Good morning, and welcome to the Enterprise Products Partners conference call to discuss fourth 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.

With that, I'll turn it over to Jim.

Thank you, Libby. The headline for the fourth quarter is a record $2.7 billion of EBITDA, surpassing the previous record of $2.6 billion set in the fourth quarter of 2024.

We brought on a number of assets in 2025: Frac 14 in mid-October; Mentone West and Orion mid-year; several gathering and treating projects in the Permian; the Neches River Terminal ethane export train mid-year; the mid-year start-up of diluent exports to Canada; and finally, the Bahia NGL pipeline in December. All these assets have performed well, but they also fill holes created by a decline in our commodity-sensitive businesses and marketing spreads.

Market realities shaped the year. Crude oil prices averaged about $12 a barrel lower than in 2024.

That reduced many of the pricing spreads we've benefited from over the prior three years. Octane market margins were weaker in 2025.

A large 10-year LPG export contract, originally signed at double-digit fees, was recontracted at market rates. RGP/PGP spreads were 14 cents a pound in the fourth quarter of 2024, but only 3 cents a pound in the fourth quarter of 2025, which is a reflection of the weakness in the housing market.

During '24 and '25, we renegotiated our RGP purchase agreements to a fixed-fee structure, which makes our splitter business largely spread-agnostic. The splitters are now essentially an annuity.

We're fully contracted on our ethane export terminals and all 20 processing trains that we will have online in the Permian by year-end. For ethane exports, typically ships must be built and receiving terminals constructed to ultimately ramp to full utilization at our docks.

With that being said, however, the ships seem to be coming earlier than the receiving. For processing, while production growth builds over time, the two trains we brought on in mid-year 2025 are virtually full today.

Our LPG exports are highly contracted through the end of this decade, and we continue to see strong interest for additional long-term commitments. We expect modest growth in 2026 as these assets and the assets we're bringing on in 2026 continue to ramp.

We expect to see double-digit growth in 2027 once these assets reach full utilization. Naysayers doubted Bahia in the beginning, but that is to be expected when you're first.

Bahia and Shin-Oak is an integrated system, has 1.2 million barrels a day capacity, and are running at 80%. Having Exxon as a UJI partner and agreeing to expand Bahia to 1 million barrels per day is a win for both Enterprise and Exxon.

Associated with the UJI are a dozen downstream agreements. On the export front, Enterprise continues to expand its NGL export franchise.

In 2025, we loaded between 350 and 360 million barrels across 744 ships, and that will only grow as we complete Phase 2 of the Neches River Terminal and the LPG expansion up the Houston Ship Channel. By next year, we expect to be exporting near 1.5 million barrels a day of NGLs, or 550 million on an annual basis.

A little history lesson: we've been doing international business since 1983, when we built our LPG import terminal. In 1999, we expanded the facility to include export capabilities.

Many of our customers have been with us for more than 20 years. They know us.

They know how we behave. They like how we operate.

They are more than just customers. Relationships like that tend to be very sticky.

We spend a lot of time with our customers around the world and domestically. For example, over the holidays, I was in Thailand meeting with three large petrochemical companies.

Christiana was in Europe in the fourth quarter and will be back in March. On the crude team, Cary Waybourn was in Asia in October, Jay Bany will be in Europe later this month.

In NGLs, God bless Tyler Cott and his travels. Tyler was in Asia in November with stops in Korea and India, and will be in Europe this month and back to Asia in March.

Finally, Tug and I will be in Japan next month to visit several export customers. We are equally focused on our domestic customers, be they producers, petrochemicals, refiners, traders, or wholesale.

We deliver roughly 25 million barrels a month of ethane to US crackers. That's around 300 million barrels a year.

In total, we move over 14 million barrels per day of oil equivalent throughout our 50,000-mile pipeline network. Additionally, Enterprise looks at its storage hubs as a critical part of its infrastructure to support its customers: Cushing, Midland, Houston, and Mont Belvieu.

These are all open-access systems where our customers can trade freely without any concern of being held hostage. We are proud of our record $2.7 billion of EBITDA in the fourth quarter, but as investors look to the future, I would encourage you to look beyond the numbers.

Enterprise's long-term success is driven by our culture, our teamwork, our creativity, and our laser focus on customer relationships. Those intangibles are what give rise to the numbers you see each quarter.

Randy?

Thank you, Jim. Good morning, everyone.

Starting with the income statement items, net income attributable to common unit holders was $1.6 billion, or 75 cents per common unit on a fully diluted basis for the fourth quarter of 2025. In the fourth quarter, our adjusted cash flow from operations, which is cash flow from operating activities before changes in working capital, grew 5% to $2.4 billion.

This strong finish propelled us to a record $8.7 billion in adjusted cash flow from operations for the full year 2025. We declared a distribution of 55 cents per common unit for the fourth quarter of 2025, which is a 2.8% increase over the distribution declared for the fourth quarter of 2024.

The distribution will be paid on February 13th to common unit holders of record as of the close of business on January 30th. The partnership repurchased approximately $50 million of its common units in the fourth quarter, bringing total repurchases in 2025 to approximately $300 million.

Inclusive of these purchases, the partnership has utilized approximately 29% of its authorized $5 billion buyback program. In addition to buybacks, our distribution reinvestment plan and employee unit purchase plan purchased a combined 4.7 million common units on the open market for $150 million in 2025.

This includes 1.2 million common units purchased on the open market for $37 million during the fourth quarter 2025. For 2025, Enterprise will have returned $5 billion of capital to our equity investors, comprised of approximately $4.7 billion, or 94% in distributions to limited partners and $300 million through buybacks, resulting in a payout ratio of adjusted cash flow from operations of 58%.

Since our 1998 IPO, we have prioritized unit holder value by responsibly returning nearly $62 billion through distributions and buybacks, all while building one of the largest energy infrastructure networks in North America. Total capital investments were $1.3 billion in the fourth quarter of 2025, which included $1 billion for growth capital projects and $203 million of sustaining capital expenditures.

For 2025, organic growth capital investments were $4.4 billion, with about $100 million of expenditures slipping into 2026. We also had $620 million of sustaining capital expenditures.

With the completion of major projects such as the Bahia natural gas liquid pipeline and the first phase of the Neches River Terminal, we continue to believe our organic growth capital expenditures in the near term will return to our mid-cycle range. With that said, our commercial teams have had great success in completing major agreements with producers since our last earnings call.

In November, we announced ExxonMobil's acquisition of an undivided joint interest in Bahia natural gas liquid pipeline and the related expansion of Bahia to 1 million barrels a day and a 92-mile extension to connect Exxon's Cowboy processing complex as well as Enterprise plants in the Delaware Basin. In January, we executed agreements to provide a large producer in the Delaware Basin with integrated services, including acid gas gathering and treating, natural gas processing, and NGL transportation and fractionation services.

These long-term agreements support our building a 24-inch trunkline to extend the partnership's acid gas gathering system in northern Lea County, a fifth treater at our Dark Horse facility, and a third acid gas injection well. In addition, we executed long-term agreements with Haynesville producers to an extension of our Haynesville natural gas gathering system, along with downstream agreements to provide natural gas processing, treating, and transportation services on the Acadian system.

We have also had success in executing agreements with petrochemical customers that support incremental extensions of our ethane, ethylene, and propylene pipeline systems. As a result of these successes and visibility to potential projects, we expect growth capital expenditures for 2026 to be in the range of $2.5 to $2.9 billion, netting to $1.9 to $2.3 billion after applying approximately $600 million of proceeds from asset sales already received earlier this year, which represents the final installment from Exxon on the Bahia sale.

The pace of some of these expenditures will depend on the cadence of producer activity. However, we believe we will be at the higher end of this range.

Sustaining capital expenditures are expected to be approximately $580 million in 2026, which includes approximately $80 million for the turnaround of our octane enhancement facility that should be completed later this month. As Jim noted earlier, we expect modest adjusted EBITDA and cash flow growth in 2026 as assets completed in 2025 ramp in volume and as assets that are completed throughout 2026 begin operations.

We expect this to ultimately lead to 10% area growth in adjusted EBITDA and cash flow in 2027 compared to 2026. Enterprise's adjusted cash flow for 2025 was $3.1 billion, and this adjusted free cash flow, that's our cash flow from operations less capital investments and acquisitions.

Subtracting distributions to limited partners results in 2025 discretionary free cash flow of a negative $1.6 billion. Based on our currently expected lower level of net capital investments in 2026, which is comprised of capital expenditures plus acquisitions less proceeds from asset sales, and the net increase in distributions, we expect discretionary free cash flow has the potential to be in the $1 billion area in 2026.

In terms of allocation of capital, we see cash distributions to partners growing commensurate with operational distributable cash flow per unit growth. In the near term, we expect for our discretionary free cash flow to be split between buybacks and retiring debt.

In 2026, we currently expect this split would be approximately 50% to 60% in buybacks. Future growth in cash distributions to partners can also be further enhanced by the percent of common units we retired through buybacks.

Our total debt principal outstanding was $34.7 billion as of December 31, 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 98% of our debt was fixed rate. At December 31, our consolidated liquidity was approximately $5.2 billion, including availability under our credit facilities and unrestricted cash.

Adjusted EBITDA increased 4% to $2.7 billion for the fourth quarter, compared to $2.6 billion for the fourth quarter of 2024. Adjusted EBITDA for 2025 reached a record high, just shy of the $10 billion mark.

We ended the year with a consolidated leverage ratio of 3.3 times on a net basis after adjusting debt for the partial equity content of our hybrid debt and reduced by the partnership's unrestricted cash on hand. Our current leverage ratio reflects significant investment in large-scale projects that we recently brought into service and the midstream asset acquisition from Occidental, where the debt is on the balance sheet, but the resultant annual adjusted EBITDA generation from these investments has yet to flow into our trailing 12-month EBITDA figures.

Our leverage target remains three times, plus or minus a quarter turn, or 2.75 times to 3.25 times. We believe our leverage will return to within our target range by the end of 2026, when we have a full year of adjusted EBITDA from some of these projects.

With that, Libby, we can open it up for questions.

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

Thanks, operator. Morning, everybody.

Wanted to start with the '26 and '27 outlook comments. You exited '25 really strong.

Just wondering if you guys maybe walk us through some of the puts and takes off this fourth quarter exit rate as you think about '26 growth. Just trying to get a sense of what's ratable here and if you guys see yourself still landing in that 3% to 5% growth range.

On '27, you mentioned double-digit growth. Just curious how you're thinking about the risks to achieving that level of growth.

Maybe another way of asking, what commodity environment underwrites that level?

I think, Spiro, this is Jim. I think, given that in my script I mentioned we didn't have as many outsized spreads as we had the three previous years, I think fourth quarter's weighted more ratable than not.

Hey, Spiro, and just as a follow-up on the second part of your question, I think probably as we mentioned, we're sort of looking at modest cash flow and EBITDA growth in 2026 compared to 2025, probably at the lower end of that 3% to 5% range.

Morning. Under comments related to the NGL export cadence, specifically on the phases of Neches River ramping up over time, can you expand on the cadence and ramp-up of earnings contribution from these expansions?

How should we think about the ramp and steady-state contribution as we move through 2026 and into 2027?

Hey Theresa, this is Tyler Cott. I'll speak to the volume, which should correlate to the earnings.

Neches River came online last year, as the fourth quarter. We started to ramp volumes of ethane in earnest.

That ramp will continue into the first several months of this year. I would say by the second quarter, our overall ethane export capacity should be very near full utilization, at which time our second train at Neches River will come online, and that will have a ramp-up profile over the next several months, largely propane at first, but then shifting to mostly ethane by around the end of next year.

Thanks. Good morning, everyone.

Wanted to ask, as Waha prices have been pretty volatile the last few months. Fourth quarter, prices really low, spreads were wide.

Then of course, in January, we've had this winter storm, Waha prices spiked. I wonder if you could just remind us how EPD is impacted by changes in Waha prices in both directions.

This is Tug speaking. As far as a low Waha price, we have gas transport capacity, we benefit from a higher—we call it West-East or West to West to South spreads.

We'll be able to monetize that. In respect to recent volatility on a higher gas price, we do have storage assets that can monetize that as well.

We benefit from volatility on both sides.

Great, thanks for that. Then, I wonder if you can just give us a little color on what your producer customers are telling you in terms of their plans for 2026, and how you see that translating into supply growth, especially in the Permian.

Thanks.

This is Natalie Gayden. On the G&P side, our Midland volumes are outperforming the expectations, tracking pretty closely with last year's volume growth.

Just to give you some color, well connects are at a record high this year of 590. Then in the Delaware, same kind of thing, the growth curve is steepening there, and we've got an estimated 500 wells turning to production this year and more next year.

We're definitely keeping our running shoes on.

Hi, good morning. I don't think you have a ton of exposure to the E&Ps announced in the merger yesterday, but just as a more high-level, I guess, theoretical question, can you give your thoughts of how much more negotiating power a large E&P would have over midstream contracts versus two small E&Ps, and if there is more consolidation, if that is kind of a negative for midstream?

Randy, you want to try it, or you want me to? Hi, Jean Ann, this is

Jim.

With the people we have, I don't think it makes a difference. Our folks are pretty good at seeing value and doing win-win deals with producers, whether they be large majors or large independents.

Very clear. Then as a follow-up—

Did you expect any other answer, Jean Ann?

No, not really. I appreciate it.

I guess as a follow-up, do most of the Midland to ECHO crude pipeline contracts roll off in 2028, 2029? I know that there's been some discussion of blending and extending, not sure if that should kind of be later at this point.

Jean Ann, this is Jay Bany. For '28, we have our first contracts roll off, but over really the course of last year and the year prior, we have done not only new contracts to fill that space, but blend and extends.

It's roughly about 20% you'll see roll off in '28, but we'll be working on that this year and next.

Great. Thank you.

Hi, good morning.

Good morning.

Appreciate the color on the 10% EBITDA step-up '25 into '27 there. Just want to dive in a little bit more with regards to buybacks and the pace thereof.

Is there any kind of formula that you think about or other methodology when you think about the buybacks? I think I recall if there's $1 billion of free cash flow, it might be 50% to 60% deployed towards buybacks, and so just kind of trying to figure out how that might work out over the course of the year.

Jeremy, and in the prepared remarks, pretty much based on where we currently are, what we see 2026 with free cash flow in the neighborhood of a billion dollars, we really see that split where 55% to 60% of the buyback would be—or 50% to 60% of the cash flow would be allocated towards the buybacks. That would really be some level of opportunistic and some level of programmatic purchases is the way we're currently thinking about it.

Got it. Thank you for that.

Maybe if we could just pick up on the freeze-offs one more time. I wouldn't expect it to be the same type of uplift as Uri, as we saw in the past, but could we see the potential for sizable uplift as optimization opportunities might have been greater than what you typically see?

This is Tug. I'll just say we saw production fall off, similar to prior winter events, and we were able to more than make that up by optimizing our system.

Uri was, I would say, an exception to every winter storm, I would not be expecting that.

Got it. Thank you for that.

Hey, team. Thank you for the time.

Jim, you spent a while talking through your kind of international customer base on the NGL side. Can you share a little bit more color for us on what you're hearing in terms of demand trends and maybe how that compares to this time last year?

I'm going to let Tyler take it.

Hey, John, this is Tyler Cott. I would say overall, obviously, there's been a lot of noise in the last several months in the international and export markets, but demand has proven to be pretty resilient.

US LPG is finding its way into new markets: India, Southeast Asia, other places in Asia. Demand has been pretty healthy, and maybe the ultimate barometer for us is we still have a lot of interest in our export capacity long term, both LPG and ethane.

Got it. Thanks.

Maybe just following up quickly, just to clarify what Spiro asked, it sounds like some of the ramp on the new projects that came into service last year and this year is going to pick up more in '27, I guess. Could you just walk us through, I guess, any incremental headwinds you're expecting for '26 versus '25 that might offset some of that ramp?

Zack—let me take the first shot at it, Zach. Frac 14 is full.

The two processing plants are virtually full, will be. The ethane terminal, y'all talked about, would be full at the end of the year.

LPG is full, isn't it? The expansion, you're well on your way, contracting that.

That comes on in the fourth quarter?

Yes.

Did I answer it all, Zach?

I think you did.

Headwinds, I don't... Commodity environments, I'd just say, as Tug, on the LPG contract, well on our way.

We're 85% to 90% contracted on that.

Even on the expansion?

Even on the expansion.

Good.

Ethane, we're fully

contracted. Headwinds are, I don't know, $40 crude's a headwind.

The one other, I guess, commodity-sensitive business that we have is our octane enhancement business, but that's only 20,000 barrels a day. It seems like there was a big change from 2024 to 2025, but really from '25 to '26 you don't see nearly that magnitude of change.

I wouldn't look for too much of a headwind there.

No, I don't think there is at all.

All right, team. Appreciate the color.

Thank you.

Good morning. First, congrats on the beat and a strong quarter.

Second, we look at your partnership with Exxon in a very optimistic way, two giants coming together. I'm trying to understand, are there more opportunities to collaborate with Exxon?

They're obviously looking to get big into power generation with the carbon capture and sequestration, and you have the infrastructure to move carbon dioxide. Can you talk a little bit more about your partnership with Exxon, and can it grow over time, and what are the opportunities over there?

Thank you.

We touch Exxon in so many places I can't count it, and we will continue to try to do more deals with Exxon. We like them.

I don't think carbon capture will be in the portfolio.

Thank you.

Yeah. Hey, morning.

Thanks for taking my questions. I noticed in the press release there was mention of sour gas treating capacity expansion and then potential opportunity to expand activity on the acquisition from Oxy.

The question is really, does that kind of support you filling up your Y-grade pipelines out of the Permian Basin to get over the 60% utilization on the Bahia pipeline, or does that present upside to that number?

We said we were at 80% utilization. We're pretty close to getting to the 600, as we speak, or the 1.2 million, as we speak.

Natalie, you want to speak to the other?

I would just say that our G&P footprint is a stronghold on feeding the downstream pipelines. Any gas that we go win or packages of gas that we bring through the gathering and processing system are good for that.

Yes, an expansion of Pinon and Oxy truck volumes eventually coming in a big way in 2027 to us is good for the NGL portfolio.

Got it. Sorry for misspeaking on that number.

My follow-up, if I could ask another, is just on the opportunity on the propane side on your product pipelines in the first quarter of the year, given the cold weather in the Northeast. Could you just talk about what you're seeing in that system moving propane up the product pipelines?

Thanks.

Jason, I'd say all of our propane pipeline saw really strong demand ramping towards the end of the year, and January's been as strong, potentially as strong as January of 2025, if not stronger.

All right. Thanks.

Thanks for the time, everyone. I wanted to start on the natural gas segment.

Looks like Q4 results saw a decent benefit from gas marketing there. If you could talk about your intentions on how to manage that marketing space going forward, particularly in the back half of the year and into 2027, as we start to see diffs around Waha narrow significantly.

This is Tug. With respect to that space, we do have an open position on our natural gas capacity.

As far as managing that space long-term, if there's an opportunity to bundle with G&P deals, provide integrated solution for one of our customers, we'll evaluate that and contract that out long-term, and then the short-term will monetize that with any short-term opportunity or volatility. I'll pass it to Natalie.

I don't have too much to add other than remember, our Midland contracts are basically POP with fee floors. As that gas price strengthens, which has been kind of supported, I guess, you'll see the 4 Bcf or 4.5 Bcf that's coming online this year.

A stronger Waha basis, we'll get the benefit of that, too. As Tug mentioned, anytime we try to pair the capacity that we can sell, it's always paired with G&P.

):

Okay. Thanks for that color.

One more, if I can sneak it in, just a clarifying question on this Haynesville-Acadian expansion. Curious if you could just provide some more detail behind the project, like anything about the size.

Also curious what type of customer is really driving that expansion. Are these coming from public or private producers?

Thanks.

Hey, this is Natalie Gayden. That's an expansion of the gathering system.

Increasing treating and our reach, I guess you could say. It's a mix of privates and publics.

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Great. Thank you.

Hey, good morning, team. Thank you guys very much.

I appreciate it. Nice to be on here.

Maybe to follow up a little bit on the '27 conversation, just to talk to the texture of the '27 CapEx guidance. You had a few projects announcements this morning.

Can you speak to how much of that initial FY '27 CapEx is spoken for? Would new incremental project announcements represent incremental CapEx on that FY '27 range of $2 to $2.5 by chance?

I've got a follow-up.

Julien, this is Randy. The range that we threw out up to $2.9 billion, that includes some projects that we've got our sight on that we've not FID'd and not announced, I think we've got some leeway to fill up that $2.9 billion.

Again, as you heard on the call, with some of the growth that we're seeing, we're expecting to be at the top end of that range for 2026. For 2027, I think we're still in that range of $2 to $2.5.

Right. Exactly.

Excellent. Just clarifying '27 real quickly in terms of the EBITDA guidance itself, you're saying you expect double-digit growth here '26 versus '27, just to clarify here.

Just go for it.

Thank you for that. The clarification is our current expectation is that we would see EBITDA growth in the neighborhood of 10% 2027 over 2026.

Again, from 2025 to 2026, really just modest growth. Probably one other thing I would clarify from an earlier question with Spiro, I think what Jim said, there's a lot of ratability in our fourth quarter earnings just from a business standpoint, but I will remind you, fourth quarter and first quarter are seasonally stronger businesses, don't straight-line this.

Right. Absolutely.

Then just speaking of expansions on Bahia real quickly with the UJI with Exxon, can you talk a little bit about the opportunities there, especially as you think about volumes ultimately landing in the Mont Belvieu complex here? Just where could that go next as you think forward and next steps here?

Potentially incremental '27 CapEx onwards?

This is Justin Kleiderer. We're off on the expansion as backed by Exxon.

It is a UJI, Exxon has rights to make connections on the origin and destination front as they see fit, as Jim also alluded to. We executed 12 downstream agreements that speaks to the overall breadth of our relationship with Exxon.

It was a good transaction for Bahia, and I think it brings Exxon and Enterprise closer together, and we'll see where it goes from here.

All right, fair enough, guys. Best of luck.

Talk soon.

Hi, good morning, and want to revisit the 2027 commentary as well, if I can, Randy. 10% growth would be over $1 billion of EBITDA growth in just one year.

I was looking back, that'd be the fastest organic growth for the company really this decade. It sounds like a lot of that is from the LPG expansion and Neches River, but is there anything else you would highlight that's big and chunky, particularly in '27?

Then separately, I just want to make sure Bahia, as it's a UJI, that's treated on a net basis, right? That's not consolidated in your EBITDA or anything like that.

I tell you what, why don't we handle your last question first? Daniel, you want to take that?

Yes, the UJI will be proportionally consolidated, we will only report our share of that investment.

Got it.

Then, Keith, back on your earlier question, really, I would say across the board. If you start with our NGL segment, we've got another plant that will be coming up, processing plant that will be coming up in the Delaware later in the first quarter, you get a full year of benefit there.

There's another processing plant that we're looking to bring on in the Midland Basin at the end of this year that you get a full year benefit from in 2027. With the Oxy Rock acquisition that we made, you'll see more benefit from it in 2027.

If you think about then all the downstream that comes with that, and I'll go back: Frac 14, you would get a full year benefit of Frac 14; Frac 15, you will come in and get benefit from there as well as the incremental expansions on the acid gas. Then just think about all of that flowing downstream through Bahia pipeline into the fractionators and then into the distribution system and across the marine terminals.

This is Tug. I'll add as well, we'll have a lot of higher fees kicking in on our Acadian-Haynesville system as well.

That's helpful color. Thanks for that.

Had a quick follow-up on the NGL marketing. It's very strong quarter in Q4.

You almost matched a year ago when you had those very wide export arbs. What types of activities are driving strong NGL marketing in Q4, and what are your expectations for '26?

Do you see that as an area of upside?

This is Tug—we had a lot of storage opportunities. We had high utilization on our ethane export assets.

Just be a mixed bag of standard opportunities that they present themselves, we always capture.

Thank you.

Hi, good morning. Just one quick one here, and it might be a little early, but I'll take a shot either way.

Just thinking back to that Oxy gathering deal, do you see any potential for more of the same types of deals on the horizon given this recent M&A news in the upstream side, or do you kind of see inorganic spend as maybe lower priority now given the expected macro outlook this year?

This is Jim. I don't see as many girls on the dance floor as there used to be.

Okay.

Thank you to our participants for joining us today. That concludes our remarks.

Have a good day.