Genesis Energy, L.P.

Greetings and welcome to the Genesis Energy fourth quarter 2025 earnings conference hall webcast. At this time, all participants are in listen-only mode. A question and answer session will follow the formal presentation. You may be placed in the question queue at any time by pressing star one on your telephone keypad. As a reminder, this conference is being recorded. If anyone should require operator assistance, please press star zero. It's now my pleasure to turn the call over to your host, Dwayne Morley, Vice President, Investor Relations. Please go ahead, Dwayne.

Good morning, and welcome to the 2025 fourth quarter conference call for Genesis Energy. Genesis Energy has three business segments. The offshore pipeline transportation segment is engaged in providing the critical infrastructure to move oil produced from the long-lived Ross Reservoir from the deepwater Gulf of America to onshore refining centers. The marine transportation segment is engaged in the maritime transportation of primarily refined petroleum products. The onshore transportation and services segment is engaged in the transportation, handling, blending, storage, and supply of energy products, including crude oil and refined products, primarily around refining centers, as well as the processing of sour gas streams to remove sulfur at refining operations. Genesis's operations are primarily located in the Gulf Coast states and the Gulf of America. During this conference call, management may be making forward-looking statements within the meanings of the Securities Act of 1933 and the Securities Exchange Act of 1934. The law provides safe harbor protection to encourage companies to provide forward-looking information. Genesis intends to avail itself of those safe harbor provisions and directs you to its most recently filed and future filings with the Securities Exchange Commission. We also encourage you to visit our website at genesisenergy.com where a copy of the press release we issued this morning is located. The press release also presents a reconciliation of non-GAAP financial measures to the most comparable GAAP financial measures. At this time, I would like to introduce Grant Sims, CEO of Genesis Energy LP. Mr. Sims will be joined by Kristen Jesselitis, Chief Financial Officer and Chief Legal Officer, Brian Sims, President and Chief Commercial Officer, and Louie Nichol, Chief Accounting Officer. And with that, I'll now turn the call over to Grant.

Thanks, Dwayne, and good morning to everyone. Thanks for listening to the call. As noted in our earnings release this morning, our fourth quarter results came in slightly ahead of our internal expectations as our offshore pipeline transportation segment saw strong growth driven by steady base volumes, a full quarter of volumes from Shenandoah well above its minimum volume commitment, along with continued ramping volumes from Salamanca. Our marine transportation segment returned to a more normalized level of operating performance as our refinery customers increased runs of heavy crude oil, which drove higher volumes of intermediate black oil available for transport. In addition, the transitory market conditions and supply pressures that impacted our blue water fleet last quarter now appear to be behind us, all of which should provide for a constructive outlook for our marine segments as we look ahead. The strategic actions we took in 2025, combined with the strong operating performance from our underlying businesses and new offshore volumes, enabled us to exit the year with effectively zero outstanding under our $800 million senior secured revolving credit facility at the end of the year after giving effect to cash on hand. With ample liquidity, and an increasingly clear line of sight ahead of us, the board made the decision to increase our quarterly common unit distribution to 18 cents per unit, representing a 9.1% increase year over year. Furthermore, Just last week, we opportunistically purchased an additional $25 million of our corporate preferred units in a privately negotiated transaction. Taken together, these actions demonstrate our disciplined approach to capital allocation. As we look ahead to 2026, and assuming our other businesses perform as expected, the Genesis story at this point is largely a deepwater Gulf of America growth story. Based on our ongoing discussions with our offshore producer customers and the conversations we have with them during their year-end budgeting cycle, we have been provided with lots of information, including expected production volumes for 2026 and beyond, along with current and future expected drilling schedules. We were also notified of certain planned and routine turnarounds they have scheduled for 2026, a couple of which will take place at production facilities where we handle the hydrocarbon molecules more than once, and thus can be more financially impactful. While we benefited from no significant turnarounds in 2025, these are absolutely normal and customary, and in some cases, unfortunately, they can last upwards of 30 to 45 days each. These are their plans, and as I believe everyone can appreciate, We ultimately do not control our customers' operations, nor the precise timing of them drilling, completing, and bringing new high-impact wells online. We fully understand that plans and schedules offshore change. Deepwater drill ship schedules change. Weather throughout the year changes. Plan turnarounds can be delayed or extended for a variety of reasons outside our control. What is important, though, is that despite all of this, And a heavier than normal recurring dry docking schedule, which we'll go into more detail in 2026, we still reasonably expect to deliver sequential growth in adjusted EBITDA of plus or minus 15 to 20% over our normalized 2025 adjusted EBITDA of approximately $500 to $510 billion. We obviously hope to exceed the top end of that range in 2026. And quite frankly, we could easily make a case for such an outcome. To the extent our actual results differ in any significant way, we would simply view that as more of a timing issue, with ultimate cash flows just sliding to the right, rather than any fundamental degradation in the long-term cash flows expected from the fields contracted to access our offshore infrastructure. You know, even if certain offshore activity slips to the right, 2027 should be meaningfully stronger than 2026. based upon our producer customers' current development plans that we've seen. And as a result, the opportunities available to us in 26 become even more compelling in 2027 and beyond. With that, I'll go into a little more detail on each of our business segments. As noted in our earnings release, our offshore pipeline transportation segment delivered another quarter of strong sequential growth, with both segment margin and total volumes increasing across our chops and Poseidon pipelines, rising approximately 19% and 16% respectively versus the third quarter, marking the third consecutive quarter of sequential improvement. In fact, from the first quarter to the fourth quarter of 2025, segment margin increased by roughly 57%, with total volumes across both systems growing approximately 28%. These results were driven by steady volumes from our legacy fields, strong contributions from Shenandoah, and a continued ramp-up in volumes from Salamanca. During the quarter, volumes from the Shenandoah FBU remained steady as the facility continued to operate at or near its 100,000-barrel-per-day target rate from four Phase I wells. At Salamanca, volumes continued to ramp from its first three wells, and we remain encouraged by both reservoir performance and the remaining development plans. An additional well at Salamanca is scheduled for completion in this second quarter, with the potential for a fifth well as early as the fourth quarter. Together, these wells are expected to result in total production of 50,000 to 60,000 barrels a day per day from the Salamanca production facility. Looking ahead, we expect the monument development a two-well subsea tieback to Shenandoah, to be completed and flowing through our facilities by late this year, certainly early 2027. Following Monument, a fifth well at Shenandoah is scheduled to be drilled, which could increase total throughput across the Shenandoah FPU to as much as 120 KVD, with potential upside of an additional 10,000 to 20,000 barrels per day in early 2027. In addition to the five development wells between Salamanca and Shenandoah, We're aware of at least eight additional development or subsea tieback wells at legacy production facilities served exclusively by our pipeline infrastructure that are planned to be drilled over the next 12 to 15 months. Taking together, this activity underscores that producers in the Gulf of America continue to prioritize long cycle, high return deep water developments. We remain actively engaged in commercial discussions around future tieback and development opportunities that can access our offshore systems as projects are sanctioned. Given the competitive economics and long planning cycles associated with these developments, we do not expect near-term commodity price volatility to materially impact offshore development activity in the Gulf. As we look beyond 2026, we would be remiss not to highlight the results of BOEM's most recent lease sale, Big Beautiful Gulf One, or BBG1, which was held on December 10th, 2025. The outcome of this sale further reinforces our view, and that of the broader upstream industry, that there remains strong long-term interest in the central Gulf of Mexico. BBG-1 generated over 300 million in high bids for 181 tracks covering approximately 1 million acres in federal waters, with roughly 65% of the acreage located in the central Gulf of Mexico. When combined with lease sales 259 and 261, which took place in March and December of 2023, respectively, more than 4.4 million acres have been leased in federal Gulf waters over the past three years. Approximately 2.4 million acres, or 53% of the total, which are located in the central Gulf, where our offshore plant land infrastructure is located and has existing capacity. The breadth of current development activity, the scale of recent lease sales, and the long cycle nature of deepwater investment all underscore our conviction that the Gulf of America remains a world-class basin with decades and decades of existing inventory. We believe Genesis is uniquely positioned as the only truly independent third-party provider of crude oil pipeline logistics in the region, offering producers with flow assurance, and downstream market optionality along the Gulf Coast. Our differentiated asset footprint, deep customer relationships, and decades of existing and future inventory ahead position us for continued growth and decades and decades of opportunity in this world-class basin. Our marine transportation segment returned to a more normalized level of operating performance during the quarter. Market conditions across both our brown water and blue water fleets stabilized as refinery runs of heavy crudes increased and broader equipment utilization improved. Demand for our inland or brown water fleet recovered as Gulf Coast refiners responded to the widening of light to heavy differentials and increased runs of heavy crude oil, which allowed the supply of intermediate black oil needing to be transported to return to more normalized levels. Looking ahead, we remain optimistic that our marine transportation segment could benefit over time from additional volumes produced in the Gulf of America and incremental crude imports into the Gulf Coast, including volumes from Canada, the resumption of exports from Kirkuk, Iraq, and the potential for additional volumes from Venezuela should they all materialize. At a minimum, all of these additional heavy or medium sour volumes showing up on the Gulf Coast should cause heavy to sour differentials to continue to widen, providing refiners the incentive to process increasing volumes of heavier crudes. To the extent these additional heavy volumes come to fruition, this should result in additional intermediate refined product volumes that need to be kept heated and moved from one refinery location to another, which should drive demand for our inland heater barges, providing a constructive backdrop for increasing rates as we move through the year and into next year. Recent commentary from Gulf Coast refiners would reaffirm they are, in fact, starting to see additional heavy sour discounts as additional volumes arrive on the Gulf Coast. To quote from Valero's recent earnings call, looking at differentials, not only with Venezuela, but we've had several beneficial factors that have occurred to kind of help move this market weaker. After last year with discounts fairly tight, most of these market moves are making differentials increasingly favorable for refiners with high complexity refiners such as ours. We are pushing to maximize heavy crude processing in the system going forward with better differentials, end quote. Meanwhile, conditions in our blue water fleet have normalized as incremental capacity that migrated from the west coast to the gulf coast and mid-Atlantic trade lanes has largely been absorbed by the market. As we noted in our earnings release, 2026 is expected to be a higher maintenance year for our blue water fleet, with four of our nine offshore vessels scheduled to undergo regulatory dry dockings in the first half of the year. These planned shipyard periods will temporarily reduce vessel availability and may mute the near-term benefit of any improvement in day rates. Importantly, however, we expect these vessels to reenter the market against a more constructive backdrop and be well positioned to recontract at day rates that are consistent with or modestly above their current levels when they exit the shipyard. In addition, the American Phoenix remains under contract through early 2027. Based upon prevailing market rates for comparable assets, we would expect the American Phoenix to recontract at a higher day rate in our current charter when that contract expires. Overall, we remain confident in the long-term fundamentals of the marine transportation sector. With effectively zero net new supply of our classes of Jones Act vessels and the high cost and long lead times required to construct new equipment, the market remains structurally tight. As demand continues to improve across both our brown and blue water fleets, We expect our marine transportation segment to deliver stable to modestly growing contributions in the years ahead. Our onshore transportation and services segment performed in line with our expectations during the quarter. Throughput volumes continued to increase across both our Texas and Raceland terminals and pipelines as new offshore volumes ramped and moved onshore through our systems. Our legacy refinery services business also delivered results largely consistent with our expectations. As we have mentioned in the past, our refinery services business has faced certain structural headwinds over the past several years. Specifically, we have been supply constrained, in part because refineries moved to run more light sweet crudes as a result of the shell revolution over the last 10 to 15 years. As shell production is peaking, and or the gas-to-oil ratios are increasing from the shell plays, and as the heavy showers we mentioned above are returning to the Gulf Coast, we believe we should have the opportunity to make more NASH, or sodium hydrosulfide, at several of our existing facilities in future periods. We, generally speaking, can sell every ton we make, and we look forward to restoring some of our supply flexibilities. As our financial performance continues to strengthen over the coming years, and we generate increasing amounts of free cash flow, we will continue to reduce debt in absolute terms, redeem our high cost corporate preferred securities, and thoughtfully evaluate future increases in our quarterly distributions to common unit holders over time. Importantly, We will pursue these objectives while maintaining the flexibility to evaluate future organic and inorganic opportunities as they may arise. Finally, I would like to say that the management team and the board of directors remain steadfast in our commitment to building long-term value for all of our stakeholders, regardless of where you are in the capital structure. We believe the decisions we are making reflect this commitment and our confidence in Genesis moving forward. I would once again like to recognize our entire workforce for their individual efforts and, importantly, unwavering commitment to safe and responsible operations. I am extremely proud to be associated with each and every one of you. With that, I'll turn it back to the moderator for questions.

Thank you. And I'll be conducting a question and answer session. If you'd like to be placed in the question queue, please press star 1 on your telephone keypad. A confirmation tone will indicate your line is in the question queue. You may press star 2 if you'd like to remove your question from the queue. One moment, please, while we poll for questions. Our first question today is coming from Michael Blum from Wells Fargo. Your line is now live.

Thanks, Zach. Good morning.

Morning, Michael.

Bill, I wanted to start with the guidance for 2026. You know, if I simplistically just annualize Q4 25 EBITDA and compare that to the midpoint of the 26 guidance, there's a delta there of call it 35 to 40 million. So I'm wondering if you can just give us a rough ballpark for how much of an EBITDA deduct you're assuming for typical hurricane disruptions and then the higher than typical marine maintenance, because if I just remove those, you know, and don't even assume volume growth, which in the offshore, which I'm sure you'll have, just wanted to get a sense of, like, where the low in the guidance could come. Thanks.

Yeah, no, I mean, it's a good question, and as we basically tried to explain, we think that we're being conservative, especially based upon the some of the things that we've been told by our producing customers. But, again, yeah, we are assuming 10 days' worth of anticipated downtime for, in essence, treating the third quarter as an 82-day quarter instead of a 92-day quarter for our offshore business. We probably – net expect a $5 million to $10 million reduction on segment margin line, if you will, from the heavy dry docking schedule on the marine side. So, you know, I think that, you know, as I said in the commentary that I just gave, that we fully expect and we can make a case that we can comfortably exceed it. But, you know, we're – the only reason that we're not, you know, pulling out a larger number, the primary reason is basically just taking into account that things can happen beyond our control and try to emphasize to make sure that everybody understands that it's really just a timing and recognition of the future cash flows out of the Gulf of Mexico and has nothing to do with structural issues or subsurface issues. So hopefully it will turn out to be a conservative range that we throw out.

Great. Appreciate that. And then on capital allocation, I really have like a two-part question. First, can you just remind us where you'd like to take the leverage ratio and what time frame you think you'll get there? And then as it relates to distribution growth, how do we think about the cadence of increases going forward? Is this something you'll be evaluating, you know, once a year every fourth quarter? And will the growth in EBITDA, is that a good proxy for how we should think about growth in distribution?

Well, you know, I mean, again, on a bank-calculated basis, I think at 1231 it was 5.12. So as we continue to use our increasing amounts of free cash flow to pay down debt in absolute terms at the same time that we're seeing an increase in our calculated LTM EBITDA, you know, I think that in essence it's – ratios are going to improve because we're paying down the numerator while at the same time the denominator is increasing. Our long-term target has always been in the neighborhood of four. Again, we have a pretty clear line of sight on it. Assuming that everything holds up and the producers do, the quicker they do things, the quicker that we'll hit those targets, but there's pretty obvious that we can get there. So depending upon, you know, that performance dictates the time schedule under which we get there. Relative to distribution growth, it's something that the board discusses every quarter. There is no hard and fast program that, in essence, we can talk about at this point. But I do think that it's – It's clear that the board is committed, as are we as a management team, to kind of an all of the above approach. As we said, we were also successful in negotiating a redemption of another tranche on a negotiated basis of the outstanding corporate preferred. So, you know, we will evaluate it on a quarterly basis and, you know, let the market know how our – how things are going at that point in time, so.

Thank you.

Thank you. Next question today is coming from Wade Suki from Capital One. Your line is now live.

Thank you, operator, and good morning, everyone. Appreciate you all taking my questions. Just wanted to, the question I've probably asked of you guys before, But, you know, repetition is always a good teacher. But wondering if you might be able to sort of revisit how you think about potential opportunities to pick up, let's say, the remaining interests in some of these offshore systems that you have, you know, how that might fit with your longer-term priorities and, of course, appreciate any insight you might have there or, how the counterparties might be looking at it. But, yeah, to the extent you could sort of clarify or revisit that for us, that would be great. Thank you.

Well, you know, again, we're not going to comment in one form or another as you would expect on the potential for M&A activity or other things. I mean, obviously, you understand from our enthusiasm that we very much – like our existing position, to the extent that, you know, from an ownership position it would be possible to increase that exposure, that's something that we would be very comfortable with. But, you know, as I want to point out, and you mentioned repetition is a good thing, that we have substantial existing capacity on our two major pipelines, the 64% owned and operated Poseidon Pipeline and 64% owned and operated CHOPS Pipeline. And so we are in a very comfortable position and arguably an enviable position that depending upon developments in the right place that we could have, you know, substantial increases and see substantial increases in segment margin and basically flowing to the bottom line in terms of incremental EBITDA you know, without spending any capital. So, you know, it's a good runway of continued opportunities in the central Gulf that we think that we've positioned ourselves for.

No, no question. Appreciate that, Colin. Just switch gears a little bit. I think I know the answer here, but obviously some M&A among a customer or maybe soon to be two customers. Just wondering if you could sort of speak to, you know, impact, expectations. I would expect some maybe acceleration potential, but any kind of longer-term impact you might see from that would be great. Thanks again.

Can you repeat it? I'm sorry, I didn't quite fully understand the question.

No, I was asking about some of the consolidation we've seen among your customers in the Gulf. And I think there's soon to be one more possibly. So just wondering what the implication might be for you all longer term. I imagine positive acceleration and whatnot, but love to hear your thoughts on that.

Yeah, it's a very good question. And I think that, you know, it A transaction just closed yesterday, which was basically Harbor Energy out of the UK closed on the acquisition of Log. Log is obviously an extremely important customer of ours. To the best of my knowledge, we actually moved 70% of Log's operated production through our pipelines, with most of it, those coming through, or the large portion of that coming through our SACO lateral and then downstream transportation, which is 100% on the downstream transportation or 64% on the sideline. It is in the public domain, as Harbor said, that is their intent to double that production from the asset base that they're acquiring in the log acquisition to double that between now and the end of 28. So that's a positive read-through on banks. So If anything, we view that as an extreme positive of a large, significantly large public company acquiring a private company and with the full intent of doubling its production over the next two years is a very good outcome for us, especially given our existing relationship with law.

Perfect. Thanks so much. Appreciate it.

Thank you. Thank you. Next question today is coming from El Paso, from RBC Capital Markets. Your line is now live.

Hey, good morning, everyone. I just wanted to go back to the guidance. And can you maybe provide a little more detail around, you know, what specifically are you embedding in offshore for Salamanca and Shenandoah? And you also mentioned kind of, you know, the development. of eight additional tieback wells planned at legacy facilities? Like, is any of that in your 15 to 20% guidance? I'll stop there, then I have some follow-up.

Yeah. I mean, basically, Elvira, again, yes, based upon what we've been doing, able to ascertain in terms of talking to our producer customers that we are extremely comfortable that we will meet or achieve the 15% to 20% off of the baseline that we talked about. And again, we are trying to set expectations to under-promise and over-deliver on a prospective basis, but to make sure that to reemphasize that to the extent that there's any failure to achieve overperformance is really just a timing issue and not an underlying ultimate value consideration. So that's the approach that we're taking as opposed to formal guidance. It's more of an informal guidance that – we could easily construct a case, as I said, of the prepared remarks based upon what we know to significantly exceed that range that we just threw out there.

Okay, great. And then just going back to the dry docking, I think you said the expectation there was $5 million to $10 million kind of impact to margin. Is there an impact to maintenance capex on that?

Yes. I think we made reference to it in the earnings release itself, but because of that, yes, we would expect this to be a heavier maintenance capital year than we experienced in 2025.

Is there any quantification of of the impact that you can provide?

I think in generally speaking that if you looked at a $15 to $20 million increase, that would be within the ballpark.

Okay, great. And then just one last question for me. You mentioned how the refineries are increasing runs of heavier crude and importing more Venezuelan crude. What do you think? How much incremental inland barge utilization could this drive, you know, this year?

Well, utilization has remained fairly high, but as the, which is the necessary condition before rates start going up. So, as we anticipate whether or not, you know, we gave a specific example of Valero, but P66 and others have also mentioned it, that as we see more and more of the heavies run, whether or not it's Venezuelan or incremental Gulf of Mexico medium sours or other imports of Canadian and other things, that the total black oil pool or the total supply of intermediate refined products, which were specifically designed to do, will go up. And so in an already, in essence, close to 100%, if not practically 100% utilization world, we anticipate being able to move prices up, day rates up, as we progress through this year and on into next.

Great. Thank you very much.

Thank you. Thank you. We reach the end of our question and answer session. I'd like to turn the floor over to Grant for any further closing comments.

Well, as always, I appreciate everybody listening in, and we look forward to the delivering more good news as we progress through 26. So thank you very much.

Thank you. That does conclude today's teleconference webcast. We just connect your line at this time and have a wonderful day. We thank you for your participation today.