Phillips 66 (PSX) Q3 2026 Earnings Call Transcript

Operator: Welcome to the Third Quarter 26 Phillips 66 Earnings Conference Call. My name is Hillary, and I will be your operator for today's session. At this time, all participants are in a listen-only mode. Later, we will conduct a question and answer session. Please note, that this conference is being recorded. I will now turn the call over to Sean Maher, Vice President Investor Relations and chief economist. Sean, you may begin.

Sean Maher: Hello, everyone. Good morning, and thank you for joining the Phillips 66 Third Quarter 26 Earnings Conference Call. Participants on today's call will include Mark E. Lashier, Chairman and CEO Kevin J. Mitchell, CFO Donald A. Baldridge, Midstream and Chemicals, Richard G. Harbison, Refining and Brian Mandell, Marketing, Commercial, and Renewable Fuels. Slide 2 contains our safe harbor statement. We will be making forward looking statements during today's call. Actual results may differ materially from today's comments. Factors that could cause actual results to differ are included here as well as in our SEC filings. We will also discuss both GAAP and non GAAP financial measures. Reconciliations of the non GAAP financial measures to the most directly comparable GAAP measures included in today's presentation and the Phillips 66 earnings release. Today's presentation the earnings release, and supplemental financial and operating information can be found on the Investor Relations section of the Phillips 66 website. With that, I will turn the call over to Mark.

Mark E. Lashier: Thank you, Sean. At Phillips 66, we are focused on operating our assets safely and reliably. Enabling us to supply the products that our customers depend on, and to help the U.S. and global economy grow. In today's remarks, I will focus on 3 strengths that define Phillips 66. Operating performance, capital allocation, and future growth. First, operating performance remains strong. Underpinned by disciplined execution and industry leading safety performance. We delivered strong refining utilization of 98% and third quarter record distillate yield of 41%. In midstream, we achieved fractionation volumes of over 1 million barrels per day wellhead volumes of 4.6 BCF per day, a 105% utilization at the Freeport LPG export dock. These results demonstrate our strong operating performance. Second, we remain committed to disciplined capital allocation and to returning greater than 50% of net operating cash flow excluding working capital, to shareholders. We will also fund a disciplined capital program, including sustaining capital, while retaining flexibility for additional share repurchases and debt reduction. Third, we have a clear path for future growth. All projects must compete on a risk adjusted basis. This discipline keeps us focused on increasing return on capital employed by building the best business not simply the biggest business. We have a compelling set of organic opportunities across the portfolio and we are excited to bring them to fruition. These projects support the growth of normalized return of capital into 2030 and beyond. In our Midstream G&P business, we are increasing Permian volumes and adding processing capacity with the Iron Mesa and Zeus gas plants. In NGL transportation and fractionation, we are expanding the Coastal Bend pipeline system, and building a third fractionator in Corpus Christi. Finally, our Western Gateway project creates an integrated value chain that is expected to generate returns across multiple segments. Through these midstream projects, we are positioned to achieve our stated targets and deliver mid single digit adjusted EBITDA growth through the decade. In Refining, the Humber gasoline quality improvement project will enable production of higher quality gasoline for premium markets. We are delivering record operating performance in the Central Corridor. Supported by the full integration of the Wood River and Borger refineries. Additionally, strong financial results have benefited from greater than $50 million of near term operational and commercial annual synergies from the WRB transaction and we have line of sight to more. In chemicals, CPChem's golden triangle polymers and Ras Laffan Petrochemicals projects remain on track for full operations in 2027. These projects add earnings capacity while leveraging CPChem's advantage feedstock position. Our integrated liquids portfolio is built to meet growing global demand. Continuous improvement across our operations, ratable midstream growth, and advantaged refining footprint, and top quartile chemicals assets strengthen our ability to reliably supply the markets we serve. Supported by attractive infrastructure and global commercial reach, we are well positioned to create value through the cycle. Phillips 66 is defined by strong operating performance, disciplined capital allocation, and a clear path for growth. Together, these strengths deliver high return opportunities and enable us to increase cash returns to shareholders. We are prepared to compete in any environment, and generate durable economic value. We strengthen the foundation of the business and build a culture of continuous improvement. Moving forward as a stronger, more agile company. Now I will turn the call over to Kevin.

Kevin J. Mitchell: Thank you, Mark. Moving to slide 4, our capital allocation framework remains unchanged. We fund the dividend and sustaining capital, invest selectively in high return opportunities, maintain balance sheet strength, and return cash through share repurchases. Our commitment to return greater than 50% of net operating cash flow, excluding working capital, is a priority. We recently announced a second dividend increase in 2026. Reflecting our confidence in the durability of the business model and the company's ability to generate sustainable cash flow. This represented a 10.8% increase compared with the fourth quarter of 2025. During the quarter, we reduced debt by $2 billion by paying off the remaining balance of the March 2027 term loan and through open market purchases of debt. Total debt ended the quarter at $18.5 billion and net debt was $12.7 billion. Additionally, we paid off a $500 million bond maturity on October 1st. We will continue to allocate capital prudently. Returning cash through dividends and share repurchases, while investing in high return opportunities and strengthening the balance sheet to enhance long term equity value. On slide 5, reported and adjusted earnings were $5.6 billion or $14.08 per share, Operating cash flow was $7.3 billion. Excluding the working capital benefit of $1.1 billion, operating cash flow was $6.2 billion. We continue to strengthen the balance sheet, and reduce the net debt to capital ratio to 26%. We have achieved the 2027 net debt to capital ratio target ahead of schedule. Capital spending for the quarter was $680 million. We returned $2.8 billion to shareholders through share repurchases and dividends. Looking ahead to the fourth quarter on Slide 6. In chemicals, we expect the global O&P utilization rate to be in the mid eighties. In refining, we expect the worldwide crude utilization rate to be in the mid nineties. Turnaround expense is expected to be between $140 and $170 million. We anticipate corporate and other costs to be between $350 and $380 million. Moving to slide 7, Mark will now provide some final thoughts.

Mark E. Lashier: We will then open the line for questions. Before we begin Q&A, I would like to take a moment to recognize Richard G. Harbison, our executive vice president of refining since 2022, After a distinguished career with Phillips 66, Richard has decided to retire at the end of this year. Richard has been instrumental in strengthening our focus on safe, reliable, and competitive operations while building an organization positioned for continued success. On behalf of the entire company, I want to extend our deepest gratitude to Richard for his extraordinary leadership, service, and contributions to the company. We wish him all the best in retirement. We are also pleased to welcome Chris Chandler who will work closely with me over the next few months before assuming leadership of refining at the beginning of 2027. Chris brings more than 30 years of industry experience in refining and midstream, including more than 2 decades in leadership roles at Phillips 66. His capabilities complement the tremendous strengths Richard and our refining organization have built over many years.

Operator: Thank you, Mark. We will now begin the question and answer session. As we open the call for the questions, as a courtesy to all participants, please limit yourself to 1 question and 1 follow-up. If you have a question, please press star then 1 on your touch tone phone. If you wish to be removed from the queue, please press star 1 again. If you are using a speakerphone, you may need to pick up the handset first before pressing the numbers. Once again, if you have a question, please press star then 1 on your touch tone phone. Please stand by while we compile the Q&A roster. Your first question comes from the line of Manav Gupta from UBS. Your line is open. Please go ahead.

Manav Gupta: Good morning. I actually wanted to ask you about crude differentials. You are most levered to the WCS differential, which is clearly widening out And my broader question, I will keep it to 1 question only is, I am trying to understand the advantage of North American refining as a whole versus the global peers, and you look at where TTF is trading, where Jeddah, you know, natural gas is trading, and then some of these carbon policies that Europe is looking to implement I understand you also have some European assets, but I am trying to basically zero down on where the differentials are and the benefits of North American versus their global peers, which you could talk about that?

Brian Mandell: Hi, Manav. it is Brian. So to us, it is 2 parts. First, the WTI pricing. Has been a lot stronger given the strength of diesel margins around the world. Refiners around the world pay more to pull that WTI crude to fill. To backfill crudes they are not getting. And second, on the heavy crudes, they have been pressured mostly by freight Initially, the Canadian crude was pressured by, PBF and other refinery issues. But it is mostly a freight issue. Also, you are seeing more Venezuelan crude on the market. Starting to see diluent blending in the Canadian crude for the winter. So internally, what we talk about is heavy crude is essentially a race to the bottom. For both Canadian and Venezuelan and even high sulfur fuel oil. So as you know, weaker heavy differentials play into our kit. Canadian crude is currently favored. And we import more Canadian crude into the U.S. than any other company. And then most of our refineries run heavy crudes in the central corridor in the Gulf Coast, we have strong pipe connectivity and access to Canadian crudes along with other crudes. And finally, just as a reminder, every dollar of widening of the WCS, WTI differential is worth a $140 million for Phillips 66.

Manav Gupta: My quick follow-up here is, we saw a big improvement in the pace of buybacks. You have a clear target out there. And you were lagging a little in the first half, you are clearly catching up now. So should we expect those targets to remain in place that should allow your shareholders to benefit from the up cycle and refining margins?

Mark E. Lashier: Yes, Manav. Thank you for that This is Mark. Absolutely. Our commitment is to return 50% of our operating cash flow, adjusted for working capital. We will, notice that we are building cash on our balance sheet as we try to keep up with that and we will ultimately clear that commitment as soon as we can. Thank you so much.

Operator: Thank you. Your next question comes from the line of Stephen Richardson from Evercore. Your line is open. Please go ahead.

Steve Richardson: Hi. Thanks. Mark, I wonder if we could focus in a little bit on the dividend raise. You have raised it twice this year. Pretty substantive moves. And I wonder if you could talk about how, the board looked at the sustainability of the dividend and seemingly your confidence in higher mid cycle earnings once we get through this period of higher cracks.

Mark E. Lashier: Absolutely, Stephen. We had a great discussion with the board, and there are a number of constructive elements that, boosted their confidence and our confidence in not only being able to just increase that dividend, but to support it over the long term and to continue to grow it, competitively. It all starts with the consistent earnings from our midstream business. That is the basis that allows us to meet our commitments around sustaining capital of about $1 billion and then our current outlay of about $2 billion for the dividend, as you will note in our. A lot of our documents that we have a solid plan to increase midstream earnings to the tune of about 5% a year, and we have line of sight on the projects that will do that. So that is part of the confidence building process. And then you step back and look at the improvements we have made around refining commercial value chain optimization, there is an upshift in what the base earnings surrounding refining will do, even if margins normalize in the future and if you think. If you step back and look at where we are today, we think there is about a $2 billion benefit there. If you go back to the old normalized level of margins, that benefit is about $1 billion. And we think margins will normalize at a higher level going forward for the for the near term and the medium term. And so that also builds confidence as well, and we are leaning into integration creating a lot of value there. Plus, we have a solid macro today that is allowing us to aggressively repurchase shares and strengthen our balance sheet. So that balance sheet strength lowers the cash that we are outlaying for interest payments and, of course, the share repurchases. Lowers the denominator so it keeps that aggregate outlay for dividends lower than the increases that you are seeing in the per share dividend. So it is all incredibly constructive and wholeheartedly supported by the board.

Steve Richardson: that is great. Thank you. A follow-up perhaps on the topic of CapEx, maybe for Kevin, is appreciate that you will have your normal CapEx disclosure coming later in the year. But can we just talk a little bit about how we should think about funding for Western Gateway? Is that sort of starts to kick in 2027 and 2028? And maybe just give us a sense of how you. How to think about funding that and the quantum of that as we will see in 2027. If you could.

Mark E. Lashier: Yeah. I will have Kevin drill into those details, but I just wanna make it clear that we will continue to be very disciplined around growth CapEx. We have really solid opportunities to improve refining, to improve commercial, and to grow midstream NGL. And, we will be able to grow that midstream NGL that 5% rate even while we execute Western Gateway. And so we are in a great position to deliver a very disciplined capital allocation there. Kevin, you can dig into the details.

Kevin J. Mitchell: Yeah. Well, so Western Gateway will increase our capital spending relative to the previous levels just given the magnitude of project, $2.5 billion our share for that project. And that spend takes place over. there is a small amount this year, pretty small, 26 component, but then 27, 28, 29. And the way to think about the activity is this year through the end of next year, it is all about the engineering and then the right away work and spend. And then from 28, 29, that is the construction And so what that means is 2028 is the heaviest spend year as you lay the site. Now, if we get through right-of-way, sooner, then we will start construction sooner, and that will bring some of that spend through. But as we see it right now, 2028 is the highest spend year and 2027 and 2029 are a little bit below that level. So you can kinda use that to gauge, you know, an estimate of what that is gonna look like. And we will have more once we issue the capital budget in December, we will provide more disclosure in transparency around the Western Gateway spend.

Steve Richardson: Great. Thanks very much.

Operator: Your next question comes from the line of Douglas Leggate from Wolfe Research. Your line is open. Please go ahead.

Doug Leggett: Thank you. Good morning, everyone. Mark, I think keeping on the same kind of themes of dividends and midstream and so on has already been asked. But wonder if I could just try and put some framework around this. Mid cycle is really hard to pin down right now in the refining business, but when you think about the magnitude or the proportion of your mid cycle mix, your midstream mix specifically, That 5% growth rate as a CAGR to get you theoretically to some pretty big numbers, can you frame for us how you think about that EBITDA mix of midstream relative to the rest of the business?

Mark E. Lashier: Well, certainly, midstream is growing faster than other elements of our business. We are not shying away from investing in opportunities and refining, but that is largely the strength in the kit. So we have got a strong base in refining, but we can enhance distillate production. We can enhance integration. We can enhance value creation. On the refining side, but then the growth is more concentrated on the midstream side. And you have heard us talk about Iron Mesa, Zeus gathering and processing facilities. We have the ability to expand Coastal Bend pipeline. At a fractionator in Corpus Christi, and we have opportunities beyond that as well, very similar kinds of opportunities, but, things that we are very good at efficiently and effectively. And it is not going to be a linear growth in midstream because those things come on in incremental steps, but you are gonna see that consistently throughout the end of the decade.

Doug Leggett: Mark, if just I want to share what our numbers are showing up. If I said 50%, 10 year plan of your EBITDA, 50% of your EBITDA is midstream, is that nuts? Is that crazy?

Mark E. Lashier: I do not think that is that is crazy. I think that. Yeah. If you. The math is pretty straightforward. Okay. But do not forget that So my follow-up, but do not forget that we have reset, we have reset the refining baseline as well. So refining's gathering, speed as we speak as well. But it is not in big visible increments. it is a lot of blocking and tackling. A whole list of projects. I think you can see a number of them were on 1 of the slides in the deck. No. I think the reliability performance, all of that stuff coming together is great. The problem we are having is what is mid cycle margins, but with midstreamers, what I am trying to get at is it seems there is a lot more visibility there.

Doug Leggett: But let me just take my follow-up very quickly, and it is really for Kevin or whoever wants to take this. But if your midstream is really anchoring the dividend, and your midstream is growing, let's say, to half the company's EBITDA within 10 years, should we expect a similar kind of trajectory for the dividend growth?

Kevin J. Mitchell: Well, Doug, I do think that an assumption that the dividend can. Or the per share dividend can grow at something north of mid single digits. So let's say mid to high single digits on a per year basis is pretty reasonable to get to that. And part of the way I think about that is midstream's currently $4 billion per year of EBITDA growing at about 5% per year. And you think about the magnitude of that growth and then you look at the current dividend, there is a $2 billion per year outlay. A 5% increase on that is only half of the growth in the mid midstream. EBITDA, and we are buying back shares as well. And so we are actually reducing the share count and so the absolute spend level is not increasing at the same rate. So I do think it is reasonable to assume a sort of high single digits growth in the per share dividend for the reasonable future.

Doug Leggett: that is what I was looking for. Thanks so much, guys. Appreciate it. Thanks, Doug.

Operator: Your next question comes from the line of Neil Mehta from Goldman Sachs. Your line is open. Please go ahead.

Neil Mehta: Thanks so much. And Rich, if you are in the room, congratulations to you. I have very much enjoyed spending time with you recently here at Wood River. And maybe that is a good place to start is on the refining side of the business. I would be curious over the course of 2026, how you guys have seen the commercial side manifest its way through refining results. And as we looked at the captures, Gulf Coast was probably the best reflection of that because of all this crude that is dumping down to the Gulf Coast right now? And just curious how the organization has made progress and how it is manifesting itself through the results.

Brian Mandell: Thanks, Neil. This is Brian. Maybe I will start off by just reminding you the goal of commercial, which is to extract the integration value between the assets then to extract all the optionality in any individual asset And, you know, we have 6 offices across the globe. I will tell you today that we are gonna add another office next month in Bogota, Colombia. And business is accretive to corporate ROCE by about 2% to 2.5%. So have really been focusing on commercial. Were strong before. We have doubled the size of the business. Over the past few years. But just to give you some examples maybe on in WRB, and some of the things we have done over the past couple of years that are adding incremental value. Custom crude blending off-site to make sure that the refinery can get crudes that it could not get before. 1 of the things we are looking at is Wood River Refinery, Ponca and Borger, thinking of them as a single system. And when we do that, we think about optimizing refinery grade butane as an example where we have extra refinery grade butane in the summer, and we bring it back in the winter and how to allocate it across the refineries. And then also things like product blending where we can bring up lower RVP product before it is. The market turns. Blend it up, and send it to a market that has higher RVP product. Another thing we are really focused on, and we have talked about it before, is our fleet of ships We added about over 40 time charter ships you know, prior to all the problems in the in the market overseas. Have another 40 ships coming over the next 2.5 years, and those ships are at lower freight rates than the current freight rates. So that adds a lot of value to our refining business going forward.

Neil Mehta: So those are just some examples of where we have where we have added value that is true. Really good. And maybe the follow-up is on the Gulf Coast specifically, team. It seemed like a good strong beat here, relative to where we were expecting. Anything you would call out? Was it just the crude optionality? Was it specific asset that helped to drive a disproportionate result?

Brian Mandell: In large part, it was our commercial organization and the low freight that I mentioned. We have been bringing cargoes of US based crudes to Bayway. And to Humber, and we were able to bring even more cargoes overseas, which added value to the Gulf Coast refineries. And including the discounted time charter freight. And another thing that we have been really focused on is ensuring that we are filling up the back end units. You know, Richard and team have done a fantastic job of getting the front end, the crude units filled up. Now focused on the back end units and getting more intermediates into the plants and Gulf Coast was a beneficiary of that. In Q3 as well. Thanks, Brian.

Operator: Your next question comes from the line of Sam Margolin from Wells Fargo. Your line is open. Please go ahead.

Sam Margolin: Hello. Thanks for taking the question. Maybe just on LPGs and NGLs. You know, we have seen a pretty substantial move in prices over the past month. And with respect to vertical integration, I think it is sort of well understood how you benefit in a low value LPG environment via blending and some of your downstream capabilities. Can you talk about how the mix and the integrated asset base performs in a very high value LPG environment what the difference is and how you can take advantage of that?

Donald A. Baldridge: Sure. This is Donald. And a lot of the advantages in terms of just absolute price for NGLs, you see that in our gathering and processing business where we do have sensitivity to the underlying NGL price, and that is in our sensitivities. And so we. We will get that uplift through that part of the business. And then what you are seeing though on the physical side is there is still a strong demand for LPGs globally. So we are still seeing strong pulls across the dock. Across free. Freeport, L LPG facility. So even though the ARBs, on a spot basis may not look attractive, the actual physical need for the product is what is driving that part of the business. And then if you pull that all the way forward into CPChem and you think about from ethane feed standpoint, still the U.S. ethane cracker is maintaining that cash cost advantage relative to the Brent/naphtha cash cost. So we are still seeing the ability of the competitiveness around that part of the business to hold steady.

Sam Margolin: Okay. Thanks. And then as a follow-up, Mark, you mentioned in the prepared remarks there is a list or an inventory of refinery projects, capital projects that are exciting to you. Particularly in the context of just a very clear shortage in global refining capacity that I think is structural. Could you elaborate on that a little bit? What specifically within optimization do you think is the is the best opportunity right now? And maybe some time frames?

Mark E. Lashier: Sure. Absolutely. In general, we are looking at enhancing throughput. You saw us rerate some refineries last year or earlier this year by about 45 thousand barrels a day. We are seeing improvements across the fleet. That, we will review to see if there is opportunities to even enhance those rerates. And focus on, improving distillate production and other value enhancing opportunities. Richard, you can dive in and give a few more details.

Richard G. Harbison: Yeah. Sure. Thanks, Mark. You know, when we think about this, we really think about this in a couple categories. 1 is the opportunity to debottleneck, and, we have done a number of projects, that we are starting to see the fruits of those labors, and they show up in our utilization. When you start to see that. And 1 of the sites that is particularly performing very well right now is our border facility. And that is 1 of the sites that we have actually around the edges, improved our capacity to process crude oil there. But on the other side of that, is the importance to down units as well. So once all your front end is full as reasonably can be, getting the logistics in place and the debottlenecking or the yield improvement opportunities in the downstream units, does 2 things. 1, it allows us to optimize our product values coming off the crude units. And 2, it gives Brian's organization some flexibility to introduce intermediates from outside sources to fill up the downstream units. We have had a couple of projects that we are working on that. 1 is that Borger and actually results in an additional jet production. That project's in progress. And there is also some hydrotreating and some other jet projects that we have worked at Wood River as well. And Ferndale is another good example of some projects that we put in place to increase the ability for the facility to, CARB gasoline and then enter into the market of the -- into the California market there. So think of these projects, they are not huge game changing, you know, multi billion dollar investments. They are hundreds or tens of millions of dollars of investment that are allowing us to, creep the capacity and the product quality the utilization of the assets up across the system.

Mark E. Lashier: And Rich mentioned something really important that the Western Gateway pipeline will continue to open up opportunities to enhance our central corridor capabilities, and it will level out the seasonality, and so projects will become more attractive as we look how to continue to debottleneck, add capacity, and enhance the value of what we are producing. Thank you so much.

Operator: Your next question comes from the line of Theresa Chen from Barclays.

Theresa Chen: Hi. Would you provide some color on how demand is trending across your footprint Given the broader economic backdrop, have you seen any changes in customer behavior or demand patterns across your areas of service?

Brian Mandell: Yeah. On the on the demand side, we see US gasoline down about 2.5%. More on the West Coast and less in Middle America. We have, US diesel demand down about 1.5%. Internationally, it is much harder to tell the difference between demand destruction and we call internally demand constriction or lack of supply We think the numbers are roughly similar to the U.S. Overall, though, I think demand's holding up. Well, and the response in demand is not enough to balance the market. So we expect the market to remain strong for the foreseeable future.

Theresa Chen: Thank you. And maybe taking a step back on the midstream front, Dawn, can you provide an update on your views on Permian NGL fundamentals? How are you thinking about the pace of inlet volume growth into 2027 and beyond as producer activity evolves? And related to this, what are you seeing in terms of ethane rejection versus recovery given the step up in residue capacity that is come online over the past few months?

Donald A. Baldridge: Thanks, Theresa. So we still see a robust outlook for the Permian production. I would say what is quite consistent along our footprint is producers that actually are on the wellhead connections are exceeding their forecast both on a per well basis but then just also on the overall growth trajectory. So that gives me a lot of confidence in terms of the volume growth that is underpinning the Permian outlook I think the days of concern about overbuild is now shifting to what is what is next and what is needed from infrastructure build out in the Permian. And we see the footprint that we have will continue to be able to be advantaged in capture that growth and move that down our system. Ethane prices, as you mentioned, are up. that is a positive for our G&P business. We are really not seeing a concern about, rejection. We have got exports from an ethane standpoint coming online. We have got CPChem's facility coming online. All that will be added demand in 2027. So feel good, about the trajectory of the volumes broadly speaking, NGLs and gas all out of the Permian. Thank you.

Operator: Your next question comes from the line of Phillip Jungwirth from BMO. Your line is open. Please go ahead.

Phillip Jungwirth: Yeah. Thanks. You made really good progress on lowering net debt in the quarter, and gross debt also came down continuing into October here. Looks like there is another, call it, 2 billion maturities over the next 18 months. So is the goal to just repay debt as it matures, or is there appetite to do more here whether it is lower absolute debt target or buying back debt in the open market, which I think was new for Phillip.

Kevin J. Mitchell: Yeah. Phillip, it is Kevin. So we were at 18.5 billion of balance sheet debt at the end of the quarter. We took out a $500 million maturity in October. That puts us at an 18 billion level, the target. For balance sheet debt is 17. And as you point out, we have got 1.25 billion of maturities in 2027. And so we have a comfortable path to hitting that $17 billion target We will evaluate whether it makes sense to take any of those maturities earlier. And we will also look at the opportunities to buy debt in the open market. That was quite successful in the third quarter. We did about 800 million of market purchases of debt. But fundamentally, we are not know, we are we are very comfortable with 17 billion as a debt target. We may enhance balance sheet through carrying more cash. As we look to in a strong operating cash flow environment continue with a 50% cash return to shareholders, fund the capital, and build some balance sheet strength because it just enables us to continue that post as the overall environment changes we will just be very well positioned post that. With the excess liquidity that we may be sitting with.

Phillip Jungwirth: K. Great. And then also I wanted to congratulate Richard on his retirement. Appreciate all the help and discussion over the years. Definitely going out on a high note. But the question is more related to, I guess, Chris coming back to Phillips 66 and just as he takes over refining, which I know will not be until next year, just had you see any increased areas of focus under his leadership or just specific ways he will look to continue to push the business forward?

Mark E. Lashier: Yeah. Chris is a great addition to the team. he is got an incredible history. he is got experience across site, and operations leadership. he is was involved with the midstream business when he was at Phillips 66 in business development, and he ran our corporate strategy group. So then he went off to Plains, and he was chief operating officer there. So he brings great breadth and depth of experience, but you look at his combination of Phillips 66 knowledge and his enterprise wide operating experience, he. he is able to connect strategy with execution and he is absolutely committed to safe, reliable, and disciplined processes in operating. So he is he is well positioned to just hit the ground running, pick up where Richard is leaving off, grab the baton, and, continue to build on it. there is no we do not see any big changes in the refining business priorities, the strategic direction, or the targets. Just continue to build on what, what a great foundation Richard is leaving behind. that is great. Thank you.

Operator: Thank you. Your next question comes from the line of John Royall from Piper Sandler. Your line is open. Please go ahead.

Analyst: Hi. Good morning. Thanks for taking my question. So my first question, I just wanted to ask on the cash situation and the volatility in the market. We know yourselves and some of your peers ended up in a situation in Q1 where you had to post a significant amount of collateral due to spikes in prices. It would seem like this quarter with the rising prices maybe would have been another quarter where we might see something similar, albeit to a smaller scale. But you did not see that big working capital outflow like you saw in Q1. Can you talk about what you did differently this time to mitigate those issues?

Kevin J. Mitchell: Yeah. John, it is Kevin. A couple of points on that. I mean, fundamentally, you are correct. But the magnitude of the price change was not near what it was in the first quarter. Nonetheless, we did end the quarter with about $700 million of collateral posted, but that is significantly less than what we saw the first quarter. 1 of the things we have done differently to optimize that is we are now utilizing where we can letters of credit in lieu of cash. And that was about a $100 million impact to us in the third quarter. In other words, if we were not doing the letters of credit, we would have had an incremental $400 million out the door But what I would also say from a broader working capital standpoint, we also had the benefit of rising prices and higher volumes on our net accounts payable, accounts receivable position. So that was a positive. We also have been running a positive from a tax standpoint when you think about we are accruing income taxes on current profits, which were very high. And. But we have not paid those paid those taxes yet. And so that will probably manifest itself as a headwind in the fourth quarter actually because tax and other taxes payable has been a sizable benefit to us especially in the third quarter.

Analyst: Great. Thank you. And my follow-up is on chemicals. And maybe you can talk operationally just about how your units in the Middle East are running and markets they are able to sell into to the extent there are problems with the more traditional forms of egress. And we saw that utilization guidance is down a little bit. I am not sure if that is just maintenance or is there anything impacted by the Middle East conflict there. Just any update there would be helpful.

Mark E. Lashier: Yeah. I think that CPChem's non Middle East assets have been running quite strong. And taking full advantage of the demand in the marketplace. Middle East assets are running but not. Certainly not at full rates, but they are they are running. They are finding ways to get around the restrictions at. In the Gulf. Some material is moving to the West. So, they are doing what they can in the conditions they are dealing with. Thank you.

Operator: Your next question comes from the line of Jason Gabelman from TD Cowen. Your line is open. Please go ahead.

Jason Gabelman: Yeah. Hey. Thanks for I want to go back to capital allocation because on 1 of the slides that you kinda show uses of cash Q3 to Q4, and it kind of implies that perhaps a majority of your excess cash or your free cash flow, I should say, is gonna go to the buyback And I am wondering given where debt is, where the balance sheet is, if we are moving to a place more like your peers where essentially all of the cash goes to the buyback excluding this kind of $1.5 billion of debt you wanna pay down next year. And, you know, the dividend growth. So just wondering how you are thinking about the framing of the buyback moving forward. Given the better balance sheet Yeah.

Kevin J. Mitchell: Jason, it is Kevin. So in terms of fourth quarter, we will see a higher percent going to the buyback and that is partly because we have been trailing the 50% through this year. We have been to be honest, struggling to keep up with the growth in the cash generation. So at the end of the second quarter, had returned 33% of operating cash flow through buybacks and dividends. Through the end of the third quarter, it was 40% cumulative but the third quarter itself was 45%. And so we need to be above 50% in the fourth quarter to get the full year to the 50% level. And we believe that is very doable. We think we will be able to get that and hit that. But as I mentioned earlier, as the balance sheet gets to a comfortable space, we will have more flexibility now. We will continue to look at the big outflows of cash. it is basically the capital program between sustaining capital and growth the dividend, and buybacks, And so we will continue to be disciplined around capital, but note it will be going up a bit With Western Gateway and some of the other great opportunities we have across the business. The dividend is $2 billion on a per share basis, increase but not increasing that much in absolute dollars when you factor in the impact of the buybacks. But I also wanna stay balanced. So I do not think saying that all of the excess cash flow should automatically go into buybacks. I think we will retain some of that just from a balance sheet flexibility standpoint. And we certainly have the potential to be going above 50%. that is very realistic, but I do not think we should just assume that everything goes directly into the buyback, especially in periods with very high cash generation. We would rather retain some flexibility further that out over a longer period of time.

Jason Gabelman: Great. that is that is, really helpful. Thanks. My follow-up is just going back to freight. And I know you mentioned that you have 40 vessels on time charter. You have another 40 coming in over the next couple of years. So wondering more broadly, does that fully cover your kind of freight exposure? Does it mostly cover it? Can you kind of sensitize what that 40 ships on time charter means for the rest of the business? And then any broader color on kind of your views on how long these elevated shipping rates will last? Thanks.

Brian Mandell: Yeah. Would say just to answer your first question directly, that supports about 40% of our asset based demand. And then the second question in terms of the freight, you know, I mean, the freight is incredibly bullish. it is hit high levels highest levels this month, lower. Longer voyages, ship to ship transfers, more demerged, bunker fuels, type VLCCs, and they are splitting them on Aframaxes and Suezmaxes now. We have seen product ships being used for dirty service. So there is there is a lot of reasons to think that freight will continue and our view is it will be stronger in Q4 than in Q3. I think the advantage. Again, the advantage that we have is having that freight having locked in those values ahead of time will be an asset to our refining business and to our commercial business in general. Great. Thanks for the answers.

Operator: Your next question comes from the line of Matthew Blair from TPH. Your line is now open. Please go ahead.

Matthew Blair: Thanks, and good morning. Good afternoon. Your chemicals business really outperformed peers in the third quarter. Could you talk about the supporting factors there? And then for the fourth quarter, can you walk through some of the moving parts that we had you USP contracts move at $05 in September. Sounds like you are you are pushing for an additional amount in October. How likely is that to come through? But then you also have higher ethane costs and will there be any, like, start up costs rolling through from your expansion projects in the fourth quarter? Thank you.

Mark E. Lashier: Yes. Yes. Thanks, Matt. Certainly, the CPChem's been performing well. I think that they. They are seeing strong demand globally. I am assuming partially because of disruptions in the Middle East, but also the challenges in Asia, just getting feedstocks and the whole cost structure in Asia restructuring a bit. And so that is all been beneficial to CP Chem's performance and where they are. And I think that, normally, seasonally, the fourth quarter tends to slow down a bit. But we will see how difficult that is because I think that, the China is underperforming because of their high cost feedstocks, and so that could take some of the edge off of that. Certainly, as the Golden Triangle Polymers project starts up, there will be start up costs, there. That will show up at CPChem. But things are going smoothly and according to plan.

Matthew Blair: Sounds good. And then are replica of your Atlantic Basin refining indicator. it is really taken a hit in October, due to the crude dynamics and the freight dynamics that they have talked about, but it sounds like you are you are pretty well covered on both of those areas. You mentioned sending Gulf Coast crudes to Bayway and Humber, and then talked a fair amount about locking in the freight. So is the takeaway that north. Or sorry, the Atlantic Basin capture could be quite strong, you know, much stronger quarter over quarter in the fourth quarter due to these efforts. And guess, you have any other thoughts on moving parts on refining capture across the rest of your system? In the fourth quarter?

Brian Mandell: Yep. Why do not you go ahead and start, Brian? Yes. I think a direct answer to your question is absolutely on the Atlantic Basin. We have been able to move US based crudes, which is, you know, the Brent-WTI is very wide, so US based crudes are savings and also relative to the indicator and also the freight Just in terms of, guidance for market capture, generally low to mid nineties capture in the summer and mid to high nineties capture in the winter with C4 blending. Think about tailwinds going forward. You know, we have winter diesel and bio margins with low inventories. Really expanding. Jet is over diesel, which is a benefit to us. Butane blending is helpful. Octane spreads have been good, and then we keep talking about the TC fleet, the time charter fleet, but that is very, very important in terms of getting more value out of the market than our competitors And then finally, just the continued commercial optimization. We talked about that a little bit earlier. Some of the things we are doing around WRB, but doing things across all our refineries and that. That will show up in market capture as well.

Richard G. Harbison: Yeah. And when I when I think about it, all systems, all facilities have been focused on distillate production. And max distillate production. And you saw that across the system. Where we achieved a 41% max distillate production across the entire system. And, actually, in the Atlantic Basin, our sites are really tuned to distillate production, and they can produce up to 43, 44% distillate capability out of those assets. So as we stay in the strong distillate economy and, our kit is really tuned to take advantage of that distillate production I see the market capture as favorable for all regions. That we operate in. Thank you, and congrats on your retirement, Richard. Well, thank you, Matthew. Appreciate it.

Operator: Your next question comes from the line of Joseph Laetsch from Morgan Stanley. Your line is open. Please go ahead.

Joe Lage: Hey. Good morning, team, and thanks for taking my question. So I just want to go back to the macro on the refining side, and we have of course, seen some volatility in refining margins in the fourth quarter. But still strong relative to history. Can you just talk a bit about some of the factors that you are watching most closely that could either sustain these elevated levels or, you know, push us towards a more normalized environment thinking Russian exports, Chinese export quotas, normalization of flows, just kind of how you think about you know, all those factors? Thank you.

Brian Mandell: Yep. it is Brian. Thanks, Joseph, for the question. As Sean talked about the demand side, and we are continuing to watch demand. Demand, as we mentioned, has not really been affected much You could see a slowdown in economies. Generally, diesel demand is relatively inelastic, but a slowdown in the economy could affect the markets. On the supply side, you know, we are watching the wars, both in Israel and Ukraine. We are watching that is causing a lot of market dislocation. We are watching to see if things change there. Got 7 million barrels worth of refining capacity offline in Russia, Asia, and Mideast. Watching that to see if something changes there. Again, you pointed out the Chinese exports and whether Chinese have it in the past few years been willing to really increase those exports, but whether they wanna do that now. We are watching the Russian distillate We do not think that Russia has enough distillate to make much of a difference, be quite frank. I know there were reports even to this morning. I noticed of 3 to 4 on the water, but that is a drop in a bucket compared to how much distillate is offline. So the other thing I would say too is we are watching just in general refineries. They have been pushed pretty hard with people running their refineries. And we would expect more unplanned outages given how much the. They have been pushed So that is another opportunity. And then the freight rates, you know, we talked about freight rates. Our view is freight rates are going to be higher in Q4 than Q3 and might be higher next year than they are now. So that will drive markets too. So all those things combined, those are all signposts that we are watching, but if you think about each 1 of those individually, there is reason to believe that margins are gonna maintain the strength that they have currently through most of next year. Thanks, Brian.

Joe Lage: that is helpful. And then I have. I wanted to go to follow-up on some of the capital allocation questions. And just with us the significant cash generation that we have seen and as excess cash builds on the balance sheet, can you talk about how you are thinking about potential M and A opportunities? Are there any particular areas, whether across midstream, refining, renewable fuels, or marketing, where might be seeing some opportunities in the market? Thank you.

Mark E. Lashier: Yeah, Joseph. We are always looking at opportunities. We executed things in the past in midstream of course, the. With the WRB roll up so we are not we are not adverse to doing that. Gonna be driven by an abundance of cash to go out and do anything, radical. And valuation seem to be increasing across the board. So we will be very disciplined in anything that we might do in that regard. Great. Thanks.

Operator: Your final question will come from the line of Shawn Quan Salisbury from Bank of America. Your line is open. Please go ahead.

Analyst: Hi. Thanks. I wanted to ask about the record mid volumes this quarter. You are already at 100% utilization on fractionation and LPG export. Your next fractionator does not come online for kind of a year and a half. Does this downstream constraint on your system put you at a disadvantage versus peers in terms of gaining share and what is expected to be a very strong NGL growth environment?

Donald A. Baldridge: Shawn Quan. This is Donald. You are right in terms of we have high capacity utilization on our Gulf Coast fractionation, but we also have access and contracted space at other third party fractionators. So we do not see any bottlenecks in terms of continuing to grow our Permian production. You know, we will be turning on our Iron Mesa gas plant here in the first quarter. We expect that to fill up quite quickly as well as our Coastal Bend NGL pipeline expansion comes online at the end of this year. So we see the volume growth coming through in 2027, and we have access to fractionation to be able to handle those volumes. And positions us well for when we turn on the corpus Christi fractionator in 2028 that we can readily fill it.

Analyst: That makes sense. Great. I will leave it there. Thank you.

Operator: Thank you for your questions. This concludes the question and answer session. I will now turn the call back to Sean Maher for closing comments.

Sean Maher: Thank you for your interest in Phillip 66. If you have any questions or feedback after today's call, please feel free to reach out to Kirk or myself. Thank you.

Operator: This concludes today's call. You for attending. You may now disconnect.