Welcome to the first quarter 2026 Phillips 66 earnings conference call. My name is Rob and I will be your operator for today's call. 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.

Hello everyone. Good morning and thank you for joining Phillips 66 first quarter 2026 earnings conference call participants on today's call will include mark leisure chairman and CEO Kevin Mitchell CFO Don Baldrige midstream and chemicals rich Harbison refining and Brian Mandel marketing and commercial today's presentation can be found on the investor relations section of the Phillips 66 website along with supplemental financial and operating information slide two 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 with that i'll turn the call over to mark thank you sean geopolitical events in the middle east drove unprecedented commodity price volatility during the quarter to put this in context march was the first month the price moves in major crude oil refined product and european natural gas benchmarks all exceeded the 95th percentile in the face of this volatility we remain focused on operational excellence our team is executing safely and reliably the majority of our assets are in the u.s we have pipeline connectivity to some of the lowest cost and most reliable hydrocarbon corridors in the world this positions us to reliably supply energy to support global demand due to the closure of the strait of hormuz a significant amount of global refining and petrochemical capacity is down we however continue to operate at high utilization supplying products to our customers additionally we have global placement optionality through our commercial organization this quarter has seen a significant and favorable shift in market fundamentals first the importance of u.s sourced hydrocarbons has increased due to a need for diversification and access to reliable supply second unplanned downtime in global refining assets has reduced inventories and will support margins finally reduce petrochemical production globally due to downtime and higher nap the prices has reduced inventories and will also support margins as a reminder eighty percent of CP chems capacity is on the US Gulf Coast with competitive ethane feedstock recent global events show the importance of reliable domestic energy supply our Western gateway pipeline project will address long-term refined products needs improve supply flexibility and increased reliability for the west coast markets we're excited about the future due to our strong asset footprint culture of operating excellence and attractive fundamental outlook across all of our businesses anchored by the strength of our balance sheet we're confident in our ability to navigate market volatility and capture opportunities brian will now share more on slide four about how our commercial organization is one of our competitive advantages thanks mark we have a strong commercial organization with six offices across the globe our business enhances our asset footprint by optimizing feedstocks delivering products into the marketplace and capturing value.

We capitalize in geographic dislocations and turn volatility into opportunity. With our expertise in global market dynamics, we're ahead of the game. We have an asset-backed trading model and can leverage our physical footprint to take advantage of opportunities. We trade over 6 million barrels of liquid hydrocarbons every day. This creates optionality and economic value. Markets are fluid right now and volatility is likely to persist into next year. Recent disruptions have created multiple opportunities. For example, we moved Bakken crude oil to our Beaumont terminal on the U.S. Gulf Coast and then leveraging the Jones Act waiver to our Bayway refinery. We displaced international crudes with domestic grades into our refining system and sold the international barrels into tight overseas markets. We placed gasoline from our U.S. Gulf Coast commercial blending facilities into the West Coast using the Jones Act waiver. We leveraged our global footprint to deliver LPGs and naphtha produced at our Sweeney Hub to global petrochemical customers around the world. Commercial performance is included in the results of our operating segments, enhancing their margins and improving market capture. Moving to slide five, the recent shock to the global energy system has been universal. Refining capacity has been damaged. Logistics have shifted. Arbitrage routes have changed. We are watching these and other signposts closely to capture additional value. The differentials between global indices and physical markets have spiked, and forward markets are heavily backwardated. This dynamic reflects tight global crude oil balances. The outlook for product markets looks even tighter, and we expect refining margins to be constructive through the remainder of the year. Our market analysis, commercial capabilities, and global footprint enable us to optimize the flow of molecules around our system. Our team maximizes the margin uplift across our value chains. Here are two examples of how we are optimizing our system. First, we've added two dozen originators around the globe. They speak the language, they know the culture, and they know how to source deals that unlock more value and optionality, providing long-term access to key global markets. Second, we've tripled our vessels on time charter in the past two years, securing roughly half of our waterborne crude slate. The global tanker fleet has become tight with limited spot availabilities and a large share of sanctioned vessels. This has caused freight rates to increase to historic levels. By locking in our freight rates early, we reduce the cost of crude to our refineries. We optimize around our refineries, pipelines, and terminals to ensure that we're leveraging every molecule and driving additional value from our fundamental knowledge of the global markets. Backed by world-class assets, we find opportunity and volatility to deliver greater shareholder value. Now, I'll turn the call over to Kevin.

Thank you, Brian. On slide six, first quarter reported earnings were $207 million, or 51 cents per share. Adjusted earnings were $200 million, or 49 cents per share. As a result of a sharp increase in commodity prices during the first quarter, the company's financial results were impacted by mark-to-market losses of $839 million related to short derivative positions used as economic hedges to manage price risk on certain physical positions. We had a use of operating cash flow of $2.3 billion dollars operating cash flow excluding working capital was approximately 700 million dollars capital spending for the quarter was 582 million dollars we returned 778 million dollars to shareholders including 269 million dollars of share repurchases and 509 million dollars of dividend payments we increased the quarterly dividend seven percent on an annualized basis I will now cover the segment results on slide 7. Total company adjusted earnings were $200 million. Midstream results decreased mainly due to lower volumes largely due to impacts from winter storm fern, lower margins associated with customer re-contracting, and accelerated depreciation associated with a Permian Basin gas plant. In chemicals, results increased mainly due to higher polyethylene margins. Across refining, marketing and specialties, and renewable fuels, results decreased mainly due to mark-to-market impacts. In corporate and other, the pre-tax loss increased, primarily due to the inclusion of costs associated with the decommissioning and redevelopment of the idled Los Angeles refinery site. Slide 8 shows cash flow for the quarter. We started the quarter with a $1.1 billion cash balance. Cash from operations, excluding working capital, was approximately $700 million. There was a $3 billion use of working capital, mainly reflecting an inventory build, and an increase in cash collateral on derivative positions, partly offset by the net benefit in our payables and receivables positions associated with rising commodity prices. We funded $582 million of capital spending and returned $778 million to shareholders shareholders through share repurchases and dividends. Our commitment to return greater than 50% of net operating cash flow to shareholders remains unchanged. The company increased debt in the first quarter. Given the sharp increase in commodity prices, we issued a term loan and increased borrowings on short-term facilities to manage the margin collateral requirements. We ended the quarter with $5.2 billion in cash. We are well positioned to manage further commodity price volatility through significant liquidity, including a high cash balance, and cash generated from operations. Slide 9 shows the projected path from the current debt level to year-end 2026 and 2027 debt. We remain fully committed to a total debt balance of $17 billion by year-end 2027. Consensus cash from operations for 2026 and 2027 is approximately $8 billion. In the remainder of 2026, we expect operating cash flow, working capital benefits, and the reduction of cash balances as markets stabilize to enable us to reduce debt to approximately $19 billion. In 2027, we expect operating cash flow to enable us to reduce debt by a further $2 billion to $17 billion. This is consistent with the capital allocation framework we have previously laid out, with approximately $2 billion each to dividends, share repurchases, capital spend, and debt paydown. Looking ahead to the second quarter on slide 10. In chemicals, we expect the global O&P utilization rate to be in the low 80s, driven by the uncertainty of operating levels at CPChem's joint ventures in the Middle East. In refining, we expect the worldwide crude utilization rate to be in the low to mid-90s. Turnaround expense is expected to be between $120 and $150 million. We anticipate corporate and other costs to be between $430 and $450 million. Moving to slide 11, Mark will now provide some final thoughts. We will then open the line for questions.

Great things happen when preparation meets opportunity. The current environment is attractive across all our businesses. We've prepared by focusing relentlessly on what we control. cost culture competitiveness and capital with discipline all in the service of safe reliable operations that deliver strong shareholder returns our teams are performing and we're pressing in and capturing those opportunities fully prepared fully committed to execute and win when we win you win thank you mark we will now begin the question and answer session As we open the call for questions, as a courtesy to all participants, please limit yourself to one question and a follow-up.

If you have a question, please press star, then one on your touch-tone phone. If you wish to be removed from the queue, please press star, then one 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 one on your touch-tone phone. Steve Richardson from Evercore ISI, please go ahead. Your line is open.

Hi, thank you. Guys, I was wondering if we could start on the mark-to-market adjustments and wondering if you could give us some color on some of these impacts by segment, if you could, and I know you addressed this in the 8K, but if you could get into a little bit of how the volatility that you witnessed was outside the bands of expectations, and can you also just be sure to hit on how you think about that draw liquidity what it means going forward and what it you know any impacts it may have on your shareholder return commitments yes Steve this is Kevin let me walk through some of that detail so as we laid out in the first quarter we saw a 839 million dollar mark to market

from an income statement standpoint that impacted refining M&S and renewables and the specific amounts by segment were detailed in the in the press release this is broadly consistent with what we put out in the 8k we said approximately 900 million at that point that was our best estimate at that point in time and so I think it's important to make it clear that these are mark-to-market impacts on paper hedges that we have in place physical the the market at the end of each month, but the physical inventory is not. And so there's a net impact through the income statement. I do think it's important to emphasize that we do this as a risk mitigation tool. We've been doing this for some time. It's standard practice. And in the normal course, the impacts of these mark-to-market transactions are just not that significant, not that material. But as Mark mentioned in his comments, we saw unprecedented volatility across the commodity markets in which we participate that caused this, we'll say, as a sort of outsized impact. As you look ahead in terms of what you can expect on a go-forward basis, it's very much a function of where the commodity prices move from end of March, think through, say, the end of the year. And if we were to use the forward end of day yesterday, we'd recover by the end of the year about $500 million of that $893. And it's a commodity by commodity calculation on a quarter by quarter basis. So based on the forward curve, if that were to play out as reality, that's what you'd see come back in that context. At the end of the quarter, we had a total of $3.2 billion out on margin activity. That differs from the income statement effect because we effectively consume this cash through our normal purchasing activity. So just to put some context around that, $3.2 billion out on margin at the end of March. At the end of yesterday, $3 billion, even though the absolute price levels are pretty similar to where they were at the end of the first quarter. And so you will see that come down as we work our way through the year. And then as we get into what does this mean in terms of capital allocation, debt reduction, share value, put in the presentation on debt targets, we think we will be fits in the remainder of the year operating cash flow. And as the market's stabilized, we don't need to carry that much cash into about $19 billion at the end of this year and then down to our target $17 billion next year operating cash flow back through dividends and buybacks. Frankly, we used in that calculation, but I feel pretty optimistic that there's upside there as well, and we'll hold true to that, so 50% of the others.

Thanks for the fulsome. I think I just hit as well what we've got you on CPChem. The consultants have full chain margins up, I believe, $0.33 at last check for the second quarter. I was wondering if you could talk about what you're seeing in your business and your view on capturing this with obviously very high utilization rate on the U.S. Gulf Coast into the second quarter and the balance of the year.

Yeah, absolutely, Steve. This is Mark. CPK is well-positioned to go out and capture those margins. There can be some ups that occur, but they're certainly out there aggressively pushing that. You've seen the supply and demand situation tighten up dramatically with the limitations coming out of the Middle East. And additionally, you've seen limitations for producers in Asia that, frankly, some countries in Asia are away from petrochemical production and into energy use to protect And so that further tightens things up. And the cost curve has dramatically shifted. As the price of oil has gone, low-cost ethane in North America, you see that driving the margin increases. And then there's this factor that – and so they were converting that into a deeply discounted net of the world market. We think that somewhere in a five-cost curve should have been. Now, that's been eliminated with the things that have been going on. And so it's very constructive for CPChem. They can operate at over 80 percent of their capacity is in the U.S. has been stable versus what's been going on.

Neil Mehta from Goldman Sachs. Please go ahead. Your line is open.

Yeah, good morning, Mark and team. The standout number from this quarter was really the worldwide market capture, which ticked up to 138%. And maybe you can bring this to life a little bit. Can you give us a couple of examples of dynamics that specifically drove that strength? And then when we think about sort of a mid-cycle market capture rate, you've talked about mid-90s type of utilization. I think there are a lot of investors on the call who are thinking that 2Q could be lower than that mid-90s number, though, just because of the backwardation and the curve, and just your perspective of that is actually achievable as we set up for Q2.

You know, he was pretty humble, and his open commercial team demonstrated in Q1 as leveraging that optionality. You think about the – they've at least advanced the Jones Act waivers. All those things lined up to where Brian and his team could take full advantage of that and to drive that, and that's what drove that pretty remarkable capture number, and we're really proud of what they've been doing. They weren't sitting around watching the world in a crisis.

They were moving things to – so, Brian, you can go ahead and – And, you know, as Mark said, you know, with the huge amount of volatility in the market, with market dislocations and just the integration of our businesses, there was a lot of value to be had in the market. Just maybe some examples. We profited from a long RIN position, including RINs we generated at a Rodeo Renewable Facility, and we were also able to roll some lower-cost RINs from prior year into this year. We had really strong results in our European and Asian trading businesses. As I mentioned earlier and as Mark mentioned, the time charters that we put on over the last couple of years really helped in the elevated freight market and reduced our accrued costs into our refineries. And then finally, you saw some of the product differentials like on Octane and Jet were higher than the indicators, so that helped as well. And so to give you some context maybe going forward, if we use our refining indicator, It includes a lot of the impacts already. It's embedded in the indicator. Historically, an average for the year would be 98%. In Q1, we captured, benefited from all the commercial opportunities I just mentioned. Normally, in Q2, beginning of summer driver season, we would think about mid-50s. So just thinking about some of the tailwinds and headwinds, tailwinds, things like butane blending. We think there will be more butane blending due to the RVP waivers. Strong jet or octane dips can help us there. And additional commercial value. And I think we'll continue to see some of the same value we saw in Q1. But then there's some headwinds, as you said, backwardation and inventory impacts and even turnarounds if we had some in Q2 would impact the mid-90s. and think about what you think the market will look like in Q2 and then work your way from there.

Is it fair to say mid-90s is a good starting point, though, based on the pluses and minuses?

Yeah, mid-90s would be a good starting point.

Okay. All right, and then, Kevin, can you hit slide 9 again, maybe in a little bit more detail? Because this is on the pushback since the AK came out that I know you and we have gotten on the PSX stories. Is leverage pretty elevated? And I think part of that is you're just holding excess cash. And so if you could spend a little more time just unpacking this slide, because I think it is important.

Yeah, and that is a really important point that we've effectively, from a debt and cash grossed up the balance sheet by borrowing more than we need from a normal day-to-day standpoint, but being positioned in the event that we see more extreme volatility and have need on, for example, margin calls in the event that significant price increases. It does feel like since the end of the first quarter, that dynamic has settled down a little I mean, the markets still continue to fluctuate, but we've been in this 90 to 110 market conditions stabilized. We'll be able to have an offset on debt. Likewise, on working capital, we had a big working capital use in the first quarter. We expect that the remainder of the year through the combination of exacerbated by the margin, all that gets us to our target. And I will emphasize that if we see margin conditions and that will further enhance the cash generation, will enable us to pay down the debt quicker and also enable us to return more cash to shareholders.

Very clear. Thank you, Ken.

Manav Gupta from UBS Financial please go ahead your line is open good morning guys I have a more of a theoretical question what I'm trying to get to the bottom of this based on your preliminary comments it feels your refining system which is in the US mostly is relatively insulated from these crude supply disruptions and and other things that are happening in the world where certain refining assets may be very good but can't run you are relatively insulated from these things and what i'm trying to understand is does that mean somebody like a phillips or even any u.s refiner in this environment is structurally better off than their global counterparts and if that is

the case in your opinion is this the time to be bullish u.s refining or is it this time to be bearish u.s refining if you could help us answer that i don't know it's brian you know you're absolutely right this is a time to be bullish u.s refining you know if we if we look at what's happened in the marketplace it started in asia moved to europe but u.s has been relatively insulated on supply refinery runs are strong consumer demand is healthy crude production is relatively stable and this kind of highlights how we're immune to the crisis although not largely our crude for instance at philip 66 we only purchase about one percent of our crude from the Middle East. Our crude is generally from Canada, from the U.S., and from Latin America, and of course from Canada and the U.S. It's all pipeline connected. So we are in a very, very good position.

Yeah, I would add to Brian's comments, and you think about the activities that they undertook in the first quarter, they do interface with the rest of the world's domestic supply and push normal imports out into what the global markets are demanding. And then in addition to that great position in North American refining, CPChem is rock solid in North America petrochemicals in the high-density polyethylene value chain. So all of our product lines, all of our businesses really in this environment considerable amount of time.

We completely agree. Quickly pivoting to sometimes people don't forget that you actually own significant amount of renewable diesel capacity in the u.s you never actually entered into a jv to split your capacity renewable diesel margins were negative everybody was losing money but we are in a very different environment given the size of your footprint would it be fair to say year over year you could see a material free cash flow inflection in your renewable diesel business given where we are right now well absolutely if even if you just think about the uh rins manav the current uh blended are in is more than twice what it was in 2025.

So it's just the credit value alone. And we are running very, very well right now. In fact, above nameplate capacity. So you should see a substantial difference than prior year.

Thank you so much. Doug Leggett from Wolf Research. Please go ahead. Your line is open.

Hey, good morning, everybody. Thank you for taking my questions. Brian, I wonder if I could direct this to you. So we've got extraordinary margins, you pointed out multiple times that it's steeply back-burated. And I get the bullish near-term outlook. The question is duration and what breaks it. And we're seeing a lot of airlines cutting capacity or balancing demand through demand disruption, you could argue, versus physical supply constraints. What's your response to that in terms of margins are great, but what's your view on duration? And I've got a follow-up for Kevin, please.

Thanks, Doug. You know, our view is throughout – this is going to last throughout the rest of this year and into early next year. It's constriction, trying to manage the need for products. And we kind of think of it as a race to the top. We're watching very tight crude markets and crude prices keep moving up, Brent, and as crude prices move up, products are going to have to move up even further to open up the refinery margin to keep refiners producing the products that the world needs. Clearly, the world is tight, and as you mentioned, probably jet fuel is the tightest, so the refinery margins are going to have to keep opening. And we saw that even, for instance, in our European refinery recently, where we saw the gasoline crack was somewhat weak compared to the distillate crack, which seemed to be slowing down European refineries. And then all of a sudden, the gasoline crack made a large move to the upside, opening up margins so that European refineries could produce the products that they need. So I think we'll continue to see that through this year and through the early part of next year, even if the straits are opened in the next month or two months.

Brian, would you treat this as a, would you annuitize this or treat it as a windfall?

What was the question?

Would you annuitize this or would you treat it as a windfall?

Being closed, more than just a few months.

So thank you for that. This leaves my follow-up question, which is for Kevin. Kevin, your share price is 5% off its high. And, you know, I think Mark just said we wouldn't annuitize this. the opportunity to permanently shift this windfall to your equity value comes from debt reduction versus buying back your shares. Why is that not the right answer if this is indeed a windfall?

You are correct that debt reduction creates, and debt reduction is a priority. The $17 billion target that we laid out there is a target. If we have significant excess, we will reduce debt below that level. I'm not going to go so far as to say we can all go to debt reduction. I think maintaining a degree of balance through the cycle on capital allocation, We've been pretty clear on the 50% return, of which at current levels, about half of that is the dividend and is buybacks. But as the absolute level of cash generation increases, by definition, if you take 50% back to shareholders, that's an increasing amount also going to the balance sheet. and so we view it as a balance across the board as of right now why while we may only be a few percent off of our high we still think there is um good value in our share price and so we feel comfortable with that plan and capital allocation thanks so much for taking my questions guys joel latch from morgan stanley please go ahead your line is open hey good morning mark and team

and thanks for taking my questions uh so i wanted to start on the macro just given where product prices are today can you talk about the demand trends you're seeing within your system in the u.s are you seeing any signs of demand destruction on gasoline and diesel uh and then inventory levels in the u.s have drawn to add or below the five-year range uh on on products so things are starting to look look pretty tight yeah hey joe this is brian we haven't seen much demand destruction, probably 1% down for products, both gasoline and diesel.

And then in terms of our system, we've actually done really well. We added over 500 franchise stores last year in marketing, so we're actually seeing a lot of value from the good work the sales team has done in marketing. But we haven't seen demand destruction in the U.S.

Thanks. That's helpful. And then I wanted to just ask on on the refining side so utilization rates of 95 percent in the quarter were solid uh even with some maintenance and some some third-party pipeline impacts as well uh can you just talk to some of the drivers of the performance during the quarter um and then as part of that uh operating cost they continue to trend in the right direction and i recognize there's variability quarter to quarter uh with throughput and natural gas costs but could you just touch on which ending you think you're in in the in terms of cost reduction efforts in the path of the 550 per barrel Yeah, Joe, this is Rich.

Thanks for the question, cost per barrel, and then maybe look back at some of the regional performance opportunities that we see last quarter. The cost per barrel 1Q was $6.21. That's actually $0.80 per barrel improvement year over year, so good movement there. I'm very happy with what the team has accomplished on that front. Quarter over quarter, as you indicated, it was slightly higher, and that's primarily due to fewer barrels processed in the quarter. And that was a combination of planned maintenance activity as well as there's just fewer days in the quarter, in the first quarter of the year. That does have a material effect. Total process inputs were down about 2 percent quarter over quarter. Natural gas price was also a big player in this. Prices got all the way, I think, average at about $4.87 per mm BTU at the Henry Hub. If we normalize that back to the $3 annual natural gas prices, which is the basis we've used for the $5.50 target, the number moves into the low 5.80s on a dollar per barrel OPEX basis. So that says, you know, we're well within striking range here of this $5.50 per barrel target in 2027. And the organization is really working hard. They've actually got over 200 initiatives that we're actively pursuing right now, which are forecasted to drive $0.15 to $0.20 per barrel out of the base operating costs. And these are structural changes in our cost profile and continuing a trend that we've started here well over four years ago now. And maybe an example of one or two of these, one of them is really changing our approach to how we clean FCC boilers. oilers. It doesn't sound like something very exotic, but that actually will, once accomplished, will drive down our annual cost by well over $3 million. And another example is really acid consumption in our sulfuric acid alkylation units. And we're working on tightening up the process controls and the temperature controls on those. That strategy is projected to save another $2 million per year. So it's racking these winds up one by one by one across the system, and the team has been doing a fantastic job of doing that so you know the balance of the closure continuing to increase our availability and utilization of the assets you know that continued maturity of our reliability programs as well as uh something i've mentioned before which is increasing our total process inputs by filling up the downstream units behind the crude units using all that discipline that we put in for the crude unit side to apply it to the downstream units. So this remains an ongoing execution story, and I'm very in it, and we do see additional upside on that. On the market capture regional performance side of the business, Brian covered a lot of that generally at the macro level, but what we saw on the refining side was coming in a little bit lower for us in refining, And some of that's just the anomaly of pricing. We've got prior month pricing that's coming in on crude deliveries. And really good work by the European office. And especially on the jet side of the business, the kerosene fuel, as those prices disconnected from traditional ties. A similar story, jet production there with the jet pricing blowing out. And then in the central corridor, this is where we had a lot of our turnaround activity focused for the corridor. So we did see the market capture actually go down a bit there, and that was related to maintenance activity at Wood River and Borger Facility and some mark-to-market impacts that are in the corridor. As you mentioned, there was some impact that slowed down.

Great. Thank you. Appreciate it.

Philip Jungwirth from BMO Capital Markets. Please go ahead. Your line is open.

Thanks. Good morning. How does, on Midstream, just how does the higher crude prices change how you're thinking about investment opportunities? If it becomes clear there's going to be a greater call on shale, we see the Publix raise CapEx. Just would you be willing to look more at organic growth here? If so, which parts of the value chain? Would that consist of GMP, pipeline, frack, or exports? And then just last, just how much sensitivity is there around the $4.5 billion midstream data target by year end 27 if we do see higher U.S. volumes?

Capital discipline, returns, those are very important to us. But certainly as opportunities evolve, whether that's volume growth in the field where we can add gathering and processing and capacity to serve our customers and fill our value chain up, we'll certainly pursue those opportunities. We've got growth plans in place. You'll see us continue to add capacity as the needs evolve. I think that's sort of the fair way of our midstream growth plans. You'll see that we try to maintain a balanced value chain. What I mean by that is adding, gathering and processing capacity, making sure we've got the downstream infrastructure, but also being mindful of what capacities are needed in the market. Again, going back to staying focused on capital discipline, staying focused on the returns that we can generate with those organic growth opportunities. In terms of 2027 and our $4.5 billion target, the path that we are on, and commercial successes, we feel very comfortable with where we are on that trajectory, as well as the ability to sustain that growth beyond.

Great. And then coming back to chemicals, once this straight opens up, how do you see the progression for getting back to normal operations for CP Chem, where you are guiding the lower two-key utilization, but obviously benefiting on the margin front in the Gulf Coast? And if you could also just comment on the broader industry, that would also be helpful just in terms of what does that scenario look like, steps to take, and time duration to get back to normal?

I think as far as CP Chem is concerned, in good shape, is then the greater infrastructure in the Middle East and what there may be. I think that there's probably a greater sense of urgency to get, and then petrochemicals may be a next layer, so the Gulf will be a little lag behind the energy recovery, and And then you're going to see the system need to repopulate the inventory chain, the logistics chain, and that will take some time. So I think you'll see the facts on it. And the RLPP project in Qatar proceeding as expect eruption in the progress of the RLPP project in spite of what's going on. Everybody's been safe. Everybody's doing what they need to do to get that project in 2027. Kevin, you'll see they're making great product contribute, and it'll be really sorely needed, I think. And so those are the whole dimensions for CP Chem. Thank you.

Lloyd Byrne from Jefferies. Please go ahead. Your line is open.

Hey, good afternoon, Mark, Kevin, team. Thank you for having me on. Can I start by following up on Neil's question on capture? And I know you commented on how well positioned your transportation is, But how does that impact second quarter capture or maybe even third quarter if rates continue to go on like this?

You know, given that we locked in our shipping rates, we should continue to see a benefit from shipping rates, particularly in our Atlantic Basin region.

Thanks. And let me ask a follow-up of, I don't know whether Don's on, but maybe Mark can answer it. You can comment on Western Gateway, and obviously a very good open season. Just what are the hurdles left and kind of the timing for FID?

This is Don. I appreciate it. We are quite excited about where we are on the Western Gateway project, the progress we've made to date, and where we find ourselves at the end of the second open season. How I see the path forward here is to complete the JV arrangements with Kinder Morgan, as well as execute the transportation agreements with the third-party shippers. We've got a team that's working hard to get that done. I would say with the successful conclusion of that work over the next couple of months, I'd expect we would be in a position to FID this project mid to late summer, again for a 2029 in-service date. And one of the things I I reflect back on just the progress we've made and what we've learned through the open season is really twofold. One, I think there's a strong market interest in having a new build pipeline built to Phoenix and be able to deliver reliable, secure transportation fuels to the West. And then, two, there's strong support from the state and federal groups, agencies, and officials in having this pipeline in service as soon as possible. So, that gives me a lot of confidence that Western Gateway is the right project at the right time and will deliver the right returns.

That's great. Thank you, guys.

Jason Gableman from TD Cowan. please go ahead your line is open hey thanks for uh taking my questions um i know you reiterated the four and a half billion of ebitda on midstream um 1q obviously moved sequentially lower particularly in the ngl business quarter over quarter can you just help us i guess bridge um the quarter-over-quarter decline and remind us how you get to that $4.5 billion and perhaps given Western Gateway and potential for continued activity, what type of upside do you see from that $4.5 billion?

Sure, Jason. Appreciate the question. And just in summary, at the very onset, absent the impact of volume from winter storm fern, we're right where I expected us to be from a quarter one performance. We continue to have great commercial success, not only in the growth, but also in the re-contracting which that has some impact in q1 and let me maybe unpack that a little bit when we think about uh our renewals we're quite proactive in how we do that we we tend to renew those uh a year prior to their expiration dates uh the ones uh that came up uh for this quarter we had um renewed those and and what was exciting about that is we had renewed those for per 10-year-plus terms. For me, that really validates the success of our relationships with our customers. That execution gives me a lot of confidence in our ability to continue to grow into our $4.5 billion target by 2027. The fundamentals are bright. The execution by the team is strong and as we look through with western gateway uh whether it's some of the uh follow-on expansions when we talk about additional gas plants that gives me confidence that we can sustain this growth rate beyond just 2027. got it and i neglected uh um ask about the lpg export arb opportunity in the current environment so if you could just talk about how you're thinking about that. Sure. In the near term, most of our windows are spoken for either with our term customers or by ourselves from our time charters. Where we've had success is really in our delivered time charter market where the team in Singapore is being able to optimize deliveries, be able to take advantage of the volatility, much like what you just heard Brian talk about. I think overall what this shows is the importance and the strength of the Gulf Coast LPG export capability. So I think this will continue to be a good tailwind for Gulf Coast exports, and we expect Freeport to be a beneficiary of that outlook. Great.

And my follow-up is just on some of the assets you have on the West Coast. One, given Western Gateway, does that make Ferndale any more or less core to the business than it previously was? And maybe can you also talk about the opportunity to sell down part of the interest in the renewable diesel plant as your peers have done and as that market has strengthened here?

Yeah, absolutely. From a Ferndale perspective, Ferndale is integrating well into the california market and we see targeted at northern california western gateway is a southern california opportunity strong tailwinds for the other question about the renewable yeah i think that the asset is running strong and we would all always entertain any interest but today

thanks for the answers teresa chen from berkeley's please go ahead your line is open hi there um on On the midstream front, with the crude price outlook likely risk to the upside over the medium term and potential reacceleration of activity in second tier basins, can you talk about utilization and the ability to expand your past four NGL assets that are now or soon will be connected to Kinder's double H conversion now in NGL service? Is there renewed growth? If there is renewed growth in associated gas, either in the Bakken or in the Rockies itself, How much incremental pipe capacity could you have on your Rockies to Sweeney NGL system, or would that require significantly more investment?

I appreciate the question. Our DJ production, we're seeing some record volume, so it's very exciting to see the volume in that area. And certainly, as you alluded, there's opportunities, whether that's in the Powder River Basin or the Balkan, for additional development. We certainly have a well-positioned NGL network out of Colorado that flows through our system in multiple different routes and feeds into our Sweeney complex. We've recently restarted our Powder River NGL pipeline to be able to take some early Balkan barrels. If there's growth in that area, we would certainly look at opportunities to be able to expand capacity, to be able to fill the downstream pipes that we have out of the Rockies. So that is certainly an area that we're keeping an eye on.

Thank you.

And in regards to Western Gateway, now that the commercialization process is done, what range of total capex and expected and build multiple on a hundred percent basis can you share at this point regardless of how the economics would be split between the partners still need to kind of work through some of the final details with our partner in terms of scope and connections with our perspective of shippers so we're probably premature to to have that information out there but it will will be be out there shortly thank you matthew blair from tph

please go ahead your line is open great thank you uh just one question for me could you talk about the canadian crude market looks like wcs at hardesty is one of the most attractive crudes out there are the wider dips relative to ti due to any any pipeline constraints coming out of canada and then the market structure impacts that you talked about earlier for U.S. inland barrels, would those apply to Canadian barrels as well, or are they not affected by that? Thank you.

Yeah, WTI, WCS differentials have moved wider from very tight levels earlier on this year. They're now next month at almost $18 off. And a couple of reasons. The first reason is that light sweet crudes from the U.S. are being pulled to Asia, and so that's tightening up light sweet crudes and medium sours. And the second reason is that the Venezuelan barrels on the market on the heavy grades, and so that's kind of widened the WTI-WCS. And our kind of view is they're going to stay wide. We're in a very strong position with our MidCon portfolio advantage, given the Canadian crudes to our refineries and we benefit from those widened differentials as you mentioned and currently just just as a reminder our sensitivity is a hundred forty million dollars of additional earnings for every dollar wider that the diffs become and this concludes the question-and-answer session I will now turn the call back over to Sean Maher for closing comments thank you for your interest in Phil 66 if you have any questions or feedback after today's call please reach out to kirk or myself thanks and have a great day this concludes today's

conference call thank you for your participation you may now disconnect