Thank you for standing by and welcome to Enterprise Products Partners L.P.'s Third Quarter 2024 Earnings Conference Call. At this time, all participants are in a listen-only mode. After the speaker presentation, there will be a question-and-answer session. I would now like to hand the call over to Libby Strait, Senior Director of Investor Relations. Please go ahead.

Good morning and welcome to the Enterprise Product Partners' conference call to discuss third quarter 2024 earnings. Our speakers today will be Co-Chief Executive Officers of Enterprise's 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 21E of the Securities 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. With that, I will turn it over to Jim.

Thank you, Libby. We reported adjusted EBITDA of $2.4 billion for the third quarter compared to $2.3 billion for last year’s third quarter. We generated $2 billion of distributable cash flow, providing 1.7x coverage. In addition, we retained $808 million of DCF. Our retained DCF totals $2.3 billion year-to-date. Operationally, we set 5 volumetric records, including 7.5 billion cubic feet per day of inlet natural gas processing volumes and 12.8 million barrels a day of crude oil equivalent pipeline volumes. We've benefited from contributions from the 3 new natural gas processing plants and wide natural gas price spreads between Waha and other market hubs. We're on track to complete construction of two additional processing plants in the Permian, our Bahia pipeline, frac 14, Phase 1 of our Neches River NGL export terminal, and the last phase of our Morgan’s Point Terminal Flex Expansion in 2025. And we'll have one additional processing plant coming online in Delaware in 2026. These projects provide visibility to new sources of cash flow for our company and enhance and expand the NGL value chain at the core of our business. We also announced yesterday that we completed the acquisition of Piñon Midstream. These assets are highly complementary to our Permian processing footprint by providing treating services to a prolific area of the basin that generally has been infrastructure limited due to the lack of sour natural gas treating and acid gas injection capacity. The Piñon assets are also a very strategic addition to our NGL value chain that touches everything from the wellhead to the water. I'd be remiss if we didn't recognize the tireless efforts of over 200 of our employees at Mont Belvieu who rolled from our most comprehensive turnaround for the PDH 1 plant right into a turnaround for our PDH 2 plant. Our employees completed these 24/7 turnarounds with extreme diligence and without any lost time accidents. We believe this time and investment will result in higher utilization rates and performance for both of these facilities going forward, and we look forward to their contributions in 2025. We're excited about the number of inbound inquiries that we're getting related to new natural gas demand in Texas from both data centers and new gas-fired power plants that are being built under the Texas Energy Fund. There are a lot of people talking about exposure to data centers. It seems that it's a very trendy topic, and everybody who has a piece of pipe in Texas is promoting it. The reality is there's a very small list of companies with pipeline and storage assets best positioned to benefit from this build-out, and Enterprise is one of them. It is difficult to quantify the ultimate demand and timing at this point, not knowing which projects will proceed. That being said, it is one of the most promising signals we've seen in natural gas in a long time, and we're looking forward to serving this new influx of demand. At Enterprise, we take pride in the fact that our organization is not siloed. Everyone is important. We all pull in the same direction every day. The dedication, commitment, and creativity of all our employees have always been the key to our success. We always strive to improve. We operate an integrated value chain, providing a wide range of services from the wellhead to the water. Our systems are highly automated and provide us with billions of data points. Each link in that chain presents an opportunity to provide a service, earn a fee, or enhance profitability by increasing our margins or reducing our costs. Over the last 5 years, we have developed a talented big data and data science team that works closely with all areas of our company. We're now using big data for everything from predictive maintenance to market analytics to asset optimization. One of the many examples is our pipeline controllers now use real-time profit optimizer programs to help determine when and how they run compressors and pumps based on real-time power and fuel costs. Data and the insights it can provide are, in many respects, the new currency. And our proprietary data will forever be an opportunity for Enterprise. As we sit in the final quarter of '24 and head into '25, our work is not done. Each year presents new opportunities and new headwinds. We have built a network of assets and a culture that delivers strong results throughout business cycles, administrations, and market conditions. Our company is built for the long run. As always, we have never been more excited about what the future will bring for our company. With that, Randy.

Thank you, Jim, and good morning. Starting with income statement items, net income attributable to common unit holders was $1.4 billion or $0.65 per unit for the third quarter of 2024. This is an 8% increase over the third quarter of 2023. Our adjusted cash flow from operations, which is cash flow from operating activities before changes in working capital, increased 4% to $2.1 billion for the third quarter of 2024 compared to $2 billion for the third quarter of last year. We declared a distribution of $0.525 per common unit for the third quarter of 2024, which is a 5% increase over the distribution declared for the third quarter of last year. This distribution will be paid on November 14th to common unitholders of record as of the close of business on October 31st. In the third quarter, the partnership purchased approximately 2.6 million common units off the open market for $76 million. Total repurchases for the trailing 12 months were $252 million, or approximately 9.1 million Enterprise common units, bringing total purchases under our buyback program to approximately $1.1 billion. In addition to buybacks, our distribution reinvestment plan and employee unit purchase plan purchased a combined 6.5 million common units on the open market for $181 million during the last 12 months, which includes 1.6 million common units on the open market for $47 million during the third quarter of 2024. Notably, 48% of our employees participate in the unit purchase plan. At Enterprise, we really do practice what we preach. For the 12 months ending September 30, 2024, Enterprise paid out approximately $4.5 billion in distributions to limited partners. Combined with the $252 million of common unit repurchases over the same period, our total capital return was $4.8 billion, resulting in a payout ratio of adjusted cash flow from operations of 56%. We returned roughly $1 billion more than our growth capital expenditures were for the same period. Total capital investments in the third quarter of 2024 were $1.2 billion, which included $1.1 billion for growth capital projects and $129 million of sustaining capital expenditures. Our expected range of growth capital expenditures for 2024 remains unchanged at $3.5 billion to $3.75 billion. We have received overwhelming interest from our producer customers following our recent acquisition of Piñon Midstream. As Jim noted, these assets not only enhance our processing footprint, but allow us to attract more acreage in the Delaware Basin. Additionally, yesterday we announced a contract with Oxy to potentially build a CO2 pipeline that would serve the Houston Industrial Corridor. We are updating our 2025 estimated growth capital expenditure range to $3.5 billion to $4 billion to encompass potential growth opportunities in connection with these announcements. Sustaining capital expenditures are expected to be approximately $640 million in 2024, which is higher than our original estimates, primarily due to costs associated with the turnaround of the two PDH facilities. As of September 30, 2024, our total debt principal outstanding was approximately $32.2 billion. Assuming the final maturity of our hybrids, the weighted average life of our portfolio was approximately 19 years. Our weighted average cost of debt is 4.7%, and approximately 98% of our debt was fixed rate. Our consolidated liquidity was approximately $5.6 billion at the end of the quarter. This includes availability under our credit facilities and unrestricted cash on hand. Our adjusted EBITDA was $2.4 billion for the third quarter and $9.8 billion for the 12 months ended September 30, 2024. As of that date, our consolidated leverage ratio is 3.0x on a net basis when adjusted for the partial equity treatment of our hybrids and reduced by the partnership's unrestricted cash on hand. Our leverage target range remains 2.75 to 3.25, and at 3.0x, we're in the middle of that range. Libby, with that, we can open it up for questions.

Thank you, Randy. Operator, we are ready to open the call for questions.

Our first question comes from the line of Theresa Chen of Barclays. Your question, please, Theresa.

Good morning. I wanted to follow up on Jim's comments about the data center and power demand theme. Just how do you see Enterprise participating in this? And if you have any color details on commercial discussions to date.

Hi, Theresa, this is Natalie. As Jim said, we've been inundated with data center demand from infrastructure players that have likely exceeded the Bcf a day of demand in the next several years. Let me explain a couple of different aspects. Some of them have shared with us that they are no longer bringing power to data centers; rather, data centers are going to power sources. As you know, we've got several pipelines in the Dallas, Fort Worth area, and San Antonio. A couple of facts that I think you would be interested in: if you think about it, the Dallas area data centers ranked fourth in power today but are second in the most planned power. San Antonio is even more impressive. It's 17th in power but ninth in most planned power. So, if you think about it that way, there are some regions that are probably losing market share to San Antonio and Dallas, and we stand in a good position to be able to serve those centers.

Thank you. And then related to the recent Piñon acquisition, can you provide some details on how you plan to integrate it across your NGL assets and the ability you have to roll out treating services beyond the immediate to midstream acreage and just the long-term value creation you see from these assets, please?

Natalie, you're still up.

Yes. You can think of it this way: we won't treat Piñon any differently than our integrated GMP assets. There won't be many treating deals behind Piñon that don't come with processing deals to serve the integrated value chain.

So it leads to more organic growth through processing.

Yes.

Thank you.

Thank you. Our next question comes from the line of Jean Ann Salisbury of BofA. Your question, please, Jean.

Hi, good morning. Ethane storage is full. There's no new demand until your and ET's export facilities come online next year. Can you kind of talk about how you see this resolving? Do you see a big step down in ethane recovery? Would that change your growth rate in the next few quarters, and is there a positive offset to that for Enterprise in your portfolio?

Hi, Jean. This is Tug Hanley. Yes, as far as recoveries and rejection, that will balance the market. Regionally, there are other places other than the Permian Basin where the gas base does not make sense to recover necessarily or transport to market. As far as opportunities for us, it’s going to lead to some positive storage opportunities in collecting contango.

Okay. That makes sense. And then my follow-up is about the TW Product slide. Is this the final state of the TW Products System? I think you said in the release that it's 20,000 barrels a day of truck loading capacity in Utah. Can the pipe do more than that if you add truck loading capacity, or should we think about this as being the end state of the system?

Hey, Jean Ann, it's Justin. No, we have more capability to add truck capacity. In fact, we're doing that right now in our Permian terminal because our terminal is full. So, as we identify additional demand and our demand further up the system continues to ramp, we'll look for those deep bottlenecking opportunities to take advantage of it.

Okay, great. Very clear. I'll leave it there. Thanks.

Thank you. Our next question comes from the line of Spiro Dounis of Citi. Your question, please, Spiro.

Thanks, Operator. Good morning, everybody. I wanted to go back to Piñon really quickly. Maybe can you just walk us through your decision to buy versus build there. Just curious if that was in any way reflective of some sort of bottleneck on the treating side in the basin.

I guess I'll start, Natalie. First of all, if we had built Greenfield, we were looking at 3 years, if I'm not mistaken. We've missed some opportunities because we didn't have this service. So we needed the platform, and it was the easiest, quickest way to get it.

Yes, that's good.

Does that answer it, Spiro?

It does. I appreciate that. Second question, just maybe sticking with New Mexico. I guess last week there were some news headlines just around a new setback rule that could come into play. I know this pops up from time to time, and it sounds like at least for now there's not much to do around it. But just curious to get your view on the potential impact if something like that comes into play.

I didn't hear the question, Anthony. Did you …

Setbacks in New Mexico.

Yes, there have been setbacks in New Mexico. I'll share my thoughts first, and then Natalie can add to it. I believe the industry remains strong, and as I've always said, once we know the rules, we'll adapt accordingly. Natalie, I haven't heard anyone mention taking action beyond studying these rules. From the meetings I've attended, it hasn't impacted people's plans so far. It's important to remember that we drill horizontal laterals that can extend 3 or 4 miles. From a fundamental perspective, I'm confident the industry will adjust once the rules are clear. Are you hearing anything different?

Nothing different. I think it's too early to speculate on what impacts it will have, and it’s more than just commentary from a few New Mexico producers.

Great. I appreciate the color. Leave it there. Thanks, team.

Thank you. Our next question comes from the line of Jeremy Tonet of JPMorgan. Your question, please, Jeremy.

Hi, good morning.

Good morning.

Just wanted to touch base with Tony here on, I guess, more on the macro outlook and the producer-customer conversations, as well as what the macro team sees as far as production trends at this point in time, given the volatility we've seen in commodity prices.

Yes, this is Tony. I'll start. We've been publishing forecasts for some time, and this is likely the second or third occasion we've updated midyear. This is in response to the data we are observing in both traditional metrics and new targets in gassier areas. Regarding the EIA numbers, I realize that they can be difficult to rely on. Although they are making efforts to improve, progress has been slow. In the Permian Basin, we have noted significant variability due to weather impacts in the Bakken and Gulf of Mexico. Therefore, let's concentrate on the stable factors that substantially affect the figures, particularly in the Permian Basin. We indicated that over a three-year horizon, focusing solely on black oil, we anticipate an increase of roughly 1.5 million barrels per day. For 2023, we are projecting around 750,000 barrels, and for 2024, we expect between 350,000 to 400,000 barrels, with a notable concentration of this growth expected in the latter half of the year. We believe the Permian will achieve the target of approximately 1.5 million barrels by 2025. It is worth mentioning that our forecast reflects a significant change concerning the commitments that producers are making to gassier basins. Natalie, I'll hand it over to you from here.

I agree. I think we often see it in our production plans from our producers. Their PDP isn't coming off as expected, or let's just say some of the B plans are holding a little longer. However, generally gassier, even if they miss it by just a small margin, we've seen that happen time and time again. It’s not large numbers, but definitely something to keep an eye on.

Got it. That's helpful there. Thank you for that. And maybe shifting gears a little bit here with Bahia. It looks like the timeline shifted a little bit there, so just wondering if you could update us on project development there and also your current thoughts on Permian NGL pipeline egress. How do you see that shift?

Hey Jeremy, this is Justin. We are experiencing minor delays in our expected timeline for the permit to construct, which has pushed things from the first half of the year into the third quarter. Regarding commercial development, as you noticed in our latest presentation, Tony's updated NGL forecast shows a significantly different outlook for industry utilization. By 2028, we now expect overall industry utilization to exceed 90%. We are still following the same strategy we discussed earlier for our commercial development, but it ultimately depends on how the additional supply is contracted, whether through additional GMP assets that Natalie mentioned or by pursuing third-party NGLs.

Got it. That's helpful. Thank you.

Thank you. Our next question comes from the line of Michael Blum of Wells Fargo. Your line is open, Michael.

Thanks. Good morning, everyone. I wanted to ask about the announcement yesterday on the CO2 pipeline project with Oxy. Can you confirm this is new pipe, you're not repurposing, and get a sense for how many miles of pipe are we talking about, and do we expect to get your typical midstream contract structure and typical midstream return on a project like this?

Good morning, Michael. This is Bob Sanders. The contract with 1.5 is a fairly straightforward transportation agreement. When 1.5 goes to FID, they will tell us what emitters to connect to so we know what to design for. It is new pipe because it is ANSI 900 pipe. It's a high-pressure pipeline system. We expect 1.5 to reach FID sometime in the first half of 2025, and at that point, we'll know the capital requirements, and the fee will be set accordingly.

Great. Thanks for that. And then I just wanted to ask about LPG export dock spot rate dynamics. The rates have increased in recent months. I wanted to get a sense of how full your docks are from that perspective, and are you able to capture any of these higher spot rates, or are you basically fully contracted?

Yes, this is Tug. So, we've mentioned in prior earnings calls that we did a debottlenecking project at the ship channel, providing us with higher capacity. Currently, we have anywhere between 2 to 3 spot cargos per month, and we are capturing those higher values, averaging mid $0.20 per gallon.

Great. Thank you.

Thank you. Our next question comes from the line of Neal Dingmann of Truist. Please go ahead, Neil.

Good morning. Thanks for the time. My first question is on your petrochemical results specifically. Are you all continuing to expand the ethylene and propylene systems? I'm just wondering, do you continue to believe more export capacity will be needed there?

Hey, Neal, it's Chris D'Anna. We are continuing to grow, particularly our ethylene pipeline system. If you remember, that pipeline system didn't exist before 2019. We've built a substantial system and plan to continue that growth. In terms of our exports, we have an expansion underway at our Morgan's Point dock, and the first phase will be online at the end of this year.

Chris, perfect.

Let’s talk for a moment about what you’re seeing in Europe and the opportunities that presents for us.

Yes, I think one of the growth opportunities that we see for ethylene exports, in particular, is Europe. With the economics that those crackers have, one, they're quite a bit smaller, so they don't have the economies of scale that we have here in the U.S. And secondly, just the overall feedstock dynamics, it’s ethane versus naphtha, or natural gas versus crude, creates different fundamentals. Therefore we expect to see, and we've heard from many chemical companies, that they're doing strategic reviews of their European assets. Thus we expect to see some closures, leading to additional ethylene exports directed that way.

Great details. Thank you.

Thank you. Our next question comes from the line of Keith Stanley of Wolfe Research. Your question, please, Keith.

Hi. Thank you. Good morning. First, just curious for an update on commercial conversations on the spot project. I think there was a quote a week or two ago from a conference about trying to get a first customer to sign up for that project. Just an update on any momentum you're having there.

You want to take that, Jay?

Hey, Keith. This is Jay Bany. Yes, related to commercial conversations, they're quite extensive and in various degrees of development, ranging anywhere from we’re working through definitive agreements, to changing term sheets. I'd say a large portion of our customer base is currently evaluating the cost inefficiencies related to ship-to-ship transfers and how that affects their business, both their revenues as American producers or ultimately the delivered price for international customers. Therefore, we expect to receive some of that feedback by the end of this quarter or early first quarter.

Thanks for that. Second question, I'm admittedly not sure this is a great answer to this necessarily, but the valuation gap between the C-Corps in the space and the MLPs is at a record high above anything I can recall. Are there any potential ways the company could capitalize on that? I don't know if it's selling assets at higher valuations or other ways to respond to the market seemingly valuing C-Corps much more highly than MLPs these days.

Hey, Keith, this is Randy. I don't think there's any quick solution or answer there. I think trying to play the game of selling assets at a higher valuation is somewhat short-sighted, especially considering the depreciation recapture that comes, which ultimately gets pushed down to all your limited partners. All it becomes is a tax event for your limited partners, and I'm unsure what you actually accomplish. We've seen this before, a couple of years ago, when the two compressed, as there's generally been a significant difference in these asset classes, and typically the market resolves it one way or another.

Thank you. Our next question comes from the line of John McKay of Goldman Sachs. Please go ahead, John.

Hey all. Thanks for the time. I just want to clarify, Rand, is the up-fee idea still being considered? Is there any reason you guys have permanently put that to the side at this point?

I appreciate the thought there. I believe this is another case where the details matter. First, you would have two securities outstanding, which means you'd need to establish liquidity for the second security. Then, you'd need to consider how to use the proceeds. In my review over time, I haven't seen any significant differences, whether it was the institutional class units of a partnership that catered more to institutional investors or the underlying MLP. To us, this introduces a lot of complexity without offering substantial benefits.

That's clear. I appreciate that. Second quick follow-up. I appreciate the comments and all the work done on the PDHs. I just want to clarify, are both plants fully operational now? Is this a fourth quarter run rate going forward? Is this projected for first quarter '25? If you could also remind us what those two assets could add to cash flow on an ongoing basis, that'd be great.

They're up and running, both of them, operating at full rates if not higher. And Chris, I'd estimate it to be in the neighborhood of $200 million.

That's right.

That's clear. Congrats on getting that done, and thanks for the time.

Thank you. Our next question comes from the line of AJ O'Donnell of TPH. Your question, please, AJ.

Hey, good morning. Thanks for taking my question. Just a quick one on Matterhorn, with that pipeline now running about a Bcf, or over a Bcf a day. Curious if you guys have seen a jump in flush production into your system in Q4, or if the majority of the pipeline volumes are just flows shifting around the basin or redirected gas.

I don't think we've seen a flush production yet, have we, Natalie?

Yes.

Okay. Maybe just going back to the capital budget then, just trying to understand the increase in the '25 budget. I was hoping you could provide a bit more information on the types of projects you're seeing with Piñon. I'm just curious if there's any more of that to potentially be announced in the '25 budget, or does that seem a little bit further off?

I believe you'll see Piñon projects next year.

Yes. We'll do our job as well.

Natalie says yes.

Okay. Thanks, guys.

Thank you. Our next question comes from the line of Manav Gupta of UBS. Your question please, Manav.

Hi, good morning. You guys did a very good job of explaining some of the 2025 growth projects. Help us understand the product pipeline is pretty strong, whether it's Mentone West 2, or Neches River. How should we think about the key growth projects for 2026 at this stage?

Yes, Manav, thanks for the question. I think we're still at the point where, and we try to point this out in our supplemental slides for earnings, and you come in and you look at the projects that have been FID'd. I want to say that the runoff in 2026, what we have remaining to spend on currently FID projects is probably about $1 billion, $1.2 billion. If you would, in 2026 we have room that we put in there that we think will probably be in the range of $2 billion, maybe upward to $2.5 billion, but we have room for the development of other growth-oriented projects between now and then. We think 2024 and 2025 will be a period of elevated CapEx, which will revert back to a longer-term basis of around $2 billion to $2.5 billion.

Perfect. Thank you.

And you saw this, and again, I'll come back in, I'm sorry. You sort of saw the same thing in 2018 and 2019. In those years, we were about $4 billion in growth CapEx, again, with some large projects and step changes in capacity. Then you saw our growth CapEx moderate back down, and we think the same thing will happen once you get out to 2026.

Perfect. My quick follow-up is there was a little bit of a step-up in buybacks in 3Q versus 2Q. Again, as you're going through this build-out, how should we think about shareholder returns for the rest of 2024 or even 2025?

I think, again, with 2024 and 2025 CapEx at elevated levels, you'll probably continue to see buybacks in the $200 million to $300 million range. Once we get out to 2026, we'll need to reassess what the opportunities are at that time, and go from there.

Thank you. I would now like to turn the conference back to Libby Strait for closing remarks. Madam?

Thank you, and thank you to our participants for joining us today. That concludes our remarks. Have a good day.

This concludes today's conference call. Thank you for participating. You may now disconnect.