FIP - NASDAQ

Hello. Thank you for standing by. And welcome to FTAI Infrastructure Q1 2023 Earnings Conference Call. At this time, all participants on a listen-only mode. After the speakers’ presentation, there will be a question-and-answer session. [Operator Instructions] I would now like to hand the conference over to your speaker, Alan Andreini. You may begin, sir.

Thank you, Towanda. I would like to welcome you all to the FTAI Infrastructure first quarter 2023 earnings call. Joining me here today are Ken Nicholson, the CEO of FTAI Infrastructure; and Scott Christopher, the company’s CFO. We have posted an investor presentation and press release on our website, which we encourage you to download if you have not already done so. Also, please note that this call is open to the public in listen-only mode and is being webcast. In addition, we will be discussing some non-GAAP financial measures during the call today, including adjusted EBITDA. The reconciliations of those measures to the most directly comparable GAAP measures can be found in the earnings supplement. Before I turn the call over to Ken, I would like to point out that certain statements made today will be forward-looking statements, including regarding future earnings. These statements by their nature are uncertain and may differ materially from actual results. We encourage you to review the disclaimers in our press release and investor presentation regarding non-GAAP financial measures and forward-looking statements, and to review the risk factors contained in our quarterly report filed with the SEC. Now I would like to turn the call over to Ken.

Thanks, Alan, and good morning, everyone. This morning, we will be discussing our first quarter financial results and also providing an update on the latest developments at each of our business segments. For this call, I’ll be referring to the first quarter supplemental materials that were recently posted to our website. Before we get to the financials, I’m pleased to report that we will be paying our third dividend as a standalone company with our Board authorizing a $0.03 per share quarterly dividend to be paid on May 26th to the holders of record on May 15th. Now on to the financials. We posted a strong first quarter financially and continue to generate momentum across our portfolio. Adjusted EBITDA for the quarter came in at $30.1 million prior to corporate expenses, up sequentially from $9.5 million in the fourth quarter of 2022. In comparing our two most recent quarters, it’s important to remind everyone that our fourth quarter results included the impact of our Long Ridge Power Plant outage. That said, our adjusted EBITDA for the most recent Q1 was up meaningfully even after adjusting for the outage at Long Ridge. More importantly, during the quarter, each of our four segments made good progress in advancing their respective businesses and we are well positioned for substantial growth in 2023 in the years ahead. All in, we continue to target achieving this year a run rate of $200 million of annual adjusted EBITDA from our segments with no additional capital required to meet that target. In terms of the highlights of each segment, Transtar continues to be a substantial producer of cash flow for us with adjusted EBITDA coming in at $17.2 million for the quarter, up 27% from the fourth quarter of last year. At Jefferson, we began to handle volumes of refined products for export under our new contract with Exxon. Exxon completed the blade expansion in March, so we expect to see these volumes continue to increase in the quarters ahead. At Repauno, while the financial results reflected an adjusted EBITDA loss, the loss was largely a result of the forced sale of natural gas liquids in inventory that were required to be removed prior to commencing our new multiyear tolling contract on April 1st, with a new tolling contract in place, we expect Repauno to generate an operating profit going forward. And finally, at Long Ridge operations returned to normal after the fourth quarter outage and we recorded $11.3 million of adjusted EBITDA. All in, a very good quarter, setting the stage for continued growth ahead. Briefly on the balance sheet. We ended the quarter with $40 million of cash. In the aggregate, we had $1.3 billion of debt shown on the balance sheet at March 31, approximately $515 million of which is issued at or guaranteed by our holding company and approximately $750 million of which is issued on a non-recourse basis at the individual asset level. Our non-recourse debt is issued primarily at Jefferson at an extremely low interest cost, long duration with weighted average maturity of 14 years, ample flexibility to pay dividends with excess cash flow and not callable in the event of a sale. In short, we view the non-recourse debt at Jefferson is a valuable asset. I’ll spend a few minutes providing more details on each of our segments and then plan to turn it over for questions. Starting with Transtar on slide seven of the supplement. Transtar posted revenue of $41 million and adjusted EBITDA of $17.2 million in Q1, up from revenue of $35.8 million and adjusted EBITDA of $13.5 million in Q4 of last year. Both carload volumes and average rate per carload were higher for the quarter as U.S. Steel production at the Gary, Indiana and Mon Valley, Pennsylvania facilities returned to more normal levels with blast furnaces returning from temporary idling. Away from U.S. Steel, we also continue to make good progress on multiple initiatives at Transtar to drive incremental third-party revenue and EBITDA. We expect these programs to represent approximately $30 million of incremental EBITDA opportunities annually with little to no additional investment. Now on to Jefferson. Jefferson generated $19.1 million of revenue and $6.5 million of adjusted EBITDA in Q1, compared to $15.5 million of revenue and $4.5 million of EBITDA in Q4. Volumes for the quarter increased materially, both for refined products and crude oil, with total volumes averaging 163,000 barrels per day versus 102,000 barrels per day in Q4. The bulk of volume increases were attributable to the new Exxon export contract with the completion of Exxon’s $2 billion Beaumont refinery expansion in March, increasing Exxon’s refinery capacity by approximately 250,000 barrels per day to a total of 620,000 barrels per day. Exxon Beaumont is now the largest refinery in North America. While business grows at Jefferson’s Main Terminal, we also made solid progress on our recently acquired nearby property in Beaumont. We’re seeing multiple opportunities for the storage, transloading and export of renewable fuels and hydrogen-based products. And with Jefferson nearing full build-out, this site is an ideal extension for our business. We expect this new addition, which we refer to as Jefferson South to contribute incremental EBITDA as early as this year and to ultimately represent up to $50 million of opportunity for incremental EBITDA. Shifting to Repauno. We commenced on April 1st, our multiyear contract to transload natural gas liquids using our Phase 1 system. The contract, which is with one of the world’s leading trading companies has minimum volume commitments and does not expose Repauno’s commodity prices. In advance of commencing operations under the contract, Repauno sold in March its then existing inventory, recording a loss on the sale driven by depressed butane prices. While not ideal timing, it was necessary in order to commence a tolling contract and not something we expect to reoccur. With Phase 1 having commenced, Repauno is now focused on securing business for our larger Phase 2 tranloading system. As detailed on slide nine of the supplement, our Phase 2 system is expected to materially increase our storage and throughput capacity and when it comes online in a couple of years. In the aggregate, we expect Phase 2 to cost approximately $200 million to build and to generate in excess of $40 million of annual EBITDA once complete. We have demand for multiple international offtakers and our goal is to enter into long-term agreements with multiple parties in the coming months. Finally, moving on to Long Ridge. Long Ridge generated $11.3 million in EBITDA in Q1, up from an adjusted EBITDA loss of $6.6 million in Q4, which included the power plant outage that persisted for the bulk of the fourth quarter. Power generating capacity for Q1 was at 93% and gas production averaged 81,000 MMBtu per day in excess of the 72,000 MMBtu required for plant operations. As we look to the remainder of 2023, we expect both plant operations and gas production to be stable, while we progressed a number of initiatives to increase revenue and profits. In the near-term, we’re expecting final approvals in the coming months for the upgrade of the power plant to 505 megawatts, an increase of 20 megawatts from our current generation capacity. That will contribute incremental EBITDA in the range of $5 million to $10 million annually based upon current forward curves for the price of power. Over the longer term, we’re seeing increased interest from behind-the-meter customers, including data center developers and companies focused on energy transition opportunities. So to wrap up, we’re pleased with our start to 2023 and excited about the things to come in the year ahead. With that, let me turn the call back over to Alan.

Thank you, Ken. Towanda, you may now open the call to Q&A.

Thank you. [Operator Instructions] Our first question comes from the line of Giuliano Bologna with Compass Point. Your line is open.

Good morning and great to the recovery in transfer on Long Ridge this quarter. Starting off on the Transtar side. I’m curious if U.S. Steel was back up to full capacity now and related to the U.S. Steel topic, I’m curious if there’s any other business opportunities that Transtar to that into with U.S. Steel?

Yeah. Hey, Giuliano. Thanks. They are -- the blast furnaces -- all blast furnaces are back up and running and so operations there seem to be back to stable and normal conditions. That doesn’t mean for Transtar, there isn’t further opportunity for growth. Of course, U.S. Steel brings in raw materials and then ships out finished steel products. And they do that by three primary modes, rail, first and foremost, marine freight by barge, and then lastly, by truck. I think the biggest opportunity for Transtar is the conversion of truck to traffic today to rail. Rail is materially more efficient. We’ve been working with U.S. Steel on a handful of new opportunities where we think we can save them money and I definitely expect that we’ll realize some of those opportunities during the past of this year. So, yeah, certainly, opportunity probably 10% to 15% incremental revenue opportunity from our existing base through converting currently trucked freight to rail.

That’s great. And staying on the Transtar topic and where do you stand on the initial third-party business opportunities that you’re working on that you’re mentioning should drive roughly $30 million of incremental and…

Yeah.

… what’s the timing of some of those opportunities starting to roll in?

Yeah. I’d say it’s during the course of this year 2023, they are really in two primary categories. One is just third-party freight movements. We continue to open up transload facilities to stimulate some of that. Our most successful one to-date is up in the Detroit area on the Delray Connecting Railroad that’s doing very well. That itself just one transload facility will contribute at least $1 million of revenue this year, probably, up to $2 million. So we plan to open ideally dozens of transload facilities in the year ahead, so you get a sense for the impact of what that could have. Car repair is the other big component. We’ve got a big facility in Pittsburgh that is under construction and that will be opening midyear. We have an existing facility that needs some refurbishment, but down in the Texas area in Longview and that will be opening as well later this year. And so precise timing is probably roughly in the third quarter when those facilities are able to be opened up and start generating revenue. But you get a sense by the time we swing into the fourth quarter, we should be in a pretty good place for both third-party business and the incremental repair revenue.

That’s great. And I think, Ken, you’re still running back up, EBITDA trends are in the first quarter kind of before the outage we’re running, call it, $8.5 million, $90 million a quarter range with just the base U.S. Steel business and the $30 million, I mean, that would add, call it, $7.5 million a quarter. I’m curious, I thinking about your ability to get to $25 million a quarter or $100 million run rate by the end of the year?

Yeah. Feel good about it. Really, if we did nothing, no more third-party customers and no car repair. The year should be about $80 million of EBITDA for Transtar, $75 million to $80 million. We’re running today just taking the first quarter, if you just annualize the first quarter, it was about 70%. And I just think with normal growth, rate growth in the year ahead and some small additional volume growth, the full quarter effect of all the blast furnaces being operating and what have you, that should be $75 million and probably closer to $80 million of EBITDA. So bringing in the car repair and third-party business incrementally to that, we should be at an annual level of $100 million to $110 million or your $25 million plus per quarter by the end of the year.

That’s great. And okay, where is the opportunity -- on the switching topics a little bit to Long Ridge, where is the application stand for the incremental 20 megawatt operating opening up to 55 megawatts?

It is scheduled to be approved in either July or August of this year. We’re obviously rooting for July, because there is no incremental cost to that upgrade and the additional power revenue largely drops to the bottomline. Obviously, there’s a little bit more gas that’s needed to be produced or purchased in order to generate the additional megawatts, but we would be at the high end today of the $5 million to $10 million of incremental EBITDA. So call it $10 million of EBITDA starting in July or August. We have half of that, of course, on our own P&L. So it would add $5 million to the Long Ridge numbers starting in the third quarter.

That’s great. And I’m curious where things stand or to the prospects of behind-the-meter customers and if there are any…

Yeah.

… active discussions ongoing at the moment?

We’re always in active discussions. I would say those are longer term projects. We obviously have new light that will be commencing construction on the facility late this year. We have a handful of other very large prospects. These are prospects at each of which would require -- I mean, frankly, they require 500 megawatts of power. They’re significant. They are primarily focused on the data center space. There is data center developers today are with the advent of ChetGPT AI and what have you and the demands for power, there is a significant rush to new data center capacity and some of the bigger players in the space are accelerating their development plans. We’re in a dialogue with all of the major players. There’s one in particular who is closer, and again, the numbers are pretty significant. Those tend to be longer term developments. And so our goal, of course, is to sign up an additional opportunity in addition to new light at some point in the next three months to six months and then, typically, that would be a one-year to two-year build before we start actually seeing the revenue from that project. But, obviously, it’s incredibly valuable once you have it in place.

That’s great. And when I look at Long Ridge you’re at $11.3 million for EBITDA this quarter and that incremental, call it, $5 million, you are saying, 50% interest would get you up to, call it, $12.5 million per quarter. I’m curious what the drivers are to get to $15 million a quarter or $60 million a year run rate for a Long Ridge?

Yeah. It is one or two things. It’s either as we just discussed, the additional behind-the-meter customers that may take some time, but the path to that annual $60 million would definitely be there. Otherwise, it’s capacity auctions. Capacity auctions have been down materially over the past couple of years, way off market. If they return to normal, that alone basically gets us close to that $60 million. It’s just been an incredibly weak, the capacity auction market has been incredibly weak from our perspective. And meaning capacity revenues are well below where they have traditionally been. That swings back in our favor then I think we’re right there next year with the $60 million annual run rate.

That sounds good. And then switching over to Jefferson. Is the blade project with Exxon fully ramped up at this point, and if it’s not, I am curious you guys know what the exact time line is to reach full capacity?

Yeah. I would say every month is growing. We averaged 163,000 barrels per day in the first quarter. This quarter to-date, second quarter to-date, which we’ve really had largely one month behind us, we’re in excess of 200,000 barrels. And so just to give you a sense for the momentum, we have capacity to handle in excess of 350,000 barrels per day. So we still have plenty of capacity. But, yes, we’re definitely seeing increased volumes as we’re swinging into the second quarter here and the trend line is very encouraging. I would say there’s still excess capacity, and Exxon, as I said in my comments, it’s the biggest refinery in North America, frankly, the Western Hemisphere, and so there’s still plenty of additional opportunity. We have the capacity to handle it. But I like the momentum and the current run rate and like what we saw in April.

That’s great. And then I’d be curious if you can just expand on Jefferson South and if you can disclose how much you pay for land and if there’s any CapEx related to Jefferson South that is expected in the near-term?

Yeah. The -- I’ll describe it a little bit. It’s a significant site. It’s about 600 acres in total. We paid less than $25 million for the site. It has two existing tenants that are major players and has about 200 acres available for development. It’s on the other side of the river from Jefferson’s Main Terminal. The two tenants, there are some minor freight movements for the two tenants, but we do provide services to the tenants. So there are really no net operating expenses for the site. So it doesn’t impact owning that site, doesn’t really generate incremental revenue or it certainly doesn’t generate any incremental EBITDA for us, but represents a significant development opportunity. There is no CapEx that is required just to maintain the site. Like we’ve done at Repauno, we will not invest capital into that site until we have a contract that justifies doing so. I do think in the coming months we will be executing our first contract with a third-party for some transloading business. That will be the first of a handful of opportunities. We acquired this site with a set of opportunities that we had underwritten and are now pursuing and seeking to secure. Again, I think, we’ll have one year in the relatively near-term. It will represent somewhere between $5 million and $10 million of incremental EBITDA and probably a $30 million to $40 million capital investment. But, again, we won’t be investing any capital until we’ve secured business.

That makes sense. And then, I guess, it would be great if you could provide a bridge from where you are now from an EBITDA perspective to -- at Jefferson to reaching the $80 million or so per year run rate?

Yeah. Yeah. Yeah. Yeah. The simple way to think of it is, incremental volumes, assuming the same rate per barrel, obviously, generate incremental revenue and our expenses are largely fixed and so those incremental revenue dollars drop straight to the bottomline. Just to put it though in context, as I said, we moved 163,000 barrels per day in the fourth -- in the first quarter on average at an average rate of $1.30 per barrel. That $1.30 is a bit of a mix up, there’s some storage revenue, there’s throughput revenue and we are going to just try to keep it simple. So $160,000 at $1.30 per barrel, generating about $19 million of revenue and $6.5 million of EBITDA. We have capacity to handle, as I said, 350,000, up to almost 400,000 barrels per day. If you just double capacity, however, take the $165,000 that we did in the first quarter to about $300,000 and hold the same rate per barrel of $1.30, you’ve basically gotten right there to the $80 million run rate. You generate about $20 million of EBITDA in the quarter, because a significant portion of the expenses are fixed. They don’t grow with that volume growth and you’d be generating about $19 million to $20 million in the quarter. As I said, the $163,000 for the first quarter is less than where we’re currently running. We see significant positive momentum. So the path to getting to that 300,000 barrels per day plus is a process, it is a path, but I like the momentum. We’re running north of 200,000 barrels per day. So we’re on our way. I think it takes the bulk of the second quarter, ultimately, to get there at some point in the third quarter, we swing into that kind of level.

That’s very helpful. And then switching over to Repauno. I’d be curious where EBITDA should go, now that the contract went -- the new butane contract went live on April 1st. I realize it’s probably will be the transition during the first quarter of the contract went live. I’m curious where the quarterly or annual run rate should be?

Yeah. Well, our target for Phase 1 is $10 million -- the $10 million of annual EBITDA. The contract in place is for about two-thirds of our total Phase 1 capacity. So if you just assume that single contract, it’s probably closer to $5 million of annual EBITDA. The incremental capacity that’s available for Phase 1, which is something we expect to secure here in the second quarter, we’d get you to about the $10 million annual run rate. Obviously, the first quarter was not -- it was a little bit frustrating. We had to spend a little bit of money to get ready for the new contract. We had to sell some inventory, market timing was unfortunate there. That is behind us. But with the existing contract in place, it’s -- we’ll certainly be in the black. And if we can secure additional volumes to use all the capacity to Phase 1, we should be hitting, I would say, in the second half of this year, $2.5 million per quarter or $10 million annual run rate.

That’s great. And then I’d be curious where you are on the prospects for securing the two sides for Phase 2. And if there is…

Yeah.

And if there’s any CapEx at Repauno other than the Phase 2 build-out?

Yeah. No additional CapEx at Repauno. We’re done outside of what would be Phase 2. Everything’s working extremely well and there’s no need for additional capital other than the Phase 2 expansion. We have a handful of folks, all very large international players that were in a dialogue with about volumes for Phase 2. I’m glad you asked the question the way you did, because it’s not just offtake that we’re seeking. It is supply on the one side and then the offtake on the other side. Frankly, it’s less us seeking that it’s more the offtaker. The offtaker is securing volumes of butane and propane from the Marcellus and Utica and then they are, of course, securing their own offtake in the European and African markets. I would say we’re very close with one brand name, very well-known player, and that’s been several, several months of dialogue and back and forth. We have two others that are close behind. Look, these are massive institutions. They typically don’t move terribly quickly. They’re very thoughtful, of course, because they’re committing to five years to 10 years of a supply chain. But I’m confident we’ll get at least one of these guys to sign up in the coming months. And I think all we need is one. Once we have one, we’ll commit to the project and go ahead and finance it and start construction. It’s ready to go. It is permitted, engineered, ready to go. We just want to make sure we have the contract in hand before we commit the capital.

That’s great. And then kind of switching right on the assets or the specific assets. I’m curious when you think the company will be in a position to start paying down debt and reducing leverage.

We’re targeting that for later this year. At this point, we have better uses for our capital, look, our cost of debt capital is relatively high. But at the same time, right now, the way our securities work, the cost to prepay that debt is also relatively high. We have pretty attractive uses for our free cash flow. So I don’t necessarily see us using cash to repay debt at some point this year. That’s something that would start making sense as we swing into the fourth quarter and swing into 2024. The ultimate plan would be by the time we get to mid-2024, we’re in a position to refinance the entire balance sheet, and that, I think, will be a highly accretive thing to do at lower rates with a lot of excess cash. We’re really a very different company, a very different credit profile and what have you, when we’re generating $200 million of EBITDA annually. And so we’ll have the ability to refinance our debt at lower prices in the summer of next year. Maybe we’ll take advantage of things if we have the opportunity to prior to that, I’d love to. But I do think any refinancing we do should be a highly accretive thing when we ultimately do it.

That’s very helpful. And looking across the Board, are you looking at any other M&A or JV opportunities at the forming assets at this point?

Yeah. I -- the answer is, yes. We’re always looking at stuff. There are a handful of opportunities in the ports and terminals sector that we’ve been looking at. Those tend to be a little bit more spotty. We’re primarily focused on opportunities in energy terminals, leveraging some of the relationships and the platform that we have today with Jefferson and Repauno. I’d say the most recent pickup in activity is definitely on the rail space. It was very quiet last year. We’re starting to see a pickup in opportunities. I’m thrilled we own Transtar, of course, because it’s a phenomenal platform for acquisitions. And yes, we’re definitely seeing more opportunities in the rail space and that’s a nice thing. Nice tuck-in opportunities or some that are slightly more chunky but highly complementary with Transtar. So we’re always looking at stuff, and yeah, I’m pleased that we’re seeing a little bit more liquidity or fluidity in the M&A market and expect that to last for the bulk of 2023.

That’s great. Yeah. Thank you for -- yeah, answering, yeah, a number of questions and let me monopolize the Q&A there definitely [ph], but I appreciate all the answers and I will jump back in the queue. Thank you.

No problem. Thanks very much.

Thank you. I’m showing no further questions in the queue. I would now like to turn the call back over to Alan.

Thank you, Towanda, and thank you all for participating in today’s conference call. We look forward to updating you after Q2.