The corporations on our annual list of the world's 500 largest companies combined to generate $41.7 trillion in revenue over the past year.

Fortune Global 500

Almost $20 trillion in revenue—and a record-breaking $1.87 trillion in profits. Introducing the 2025 Fortune 500, the definitive list of the biggest companies in America.

Fortune 500

The corporations on our annual list posted aggregate revenues of $41 trillion for the second year in a row.

Industries included in the sector are mining, oil and gas exploration and services, pipelines, refining, and utilities.

Fortune Sector Leaders: Energy

The Fortune 500, in its 70th year in 2024, ranks the biggest U.S. companies by revenue.

The corporations on our annual list of the world’s largest companies delivered a record $41 trillion in aggregate revenues.

The Fortune 500, in its 69th year in 2023, ranks the biggest U.S. companies by revenue.

F500-2023-072-Enterprise Products Partners

The oil and gas pipeline and transportation production company jumped 17 places on this year’s list as Russia’s 2022 invasion of Ukraine created an energy shortage that boosted demand in the sector. 
<ul> 
 	<li>The company was the most profitable pipeline firm on this year’s Fortune 500, bringing in $5.5 billion in profits in 2022, up 18% from the year prior.</li> 
 	<li>The company’s $58 billion in revenue represented a staggering 43% increase from 2021, as oil prices rose significantly in 2022.</li> 
 	<li>In February 2022, one of the company’s affiliates acquired Navitas Midstream for $3.25 billion, marking an expansion into natural gas processing.</li> 
</ul>

Aggregate sales hit $37.8 trillion last year—an increase of 19%, the highest annual growth rate in the list’s history.

This year’s Fortune 500 marks the 68th running of the list.

F500-2022-089-Enterprise Products Parner

Houston-based Enterprise Products provides midstream energy services—think processing, transportation, and storage—of natural gas, natural gas liquids, crude oil, and refined petroleum products. In 2021, the company posted 50% year-over-year revenue growth, jumping 16 spots on the Fortune 500 list. In April 2022 Enterprise Products Operating, a subsidiary of the company, announced that it would work toward a carbon dioxide and sequestration solution for the Texas Gulf Coast, a potential tool for fighting CO2 emissions and climate change.

Total revenue for the world’s biggest companies fell 4.8% to $31.7 trillion this year—the first decline in half a decade.

The crude oil and natural gas company is one of the largest in the U.S., with over 51,000 miles of pipelines spread out across the country.

This year’s Fortune 500 marks the 67th running of the list.

This year's Fortune Global 500 generated $33.3 trillion in revenues and $2.1 trillion in profits.

G500-Featured Image-Logo-2020

One of the largest midstream oil and gas companies in North America, Enterprise's energy services include natural gas gathering, crude oil gathering, and treating, processing, storage, and transportation of those products.

This year's Fortune 500 marks the 66th running of the list.

F500-2020-101-Enterprise-Product-Partners

Enterprise's energy services include natural gas gathering, crude oil gathering, and treating, processing, storage, and transportation of those products.

This year's Fortune Global 500 generated $27.7 trillion in revenues and $1.5 trillion in profits.

This year's Fortune 500 marks the 65th running of the list.

This year's Fortune 500 marks the 64th running of the list.

This year's Fortune 500 marks the 63rd running of the list.

This year's Fortune Global 500 generated $27.6 trillion in revenues and $1.5 trillion in profits.

This year's Fortune 500 marks the 62nd running of the list.

The world's 500 largest companies generated $31.2 trillion in revenues and $1.7 trillion in profits in 2014. Together, this year's Fortune Global 500 employ 65 million people worldwide and are represented by 36 countries.

This year's Fortune 500 marks the 61st running of the list. Wal-Mart claims the top spot again. See who made the list.

World's Most Admired Companies

Global business is back. After limping through a worldwide financial crisis and economic slowdown, the 500 largest companies ranked by revenues shattered all sorts of performance records in 2013: They racked up combined revenues of $31.1 trillion, up 2.5% from 2012, and profits soared 27% to nearly $2 trillion. China’s 95 companies (up from 89 last year) posted $5.8 trillion in revenues. The U.S. has four fewer companies on the list than last year but remains (for now) the country leader, with 128 corporations on the list—including No. 1 Wal-Mart Stores—reporting $8.6 trillion in revenues. 

Wal-Mart stayed on top as its sales crept closer to half-a-trillion dollars. Apple moved into the top five. And UnitedHealth Group continued its steady climb. 

Key Financials (last Fiscal Year)

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Total Stockholder Equity ($M)

Profit Ratios

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Profits as % of Assets

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Earnings Per Share (last Fiscal Year)

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Enterprise Products Partners processes, transports, stores, and ships oil and natural gas products across the United States. Enterprise is a "midstream” energy company, meaning it connects the producers of oil and gas with distributors and retailers. The company oversees about 50,000 miles of pipelines, most originating in Louisiana and Texas. It also owns shipping docks and storage facilities for the export of oil and gas products, and natural gas processing facilities. Founded in 1965, Enterprise Products is based in Houston.

Q3 2025

Q2 2025

Q1 2025

Q4 2024

Enterprise Products Partners (EPD): Company Profile, Stock Price, News, Rankings

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Enterprise Products Partners

enterprise products partners

Thank you for standing by and welcome to Enterprise Products Partners L.P.'s third quarter 2025 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. To ask a question during the session, you will need to press star 11 on your telephone. To remove yourself from the queue, you may press star 11 again. I would now like to hand the call over to Libby Strait, Vice President of Investor Relations. Please go ahead.

Good morning and welcome to the Enterprise Products Partners conference call to discuss third quarter 2025 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.

Thank you, Libby. Good morning. Before we dive into our third quarter results, I want to take a moment to recognize the upcoming retirement of Tony Chovanec. Tony's been more than a colleague. He's been a dear friend and a guiding force at Enterprise for nearly two decades. His leadership in building our fundamentals and supply appraisals helped steer Enterprise through the shale revolution and set the standard across the industry. We wish him all the best in the next chapter and thank him for his invaluable contributions. Tony will be with us through the start of next year, but we wanted to make sure we had an opportunity to congratulate him on an incredible career on this call.

Those kind words and to all y'all here around the table, I really appreciate y'all people on the call, the analyst community, our producers, our customers around the world. I'm forever grateful for the interest and respect that you've always shown for in our fundamentals and our supply pressure work. Sincerely, Jim, I want to thank you for years ago when we sat down at your table recognizing early on that we had something that we now know as the Shale revolution and as you put it, you had a bunch of reports on the table in front of you and you told me something's different this time and giving me the chance to establish a fundamentals team that I've been so honored and frankly humbled to be part of.

I guess last but not least, Corey Johnson, the data science team, what y'all have taught me over the last four years I'll take with me the rest of my life. Thanks to everyone.

I'm about to cry, Tony. Matter results today, we reported adjusted EBITDA of $2.4 billion for the third quarter, generating $1.8 billion of distributable cash flow, providing 1.5x coverage. Additionally, we retained $635 million of DCF. When I look at the third quarter results, I'm reminded of the long-anticipated projects we're commissioning in the fourth quarter. Third quarter results were lighter than expected, but far from discouraging as we look ahead to year end and into 2026. After a three-month delay, Frac 14 is now in service and will contribute to our results going forward. The Bahia Pipeline and Seminole Pipeline Conversion will come online in tandem, adding capacity to our NGL pipeline system and returning capacity and flexibility to our crude oil pipelines.

We originally planned for these projects to be completed around mid-year, but we look forward to completing them in the remaining months of 2025 and what they'll deliver. Our PDH plants are looking up, with PDH 1 averaging 95% of nameplate and PDH 2 showing similar promise as it resumes operations following a third quarter turnaround to address coking in the fourth reactor, an issue the technology licensor has committed at the highest levels to resolve. If you add all that up, I see a lot of upside that was pushed out of the third quarter. As you know, our petrochemical facilities at Mont Belvieu face their share of opportunities and challenges. Enterprise is built on engineering and operational excellence, and Randy and I couldn't be more proud of the incredible work our petrochemicals teams have done to bring these assets up to our standard.

We've never been more confident in the team we have in place today. With the Neches River Terminal set to be completed next year, we're nearing the end of a multi-year, multi-billion dollar capital deployment cycle that began in 2022. These strategic investments, including pipelines, marine terminals, and key acquisitions, put us in a great position to capitalize on long-term growth from the Haynesville and Permian basins. Finally, I'm sure Randy's going to hit this, but I kind of enjoy stealing his thunder from time to time to say this morning we announced a $3 billion increase to our buyback program, taking it from $2 billion to $5 billion. While we see plenty of opportunities to efficiently expand our footprint in the future, we are also well positioned to continue our strong track record of returning capital to our unitholders.

Growing distributions will continue to be our primary focus, but this expanded program enhances our flexibility to grow buybacks alongside rising free cash flow. We're excited about the next chapter, not just in the years ahead, but in the decades to come. With that, I'll turn it over to Randy.

Thank you, Jim, and good morning everyone. Starting off with the income statement, net income attributable to common unitholders was $1.3 billion, or $0.61 per common unit on a fully diluted basis for the third quarter of 2025. Adjusted cash flow from operations, which is cash flow from operating activities before changes in working capital, was $2.1 billion for the third quarter of 2025. We declared a distribution of $0.545 per common unit for the third quarter 2025, which is a 3.8% increase over the distribution declared for the third quarter of 2024. The distribution will be paid November 14th to common unitholders of record as of the close of business October 31st. In the third quarter, the partnership purchased approximately 2.5 million common units under its buyback program for $80 million.

Total repurchases for the first nine months of 2025 were $250 million, or approximately 8 million Enterprise common units, bringing total purchases under our buyback program to approximately $1.4 billion. In addition to buybacks, our distribution reinvestment plan and employee unit purchase plan purchased a combined 3.5 million common units on the open market for $114 million during the first nine months of 2025, including 1.2 million common units on the open market for $37 million in the third quarter. For the twelve months ending September 30th, 2025, Enterprise paid out approximately $4.7 billion in distributions to limited partners combined with the $313 million of common unit repurchases over the same period, Enterprise return total capital was $5 billion, resulting in a payout ratio of adjusted cash flow from operations of 58%.

As Jim mentioned earlier, we expect an inflation inflection point in discretionary free cash flow in 2026 as we have completed a four year period of large investments, both organic and acquisitions, that have enhanced and expanded our integrated footprint in the Permian and Haynesville Basins and our premier wellhead to market businesses serving domestic as well as international markets via our marine terminals. With the completion of the major projects such as Bahia NGL pipeline and Neches River Terminal, we continue to believe our organic growth capital expenditures in the near term will return to our mid cycle range of approximately $2 billion-$2.5 billion per year and largely consist of pipeline expansions and smaller projects both on the supply and demand side and natural gas storage, treating and processing facilities.

As Jim noted earlier, we announced our board has approved an increase in our common unit program of $5 billion. The program now has $3.6 billion in capacity, allowing us to increase the amount of our annual buybacks as our free cash flow increases. In terms of allocation of capital, we see cash distributions to partners growing commensurate with distributable cash flow per unit in the near term, with discretionary free cash flow being evenly split between buybacks and retiring debt. Growth in cash distributions to partners can be further enhanced by the percent of common units we retire through buybacks. Total capital investments were $2 billion in the third quarter of 2025, which included $1.2 billion for growth capital projects, $583 million for the acquisition of natural gas gathering systems from Occidental in the Midland Basin, and $198 million of sustaining capital expenditures.

Our expected range of growth capital expenditures for 2025 and 2026 remains unchanged at approximately $4.5 billion for 2025 and $2.2 billion-$2.5 billion for 2026. We continue to expect 2025 sustaining capital expenditures to be approximately $525 million. Our total debt principal outstanding was approximately $33.9 billion as of September 30, 2025. Assuming the final maturity date of our hybrids, the weighted average life of our debt portfolio is approximately 17 years. Our weighted average cost of debt was 4.7% and approximately 96% of our debt was fixed rate. At September 30th, we had consolidated liquidity of $3.6 billion, which includes availability under our credit facility and unrestricted cash on hand. Our adjusted EBITDA was $2.4 billion for the third quarter and $9.9 billion for the last 12 months.

As of September 30th, our consolidated leverage ratio is 3.3x on a net basis after adjusting debt for the partial equity, treated the hybrid debt and reduced by the partnership's unrestricted cash on hand. This is above our leverage target of 3.3x plus or minus a quarter, or a range of 2.75x-3.25x. This is due to the capital expenditures on our large projects such as Frac 14, Bahia NGL Pipeline, Neches River Terminal, and the acquisition of Occidental's Midland gathering system being included in our debt balance. Without EBITDA included in our trailing 12 months of EBITDA, we believe our leverage will return to our target range by year end 2026 when we have a full year of EBITDA from these projects. With that, Libby, we can open it up for questions.

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

As a reminder to ask a question, you will need to press Star 11 on your telephone to remove yourself from the queue. Please press Star 11 again. Please limit yourself to one question and one follow-up or two questions to allow everyone the opportunity to participate. Please stand by while we compile the Q&A roster. Our first question comes from the line of Jean Ann Salisbury of BofA. Please go ahead, Jean.

Good morning. There are lots of Permian gas pipelines coming on next year in the basin. Do you think that that's going to drive producers to produce more gas at the margin? Do you consider that to be a constraint?

You know the Permian Basin, Jean Ann is an oil basin first and foremost and it will be forevermore. I think the thing that more gas pipelines does do is just add NGLs transportation takeaway for both NGLs and natural gas. At the end of the day, I'll say it's healthy for the producers, meaning.

That's kind of the bottom line. That's how we see it. Jean,

I think I have one more for you, Tony. I think I know what you're going to say, but as LPG exports ramp, I've gotten this question a lot from people. Do you see Asia, rescom and petchem demand as sort of an unlimited sink for all that LPG, or is there going to potentially require extreme price pressure on global propane to make it flow?

You know, Jean, I'm going to punt that one to Tug because he travels the world, he and his team, if that's okay. Tug, can I do that?

Yeah, this is Tug. In short, I would say both. Rescom demand is growing internationally and petrochemical due to lightening of the petrochemical feed slate. The growth is really tied to supply. The U.S. will export what's needed to balance the market, and price will ultimately adjust upon that global demand. We're not necessarily worried about demand.

This is Jim. I've got a fundamental that I always believed in. Price creates supply, and price creates demand. We're not going to have an issue with demand.

Hey Jean, that makes sense. Jean, while you're still online, I guess I sort of have one for you. You and I have always been in the industry sort of obsessed with this molecule called ethane as you and we haven't always been on the same side of the ledger relative to this molecule, which now again just looking back has become very important and will become more important. I remember in 2018 at our analyst meeting I was on crutches and we were at the Museum of Natural Science and sitting there on the sidelines and you came and sat down next to me and you said I want to sit next to the only methane bear besides myself in the industry. You remember that?

What I'd like to say is we're approaching a million barrels a day of exports for ethane. You know, that's a line of sight that the industry can see and we still have it. Just like we talked that day, we still have 600,000-800,000 barrels a day that's being rejected.

Tony, thank you for all of your help and time over the years. I'm really going to miss working with you.

Thank you. Our next question comes from the line of Theresa Chen of Barclays. Your line is open.

I'd also like to congratulate Tony on his retirement and thank him for his insights and help over the many years. We wish you the best, Tony.

Going to the capital allocation side of things on the upside buyback authorization, would you talk about or just provide more details on the capital allocation outlook for the next couple of years? What do you see at this point as a steady state run rate for CapEx, and do you expect to buy back stock on a more ratable basis given the visibility in free cash flow growth, or will it be more opportunistic and dependent on market dynamics?

Theresa, this is Randy. Yeah, I think when we come in and think about sort of as you put over the near term, the next two or three years on organic growth CapEx, we do see it in the $2 billion-$2.5 billion range. With the projects that we currently have announced and with a few that we've got pretty good visibility on that we think will come forward, that's included in expectations next year. We see really $2.2 billion-$2.5 billion. Could next year get to $2.6 billion-$2.7 billion? It could, but we don't see it going to $3 billion. I think that's sort of where we are on the CapEx side. As a result, given those numbers, we'll have some free cash flow to deploy. At this point, looking to split it between buybacks and debt pay down.

I think because we're leaning in a little bit more on buybacks than what we've done over the last two or three years, there could be an element of programmatic buybacks in there as well. With the component of debt pay down that we have in there as well, that gives us a little bit more flexibility to be opportunistic. I see the buybacks having a component of both programmatic and opportunistic.

Understood, thank you. With Dyno's announced plans yesterday to potentially move up to 150,000 bpd of refined products, primarily from its own refineries, from PADD 4 to PADD 5, could this lead to better utilization and/or marketing opportunities on your Texas Western product system that recently went into service and ramped? How do you see this evolving?

Yeah, Theresa, this is Justin. Clearly, a lot of headlines out there with respect to people reacting to the ongoing closures and potential future closures in California. Two points to make. There's a lot to unpack with respect to the projects out there, whether or not they go or not, and also what the future closures or potential closures in California will be. We'll hang our hat on two things with respect to the system. One is we run a unique corridor pretty much direct to Salt Lake. To the extent that Salt Lake gets net shorter as a result of these projects, we're going to stand to be the beneficiary. If you zoom out to our overall product system, both our TW system and our legacy TE system benefit from Mid Continent pricing being at a premium to the Gulf.

Really, all three of these projects that have been announced do some degree of that. Our overall product system will benefit if any of them go. Again, early days, so we'll just have to see how it plays out.

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

Thanks. Good morning. I also wanted to wish congratulations to Tony. We really enjoyed working with you. Congrats.

Macro question, I guess. You're signaling here an inflection point. You've completed a big capital build-out phase and now you're kind of pivoting to some more cash, cash return to shareholders. How much of this is just your view that the macro is less constructive? Oil prices lower, drilling slowing, etc. Is it just a function that you think your system is built out, you're still expecting that growth but you just have ample capacity?

Yeah, Michael, I think it's just a function of large projects. I come back in and if you look at, if you just look at our history, we have had some large capital intensive projects that we put into service and again our CapEx has flexed up and then it's come back into a sort of a normal mid-cycle range and I think that's where we are.

Probably the most recent cycle of that was in 2015, 2016, where we built the Morgan's Point ethane export facility. We built the Aegis Ethane Pipeline running over to South Louisiana and then we built the Midland ECHO 1 system. That was a period of elevated CapEx. We came back down into sort of a $2.5 billion range until we saw the next large capital project. I think it's more of a function that as opposed to a change in our macro view of the economy.

On the buyback, wanted to ask how you're going to basically balance.

The potential increase in buybacks with any tax ramifications for your unitholders, and does that create any kind of limit to the amount of buybacks you can do in any given year because of taxes?

Really, the tax ramifications are really for those selling unitholders, not for the unitholders that remain.

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

Hey, good morning everyone. Thank you for the time, Tony. I'm going to make sure we get a few last ones out of you while we still have you. Thank you again.

We haven't really talked about the broader macro that much. The last question kind of touched on it. I'd love just to hear you guys were a little ahead of the curve on being a little cautious earlier this year. I'd love just to hear a little kind of mark to market on what they're thinking now and what you're hearing from your Permian producer customers.

Yeah, I think, Natalie, tell us what you're seeing on our systems would be the best way to start.

Hey, Michael, this is Natalie Gayden. I would say in Midland volumes are outperforming our expectations. I think the last time I sat on this call I gave some well connects just for color. Well connects in 2026 are up 25% from what I told you last time. We're now expecting almost over 600 wells to be connected to the system next year. A lot of that is fourth quarter surge from the original 500 in the Delaware. Same growth trajectory. We've got a record number of wells being connected to the low pressure system we've built up in the northern Delaware. That growth curve is steepening for Delaware and that trajectory remains intact and increasingly constructive. Lastly, I'll say this, and I may say it more than once, we don't talk about base volume durability and PDP and how it holds in on gas.

I think that sometimes what people miss and I'll just give you an example. We have a producer in Midland that finished their development program a year ago. Today in Midland those volumes are flat with where they were then. In some part of the PDP and the base volume and durability of that volume, I think that's just upside down.

Jay, you got anything on crude oil or Justin on NGLs?

Yeah, this is Jay on crude. My story is similar to Natalie. Again, we don't have the same large footprint. We're probably more heavily weighted to Midland Basin. From 2024 averages to 2025, we saw well above a double-digit gain in gathering, and we're seeing at least based on producer curves for 2026, something very similar.

Yeah, I mean, we've mentioned it. Seminole comes up at the beginning of next year. We do have some space as that pipeline ramps up. Over the course of 2026, we become very well contracted over the year.

The PDP wedge is the most underappreciated thing in the industry, particularly when you're a midstream company. That's the reality, and we see it time and time again.

That's absolutely clear. I appreciate all that color. Second one from me is.

Little bit about some of these projects coming on maybe a little later than hoped. Could you just give us a general target, you know, $6 billion of projects coming on between now and, you know, next couple quarters. When would you expect those all generally all SQL to be fully ramped?

What was the question? I think you asked when did these projects, when would we expect them to be fully ramped? That I referred to in my—yeah, I think what I said was Bahia will be on at end of November, 1st December. Justin, okay, Frac 14 is up and running. PDH 2 was in the process of.

Yeah, this is Tug. NRT will be, it's ramping right now. It'll be full, call it by the middle of next year, the first train, and then the second train comes online shortly after that. That'll be our LPG ethane flex train, and we'll have long-term LPG contracts commenced once that train starts as well.

Are you fully contracted on ethane and LPG?

We're around 90% contracted on LPG, and we are fully contracted on that thing for term.

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

Enterprise Products Partners (EPD) Q3 2025 Earnings Call Transcript

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