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Headquartered in Tulsa, Oneok specializes in the gathering, processing, and transportation of the natural gas and liquids that help fuel the nation’s industry.

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Tulsa's Oneok (pronounced "one-oak") is an Oklahoma energy company that gathers, stores, and delivers natural gas from across the U.S. Its fortunes closely tied to the global price of crude oil, the company fell 57 spots on this year's <em>Fortune</em> 500.

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Oneok is a leading U.S. midstream energy company that provides gathering, processing, fractionation, transportation, storage, and marine export services for natural gas, natural gas liquids, refined products, and crude oil. The company operates through four main segments: natural gas gathering and processing, natural gas liquids (such as ethane, propane, and butane), natural gas pipelines, and refined products and crude, serving a broad range of energy producers and end users. Founded in 1906 as the Oklahoma Natural Gas Co., Oneok has evolved from a regional utility to a diversified energy infrastructure leader, notably expanding its portfolio through major acquisitions, such as Magellan Midstream in 2023, which added significant crude oil and refined products assets, and, more recently, EnLink Midstream. Oneok has a pipeline network spanning approximately 60,000 miles.

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Oneok (OKE): Company Profile, Stock Price, News, Rankings

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Oneok

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Ladies and gentlemen, please stand by. We are about to begin. Good morning, and welcome to ONEOK's second quarter 2026 earnings call. As a reminder, this call is being recorded. If you would like to participate in a question-and-answer session following the speaker's ongoing remarks, simply press star one on your telephone keypad. At this time, I would like to turn the conference over to Megan Patterson, Vice President, Investor Relations. Megan, please go ahead.

Thank you, Jess. Welcome to ONEOK's second quarter 2026 earnings call. We issued our earnings release and presentation after the markets closed yesterday, and those materials are available on our website. After our prepared remarks, management will be available to take your questions. Statements made during this call that might include ONEOK's expectations or predictions should be considered forward-looking statements and are covered by the safe harbor provision of the Securities Acts of 1933 and 1934. Actual results could differ materially from those projected in forward-looking statements. For a discussion of factors that could cause actual results to differ, please refer to our SEC filings. With that, I'll turn the call over to Pierce Norton, President and Chief Executive Officer.

Thank you, Megan. Good morning, everyone, and thank you for joining us today. Joining me on the call are Walt Hulse, our Chief Financial Officer, Randy Lentz, our Chief Operating Officer, and Sheridan Swords, our Chief Commercial Officer. Yesterday, we reported second quarter earnings and raised our 2026 financial guidance for the second time this year, reflecting strong year-to-date performance and continued momentum heading into the back half of the year. Our second quarter results were driven by record NGL throughput volumes, strong refined products demand, and continued volume growth across our systems. The quarter highlighted the positioning of our asset footprint, the value of our integrated platform, and the outstanding execution of our employees. The broader energy backdrop remains constructive, but the more important point for ONEOK is that we're converting that backdrop into visible growth.

Our footprint connects key supply basins with domestic and international demand across natural gas, natural gas liquids, crude oil, and refined products. The connectivity across our business segments gives us multiple ways to grow earnings, optimize existing assets, and allocate capital toward opportunities with attractive returns. Importantly, these opportunities are not confined to a single commodity or region. Our integrated system enables us to create value across multiple demand drivers, a differentiator for ONEOK. Our confidence is reflected in our long-term outlook. We continue to target mid to high single-digit adjusted EBITDA growth over the next five to seven years, supported by three factors that are increasingly visible.

Recently completed and soon-to-be-completed projects drive structural growth spanning Permian Basin processing capacity, Powder River processing capacity, Midcontinent fractionation capacity, refined products expansions, and natural gas transportation and storage capacity and LPG exports. Operating leverage available across our assets, requiring little to no capital investment and allowing us to be flexible to customers' needs and timing. Finally, a growing pipeline of high-return organic projects, bolt-on acquisitions, and commercial optimization are creating additional investment opportunities across our system, where commercial discussions are improving our confidence in timing, scale, and returns. Our long-term strategy remains grounded in the same principles that have gotten us where we are today: operational excellence, financial discipline, and a value-driven approach to capital allocation. With that, I'll turn it over to Walt for a financial update. Walt?

Thank you, Pierce. As Pierce mentioned, our second quarter performance and strengthening outlook across our business supported a second increase to our 2026 financial expectations. We now expect a 2026 net income midpoint of $3.6 billion, a diluted earnings per share midpoint of $5.68, and an adjusted EBITDA midpoint of $8.35 billion. This represents net income and adjusted EBITDA increases of $150 million and $250 million, respectively, compared with our original guidance provided in February. At the segment level, Natural Gas Pipelines and refined products and crude continue to perform toward the upper end of the adjusted EBITDA ranges provided in our original guidance. Natural Gas Liquids and gathering and processing remain well-positioned through the balance of the year.

Across the portfolio, organic volume growth, EBITDA from recently completed projects, and attractive hedging and commercial opportunities are providing momentum in the second half of the year and into 2027. Our 2026 capital expenditure guidance remains unchanged at $2.7 billion-$3.2 billion. We expect capital spending to accelerate through the second half of the year as several major projects move towards completion, bringing us towards the upper end of our CapEx guidance range. Turning to the second quarter results. ONEOK reported net income of $965 million, or $1.53 per diluted share, a 13% increase year-over-year.

Adjusted EBITDA totaled $2.12 billion, up 7%, driven by volume growth and strong segment-level performance. We continue to expect earnings to largely follow the normal seasonal cadence of our business as we move through the remainder of 2026. With the tailwinds I just mentioned supporting second half results, our overall financial position remains strong and continues to provide the flexibility to invest in the business, return capital to our shareholders, and pursue opportunities that create long-term value.

As additional guidance on the application of the One Big Beautiful Bill and the Inflation Reduction Act of 2022 has become available, we've continued to evaluate the impact of the tax legislation, particularly as it relates to acquisitions and bonus depreciation. Based on our latest analysis, we now expect approximately $2.6 billion of cumulative cash tax benefits, compared with the approximately $1.5 billion we previously discussed. These additional benefits, combined with our existing tax attributes, are expected to defer meaningful cash tax payments until 2031, extending our cash tax runway by approximately two years and further enhancing future free cash flow generation. Higher earnings and improved free cash flow also support continued progress towards our long-term leverage target of 3.5x debt to EBITDA. I'll now turn it over to Randy for an operational and large capital projects update.

Thank you, Walt. Our teams continued to execute at a high level throughout the second quarter while maintaining focus on safety, reliability, and customer service. Performance across the system remained strong, supported by increasing customer activity, improving asset utilization, and contributions from recently completed projects. As volumes grow across our footprint, we're seeing the benefits of the connectivity and scale of our assets. We continue to advance project portfolio, and as of August 1st, our Denver area refined products expansion was placed in service. This project adds 35,000 bpd of capacity into one of the fastest-growing markets in our footprint and provides a new direct jet fuel connection to Denver International Airport.

In the Permian Basin, we continue to expand processing capacity to support growing producer activity. Following our recently relocated 150 MMcf/d plant in the Midland Basin, we remain on track to complete 110 MMcf/d of Delaware Basin plant expansion projects during the third quarter. Additionally, based on production outlooks in the basin, we've increased the capacity of our Bighorn Plant to 400 MMcf/d from an initial capacity of 300 MMcf/d. Bighorn remains on schedule for completion in mid 2027. Upon completion, our Permian processing capacity will increase to nearly 2.4 Bcf/d. In addition, along with our initial 60 MMcf/d Cutter Plant in the Powder River Basin, which was previously announced, we've begun construction on another 120 MMcf/d Cutter 2 Plant, which we expect to be online in the first quarter of 2028.

Finally, Phase I of our Medford Fractionation project remains on track for completion during the fourth quarter. Medford Phase I will add 100,000 bpd of Midcontinent Fractionation capacity, with Phase II expected to be completed in the first quarter of 2027. Looking ahead, the projects entering service over the next several quarters are expected to add visible earnings, increase system utilization, and support our long-term growth outlook. With that, I'll turn the call over to Sheridan for a commercial update.

Thank you, Randy. Commercial activity remained strong during the quarter, supported by favorable fundamentals across all four of our business segments. We delivered solid volume growth across our integrated system, driven by increased customer activity, healthy domestic and international demand, and continued production growth in key producing basins. Starting with the Natural Gas Liquid segment. Raw feed throughput volumes increased 7% year-over-year, with growth across all regions. Utilization continued to increase across the system, supported by improved seasonal demand and producer activity.

The Gulf Coast Permian region led performance, increasing 15% year-over-year, driven by increased production volumes and the continued ramp up of recently connected third-party plants. In the Rocky Mountain region, NGL volumes increased year-over-year, even taking into account a contract roll effective at the beginning of the quarter, which was previously discussed and assumed in guidance.

This was more than offset by growth across the region and continued strength in ethane recovery. Higher NGL pricing and export demand continued to support ethane recovery across all regions, and we expect these dynamics to remain favorable into the third quarter. Global NGL demand remains strong, supported by growing petrochemical demand and continued interest in securing long-term access to reliable U.S. supply. We're pleased to announce that we've reached our targeted contracting threshold of 80% for our 200,000 bpd of LPG export capacity, which is currently under construction as part of our export dock joint venture.

The capacity is supported by high-quality counterparties, and customer interest remains robust, including discussions that extend beyond the initial contracted period and into the next decade. This underscores both the growing demand for U.S.-sourced LPGs and the value of the terminal's advantage locations. Turning to the Refined Product and Crude segment. Demand fundamentals remained positive during the quarter. Year-over-year refined products volume shipped increased 8%, supported by gasoline and diesel demand, high refinery utilization, and refinery maintenance dynamics.

Blended volumes were also strong during the quarter, driven by increased system throughput. Higher gasoline volumes allow us to blend more product and further optimize operations across our network. While our hedge position limited our ability to fully capture the benefit of wider spring blending spreads, we have secured additional fall hedges at higher prices and extended new hedges into spring 2027, improving visibility into future blending margins. The location and flexibility of our refined product system and our ability to clear barrels in a dynamic market remains significant competitive advantages.

As refinery utilization remained high and product flows continue to evolve, our unique bi-directional connectivity between the Mid-Continent and Gulf Coasts allow us to efficiently connect supply with the strongest demand markets, including an increasing pull for U.S. refined products and exports along the Gulf Coast. Demand for our marine export services also remained robust. At our Seabrook crude export joint venture, throughput increased approximately 20% compared with the first quarter, included record crude oil loadings in May. The facility remains highly contracted and under take-or-pay agreements for the foreseeable future.

Midland crude gathering volumes increased 10% compared with the first quarter, reflecting continued strength in this higher-margin business. Rigs have steadily increased on our Midland crude gathering position throughout the quarter, and we currently have more than 30 rigs operating on our acreage. In addition, strong Houston area refining and export demand drove outperformance on our long-haul crude oil pipelines. Moving to the Natural Gas Gathering and Processing segment. Volumes increased across all regions compared with both the second quarter of last year and the first quarter of this year.

Producer activity remains healthy across our footprint, and development plans continue to track largely in line with expectations communicated throughout the year. We maintain good visibility to the remainder of 2026 and into 2027. In the Permian Basin, our recently added Midland capacity expansion positions us well to support increased development activity in the Barnett formation. While our planned projects in the Delaware Basin provide additional capacity to support anticipated growth into 2027 and beyond. We currently have 11 rigs on our acreage in the Mid-Continent and 13 in the Rocky Mountain region, up two rigs in the Rockies compared with last quarter.

Both areas experienced a seasonal pickup in activity during the second quarter, driven by higher well completions. I'll close with our Natural Gas Pipeline segment, where continued transportation demand and favorable market conditions drove another strong quarter. Waha to Katy location price differentials continued to benefit this segment during the second quarter. We expect lower earnings in the second half of the year as Permian takeaway capacity enters service and differentials narrow, consistent with our full-year outlook and guidance assumptions. Looking forward, power generation, LNG exports, and industrial development continue to support increasing natural gas demand across our footprint.

We continue to advance commercial discussions supporting multi-large scale data center developments. While these projects have not yet reached FID, continued commercial project reinforces our confidence in the scale and durability of the opportunity. From a power generation perspective, we were recently awarded a supply agreement for a 1 GW of power plant demand, further expanding our participation in a growing source of natural gas demand. Supporting electric generation has long been a core part of our business. Our intrastate natural gas pipeline system is already directly connected with numerous power plants across our footprint and is well-positioned to serve future demand growth. Pierce, that concludes my remarks.

Thank you, Sheridan, Randy, and Walt. As we step back, it's clear that demand fundamentals remain strong, and the long-term outlook for U.S. energy infrastructure remains compelling. As we look across our business, the message is straightforward. We've raised guidance for the second time this year, extended our cash tax runway, advanced key projects, and strengthened visibility into earnings growth and free cash flow through 2026. Our integrated multi-molecule platform positions us to capture opportunities across commodities, regions, and demand drivers while maintaining financial and disciplined flexibility. Most importantly, none of this would be possible without the dedication of our employees and their commitment to safe, reliable, and disciplined execution. With that, operator, we're ready to take questions.

Thank you. If you would like to ask a question, please signal by pressing star one on your telephone keypad. If you're using a speakerphone, please make sure your mute function is turned off to allow your signal to reach our equipment. We do ask that you limit yourself to one question and a follow-up to fit in as many questions as possible. Again, press star one to ask a question. We'll pause for just a moment to allow everyone an opportunity to signal. Our first question comes from Spiro Dounis with Citi.

Thanks, operator. Good morning, team. I want to start on the growth strategy from here. Pierce, I think you had talked about aspiring to grow mid to high single digits over the next few years, and curious just to get more color on that front. Specifically, how much of that growth can be underwritten by filling up the white space that you mentioned on the current system versus building out new infrastructure? You mentioned a growing backlog of projects coming. How should we think about maybe the timing of when those projects could come to market, and maybe which verticals you see probably getting the most attention?

Okay. Spiro, I'd start out by saying that it's not one thing that's driving this conclusion for us. We actually have a multi-reinforcing growth drivers. Our assets are positioned in these premier growth basins in the U.S. and especially in our export markets. The growth across our footprint is actually underpinned by basically five things, not just filling the white space that you mentioned. It's the continued strong Permian, Mid-Continent, and Powder River growth, and the associated natural gas liquids. It's the stable Bakken growth through improved well productivity. It's the rising U.S. LPG export market, and there's a shift definitely in the global crude oil demand to a more reliable and a more resilient supply. Then you've got your LNG exports driving the natural gas increase across the United States.

It's driven by that growing 30 BCF/d or over 30 BCF/d LNG export, and your domestic natural gas power generation and industrial demand. These facts all give us the confidence that we have to that high single-digit EBITDA growth over the next five to seven years. It's not just one thing, it's a multitude of things, and it's across all five of our business segments.

Got it. Thanks for that, Pierce. Second question maybe for you, Sheridan, just zeroing in here on the NGL segment. Looking for more color around the dynamics around the quarter. Volumes were really strong, as you pointed out, but margins may be a little bit softer overall. Can you talk about some of the dynamics that were driving that this quarter and how you're thinking about margins going into the back half of the year? Should they stay at these levels, or do you think there's reason to think we could see expansion?

Yeah. As we talk about the margins, we did see a little bit of reduction in the margin, overall margin on certain parts of our system, and this was really driven by increased ethane. We saw versus how much the increase in C3+ we had. That happened on all three of the segments, Permian, Mid-Continent, and the Bakken, where especially discretionary ethane out of the Bakken comes at a much lower rate than what the C3+ at full rate is getting out of the Bakken. Like I said, we did see both the increase in C3+ in the Bakken, but we also saw a greater increase in ethane. That also became apparent in the Mid-Continent, where we had a large increase in ethane in the Mid-Continent.

Those rates are tiered rates that we've had for a period of time where we charge a higher T&F rate for the C3+ than we charge for the ethane even at full rates. As that more ethane comes on it can have a little bit of effect on our overall margins that we have in there. We are seeing a lot of increase of volume across our system. One area I'd note is the Permian on volume, where we've seen here in the last month or two a strong increase in our volumes, substantial increase in our volumes. Really look at it was kind of tied to the way Waha to Katy spread. As that spread came in and Waha became positive, we saw a lot more volume than we had anticipated behind our NGL system come on in that area. We've seen July has been a great month and August is following suit on good uptick in volume on our NGL system.

Great. I'll leave it there. Thank you, team.

We'll go next to Jean Ann Salisbury with Bank of America.

Hi, good morning. There's been some talk from some E&Ps year-to-date around reducing their midstream costs. In that context, can you update us on the duration of your NGL T&F contracts out of the Bakken?

Yeah, our rates out of the Bakken are still extended for a period of time. We really don't have anything of material coming up until late this decade. Most of the stuff is into next decade. We feel very good about our NGL rates out of the Bakken at this time.

Thank you. Refined product prices in PADD 4 have continued to rise year to date versus PADD 2. I believe you've said before that your Denver pipeline is mostly long-term contracted, is there meaningful exposure to the spread at these price levels?

No. The 35,000 bbls is signed up by firm take or pay contracts. Obviously, there may be a little opportunity that always our operating team finds a way to squeeze a little bit of volume out there that we may be able to enjoy a little bit on a spread that happens there. Majority, almost all of it is under long-term firm contracts.

We'll go next to Jeremy Tonet with JPMorgan.

Hey, good morning. This is Vrathan Reddy on for Jeremy. There's potential for additional egress out of the Bakken. I was curious if you could speak to your outlook for the ethane recovery at this point, and maybe ONEOK's positioning against that backdrop.

Our egress for NGLs out of the Bakken is strong. We're running up around sometimes up to 500,000 bpd, which gives us plenty of more capacity to be able to move in there, and we can flex on the ethane if we want to. We don't really see NGL egress out of the Bakken being an issue in our forward plan.

Got it. As a follow-up, want to dive deeper on the MidCon. Looks like decent producer activity within the region. There might be a contract roll next year, curious if you could dive a little bit deeper into your outlook for the balance of 2026 and into 2027.

We continue to have contracts that roll in the MidCon in different areas, some of them were put on at a higher time where margins were higher. There could be some of these contracts coming back to more of what we see the market is at this time. Typically, anytime we're dealing with customers on that, there's a give and take in areas that we work with. There is value shifted back and forth between different basins, as we've talked about, as we bundle rates with our large contractors. Most of our contracts in the MidCon still have some term on them for a period of time. Nothing's coming up here in the next month or two or even into next year.

This is Pierce. The only thing I'd add to that is the fact that any sort of contractual movement, we've already factored that into our guidance numbers. That's fully baked in to market rates.

We'll go next to Praneeth Satish with Wells Fargo.

Hey, everyone. Good morning. I guess just turning to the Permian. Obviously you're seeing good growth there, strong demand. When we think about West Texas LPG specifically, how much remaining uncontracted capacity do you have on this system? How much more room do you have there to support the growth that you're seeing in the Permian? Maybe just sticking on Permian NGLs. If I remember correctly, with some of the legacy EnLink volumes, they're moving on relatively higher cost NGL transportation paths. As those contracts roll over, to what extent can those be migrated to West Texas LPG, and what's kind of the timeframe for that?

What I would say on your first question is we've come out and said that with the mainline expansion of West Texas NGL pipeline, we have capacity up to 740,000 bpd. With that and what we're seeing today, we still have plenty of capacity to meet the demand that we have coming on, both from our processing plant expansions and the growth that we're seeing from third-party plants coming on as well, as well as the opportunity to grow our processing even further than we have announced into the future. We think we got a very good position there. A lot of operating leverage, as you would say, that we could move additional NGLs on that system. We don't see having to expand that for a period of time. What was your second part of the question?

The second one was on the legacy EnLink volumes and recontracting and bringing some of that onto West Texas LPG.

Yeah. As I said, there's a little over 50,000 bpd that we control that was previously contracted under EnLink on another third-party pipeline. Those contracts will start rolling off here starting a little bit later, 2026 and 2027, 2028. All that volume will come directly over to our NGL pipeline when they roll off.

Okay, great. Then maybe going back to, I think it was Jeremy's question, but, I think you kind of took it as NGL egress. I think his question and mine is, there is a few proposed gas takeaway projects being proposed in the Bakken, and seems like at least one of them may move forward, sizable projects. I guess the question is, if gas egress improves in the Bakken, how does that impact your outlook for basin growth, BTU levels and really ethane recovery? Could you see more upside from potential more production growth kind of offsetting maybe some downside from lower ethane recovery? Just how do you think about that?

Yeah, I think a little bit of both. Anytime when the producers get a little bit better net backs than anything else, that helps them to increase their production or have more incentive to increase their production. In terms of our discretionary ethane that we have coming out of the Bakken, really, it's based on a lot of what's coming out of Canada and what's held back out of Canada is still the incremental barrel, incremental MCF to come on the system. We still think that on the ethane side will be a nice spread for us to enjoy on the discretionary side as we continue to go forward into the future.

We'll go next to John Mackay with Goldman Sachs.

Hey, team. Thank you for the time. I want to go back to some of the questions around the longer-term growth outlook. Pierce, I appreciate the kind of different drivers you called out there. Just curious if you could touch a little bit more on kind of the incremental growth spending, kind of where projects could fit in there, and what you think a kind of run rate growth CapEx budget could be like to support that outlook.

Appreciate the question. I'm going to throw that question to Walt for the capital spending update there.

Well, as we've been talking about, we have a pretty nice backlog that is building. We've got quite a bit being completed here in 2026 and 2027, all of which will then bring on that EBITDA going forward. The backlog that we have is more in the mid-size projects. We don't have any $1 billion+ right now on the horizon, so that should moderate our CapEx from the current levels down into that $2 billion-$2.5 billion kind of run rate going forward. Of course, our commercial team is always out there looking for great opportunities, and to the extent we find them, we'll clearly jump on them. I think that with that $2.5 billion run rate call it, you're going to see some very significant free cash flows still coming to the bottom line.

I appreciate that. Maybe just a follow-up for me. You've talked a couple of times in recent calls around some of these gas laterals to feed BTM or kind of broader power gen. Could you just talk a little bit about kind of what the commercialization process has been like so far, and then maybe tying it into your last comment right there, that kind of run rate level of growth CapEx, how much of that could be going towards this vertical? Thanks.

Well, I'll take the first part on AI data centers and power gen. Obviously, in my prepared remarks, we talked about that we have secured a 1 GW power gen supply contract that will be the supplier of natural gas into that system. It's a really nice project. It's not a high capital. I mean, it's over $100 million of capital we'll have to spend at a very nice return at firm demand.

We also are in late stages of discussions with a couple of other opportunities to be able to supply AI data centers. No doubt that commercialization has taken a little bit longer than what we had anticipated on some of these projects. I think we're seeing that across the board where it just takes a little bit longer time to get them across the finish line. We're feeling really good about our position, especially where they're at. We have a strong competitive position, and that's why we've been able to advance these discussions as far as we have.

On the capital, I would just say that those types of projects are really what I was talking about. They're kind of singles and doubles. They're in that $100 million to maybe $400 million-$500 million top end. Fit really nicely into our capital budget going forward. Clearly in Randy's remarks, he went through a list of other projects that we've got underway, all of which are very attractive and maybe doubles and triples there, a little bit bigger.

We'll go next to Theresa Chen with Barclays.

Morning. Given the growing global focus on energy security, reliable supply, you noted increasing commercial traction for the LPG export facility. How do you see the opportunity set for exports broadly evolving from here, both in terms of the LPG export project as well as brownfield expansion opportunities and/or recontracting to the upside on your existing liquids export infrastructure?

Well, I mean, obviously, we are very satisfied, very excited about reaching our threshold on the LPG export dock. As I mentioned in my comments, we actually have starting conversations with potential off-takers that want to start looking at when these contracts roll off into the next decade and securing that going forward. We have seen since the war that there's been a lot of additional new entrants wanting to talk about the security of the U.S. supply for both LPG and crude oil. We talked about our Seabrook export dock is 100% contracted to the foreseeable future under firm take or pay contracts. We are seeing growth across liquids demand. One thing we don't mention very often is our refined products export capacity. We are seeing good volume growth on that, good pulls on that.

Very strong, which is obviously flowing throughout our whole system down there to go forward. We see that opportunity to continue to grow. Whether or not it go forward anymore, as I said, on the LPG side, we kind of want to get this up and going and show our customers that we can operate this at the level and reliability that we promised them going forward. We continue to look and see if there's something else out there, and continue to engage with customers, and continue to go forward. There's definitely a resurgence of people wanting the security of U.S. energy supply.

Theresa, this is Pierce. Some of that upside could be in that extra 20% of international producing community wanting that full wellhead to water pull. That's one of the other reasons that we left that position open, not only just for operational reasons, like Sheridan said, but looking at potential upside for us in the future. That grounding of that 80% was important for us.

Thank you. With the Denver refined products pipeline expansion now in service, incremental commentary from the downstream community about moving additional volumes from PADD 4 into PADD 5 over time, how has your view of PADD 4 regional supply and demand balances evolved for the Denver area and beyond? As PADD 4 becomes tighter, what opportunities does this create across your infrastructure footprint that MidCon to Rockies movement? How are you thinking about potential for further expansion on that Denver pipeline system beyond the jet fuel movement?

Yeah. We're excited about how to get this pipeline up and operating. We've been working on it for some period of time. Operations done a great job to get it on time. As we've noted, we brought that on. We laid a 16-inch pipeline that has upwards of possibly 200,000 bpd of capacity. We're only running 35,000 bpd out on that.

We've seen for a period of time that PADD 4 could need more volume going forward. That could be supplied by this pipeline. There's been some talk of some projects getting into the Salt Lake City that we feel we will play a part in those, that we can get the capacity there the cheapest and the quickest, as we have set that pipeline up for expansions going forward. Getting this pipeline was very critical to us to show that and be able to show everybody that we can expand it and be able to supply that growing demand in PADD 4.

We will go next to Keith Stanley with Wolfe Research.

Hi. Good morning. First wanted to clarify on the mid to high single-digit EBITDA growth. Walt, it sounds like you're saying that's tied to $2 billion-$2.5 billion a year CapEx. Any color you can give on what that assumes for volume growth, and if that includes or does not include any bolt-on M&A of any kind?

It's really a combination of future CapEx and then, to quote Spiro there, the filling the white space. We've got plenty of operating leverage across our businesses. As we are able to do brownfield expansions off of that, we'll continue to grab opportunities that really attractive capital. Coming back to some of the drivers on that, here in the short term, and we think going forward, Sheridan mentioned the world looking for diversity of supply. We've seen very significant volume growth on our refined products go into the Gulf Coast, and that could be really meaningful for us because it's pulling tariff across the system. We've got rigs up in every one of our basins and visibility to more coming. Commodities were well hedged here in 2026, so we didn't really get a big benefit from this pop here in 2026.

We'll enjoy it on the incremental supply that we get above what we had hedged, but we're going to really see that benefit as we roll into 2027. One that we found really interesting, while we did benefit from the Waha to Katy spread, as that narrowed down, we really have seen a nice pickup in NGLs from volume that was shut in behind our system, mostly on the third-party plants. With this constructive backdrop here, we're confident in the new guidance. If the momentum holds, we might even be updating you in Q3.

Great. The second one on ethane recovery is: is there any way to quantify how much incremental ethane recovery you saw with the market dynamics in Q2 and I guess the Bakken and the MidCon? It just seems like a pretty meaningful boost to volumes based on the change in rate.

Yeah. I would say we saw a significant increase in ethane recovery in the MidCon. That's probably one of the biggest one at full rates, and which has been good. There was still the up in the Bakken because of the difference in rate that you have between a full rate for a C3+ versus this discretionary ethane that we bring on. A little bit of volume can affect that by, I think it was down $0.01 or so. It can affect that with those rates that we have there. We saw good ethane recovery in the Bakken. Obviously in the Permian, we also saw a little bit more of ethane coming on the Permian. The growth in the Permian was much more weighted to the C3+ side.

We'll go next to Sunil Sibal with Seaport Global Securities.

Yes. Hi, good morning, and thanks for the time this morning. I think in your prepared remarks, you talked about upsizing some of the projects that you had previously announced. I was curious, is that a result of more customers coming in or just your existing customers kind of increasing their demand for the processing capacity?

This is Randy. We've got a little bit of both. We have existing customers that are really performing. As Walt mentioned too, I think the Waha spread there narrowing has helped a lot. We're seeing that increase, we're also just seeing our commercial people doing a really good job of doing additional deals and interesting existing customers to increase that. It's a little bit of both.

Okay, thanks for that. Then, with the mid to single-digit EBITDA growth that you guys outlined for the foreseeable future, I was curious, how does that translate into the EPS growth rate? Obviously, seems like your capital spend is going to be fairly capped, at least from the organic growth project. I was curious if you could clarify that.

Yeah. We would think that our EPS growth rate should exceed that EBITDA growth rate, especially as we move into more free cash flow and potentially take the opportunity to buy in some shares. We're very constructive on the EPS growth rate.

Good morning. Could we get a little bit of an update on your Permian processing plants that are set to come online in near future?

In the processing plants coming online in the near future in the Permian, we have here in the third quarter, as Randy outlined in his comments, we have 110 million a day coming on in the third quarter. That will be in the Delaware. They're going to fill up pretty quickly. That 110 million a day is going to fill pretty quickly. We have good line of sight on volume growth in that area.

The Shadowfax Plant in the Midland is already up and going, and we'll be filling it as well quickly. We have the Bronco Plant that will be also out in the Delaware, which will be into 2027. We'll have that filled later into 2027. That will be filling as well. That's the one that Randy had mentioned that we originally FIDd that at $300 million a day. Due to what we're seeing with producer activity and commitments we have on our system, we've already upsized that. It was a very cheap upsize to $400 million a day, so that's making that project look even better out there.

Perfect. I just want to go back quickly to the 2026 guide. Help us understand what could drive further guidance revisions that you kind of hinted to, and what could put you towards the top end of that guide of $8.5 billion?

Well, I think that we're seeing a nice pickup in producer activity. Clearly, we've got a constructive market in the refined product side with a healthy spread on our upgrades there with the CBOB to butane spread. The fact that we're seeing rigs across the board coming in, really nice strength in our crude gathering business with rigs coming in there. It's really across the system. We're seeing our customers wanting to take advantage of these slightly higher prices and positioning themselves for growth through 2026, but really strongly into 2027.

One thing I may add to that a little bit is we came in pretty hedged in 2026 on refined products. With this increased volume we're seeing across our system, that is allowing us to hedge even more or allowing us to blend in even more, and that was not hedged at the lower prices. We're able on this incremental volume, we're able to capture that at a higher rate going forward. If that volume continues into the later half of this year, the strong volume that we think could possibly happen, that's another thing that gives some tailwinds.

We'll go next to Julien Dumoulin-Smith with Jefferies.

Hey, this is [Alex Romeon] over here for Julien. Just a quick question and maybe just a point of clarification. How much would you say, if any, of the mid to high single digit is predicated on those bolt-on acquisitions that you guys talked about? Then also just where are you seeing the best opportunities for bolt-on M&A across your footprint?

This is Pierce. I would say that the majority of that growth is the organic. It's everything that I mentioned. It's about continuing to optimize our systems. It's continuing to take advantage of synergies. Continuing to, again, quote Spiro, "Fill that white space with very little capital.

That's the majority of it. As it relates to the M&A, my message there is the same that it's always been, which is we're going to be intentional and disciplined about what it is that we're doing, and we're always looking to expand and extend our footprint in any of our basins. Wherever those opportunities present themselves, we're going to be looking at those.

Got it. That's super helpful. Then just quickly on for that mid to high single digit, what is the implied sort of Bakken volume growth underpinning that? Is it sort of similar to what you guys talked about at the beginning of the year, low single digit kind of growth?

Yeah. That's right. We're staying with that.

We'll go next to Gabe Daoud with Truist Securities.

Thanks, operator. Morning, everyone. I wanted to go back to the volume side. You had mentioned in the Permian seeing some incremental gas show up as the spread, you know, Katy-Waha spread, significantly improved. Just curious, have you quantified that number? I'm just trying to think through how you guys, at least maybe in the Permian, could land at the high end of your volume guide of 1.7 Bs.

Oneok (OKE) Q2 2026 Earnings Call Transcript

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