the first quarter. Yes, that's timing. I also pointed out that Angola LNG returned $500 million of capital. That's essentially operating cash. That's a function of operating an LNG facility and selling it into the European gas markets at TTF prices. However, just due to accounting rules, it's flowing through cash from investing and not cash from ops. For all intents and purposes, it is operating cash flow. At some point in time in the future, it might revert back to that, depending on the retained earnings in that affiliate. Another item I did not mention is it's a typical item that happens in the first quarter. We pay out our long-term incentive compensation, which a portion of that is in the form of restricted stock and performance shares. That, again, happens annually, but with a higher stock price, that was a higher payment than in previous years. That does not flow through working capital. That comes out of a long-term liability account. As I mentioned, we expect to make estimated tax payments next quarter, but that'll flow through working capital, and many of the analysts look at our cash flow ex working capital. Our IRS refund also went through working capital that we had guided to in the first quarter. In terms of our cash balances, we're running a little bit high on our cash balance. That's why we refer to net debt. We have a couple of cash items coming up. We expect to close REG around mid-year. That's $3 billion. We have an offering out right now to do a make-whole call on about $3 billion of bonds. These are bonds that are economic to call back. Then on the buybacks, I mean, we just increased our buyback guidance at our investor day back in March to $5 billion-$10 billion. We were at $5 billion rate here in the first quarter. We're doubling it now to the top of the range of $10 billion, and we'll just see where the environment goes from here. We are setting the buyback at a rate that we can maintain across the commodity cycle. We could have a higher buyback rate this quarter or next quarter, but the goal is not to maximize the buyback rate in any individual quarter. It's to set it at a level that we can maintain when the cycle turns, and therefore, we can rebalance our net debt ratio closer to our mid-cycle guidance. Thanks, Phil. Thank you. Thank you. We'll take our next question from Devin McDermott with Morgan Stanley. Hey, good morning. Thanks for taking my questions. The first one I wanted to ask is just on the Permian results and guidance increase. I was wondering if you could talk through in a bit more detail some of the drivers there. Are you know, adding activity? Is it better performance on the activity you had already had budgeted for? Is it non-operated? Just walk through some of the drivers there and how you're thinking about that. Yeah, Devin, we did have a strong first quarter, and you know, a couple of big things to bear in mind there. You know, as we slowed things down in 2020 when you know, demand contracted due to the pandemic, what happened is we ended up with an inventory of drilled but uncompleted wells that grew beyond what you know, would be kind of a normal run rate for our rig fleet. We've been working through that and we're back down now to what you could think of as a more normal factory model. We'll always wanna have DUCs out in front of the completion crews, but that had grown you know, to a larger than normal rate. As we've caught that up, that's pretty efficient. It's the first place you turn. As you see, the cycle turn is completing those wells to get that production online, and we'll be moving into a more of a factory model, so it'll level out a little bit versus what might feel like a little bit of a surge. We also get some non-ratable joint venture bookings that show up. Both of those contributed to a very strong first quarter. Of course, you know, by the time you look at how that would roll through and the continued activity for the rest of this year, it's pretty clear that we'll end up higher than the initial guidance that we had put out. We haven't stepped up our program. We haven't stepped up number of rigs. We haven't stepped up spending. It's all really a function of getting the machine running again. Then underneath that, there's ongoing efficiency improvements that we continue to see. Got it. That's very helpful. Thanks. My second question is on your global gas and LNG portfolio, and I was wondering if you could just give us an update on how you're looking at some of the medium and longer term opportunities there, given what's going on in markets, and specifically I'm thinking about Eastern Med and that gas position, and then also whether or not integration into some type of LNG facility in the U.S. might make sense for some of your production growth there as well. Sure. You know, LNG is on everybody's mind these days. It's important to meeting Europe's needs. It's important to delivering a lower carbon energy system globally, and we see this strong market here in the near term. Eastern Med is a wonderful asset. I was just over there two weeks ago. I visited the Leviathan platform, spent a lot of time with our people in the business there, and they've recently completed a project to increase infrastructure access to regional markets. We're actually flowing more gas into Egypt as a result of that. We're looking at a number of other opportunities to further increase production because the resource there is quite prolific, and that includes further coal to gas switching in Israel for the regional supply into neighboring countries, potential power generation for power distribution through the region, floating LNG, potentially using ullage and other LNG facilities in the region. A number of different commercial options that are being evaluated and worked. More to come as those mature, but it's an area of high priority for us because the market demand for it. When you look at the U.S., clearly, you know, we've got a lot of gas production here that largely prices at Henry Hub today. There are these projects that, you know, are in the process for LNG export facilities. We've had discussions with a number of those developers. Nothing to say more than we've had discussions at this point. That's a part of our LNG portfolio that we've been very focused on the Pacific Basin historically. As the Atlantic Basin markets now look a little bit different, as we flow gas from our West African assets into the Atlantic Basin, it may make sense for us to have some US supply as well. We'll advise you as we advance anything there. Thank you. Thank you. We'll take our next question from Neil Mehta with Goldman Sachs. Good morning, team. Mike, I'd just love your perspective on the oil macro. You always have a good read on it. It strikes us that inventories for product and oil are very tight right now. You've got jet fuel recovering over the summer. We'll see what happens in China. Shale has an inelastic supply response. How does this ultimately resolve itself in the near term? Do you ultimately need to solve for demand destruction through crack or flat price of oil, or is there something that we're missing? No, Neil, I mean, you're putting your finger on all the levers. You know, if you step back from it, supply always responds more slowly than demand does. In normal times, which we have not been in for the last couple of years, both of them kind of gradually move in relative sympathy with one another. You've got storage out there that can buffer any short-term imbalances. You know, I'm repeating what you all know, but in 2020, we saw a contraction unlike anything I've seen in my lifetime, and we had to really constrain activity. There was no sense producing more oil when the world needed a lot less, and it wasn't clear at the time how long that might last and how deep it would be. The entire industry, every segment of the industry, responded to that. As we've come out of the pandemic, demand growth has surged. As you say, we haven't seen it all come back yet. Air travel, while it's domestic air travel in the U.S., is pretty strong. International air travel still has a ways to go to recover to pre-pandemic levels. China and other parts of the world are still in various stages of lockdown at various points in time, and so we haven't seen a full recovery of demand there. Even with that, demand has now responded more quickly than supply can match it. You overlay, you know, a host of other issues, right? The independent E&Ps, you know, feeling more of an obligation to return cash to their shareholders. Some of the big integrated companies, you know, have reprioritized new energy versus traditional energy and have indicated they intend to shrink rather than grow their, you know, oil and gas production. Then, you know, the NOCs, you can go around the world, everybody's got a little bit of a different situation. It's a market that is not stable. It's not at equilibrium right now. As you say, inventories are quite low, demand is still strong, and economies to this point seem to be handling it. At some point, particularly if prices were to move higher, I do think it starts to be a bigger drag on the economy than what we've seen to this point. There's a lot of tension in this market, and the supply response is coming. You know, we're up 10% in the U.S. year-on-year. You know, we're working on the big project in Kazakhstan, which will start up over the next couple of years. Others around the world have got things that they're doing as well. It just comes in at a different pace than the demand has moved. I think we're in a market that's tight right now, that has a lot of uncertainty. I think that is not likely to resolve itself in the near term, the uncertainty. Things like the SPR release in the near term can do a certain amount to calm those markets. You know, over time, it's a cyclical business. There's a lot of resource out there that can be produced at prices lower than we see today. You know, one of the lessons from history is just as the bad times don't last forever, neither do the times when prices are strong, and so we can't start to believe they'll always be like this. I think you know, in the relative short term here, you know, the tensions that you referred to are likely to remain. It's a great perspective, Mike. Another big picture question is, if you think about 20 years ago, at the beginning of the last super cycle, you had very similar, very large multiple arbitrages between the super majors and even large independents and some of the majors. One could look at your multiple on consensus and say you had traded premium relative to a lot of the global majors. Do you think there's value in mega M&A in this space? And do you see yourself as a logical consolidator, given that M&A is such a core competency, and it worked out incredibly well for you 20 years ago with Texaco? Yeah, you know, we're always looking at these things, Neil. I think history would suggest that deals done in an upcycle or near the top of the cycle don't necessarily look as well in hindsight as deals that were done at a different part of the cycle. You know, 20 years ago, when there was a number of transactions that you refer to, we were coming out of oil prices in the teens or the 20s. Consolidation made sense. There were a lot of synergies to be harvested as you put some of these companies together. I think the entire industry is more efficient today than it was then. Certainly large companies, which you referred to kind of large scale M&A. I think the synergy opportunities, while no doubt there would be some, they may not be of the same magnitude that they were 20 years ago. We've all used technology and other things to improve the efficiency of our operations. You know, I never say never, but you know, I don't know that just because we're trading at a relatively strong multiple right now, that should lead you to believe that it means we're more likely to do something than our track record of discipline would suggest. Thank you, Mike. Thank you. We'll take our next question from Jeanine Wai with Barclays. Hi. Good morning, everyone. Thanks for taking our questions. Good morning. Morning, Jeanine. Morning. Our first question, maybe we just hit back on cash returns. The buyback for 2Q annualized again is at the top of your range. Pierre, I think you reiterated on Phil's question that buybacks are intended to be through the cycle. Can you just maybe provide a little bit of commentary on how you're viewing the buyback in relation to mid-cycle cash flow? Thanks, Janine. The buyback rate of $10 billion is a company record. In previous, highest buyback rate was back in 2008. As you say, we wanna maintain it across the commodity cycle. We're very in tune with what our mid-cycle cash flow capabilities are. We showed at our investor day a low case at $50 Brent and showed that we could maintain the buyback for multiple years, even though $50 is notionally right around the break even for covering both our dividend and our capital. Then of course, we showed a high case at $75 where buybacks were in fact higher than the current $10 billion guidance. We could buy back at that point in time, it was more than 25% of the company. It's a little bit less based on the current stock price. That's exactly how we're thinking about it. You know, to Neil's question and the macro, it was just two years ago today on this earnings call that Chevron was the only company to show a two-year stress test at $30 Brent. That was a real stress test. We showed that we could maintain the dividend, invest in the business for long-term value. We certainly reduced some short cycle capital. Yes, we would take on some debt, but we'd have a debt ratio that would still be very manageable, and in fact, would be not far from where many of our competitors were entering the COVID crisis. As Mike says, we're mindful of the cycles that are in our business. We have to plan and manage for them. Again, we can afford a much bigger buyback program next quarter. You know, Janine, that a net debt ratio under 11% is not what we're targeting. I mean, that's just how the math works. We grew our dividend 6% earlier this year. Our dividend is up nearly 20% since COVID, while many in the industry cut their dividends during the last couple of years. Our investment, organic investment, is up more than 30% versus last year. When you include our announced acquisitions, total investment is up 50%. Clearly, we're investing, as Mike has said, to grow both our traditional and new energy businesses. We've paid down debt, and we've been increasing our buyback as we've seen the strength of this upcycle and the likely duration of it increase. The cycle will turn, and we'll continue to do buybacks, and so we wanna set the buyback at a rate that we can manage it, not only at our mid-cycle cash flow generation capability, but even when it goes below that. Again, there's gonna be a time where we're gonna be buying back shares, and we'll be doing it on the balance sheet because we'll wanna relever back, closer to that 20%-25% net debt ratio range that I've talked about. Okay, great. Thank you. Very helpful. Maybe if we just can move back to the assets on the Permian. Permian for you guys is firing on all cylinders. Clearly have a big asset there with huge long-term value. One of the things that has been talked about a bunch recently is just FT on the gas side, and how you kinda see that evolving. Just wondering how Chevron is looking at that for your long-term plans. Thank you. Yeah, Jeanine, I'm glad you talked about long-term plans because we've had a long-term Permian plan. Interestingly, notwithstanding one of the most volatile two-year periods we've seen, our production profile doesn't look that different than it did just a couple of years ago in terms of where we're headed. Of course, that drives everything from contracting for rigs and completion services to takeaway capacity for oil and gas liquids and gas. We've got sufficient takeaway capacity for our production through the middle of this decade. As we look forward, we're working on, you know, what it takes beyond that period of time. You know, we don't flare in the Permian, and so we've got to be sure we've got gas takeaway or we're not going to produce oil. It's a high priority for our midstream team, b ut we don't see pinch points anytime soon, and we continue to be a very attractive shipper for the people that we you know we do business with because we're predictable. We've got you know a strong track record of continuing to deliver the growth that we have indicated, we got a strong balance sheet and all those things mean that people like to do business with us. We feel pretty good about that for the next few years. Great. Thank you. Thank you. Thank you. We'll take our next question from Paul Cheng with Scotiabank. Good morning. Good morning. Two questions, please. First on the inflation. I'm just curious then for your CapEx for the next, say, two or three years, do you have a percentage you can share? What percent of your CapEx is in pretty much fixed price contracts, so don't subject much to inflation, and what percent is really quite vulnerable to inflation? And also when we're looking at your CapEx for this year, the Bunge JV $600 million investment, is that included in your original budget or that this will be in addition to your original budget? That's the first question. The second question maybe is for Mike. That with the much sharply higher commodity prices, when you have discussion and negotiation with the NOC, the host government, is there a change in the attitude or that it become more difficult for you to get better terms or that this is happening too quick and so you haven't really seen any change in the way how you conduct discussion with your counterparty, the national oil companies or the host government? Thank you. I'll start. Pierre, do you wanna start on? Yeah, go ahead. I'll start on the first question. There are several parts to it. First, yeah, Bunge joint venture, anything that is an acquisition inorganic is not included in our $15.3 billion budget that we shared back in December. I think we cited that, in fact, in that press release, that Bunge would be an addition. Then the other potential inorganic, there was a little bit of inorganic in the first quarter that included an investment in Carbon Clean, a technology company. REG also will not be included. You won't see REG, though, even in our total capital, our total C&E, because it's a company acquisition. Let me just talk about cost inflation a little bit. We are seeing more cost pressure in the Permian. It's manageable. If we go outside the U.S., we're seeing hardly any or much more modest increases, and none of that is changing our $15.3 billion CapEx budget that we've talked about. I'll remind everyone that the Permian is 20% of our capital budget, so it gets a lot of attention. Again, 80% of it is not or outside the U.S. is not seeing much cost pressure at all. In the Permian, as Mike said, we plan our business, so we have all the equipment and services to execute our plan. We've seen a little bit more than we had budgeted, but we can offset some of that with efficiencies in the Permian and with reductions elsewhere in the portfolio. Our focus is turning to 2023 and securing all the equipment and services that we'll need to execute that plan. We'll share the details, you know, as we update our annual budget, which we do every December. In general, Paul, you can think that we contract 30%-40% of our total supplies each year. You know, whether that every 2-3 years on a rotational basis, it can vary, it depends by location. We don't, you know, notionally, we are gonna be exposed to some of these higher prices as we move into future years. Again, we've been able to manage this year very well due to how we contracted previously. Our $15 billion-$17 billion capital guidance, which goes on for five years, kind of assumes mid-cycle conditions. It has the ability to absorb some of these cost increases that are transient. We'll execute within that. We have Tengiz coming off, which will open up more room in that capital guidance. Again, we'll share all the details, you know, when we release our capital budget in December. The bottom line is we're seeing modest increases. We said overall, our capital budget had just a few low single digits of COGS inflation for this year, a little bit more than that in the Permian. It's all very manageable, and we're working hard to secure contracts for future years' activity. Mike? Okay, Paul, your second question was on discussions with host governments on concessions and how that may be affected by the price environment. I would tell you that right now we're pretty early into this price upcycle, and I'm not sure that I can say we've seen a lot of change as you know, people are really adjusting to the environment we're in. On the broader issue of concession extensions, look, we've got to find these opportunities in negotiations that create value for the company and for the host country. You really have to look at it through the lens of both. You know, we have long histories in both Indonesia and Thailand. Would've liked to extend those concessions that are rolling off last year and this year, but we couldn't find an outcome that satisfied the host government's expectations and that would compete for capital within our portfolio, which has got a lot of alternatives. The flip side of that is Angola, where we last year extended our Block O concession from 2030 out to 2050. You know, that's a partnership that started more than 60 years ago. And there was a lot of common ground there on, you know, contributing to, you know, reliable and cleaner supply for Angola, reducing greenhouse gas emissions there, and finding a way to do that on terms that will attract capital within our portfolio. We approach each one of these things looking for value for our shareholders and to provide, you know, a proposition for other stakeholders that they find acceptable. Sometimes, we can achieve that, other times we can't. You know, more to follow probably in terms of if this turns out to be a long up cycle, how that may change those dynamics. I think, you know, the fundamental approach that we take is unlikely to change. Thank you. Thank you. We'll take our next question from Roger Read with Wells Fargo. Yeah, thanks. Good morning. Morning. Good morning, Roger. If we could, maybe talk a little bit about some of the bigger projects. Thinking about your answer earlier, Mike, on some of the macro items and, you know, under investment. I know you have some things in the Gulf of Mexico. You've obviously got an extensive LNG footprint globally. How do you think over the next couple years blending in your kind of known deepwater projects and then the possibility of doing something again on the LNG front? Yeah. We've got a nice set of projects under development in the deepwater Gulf of Mexico. Jack/St. Malo has a multi-phase pumping project that'll start up this year. Next year, we'll hit the first water flood injection on St. Malo and some additional development drilling there. Bigfoot, which is on production right now, we've got ongoing development drilling and water injection soon to follow. Mad Dog 2 is slated for first oil this year. We've got Anchor, which is expected to have first oil in 2024. Whale also expected to have first oil in 2024. We just sanctioned Ballymore, which will have first oil in 2025. There are, you know, a queue of these things that is rolling through. You know, what's a little bit different than in the past is they're not all in the same phase of development at the same time. I gave you those kind of in order of when they come on production, but we don't have them just sitting on top of each other. A lot of the lessons of maybe the last upcycle were don't take on more than you or your suppliers and contractors have the capacity to do well in any given period of time, and we're really trying to apply that here. It doesn't get as much attention or interest as we get from you know, the Permian these days or Kazakhstan, but really important part of our portfolio, really nice projects and very low carbon energy for you know, for the world. I mean, this is some of the lowest carbon intensity stuff in our portfolio. You know, our portfolio average is about 28 kg of CO2 per BOE. Our Gulf of Mexico average is six. It's not only economic, it's low carbon. It's something that the you know, I think that our country is blessed with and should continue to advance leasing in deepwater Gulf of Mexico. On the other question, LNG, I addressed earlier, a little bit of the you know, we got number of options in the Eastern Mediterranean. We're talking to some people here in the U.S. You may have seen the media reports that we have, you know, been talking to people in the Middle East about expansion projects there. We're evaluating a number of different opportunities. We'd like to grow our LNG position, the world needs it. Similar to my response to Paul, it's gotta compete for capital in our portfolio. Pierre mentioned we're gonna stay disciplined on capital. We've given you a range. We've stuck within that range ever since we started putting that out here, and that would be the intent. Just because something looks good through the lens of growth and commodity exposure, it's also got to compete for capital in a disciplined budget. We'll just see which of those, you know, ultimately, if any, you know, kind of pass that screen. That's great. Thank you. Thank you. We'll go next to Ryan Todd with Piper Sandler. Great. Thanks. Maybe a follow-up on LNG. I mean, the last couple of quarters have been impacted by various LNG volumes offline. I know you have Wheatstone and LNG maintenance in the second quarter. Any kind of clarity you can give in terms of how much volume impact that might have? Beyond that, can you give an update of the other potential volume disruptions across your LNG operations? Yeah, in the first quarter, we had a little bit at Gorgon from some of the things that we had talked about earlier. Some discovery work that was proactive, not related to an incident, but it was asset integrity work across all three trains. A little bit of that came into the first quarter of this year. Wheatstone has a turnaround underway right now of one of the two trains and also the offshore platform and some common facilities, which requires both trains to come down when you take the offshore and common facilities down. The good news is that part of the turnaround is behind us right now, and we're in the process of resuming production at one of the two trains there at Wheatstone and should have first LNG any day now. Actually the second train will be early May. We're nearly through that turnaround. We also have a turnaround at Angola LNG. That'll be in the second quarter, late in the second quarter. That's really what we've got planned for this year. Great. Thank you. You can digest that. The can digest that. The second quarter takes all the planned turnaround activity essentially, or the majority of it. Okay. Maybe a second question on refining. Can you talk about, I guess, as you think about some of the headwinds that were maybe felt during the first quarter and, you know, relative to headline margins, you know, whether it's lag on timing effects or secondary products or things like that. Can you talk about how some of those trends may reverse or shift into the second quarter looking forward, and how you think about, you know, the ability to kind of capture some of that back as we're looking through second quarter and third quarter? Yeah. I'll take a pass at that, and Pierre might wanna add something. Look, we see this in our downstream business. We're a little bit differently positioned than some of our peers in that we've got, you know, pretty heavy U.S. West Coast exposure and heavy Asia exposure, but then we're pretty light in the Middle East or Europe and some of the other basins. Our portfolio is a little concentrated more so than others. We're subject to the dynamics in those markets. China's been in a lot of, you know, kind of ongoing lockdowns. California frankly has had a little more aggressive COVID policy longer than some other parts of the world. Demand has reflected that to a certain degree. In a rising crude market, we have two effects that tend to roll through our downstream. One is just the way our inventory is valued, and so in a rising market, we tend to see negative inventory effects due to the LIFO accounting that we use. We also tend to see we're long physical and short paper as we, you know, try not to take price exposure. That paper marks to market until the physical closes. In a rising market, your paper's marking negative, the physical obviously is gaining. You see that paper and then, you know, the physical delivers, you close out the paper, and you match those up. In a rising market, those two effects tend to cause negatives. I think, in the second quarter this year, we'll probably see a lot of that reverse. Great. Thank you. Thanks, Ryan. We'll go next to Manav Gupta with Credit Suisse. My first question is a quick clarification. You did indicate there was a storm at CPC. I think it came somewhere late March, but the impact will probably be felt more in 2Q. Help us understand how long the facilities were down, and how should we model the impact on production, because of this particular storm? Yeah. Manav? Yeah. You wanna handle that, Pierre? Go ahead. Yeah. That's in our guidance, Manav, that we provided for the second quarter production impacts from planned turnarounds and downtime. Again, the CPC TCO impact is about 15% or less than 15% of that total. Okay. The second thing is. You're right, Manav. It was late March when it came up, so the effect is really, you know, in the month of April. Perfect. At your energy transition day, you had provided certain targets for growing your renewable fuel franchise. REG gets you a very long way when it comes to renewable diesel. Another area you were generally bullish on was sustainable aviation fuel. You had indicated that long term you believe this is a big growth market. Can you help us understand since then, and going forward, how does Chevron plan to build on its sustainable aviation fuel business? Thank you. Yeah, Manav. We obviously aviation demand is going to grow as we go forward. Finding a solution, it's one of the hardest to decarbonize segments of the economy because you need to have, you know, high energy density for aviation fuels or planes, you know, can't carry much in terms of their cargo. So, it's an area of focus. You know, in a traditional refinery, the distillate portion of the barrel, you can move molecules from diesel to kerosene or jet fuel. In the renewable diesel investments that we're making, there's a certain flexibility that you have there as well. We will have the ability to produce. In fact, we've already produced some sustainable aviation fuel at El Segundo. We'll see more of that coming through some of our renewable diesel facilities. We got negotiations underway with some other companies that have different technologies that wouldn't necessarily you know be the same as what we would do in a refinery. We're looking at alternate pathways, feedstock partnerships and pathways. You know, this is all gonna take time to come together. You know, quality control is really important in aviation fuels. Reliability of supply is really important. As we introduce new feedstocks, new technology pathways, you have to be really diligent in ensuring that the fuel that you ultimately produce and sell is going to perform, you know, in the engines that it's, you know, going to be consumed into. The last thing I'll say is none of this stuff is inexpensive. Sustainable aviation fuel today is not competitive with traditional aviation fuel from a cost standpoint. There has been some talk in Washington about various policy incentives that could be put into place to encourage more sustainable aviation fuel. There's a letter that was published by a whole host of people, airlines and others just in the last week or so calling for action. I think, you know, to see this scale, we gotta keep working on technology, and feedstocks, b ut it's likely that, some sort of policy incentives, will, you know, be part of the equation in order to see, more capital drawn into sustainable aviation fuel. Thank you. We'll take our next question from Doug Leggate with Bank of America. Hi. Good morning, everyone. Thanks for getting me on. I appreciate the time. Mike, I know you've, you know, flogged to death, I guess, the questions around CPC, Kazakhstan, and so on. I wonder if I could just ask a slightly different question around what's happening to realizations, insurance rates, whether that could be a durable discount on the value of the barrel coming out of Tengiz, and over what timeline. I don't know if you can offer any color there, but obviously it's something we've noticed going on in the market. Sure. You know, pre-invasion, CPC discounts were, you know, maybe a dollar or so to dated Brent. Post-invasion, the trading range has kind of been $4-$10. At prices at a pricing point called Augusta, which includes insurance and freight. Yeah, there's been a move. It's, you know, call it $7 or $8 today, probably. Now, you know, absolute price obviously has moved up a lot more than that, b ut there's a little bit that you could argue is being left on the table. I think a lot of it, Doug, depends on how things are resolved in Ukraine, and what the longer-term posture is relative to sanctions, the perceived risk of lifting at Novorossiysk, and how that translates into demand from customers and the expectations from ship owners. You know, whether it's freight rates, insurance, et cetera. Are people willing to send ships back in there the way they historically have or not? It's a hypothetical. I think that I can't really speculate on how that settles out, but I think it's a function of how this whole situation is resolved and what kind of risks people perceive on the other side of the conflict resolution. I know it's a tough one to ask in the relatively early stages of this whole thing, so thanks, Mike, for having a go. I guess my follow-up, and I think it might have been Neil that mentioned it earlier. I mean, your credentials on M&A are obviously probably the best in the industry now, Mike, and you've led that, so, and well earned. Your balance sheet is getting to a point, as you touched, you know, it's kind of almost back to 2013, 2014 levels if you project out a year or so. You know, there's strategic opportunities as this whole thing evolves, particularly perhaps in U.S. gas, LNG, and so on. I wonder if I could ask the M&A question a little differently as well, which is: when you look at your business today and how you've invested and how you've transitioned to Noble and so on, is there anywhere you would identify, for want of a better expression, a strategic want or a strategic hole, that you would like to fill, and what would that look like? Yeah. Doug, I appreciate the comments about our M&A track record and our financial strength. Those are two things that you know, we've worked hard to establish. I'll tell you, we like our portfolio. We've provided, again, I think in this year's Investor Day, you know, a 10-year outlook that says how much resource have we captured and you know, could conceivably flow into production. Not that that's a production forecast, but it's really a look at resource depth. We've talked a little bit today about gas. You know, we're a little oilier than most. Over time, can we increase some of our gas exposure would be one question. We like petrochemicals. We like CP Chem a lot. We've got a big, you know, chemicals business embedded in Korea in GS Caltex. The growth prospects in the petrochemicals business continue to look attractive. You know, we've been active in new energies and so, you know, the renewable fuels business that we talked about. You know, some other things that we're looking at in that space as well. Look, we're trying to, you know, leverage our strengths to deliver lower carbon energy to a growing world. I think that's, you know, that drives the way we think about our portfolio today and tomorrow. A number of things I've mentioned there, right? Our lower carbon contributions to economic growth and prosperity. You know, that'd be how we think about it, but I don't wanna leave the impression that we're off to the races to do anything tomorrow because we like our portfolio as it sits today and don't feel like there's a hole that has to be filled in the short-term. We really can take a long-term look. We can be patient. We can, you know, be selective if we decide to do anything. Okay. Appreciate your comments. Thank you. You bet. Thank you, Doug. We'll take our next question from Jason Gabelman with Cowen. Hey, thanks for taking my questions. First, I just wanted to clarify on the LNG maintenance. What is the cadence of maintenance across your assets going forward in future years? You've obviously had a period of very concentrated maintenance events. Is it one train a year? Or how do we think about that on a normalized basis? And then my follow-up is, you know, just given the changing energy dynamics, I wonder if your discussions with governments, both domestically and abroad, if the discussions and the sentiment has changed at all in terms of the ability to invest in places and if that's in any way starting to reshape the way you look at your investment opportunities. Okay. LNG turnarounds were typically on a four-year turnaround cycle. What that means is that to Gorgon with three trains, you'll have three out of four years, you'll have one turnaround. At Wheatstone with two trains, two out of every four years, you'll see a turnaround. At Angola LNG, we've got a single train, one out of every four years, you'll see a turnaround. On government discussions, it's just early, Jason, to say. I don't think anybody's really fully adapted and/or knows what the environment's likely to look like, a year from now, two years from now, five years from now. I think that's one that is a work in progress. Thanks. Thank you. We'll take our next question from Biraj Borkhataria with RBC. Hi. Thanks for taking my questions. The first one is just thinking about the capital framework again, and you know, through the various presentations in recent years, the management team has been very consistent in talking about improving book returns. I think, Pierre, you've been quite emphatic around stating that the market doesn't reward high capital spending, given, I guess, the industry's track record. I understand the CapEx budget and the range was only put out there, you know, a short while ago, but obviously a lot has changed in recent months. The market clearly wants more energy. You are generating, you know, record amounts of cash. The buyback's already at the top end of the range. Shares are close to all-time highs. Do you think the market is sending signals yet that would support a capital budget increase beyond what you're doing in the Permian, maybe through more exploration or otherwise? That's my first question. The second question is on TCO and the growth projects there. Has anything that's happened in the last couple of months impacted your thinking around the timeline to deliver those growth projects going forward? Thank you. Yeah. Biraj, I'll take the second one, and then Pierre's been spending a lot of time with investors, and I'm gonna let him talk to you about whether the market is signaling we ought to change our capital spend. On TCO, we just had a pretty extensive update on the project here week before last. We made good progress through the winter. We're close to having our annual cost and schedule update done, but the high level message on that is we look pretty good on budget still. We look good on the schedule for the future growth project, which is slated to start up in the first half of 2024. A little bit of pressure on WPMP, which, I believe our last update on that was, second half 2023, late 2023. Cost and schedule, despite the challenges of COVID and the other, you know, kind of regional uncertainties, still holding well. The project team there is doing an excellent job. I think Jay will be on the second quarter call and can give you a more complete rundown on things. We will have all these cost and schedule reviews completed, but nothing there that signals a significant change. Pierre, maybe you can talk about signals from the market on capital. We don't intend to change our capital guidance. The objective is to sustain and grow the enterprise at the lowest capital level. We're much more capital efficient than we were just a few years ago, let alone a decade ago. We showed, and Mike just referred to, that we can sustain and grow our traditional energy business at very, you know, reasonable rates and the rates that we don't need to grow faster, and we don't get paid for that. There's no time in our history where the market has valued growth. I mean, that's why we emphasize return on capital employed because we are a income-oriented, dividend-paying returns type of investment. Of course, we're growing new energies and we have two big transactions here expected to close soon and more on the way. If we're able to sustain and grow this enterprise, traditional energy at, you know, rates that are in line with industry growth rates, new energy faster, and we can do that at less capital, that leaves more cash flow for shareholders. What you're seeing, and back to Jeanine's question and other questions, we generate, at whatever oil price you assume, we generate more free cash flow than we ever have in the past, and that means we're able to grow the dividend at very competitive rates and have this buyback that we can maintain across the cycle. We are very sensitive to doing our part, and as we said, we're growing energy supply in the U.S. and the Permian and other locations. At the same time, the objective for a capital-intensive commodity business is to do it in the most capital-efficient way. The more capital-efficient we are, the more capital gets returned to shareholders. Thanks, Biraj. Thanks, Pierre. Thank you. Thank you. I'd like to thank everyone for your time today. We appreciate your interest in Chevron and everyone's participation on the call. Please stay safe and healthy. Katie, back to you. Thank you. This concludes Chevron's first quarter 2022 earnings conference call. You may now disconnect.