Enterprise Products Partners L.P. (NYSE:EPD) Q1 2023 Earnings Call Transcript

Enterprise Products Partners L.P. (NYSE:EPD) Q1 2023 Earnings Call Transcript May 2, 2023

Operator: Good day and thank you for standing by. Welcome to the Q1 2023 Enterprise Products Partners L.P. Earnings Conference call. At this time, all participants are in a listen-only mode. After the speaker’s presentation, there will be a question and answer session. . Please be advised that today’s conference is being recorded. I would now like to hand the conference over to your speaker today. Randy Burkhalter, VP of Investor Relations. Please go ahead.

Randy Burkhalter: Thank you, Gigi and welcome everyone. Good morning and welcome to the Enterprise Products Partners conference call to discuss first quarter earnings. Our speakers today will be Co-Chief Executive Officers of Enterprise General Partner, Jim Teague, and Randy Fowler. Other members of our senior management team are also in attendance for the call today. During this call we will make forward looking statements within the meaning of Section 21 E of the Securities and Exchange Act of 1934 based on the beliefs of the company as well as assumptions made by and information currently available to Enterprise’s management team. Although management believes that the expectations reflected in such forward-looking statements are reasonable, it can give no assurance that such expectations will prove to be correct.

Please refer to our latest filings with the SEC for a list of factors that may cause actual results to differ materially from those in the forward-looking statements made during this call. And so, with that, I’ll turn the call over to Jim.

Jim Teague: Thank you, Randy. Today, we announced Enterprise is off to another good start for the year. We reported adjusted EBITDA of $2.3 billion for the first quarter of ‘23. We generated $1.9 billion of distributable cash flow, providing 1.8 times coverage. We retained $863 million of DCF for the first quarter. We reported seven operating records and one financial record in the quarter, mostly related to our pipeline activities and export volumes across multiple commodities. We had record pipeline and fee-based natural gas processing volumes, record NGL marine terminal volumes, and near record total marine terminal volumes. In March alone, our marine terminals loaded over 70 million barrels of NGLs crude oil, refined products, and petrochemicals for export.

Our NGL and natural gas pipeline businesses, as well as our natural gas marketing and octane enhancement activities also reported strong increases in gross operating margin compared to the first quarter last year. We also saw strong margins in a refined products business offset by lower volumes and our propylene business where PDH 1 was down for 24 days during the first quarter for planned maintenance. We remain on schedule to put approximately $3.8 billion of major projects in service this year. In the second quarter, we will commission PDH 2 and the expansion of the Acadian Gas Pipeline system. In the second half of the year, we will complete our 19th NGL Fractionator, two natural gas processing plants in the Permian, and put the first phase of the Texas Western products pipeline in service.

We’re running essentially full across all our assets with the exception of the Rockies. We have significant expansions in our ethane, ethylene, propylene, and LPG systems. We’re upgrading export capacity and adding geographic diversity to our ethane export assets with positions at Morgan’s Point and now Beaumont and expanding our LPG and propylene capacity at our Houston Ship channel facility. Our ethylene export facility has been full since day one, and we’re expanding that by 50%. Ethane exports have moved from being only consumed by a handful of niche players and point-to-point movements to significant growth at a — in demand by several petrochemicals in Asia, Europe, and the Americas. We recently completed new ethane export contracts that add 240,000 barrels a day with multiple counterparties.

On spot, we received our record of decision this past November and expect to get other permits and our license in the second half of the year. We are way ahead of other applicants and we know what it takes to get a record of decision. Two buoys and a motorboat to hook up to a ship won’t cut it. We will have a 24/7-manned platform, vapor combustion, and two pipelines that provide the ability to load multiple grades of crude oil and also able to evacuate those lines during hurricane. This is on — time is on our side as we commercialize this project as we don’t think it’s needed until 2027. While the second quarter can be our weakest seasonally, we remain constructive on global market fundamentals even though the forward curve doesn’t reflect that.

In addition to low global inventories, we also note that OPEC Plus seems to be intent on managing global balances. On the demand side, expectations for most consultants range from 1.4 million to 2 million barrels a day for global demand growth in 2023. OPEC Plus economists say they are standing by their forecast of 2.3 million barrels a day demand growth by the end of 2023. From our perspective, that sounds rich. Although, the last five weeks U.S. crude inventories have drawn 20 million barrels, countering these bullish fundamentals are concerns about the global economies with central banks continuing to signal additional rate increases to tame inflation. Meanwhile, while the Chinese continue to ramp up travel in a huge way, their industrial manufacturing surprised to the downside when their PMI turned negative yesterday, regardless of the near-term mixed signals, which continued to signal a range bound (ph) market near term., For us it’s very hard to make a bearish call for oil in the medium to long term, and it’s hard for us to be too constructive on natural gas.

A wide gas to crude spread gives U.S. petrochemicals, a structural feedstock advantage that in our view is permanent. A case in point is a current operating environment where the U.S. ethylene industry is the only region that has been consistently profitable, while the rest of the world have been very selective in what they crack and how they operate. Single-use plastics are doing good. They’re profitable while durables have their challenges and their headwinds. Meanwhile, the U.S. refining industry is one of the most competitive and technologically capable in the world. In short, we expect U.S. production to continue to grow and we did expect demand at our docks will likewise continue to grow. If you want to know where we’re going, look at what we’re doing.

We continue to expand our ability to export hydrocarbons out of the U.S. to points all over the world where it’s needed. With that, I’ll turn it over to Randy.

Randy Fowler : Thank you, Jim, and good morning everyone. Starting with income statement items, net income attributable to common unitholders for the first quarter of 2023 increased 7.3% to $1.4 billion or $0.63 per common unit on a fully diluted basis. This compares to $1.3 billion or $0.59 per common unit for the first quarter of 2022. Adjusted cash flow from operations, or adjusted CFFO, which is cash flow from operating activities before changes in working capital was $2 billion for both the first quarters of 2023 and 2022. We declared a distribution of $0.49 per common unit for the first quarter 2023, which is 5.4% higher than the distribution declared for the first quarter of the prior year. This distribution will be paid, May-12 to common unitholders of record as of close of business on April 28.

As we mentioned on our February earnings call, we will evaluate another increase mid-year. In March we repurchased approximately 683,000 common units at an average price of $24.89 per unit on a, for a total cost of approximately $17 million. In addition, on a combined basis, our DRIP and employee unit purchase program purchased another 1.7 million common units on the open market during the quarter. For the 12 months ending March 31st, 2023, Enterprise paid out approximately $4.2 billion of distributions to limited partners. In addition, we also repurchased $267 million of common units off the open market. As a result, our payout ratio of adjusted cash flow from operations was 55% for this period and our payout ratio of adjusted free cash flow was 75% for this 12-month period.

Total capital investments in the first quarter of 2023 were $654 million, which included $570 million for organic growth capital projects and $84 million of sustaining capital expenditures. Our major growth projects that are sanctioned and under construction remains unchanged at $6.1 billion. We currently expect our 2023 growth capital expenditures will be in the range of $2.4 billion to $2.8 billion, which includes possible expenditures associated with projects under development and not yet sanctioned. Frankly, I have a hard time seeing us get to the upper end of this range. The changes to our CapEx ranges for 2023 and 2024 since our recent analyst day are projects under development, which are substantially comprised of potential expansions of our Permian gathering and processing systems and our NGL distribution system, including exports.

None of this creep is associated with cost overruns or delays. We expect 2023 sustaining capital expenditures will be approximately $400 million. Our total debt principal outstanding was approximately $28.9 billion at the end of the quarter. Assuming the final maturity of our hybrids, the weighted average life of our debt portfolio was approximately 20 years. Our weighted average cost of debt is 4.6%. At March 31, approximately 97% of our debt was fixed rate. Our consolidated liquidity was approximately $4 billion at the end of the first quarter, which includes $3.9 billion of availability under our credit facilities and $76 million of unrestricted cash on hand. In March, 2023, we entered into a new $1.5 billion, 364-day revolving credit agreement and a new $2.7 billion revolving multi-year agreement that matures in March, 2028.

These agreements replaced our prior credit facilities. For the 12 months ended March 31st, 2023, our adjusted EBITDA increased 11.7% to $9.4 billion compared to our trailing 12 months as of March 31st, 2022. We ended the quarter with a consolidated leverage ratio of 3:0 on a net basis after adjusting debt for the partial equity treatment of our hybrid debt and reduced by the partner’s unrestricted cash on hand. Earlier this year, we announced a lower leverage target of 3.0 times plus or minus a quarter or in a range from 2.75 times to 3.25 times. This change in financial policy, our lower leverage along with an established track record of growing stable fee-based cash flows and strong credit metrics resulted in standard and poor’s upgrading our senior unsecured credit rating to A minus with a stable outlook.

We are appreciative of this recognition as the only A minus rated midstream energy company. With that, Randy, we can open it up for questions.

Randy Burkhalter: Okay. Excuse me. Thank you, Randy. Gigi would like to remind our listeners that when they ask questions, limit their questions to one question and one follow-up please. We can go ahead and start with our Q&A.

Q&A Session

Operator: Our first question comes from the line of Spiro Dounis from Citi.

Spiro Dounis: Thank you, very much guys. First question on petchem, was particularly strong this quarter, at least relative to what we had expected. And I know in the past you’d all talked about maybe a six to nine-month period or a lag on inventories getting worked down globally before that really started to tighten. And so, I’m just curious, Jim, I know you mentioned the weaker-than-expected PMI, but is something happening maybe sooner than you’ll had expected or are we still sort of waiting to see that destocking effect take place later the year?

Jim Teague: I’m going to let Chris D’Anna answer you.

Chris D’Anna: I think what really happened in this first quarter is that, it was more of a supply shortage than stronger demand. I mean, we had decent demand just coming off of the fourth quarter, what was really weak, but ultimately it was reduced supply from a couple of PDHs being offline.

Spiro Dounis: Got it. Okay. That’s, that’s helpful. Chris, second question, just turning to Shin Oak, yes, you all were sort of looking at potential alternatives there to expanding that pipeline. Just curious if you give us an update there on maybe what some of the potential alternatives could be and how you’re thinking about the timing to make a decision there.

Jim Teague : I probably don’t want to tell you what the alternatives are, but I will tell you, we’re trying to be capital disciplined, and in the course of trying to do that, I guess we’ve kind of confused people, but we will loop Shin Oak. If we can find some options that defer that capital, then we’ll probably do that. But make no mistake, our intent is we are going to loop Shin Oak, and we’ve got a deadline on — and there’s a deadline on the permit that we’re going to have to be aware of. Does that clear it up?

Spiro M. Dounis : It does. I appreciate your color, crystal clear. Thank you, guys.

Operator: Our next question comes from the line of Jean Ann Salisbury from Bernstein.

Jean Ann Salisbury: Hi, good morning. NGL marketing has been falling in recent quarters and was quite low in this quarter. Can you talk through the drivers of this and if you see this as a trough?

Jim Teague: Lower commodity prices, but where .

Randy Fowler: I think, if you look at what we did last quarter in 2022, the first quarter of 2022, I think we had some very good opportunities in that quarter with our storage program that we didn’t have in the market this quarter. Commodity prices probably have a little bit to do with it, but there was just probably some opportunities last year that we didn’t see this year.

Jean Ann Salisbury: And then kind of a broader question, once the Houston ship channel is expanded, does Enterprise think forecast Houston crude price is trading at least at parity to Corpus or maybe even a premium?

Jim Teague: Who wants to take that? You, Tony or who?

Brent Secrest: So, there’s a couple things we’re doing. Jean Ann and…

Jim Teague: Talk about the — Jean Ann mentions it in her writeup, talk about the — Jean Ann says that the pipelines to Corpus are full.

Brent Secrest: Yeah, so we’re getting incremental barrel.

Jean Ann Salisbury: We’ll get to that Brent.

Brent Secrest: We’re getting some incremental barrels kind of month over month, and I’ll just say if you say, Permian grows 40,000 to 50,000 barrels a month that we’re getting our fair share on the Houston pipelines. There’s some premiums that happen at Corpus on the docks. I wouldn’t say those premiums are that much higher and I wouldn’t say that, they’re day in and day out. I think what you’re seeing us doing on our system, Jean Ann, is we’ve implemented a new quality program. So if you look at the quality of crude oil that we’re getting right now across our docks, it’s the best quality though we’ve seen since we’ve been up in operation and I think it compares with anything that Corpus can offer. So, I think some of that is going to be equalized, some of the freight advantages, we’ll have to overcome. But I think over time, if you look at where our program is going on crude oil, I think that we’re going to eventually get there.

Jim Teague : What was your objective in changing the — why did we change quality mark?

Brent Secrest: I mean, we did it for a couple of reasons, but I mean, one thing is we listened to our customers and we listened to our customers both on the production side. We listened to it, listened to them on the refinery side here in Houston, and then also our export customers. But if you started going through the program on what we identified, there’s probably a couple of folks out there that we’re trying to do a little bit too much aggressive blending and we’ve effectively eliminated them and done a lot more routine testing in terms of maintaining the quality that we can offer these customers downstream. Ultimately, that’s going to achieve higher prices.

Jean Ann Salisbury: That’s super helpful, Brent, as always, thank you so much, and thanks for taking my question.

Operator: Our next question comes through the line of Brian Reynolds from UBS.

Brian Reynolds : Hi, good morning, everyone. Maybe just to talk on distribution outlook and expectations. We’ve seen Enterprise raise kind of in that 1% to 5% range over the since 2018. Looking forward with leverage below three times and free cash flow still hovering around a billion dollars after dividends in the next few years, kind of curious if we could see that DPU growth rate go above 5% or perhaps, will more CapEx kind of temper that distribution growth expectation? Thanks.

Randy Fowler : Yeah. Hey Brian, this is Randy. Yeah, thanks for the question. I think coming in and really looking, at a range of 1% to 5% and going back to 2018, I would probably differ in my perspective of how I would look at it because from 2017 through, call it 2020-2021, we were really in a mode of transitioning from more of the external funding model to now more of an internal funding model. And so that we were very measured on what we did in distribution growth to be able to grow into that internally funded model. Since that point in time, I would really say since, over the last couple of years, two years, we’ve have grown more in the range of, call it 4% to 6%, and like I said we’ll come in, as I mentioned in the prepared remarks, we’ll come in and discuss with the Board here, middle of this year as far as what we want to do for the rest of this year on distribution growth.

And, again, we’ve demonstrated good EBITDA growth. Jim mentioned $3.8 billion worth of projects going into service for the remainder of the year. That gives us good cash flow growth that’ll support distribution growth down the road. And I really hate to come in and get more granular than that because I don’t want to usurp our Board or front run our Board. But I think we’ll look to continue to come in and provide distribution growth and buybacks for that matter as far as getting capital back to investors.

Brian Reynolds : Great. Appreciate it. We’ll wait for that mid-year update. And then, as my follow up question, I’ll take the CapEx question, projects under development have increased by a billion for ‘23 and ‘24. You talked about in your prepared remarks that you see, limited ability to get to the high end of that range. So, kind of curious if you can just talk about, perhaps some of the projects in the hopper and then within the existing CapEx backlog, was there any CapEx inflation or perhaps pull forward of CapEx into ‘23 and ‘24 that we should be thinking about? Thanks.

Randy Fowler: Yeah, I’ll take the first part of the question. There was not any cost of any overruns or delays on projects. In fact, Graham and his engineering team have done a great job of delivering projects on time and more often than not slightly under budget. And really the change that we’ve had since analyst day are more projects that we’ve I guess we’ve got a good bit of confidence in and we included them in the range, but they’re still subject to being completely underwritten through commercial contracts and rather not elaborate into much detail we’ll just come in and go back in. And again, what I said in the prepared remarks, and a lot of it is what we talked about at our analyst day where we’re seeing most of the opportunities for growth are gathering and processing in the Permian broadly. It is also in our NGL distribution system including, export facilities. So just seeing a lot of demand on that front.

Brian Reynolds : Great. I’ll leave it there. Enjoy the rest of your morning, everyone.

Operator: Our next question comes from the line of Michael Bloom from Wells Fargo.

Michael Bloom: Thanks. Good morning, everyone. I wanted to ask about the marine export, particularly the LPG and SA and it came in, really strong this quarter. Just want to get your color on the market what demand looks like, and are — do you think these levels are sustainable from here? Thanks.

Randy Fowler: Teague, do you want to take that?

Jim Teague : This is Teague. We did definitely see strong demand this last quarter and we’re going to expect to continue to see that demand really comes down to productions continuing to grow. It’s still a supply push and the barrel is still having a price to clear across the water.

Randy Fowler: Yes, Michael. I was — I’ve been surprised pleasantly so at Al, well we’ve done on our ethane export and I’m surprised that we’re able to do 240,000 barrels a day of new contracts with more to come.

Operator: Our next question comes in the line of Tristan Richardson from Scotia Bank.

Tristan Richardson : Hi, good morning, guys. Could you talk a little bit about PDH 2, and overall, in the pet chem segment, how should we think maybe about that fee-based mix proforma once that asset comes online relative to the sort of 70%ish fee-based we typically see in that segment?

Randy Fowler : I think this 100% fee-based, isn’t it, Chris?

Chris D’Anna : That’s correct.

Randy Fowler : So, it’s a 100% fee based with all credit worthy customers, and we always, Graham is sitting to my left. They always come in. We can do more than whatever the nameplate is, so we’ll probably have some extra pounds to play with.

Tristan Richardson : Great. And then maybe just on EHT export expansion, could you talk a little bit about the mix of products you’re seeing? I mean, you talked a lot about refrigeration at Analyst Day, and I think you highlighted that expansion could be 120 a day. Should we think of it as pretty fungible across products or primarily focused on LPG? And then could the scope change for that project just given sort of the strength you’re seeing across the dock indicated by the first quarter?

Brent Secrest : Yes, this is Brent. So, I think in terms of where it stands right now, it’s propane, butane and some propylene slated on — slate to come on the second half of ‘25. We continue to look Tristan, that is there another project there? But it’s all under evaluation, but right now it’s slated to come on the second half of ‘25.

Chris D’Anna: And I just want a correct the number. You said 120,000 barrels a day are LPG export expands into north of 170,000 barrels a day.

Randy Fowler : And we’re talking about the ship channel widening is what you might explain that. Bob, can you explain what you get out of the ship channel widening for Tristan?

Bob Sanders: Yes, sir. So, when Project 11 is complete on the widening, which we expect to be by the end of ‘24, first quarter of ‘25, it’ll add four to five hours of daylight. And most of the products we deal with are daylight restricted. So that’s easily an incremental 15% to 20% additional cargos that can come in if needs be.

Tristan Richardson : Which means to you or Zach, you sell out your refrigeration now?

Operator: Our next question comes from the line of Chase Mulvehill from Bank of America.

Chase Mulvehill : I guess, a lot of grounds been covered, but can I ask on processing margins in the Permian and kind of relative to your fee floors, obviously Waha is seeing a lot of pressure, so are we kind of at those fee floors for Waha at this point? And then also just an update on kind of how you’re thinking about, I think it’s 400 MCF a day of latent capacity on your Texas interest state pipelines, just how you’re thinking about that still holding it open or contracting it up and updates on kind of how you see Permian Natural Gas egress between the Brownfield additions and when Matterhorn comes online.

Jim Teague : Natalie and Tug?

Natalie Gayden : I’ll answer the fee floor question. Post Navita, so the first quarter of ‘23, we did hit more fee floors than I guess the end of ‘22, but less volume is being subject to the fee floor. So, I’d call it 75% of the volume, and it’s not very far under the fee floor. So, long story short, I see probably upside the rest of the year.

Tug Hanley : This is Tug, on the pipeline capacity question, we still have open pipeline capacity. We are utilizing every day as marketing, but just like every decision here at Enterprise, there’s opportunity to work with Natalie for a long-term contract opportunity. We’ll evaluate that or we’ll evaluate to continue to hold it open for spot opportunity.

Jim Teague : When we feel like it’s the right time, we will contract that capacity.

Chase Mulvehill : An unrelated follow-up on octane enhancement, you’re still generating some nice gross operating margin there and really some nice non-feeded gross operating margin as Arba and butane spreads are still wide. So, I’d be curious kind of your thoughts on how you see these spreads playing out, the rest of ’23, and how much you have hedged at this point?

Jim Teague : You want me to take it or you want to —

Bob Sanders: So, we have, right now, I think that octane enhancements about 75% hedged. We feel pretty good about where those margins are going to be. There was an earlier question about LPG pricing, and I think as you see this production come on, you look at the ability for propane and butane to go find markets, I could see that being somewhat challenged. And that’s to the benefit of octane enhancement program. Are we going to see as good a margins that we saw from the MTB uplift that we saw earlier this year? Probably not, but it’s still a very good business for us.

Operator: Our next question comes from the line of Jeremy Tonet from JPMorgan Securities, LLC.

Jeremy Tonet : Hi, good morning. Just wanted to kind of pick up a bit, I guess, on the Permian and Natural Gas, there’s been some conversation out there with ratios increasing, and just wondering if you could talk about what your experience or thoughts are — and how you see that, I guess, kind of impacting basin production as a helpful.

Tony Chovanec : Yeah, Jeremy, this is Tony — and take away dynamic.

Jim Teague : All right. QRs, when we looked at the basin holistically are absolutely going up. It’s largely driven by the preponderance of drilling in the more gassy areas and think Delaware Basin compared to say the Midland Basin. So, there’s no question that the GORs are going up. And, that’s how Midstream are contracting and that’s what producers are doing. Producers look at their portfolio, they look at what they plan to drill, and gas GORs the decline over time. Oil declines faster than natural gas does. So that impacts the long-term outlook in this regard.

Tony Chovanec : Jim, one note, does that mean you have less crude? Yeah, and I think there’s a misconception, thanks for that, Jim, that we don’t have the amount of crude that we had before, because GORs in that, that’s absolutely is not the, it’s not the fact. And you can look at our forecast, which we stand by, you have a lot of both. That’s the bottom line. You have a lot of crude, there’s been no change in those curves as we forecast. You have a lot of very rich gas. So, the answer is it doesn’t mean less crude. And ultimately this is not a bad story. It’s not a bad story for Enterprise. It’s a great story.

Jeremy Tonet : Got it. That’s very helpful there. And then just wanted to kind of come back to the LPG and Petchem side. And you’ve touched on this a few different times across the call, but just wanted to see, I guess, what patterns you’re seeing over the balance of the year. LPG exports is that kind of one time in nature and surprised do you see this strength continuing? People are concerned about a recession. How do you see LPG exports and Petchem I guess kind of being impacted by these trends looking forward?

Jim Teague : I think, and I’ll hand it to Brent, but you know, LPGs got a price to export period and price creates demand and it’s going to have to price the export and demand and there’ll be demand for it, right?

Brent Secrest: Yeah. I mean, the only thing I’d add if, so, that’s our fundamental belief. And it’ll have to go fight to maintain some sort of margin if there’s some sort of issue obviously at Enterprise, we have a pretty good shock absorber, which is our storage footprint. And if you can play this out because there’s another question about LPG export. So, and why we’re expanding our export capacity is because the market needs it. And if you look at infrastructure bottlenecks our belief is that is the production comes online, it’ll price the export, but at some point, the export capacity isn’t going to be there. And that’s an opportunity for folks like Enterprise to participate in that market. And if you go out even further and you look at the overall demand, especially what’s coming out of China with PDs, there’s going be a period of time in there in ‘25, ‘26, ‘27 timeframe, where the US producer has to catch up to the overall capacity and the overall demand.

But all this is going to be healthy for the system.

Jeremy Tonet : Great. Thank you very much.

Operator: Our next question comes from the line of Colton Bean from Tudor, Pickering, Holt and Company.

Colton Bean: Morning. Randy, coming back to Brian’s question from a different angle. Do you all view leverage as more of an output or are you intent on managing towards the target range? Meaning are there any items you view as a balancing mechanism, whether that be distribution growth, buybacks, CapEx, or would you let leverage drift below the range in any given year?

Randy Fowler: The range that we have out there I think is a sufficient range for us. For the foreseeable future that really comes in and gives us a lot of flexibility to come in and fund organic growth. If we see a surge in organic growth projects, I think, it gives us the flexibility to handle that stay in the range. I think it gives us the flexibility to come in and if we see an acquisition opportunity that we want to use cash or incurred debt for, I think it gives us plenty of flexibility to do that, as well as come in and continue to provide distribution growth and buybacks. So, I know I’m not asked, probably answering the question the way you wanted it to, but that range of 2.75 to 3.25 gives us a lot of flexibility and when we get all these new growth capital projects coming online, and again, we’ve got a lot under construction now and I think, we’ll see more of that EBITDA certainly full year of that EBITDA show up in 2024, 2025.

And then I think at that point in time, we’ll reassess.

Colton Bean: Okay. And so, it sounds like for the near term, expecting to stay within that range, and the question was more angled towards, it seems like you guys are more likely to break the bottom end than the top end. And so just if we’d see a ramp in distribution growth or buybacks, if it looks like you all were drifting into call it mid-2s or even low-2s.

Jim Teague: Colton, I’d just hate to get the cart ahead of the horse. Let us get there first, and then, and let us see what the situation looks like when that prevails and I think we’re going to do the responsible thing once we get to that point.

Colton Bean : That’s perfect. And then maybe shifting over to gathering. So, I think there’s a $25 million step up in the Rocky Mountain region called out. From what we were saying, it looked like regional pricing was actually down, specifically in the San Juan, which I think is where you have those gathering fees indexed. So, I guess, can you explain kind of what the uplift was there quarter-on-quarter?

Jim Teague : Yes. Really, I think, what we were seeing was really for a period of time, I think especially January, we really saw strong natural gas prices more driven by California, both up in the Rockies and in the San Juan. Tony, I don’t know if you want to…

Tony Chovanec: Completely agree, phenomenal prices and definitely an outlier. And that’s because utilities just wanted to prepare and say we have to have the gas.

Operator: Our next question goes in the line of Theresa Chen from Barclays.

Theresa Chen : Good morning, and I wanted to touch on the near-term demand outlook for U.S. LPG exports a bit more. Going back to your comments about the Chinese PDH unit, what are you seeing in terms of the pace and ramp of them, and do you think there could be an incremental bid for U.S. cargos later on this year due to lower LPG exports from Saudi Arabian Qatar?

Randy Fowler : I’m sorry, Theresa, what was the first part of that question?

Theresa Chen : Chinese PDH unit ramp.

Randy Fowler : Yes. I mean, so I think you’re seeing quite a few PDHs come online this year. You’ll see some next year and then obviously the year after. I don’t know if the run rates are going to be sustainable in terms of what they’re doing right now. I think they’re doing probably around 70%. There’ll be some opportunities for LPG exports. I think the overall propane consumption is only going to increase. I just don’t know if those run rates over there in China are going to be able to be maintained. If you look at our opportunities, we have the availability of some spots. Those will probably get filled up, but it’s not a ton. It’s probably two or three spots a month tug that we have available right?

Jim Teague: But we — it still goes back to the gas crude spread as to how much those PDH is run. And as we said in our script, we’re still — we can’t make a bearish case medium to long term on crude prices. And we can’t — we’re not constructive on natural gas. So inherent net gas to crude spread ought to be more LPG and ethylene plants and PDH plants in Asia.

Theresa Chen: Thank you. And the second part of the question related to U.S. potential U.S. LPG cargo is potentially getting a bid due to OPEC production cuts.

Jim Teague: OPEC definition, I think if they — they cut LPG. Tony?

Tony Chovanec: They do, but just Theresa, they’re not huge LPG exporters anyway. And they’ve been really outspoken that, at least for now, incremental barrels, whether they’re up or down, will affect internal consumption. So, they’re just another balancing item in a market where barrels are pricing to get consumed. It’s just not a — we don’t see it as a big factor.

Theresa Chen: And Brent, going back to your comments about infrastructure bottlenecks on the LPG export front, down the line eventually, where do you think the con export constraint will come about? Is it dock space? Is it refrige capacity? Is it tonnage? What does that look like?

Brent Secrest: I mean, I think it’s refrige capacity. That’s where it starts to begin with. And I don’t — if you look at what the industry’s doing right now, we’re running at pretty high rates. The dock piece is easily — easier to solve. But on the front end, I would probably say it’s going to be capacity.

Operator: Our next question comes from the line of Keith Stanley from Wolf Research.

Keith Stanley : Hi, good morning. Wanted to start with a follow-up on CapEx. So, you’re at about $2.5 billion this year, I think potential spend for next year or $2 billion to $2.5 billion. A couple of years ago, I think the company talked to $1.5 billion to $2 billion as somewhat of a run rate for CapEx. So, should we think of ‘23 and ‘24 as elevated CapEx years, or is the run rate now higher just as the company continues to grow?

Brent Secrest: I just, the opportunities are there — just good opportunities at the time. What ‘26 and ‘27 looks like? We’ll let, when we get closer to that point, but right now, we just see a lot of good opportunities both on the upstream side and the downstream side.

Jim Teague: We’re bringing on $3.8 billion worth of major projects this year. It’s like our PDH 2 plant, our fractionator, Acadian expansion those will all be full on day one.

Keith Stanley : Thanks for that. Second question just, you rolled out the project 9.3 last quarter. Any at a high level, any areas of the business that are going better than plan? Any lighter than plan? Just any high-level comments on progress towards that internal target?

Jim Teague : We probably, we have probably on petrochemicals or how we’re over-planned. So other than, I can’t think of anything other than the Rockies and I guess our Eagle Ford crude pipeline is as we’re hustling that. So other than that, Zach, you got anything going on?

Randy Fowler: No segments. I called felt the need to call up.

Jim Teague : I think segment by segment we’re pretty close to where we land.

Keith Stanley : Okay. Thank you.

Operator: Thank you. One moment for our next question. Our next question comes from the line of Neal Dingmann from Truist.

Neal Dingmann: Morning gentlemen, thanks for taking my questions. My first is on shareholder return. I’m just wondering, given how strong your financial position continues to be with over $4 billion of liquidity, I’m just wondering, what factors go into the decision on the unit repurchase, on a go forward?

Jim Teague : Yeah, Neal, good morning. And, yeah, Neal, it really, I guess we had had talked that the buyback program is still more in, more of an opportunistic program right now. And I guess good news, bad news is frankly in the first quarter we didn’t see a lot of good opportunities. When we in the month of March, I think around the Silicon Valley Bank failure, there was more volatility in the market and the units were under pressure and we saw good value and we came in and executed then our, just, our window wasn’t long enough. We would like to have bought more, but, the units rallied pretty quickly on the heels of that.

Neal Dingmann: No, that’s great. Great to hear. And then my second question on petrochem specifically, looks like the propylene side was slightly down, just largely, I think more mostly just on the planned maintenance. I’m just wondering, can you remind me of any major plan maintenance for the remainder of the year, specifically for that, that propylene production facilities?

Randy Fowler: Graham, you got any? No, we’ve currently got a couple of splitters in down for plan maintenance, but after that it’s, yeah, we got a couple splitters down right now for plan maintenance, but after that I think we’re done for the year.

Jim Teague : And those splitter turnarounds, they’re not going to, they’re not material to any financials.

Randy Fowler: I’m going to hold you to that.

Operator: Thank you. At this time there are no further questions. I would now like to turn the conference back over to Randy Burkhalter for closing remarks.

Randy Burkhalter: Thank you, Gigi. That concludes our call today everyone, and we’d like to thank our listeners for joining us today and have a great rest of your day, and goodbye for now.

Operator: Thank you. This concludes today’s conference call. Thank you for participating. You may now disconnect.