Good day, everyone, and Welcome to the PBF Energy Q3 2026 Earnings Conference Call and Webcast. At this time, all participants have been placed in a listen-only mode, and the floor will open for questions following management's prepared remarks. If anyone should require operator assistance during this conference, please press star zero on your telephone keypad. Please note this conference is being recorded. It is now my pleasure to turn the floor over to Colin Murray of Investor Relations. Sir, you may begin.
Thank you, Jeannie. Good morning and welcome to today's call. With me today are Matt Lucey, our President and CEO, Mike Bukowski, our Senior Vice President and Head of Refining, Joe Marino, our CFO, and several other members of our management team. Copies of today's earnings release and our 10-Q filing, including supplemental information, are available on our website. Before getting started, I'd like to direct your attention to the safe harbor statement contained in today's press release. Statements expressing the company's or management's expectations or predictions of the future are forward-looking statements intended to be covered by the safe harbor provisions under federal securities laws. Consistent with our prior periods, we'll discuss our results, excluding special items, which are described in today's press release. Also included in the press release is forward-looking guidance information. For any questions on these items or other follow-up questions, please contact investor relations.
I'll now turn the call over to Matt Lucey.
Thanks, Colin. Good morning, everyone, and thanks for joining our call. Q3 earnings speak for themselves. We intend to convert those earnings into lasting improvements in our business. The company reduced net debt by more than $1.2 billion during the quarter and by more than $2 billion this year. As Joe will detail, our balance sheet transformation has put the company on its strongest financial footing since our formation. Over the last seven years, markets have become increasingly volatile, with shorter cycles, as evidenced by the three once-in-a-generation events over that period. Prudence dictates a deeper balance sheet to navigate this new reality. The company's focus is to execute. Execute our base business and do so efficiently. Importantly, through our business improvement initiatives to improve the competitive positioning of each asset we own. Extract incremental profitability through all cycles, up or down.
We are investing our assets to improve utilization, reliability, and yields, which will translate into stronger through-the-cycle cash flow and make our system more resilient. By executing well on these priorities, we will maximize the resilience of our system, create greater long-term shareholder value, and increase our ability to return capital to shareholders. Turning to the market, the biggest disruptions to the oil market have materialized in the availability of refined products. The disruptions have coincided with what was an already structurally tight refining market. On the crude side, the market has adapted reasonably given the circumstances. Flows through the Strait of Hormuz have recovered to roughly 3/4 of pre-war levels, with some recent weekly reports higher. But product flows remain well below pre-war levels. Recently, the dramatic increase in freight rates has really put pressure on the Asian refiners.
Freight, coupled with rising natural gas costs overseas, is raising the cost to run international capacity. Headwinds that U.S. refiners are less exposed to due to our shorter transit times and abundant domestic supply of natural gas. Freight dynamics, paired with growing production of heavy crudes, has widened the light-heavy differentials. PBF's crude slate flexibility and close proximity production is a real tailwind going into the Q4 for our cost of crude. The freight realities raised the bar for delivery of imports needed in our product-short coastal markets. PBF sells the majority of our products domestically, thereby avoiding costly transits. The story on products remains a supply story. More than 5 MMbpd of global capacity is offline, a portion of which with physical damage. With global inventories roughly 500 million bbl below pre-war levels, there is essentially zero cushion in the system.
Policy responses can be helpful on the margin. However, at the core, the world is simply short refined products. Benchmark cracks reflected the tightness. The New York Harbor 2-1-1 averaged nearly $65 a barrel in the Q3, compared with about $26 a year ago. Nowhere are current product dynamics more clear than our coasts, which are structurally short refining capacity and dependent on imports. California alone imports roughly 250,000 bbl a day of gasoline, about 30% of its demand. The situation reinforces a point we have made for some time. U.S. refining is critical infrastructure. Looking ahead, demand has proven resilient, holding up well domestically. Peace may, and hopefully will, normalize trade flows, but it will not restore damaged capacity, rebuild depleted inventories, or reverse years of capacity rationalization. Crude normalization will happen much quicker than stabilization in the product markets.
Taken together, we believe that refining has entered a new higher cycle, characterized by higher volatility with a bias towards wider crude differentials. Given our high complex coastal refining system, PBF is well-positioned for this market environment. None of this changes what we can control. To be successful, enhance value for our investors, we must operate safely, reliably, and responsibly, and we must execute on our process improvement initiatives to maximize market capture. With that, I'll turn the call over to Mike.
Thank you, Matt. Good morning, everyone. In the Q3, our throughput averaged approximately 924,000 bbl a day across the system, which is in line with our overall guidance for the quarter. On the West Coast, we began the Martinez hydrocracker turnaround in September and completed it in October as planned. Also in September, we closed the acquisition of the two hydrogen plants servicing our Torrance refinery from Air Products. Owning and operating those assets allows us to more closely integrate their operations, maintenance, and turnarounds with the refinery, which we expect will improve the overall reliability of Torrance. On the East Coast, the Paulsboro crude unit turnaround also commenced in September and was completed in October as planned. Both the Martinez and Paulsboro turnarounds were within budget and industry benchmark targets. With Paulsboro back online, we are well-positioned to supply our markets as temperatures drop in the northeast.
At Chalmette, the pretreater and reformer that were taken offline in May are back in service. Chalmette had no impact from Hurricane Isaias. With our turnarounds complete, we have a clear operational runway for the remainder of 2026. For the Q4, we expect total throughput of 925,000- 985,000 bbl per day. We continue to make progress on our refining business improvement program. RBI generated in excess of $230 million of run rate cost improvements that were included in our 2026 plans, and we expect that to grow to more than $350 million by year-end 2026. Some recent accomplishments. Our turnaround performance continues to improve, as demonstrated by the execution of the Martinez and Paulsboro turnarounds this quarter. Our RBI-driven 2026 capital reductions are tracking approximately $88 million versus our $70 million commitment, including approximately $54 million from turnarounds.
Natural gas intensity across our system is down approximately 11% year-to-date, and for instance, Toledo has improved its overall energy intensity by 10%-15%. Our strategic sourcing organization has identified approximately $55 million per year of savings across three waves of contract renewals. As Matt mentioned, investing in our assets is a key pillar of our strategy to enhance the long-term value of our system. We've identified a number of relatively small to mid-scale projects that will improve utilization, yields, and reduce costs, and we've already begun executing this plan. In the Q3, we completed the first phase of a jet fuel project at Chalmette. By upgrading high sulfur diesel, we are now producing approximately 10,000 bbl per day of jet fuel, and in 2027, we plan to increase that capability to 20,000 bbl per day.
As a further example, we've identified a similar opportunity at Paulsboro included in our 2027 plans, where upgrading lower value intermediates will increase our gasoline yield and blending capability by about 10,000 bbl per day. To be clear, these are yield improvement projects, not capacity expansions. We are not pursuing high-cost mega projects, and we have no intention of investing in large capacity expansions. RBI is central to improving PBF's future performance, but it will not distract us from our obligation to operate in a safe, reliable, and environmentally responsible way every day. I'll now turn the call over to Joe Marino for our financial overview.
Thanks, Mike. For the Q3, excluding special items, we reported adjusted net income of $12.78 per share and adjusted EBITDA of approximately $2.3 billion. Our discussion of Q3 results excludes the net effect of special items, which decreased net income by a net after-tax charge of $29 million or $0.24 per share. These primarily consisted of approximately $11 million of costs associated with the RBI initiative and $28 million pre-tax loss on extinguishment of debt related to the redemption of our 7.875% Senior Notes due 2030 and the write-off of a portion of deferred financing costs in connection with refinancing activities. PBF's results for the quarter are primarily a reflection of the strong product markets driven by tight supply and relatively firm demand. With our full system available this quarter, we were able to improve our capture in an elevated market environment.
On the Martinez insurance claim, total recoveries to date are $1.25 billion net of our deductibles and retention. As expected, we did not receive further payments in the Q3, and we are working with our insurance group to finalize the claims process before year-end with a final payment expected in a similar range to the recent precedents. Also included in our results, the $62 million of equity income from our investment in SBR, or approximately $72 million of EBITDA, as the renewable business continues to benefit from strong margins and higher credit prices. SBR produced an average of approximately 19,200 bbl per day of renewable diesel in the Q3 at the upper end of our guidance range, and we expect Q4 production of 18,000- 20,000 bbl per day.
PBF's cash from operations for the quarter was approximately $1.9 billion, which includes a modest working capital tailwind of $56 million, primarily driven by the timing and delivery of hydrocarbon purchases. Higher commodity prices are generally a tailwind to working capital, but as a significant portion of the price increases occurred late in the quarter, we are seeing benefits flow through in early Q4. We also expect a cash tax payment to flow through working capital in the Q4. However, the ultimate impact on Q4 working capital will depend on where prices go from here. Cash invested in consolidated CapEx for the quarter was $177 million, which includes refining corporate and logistics. This amount excludes approximately $8 million related to the Martinez rebuild and $46.5 million associated with the Air Products asset purchase.
Our guidance for 2026 capital expenditures remains $825 million to $875 million, excluding capital related to the Martinez rebuild. Included in that guidance is funding for advanced purchases of materials for the turnaround through schedule to 2027. We ended the quarter with approximately $2.5 billion of cash, approximately $2.1 billion of total debt, and $426 million of net cash, reducing net debt by more than $1.2 billion during the quarter. In September, we issued $550 million of 0% exchangeable notes due 2032 and used the proceeds and cash on hand to fully redeem the $500 million of 7.875% Senior Notes due 2030. We also closed the acquisition of the Torrance hydrogen plant, which was financed with a seller's promissory note of approximately $340 million that is included in our total debt.
Subsequent to quarter end, we fully redeemed the outstanding $800 million 9.875% Senior Notes due 2030 using cash on hand. Following this redemption, our gross debt is approximately $1.4 billion, inclusive of the Air Products promissory note. As a result of these actions, interest expense is coming down. However, including refinancing costs, we expect 2026 interest expense to be within our guidance. Importantly, while we are still in the midst of our 2027 budgeting process, we expect this year's refinancing and debt paydown to reduce interest expense by at least $130 million in 2027. We project using a substantial majority of our NOLs in 2026, and you can continue to use an effective tax rate of approximately 26% for modeling purposes. As Matt mentioned, our capital allocation framework is focused on strengthening the balance sheet, investing in our assets, and delivering long-term value and returns to shareholders.
While we do envision allocating capital to strategic and margin-enhancing spending at the refineries, our intention is to be prudent stewards of capital and allocate tactically for long-term strategic benefit. Today's 18% increase in our quarterly dividend reflects our confidence in that approach. Operator, we have completed our opening remarks and we are pleased to take any questions.
In a moment, we will open the call to questions. The company requests that all callers limit each turn to one question and one follow-up. You may rejoin the queue with additional questions. If you would like to ask a question, please press star one on your telephone keypad. A confirmation tone will indicate your line is in the question queue. You may press star one again if you would like to remove your question from the queue. For participants using speaker equipment, it may be necessary to pick up your handset before pressing the star key. One moment, please, while we pull for questions. Your first question comes from the line of Manav Gupta with UBS. Please go ahead.
Congrats team, and great job. Dividend raised, debt lowered. My first question is, you are one of the biggest users of beneficiaries of quality discounts. We are seeing quality discounts widen across the world. If you could talk about what is driving that and how PBF benefits from it. Again, on the West Coast, a little tricky because ANS is trading at a slight premium to Brent. I am just trying to understand how you are managing your crude purchases on the West Coast. If you could talk about all those things.
Sure. Thanks, Manav. Simply put, crude costs across our system in California, in PADD 1, and in the Gulf Coast look like real tailwinds for our system. Our strength has always been on the back of our complexity. As crude differentials widen out, we're certainly the beneficiary of that situation. California is a bit unique because the California grades, in particular, impact our West Coast system. We're maximizing how much California crude we can run. Indeed, the dynamics in California are a bit unique, but we have a proprietary pipeline that has even a little space left, so we try to gobble up as much California crude as we can. The other aspect is the Gulf Coast and the East Coast will directly benefit from a widening light heavy differential. Follow-up, Tom?
The Latin American heavies are really driving the discounts that everybody is seeing and talking about. We're seeing freight drive the FOB valuations in South America much lower. The Canadian markets are following that, and our system is taking advantage of that everywhere we can. We run a substantial amount of heavies, so very beneficial.
Perfect. My second follow-up is a little more tricky. I'm just trying to understand what's the right level of cash for a company like PBF to hold on the balance sheet. Too low of a cash is a problem, but too much of the cash on the balance sheet kind of makes you a very interesting acquisition target because you have a unique footprint. The world realizes the benefits of North American refining, and if you start getting to a point, where 40%-50% of your market cap starts sitting as cash on the balance sheet, then you become a very interesting acquisition target. So I'm just trying to understand what's the right amount of cash to be holding on the balance sheet?
It is a bit tricky because the volatility has been so severe in the marketplace. As I commented, three once-in-a-generation or once-in-a-career events in seven years, that gives you pause and obviously the up cycle. We have had down cycles on the back of the pandemic. But in refining, there is no replacement for a strong balance sheet. So we intend to maintain that. The sort of percentages you were quoting there were a bit a ways from that. So that is not an issue for today. But if you take a step back and you get the balance sheet as strong as it possibly can be, then we just bring good, prudent, disciplined management of the capital that we have. We have increased our dividend. We did that very methodically.
We always look at our dividends this time of year, and we stated that we want it to be competitive and maybe most importantly, sustainable through all markets. Obviously, we have completely reconfigured the debt side of the balance sheet, and so we have tremendous confidence in our dividend and the increase therefrom as sustainable through all markets. So we addressed the net debt. We increased the competitive dividend this quarter. Share buybacks are always a critical component of shareholder return programs, but we also think we can benefit significantly from low-hanging fruit. If you think back to PBF's history, standing on our feet when we first became public and then growing, we are really at a moment now where as a company across our system, my guess of our inventory of low-hanging fruit is simply larger than others.
When I say low-hanging fruit, I am really implying no one in these halls are contemplating, as Mike said, mega projects or massive expansions. But the example of what we did at Chalmette where we are converting high sulfur diesel into jet fuel, and we are doing that for under $20 million of capital. That delta of high sulfur diesel in the Gulf to jet is about $0.20 a gallon. So if you want to say $8, $9 a barrel and 20,000 bbl a day, that really makes us a more resilient company. That capital has such a high return.
That project has such a high return, that is the best allocation of that capital. But we have other projects like that through our system, and so we are going to be evaluating those very prudently, very cautiously, very disciplined. But we think we have a tremendous opportunity to deepen the keel. That is where our focus is.
Thank you, Matt, very comprehensive. Congrats on a great quarter, and looks like the fourth one will be very, very strong also. I will turn it over.
Thanks, Manav.
Your next question comes from the line of Doug Leggate with Wolfe Research. Please go ahead.
Hey, guys. Let me echo, Matt, what a turnaround in the last year after all you have been through. But if I do not mind, I am going to follow up on Manav's question and ask the question about cash a little differently. You have done this zero coupon convertible. You are basically looking at, it seems, to keep some level of debt on the balance sheet, and you are still quite a volatile business just by the nature of the cost base and everything else. My question is why keep any permanent financing? You have taken the net debt to zero. Why have any permanent financing on the balance sheet? Because all it does is exacerbate the volatility of your business. That is my first question.
My second question is I just wonder, coming out the other side of Martinez, can you give us a refresh on what you think the sustaining capital and the operating cost base of the business is? Because on our numbers, your capacity to generate extraordinary free cash flow in this environment continues, but clearly, the market is not giving you credit for that. So we just want to figure out where the gap is. Thanks.
All right. So in regards to why have any debt at all, we have a view that, again, it's prudent. It makes a lot of sense to maintain access to the capital markets. So we have two pieces of paper now. We have a $500 million bond and a $550 million convertible bond. But what we've done over the last year is if you look at our historical interest expense, it's been roughly $175 million a year. The interest expense on those two pieces of paper is less than $40, $37.5 million a year. So we've dramatically reduced the cost of the fixed charge of carrying the debt, and I think it's absolutely appropriate for our company to maintain access to the capital markets. So that is what really drove the decision to maintain the instruments that we have in place.
I think it just makes the company stronger going forward and maximizes optionality going forward. In regards to your second question, Martinez. The issue with Martinez is completely behind us. In fact, Martinez just completed its turnaround on its hydrocracker on time. So in terms of having the full force and effect of our business, we have it. We think we have real tailwinds. The required spending, there's no material change going forward. 2027 will be a heavier turnaround schedule than most years. It's never ratable. It's never perfectly ratable. We were able to move some turnarounds from this year because of the market we've been in. But there's nothing changed. I would say 2027 is probably a higher turnaround year. Actually, I know 2028's going to be a lighter turnaround year. But was there anything else specific you want in regards to that?
Well, I think really what I'm driving at, Matt, is obviously you've had your business optimization, the benefits coming through there, but we haven't really seen a clean year for capital with Martinez back up and running. So what I was really trying to get to was what is the call on your cash flow to maintain the business, including turnarounds and the operating cost post the business improvement initiatives that you've had underway?
Sure.
You can take it offline if necessary, but I wanted to [crosstalk]
No, I think it's important to address. Happy to. Mike, why don't you speak to the success that we've had with RBI and how that will play out over 2027?
As we said, RBI was $230 million, and that was broken down between capital and OpEx. We said that roughly $70 million was going to come out of capital and $160 million was going to come out of OpEx. Let's talk about OpEx first. When we contemplated this program back in the tail end of 2024, there was a couple of things that happened that we didn't anticipate. One, as you mentioned, was the Martinez, and that delayed some of the savings. The other thing that happened was the market that we've had in the past couple of months or past quarters or so. As I look at the OpEx, we're maybe about 10%, maybe $8 million-$10 million of savings shy for this year.
You flip that and look at the capital and the turnarounds, we're up about $20 million. Net-net, we're meeting our commitment. Turnaround is an interesting thing, and it's difficult to measure year-on-year. As Matt said, it's not usually ratable. One thing that we look at is we benchmark every turnaround. Prior to kicking off RBI, we were in the bottom half of the industry in terms of our turnaround cost performance. We put a lot of things together in place in 2024 to get better, to get predictable first and foremost, and then 2026, we focused on competitive. Now 2026 turnaround performance is in the top half of the industry benchmarks.
And then when you look at sustaining capital, we took a baseline of where we were spending sustaining capital before, and it was about $230 million, and we saved about $25 million-$30 million on that. So it will change from year- to- year based on the size and the complexity of the turnarounds. So it is not always ratable. And as Matt mentioned, next year is going to be one of our larger turnarounds because of our two deferrals that we had into this year. But we continue to make continuous improvement on both the OpEx and the capital side. So that is how we look at it.
And just one final comment.
[crosstalk] Yeah. We will get into the details with Colin. Go ahead.
One final comment in that regard, which is we are just stacking these wins, right? So the reduction in interest expense, the RBI savings on the operating cost side, the RBI savings on the capital side, the margin improvement in projects such as the Chalmette Jet production. Each one of these is deepening the keel and making our company more resilient. And obviously, it will make us more profitable not only through down cycles, but through up cycles as well.
Appreciate the details, guys. I'll get into the details with Colin offline. Thanks so much.
Thanks, Doug.
Your next question comes from the line of Joe Laetsch with Morgan Stanley. Please go ahead.
Hey, good morning, Matt and team, and thanks for taking my questions. I wanted to start on the refining side and within the regions, one of the areas that came in stronger than we expected was the West Coast. Could you just talk a bit about how those assets are running post-turnaround, and then also what you're seeing just on the ground in that market, from a demand perspective as well?
Paul, do you want to quickly comment on demand?
Well, look, West Coast demand has been resilient. Even with these volatile prices that we've seen in the marketplace out there, it's been remarkably resilient. Our wholesale numbers have gone up actually a little bit. We think that's probably some branded going to wholesale. But in general, from a demand standpoint, West Coast has been pretty steady over the last 12 months.
I think broadly on the marketplace, our assets are, now that we're fully up and running with a very clean runway, we're very well-positioned in the marketplace. As we've talked about for multiple quarters, it's on the product side. It is a market that requires massive imports into the state just to balance, but importantly on the crude side as well, where we have not only the two refineries, we have our M-70 pipeline, where we can maximize our access to California-grade crudes, and obviously some production has come online. Some new production has come online this year. So I think as a competitive positioning, PBF and our access and exposure to California looks very attractive going forward.
Thanks, Matt. That's helpful. Then just looking in the Q4, I recognize it's still early in the quarter and there's a lot of volatility in the market, but could you maybe just walk through some of the puts and takes that you're thinking about on capture relative to 3Q in particular? As we think about the benefit from the wider WCS differentials, anything on crude backwardation, secondary product margins that you all are watching, any color you can provide would be helpful. Thank you.
Sure. We are further into the quarter on crude than we are on products, just because you buy your crude in advance. I think my expectation for the Q4 is to have widening crude diffs, which obviously are quite impactful to our business. I think it would be folly for us to predict prompt cracks. Obviously, 1/3 through the quarter, they have been quite strong. Indeed, just my sneak peek into what October looks like, it looks quite strong. Going forward, as we talked about, if a turn around the world is achieved today, none of the problems are solved on the product side. That being said, prompt prices and prompt cracks can jump around, but the Q4 looks obviously very constructive with the backdrop we have.
Great. Thanks. That is helpful.
Your next question comes from the line of Phillip Jungwirth with BMO. Please go ahead.
Yeah, thanks. Good morning, and really strong results. Sticking with the Q4, throughput guidance was really strong. I was looking back, and I think there is only one other quarter in PBF history where you were above the midpoint. Obviously, no turnarounds planned, but was just hoping you could speak to the level of confidence in the system and just what is allowing you to run at a higher rate into year-end. Separately, is there the ability to run a heavier crude slate into 4Q, just given the continued weakness in differentials? If so, could you push a higher distillate yield also?
I promise you, we will run the most economic grades that we can get our hand on and push our system in that regard. There is nothing to discuss on that front other than we will absolutely maximize our economic outcome based on the crudes that are available. I am sorry, your first question was in regards to throughput. The market is dictating it to a great degree. Generally speaking, you do have turnarounds in the Q4, and generally speaking, the market does not always incent max runs. Obviously, the world is in desperate need for our products, and we intend to manufacture as many as we can in this period.
Great. Coming back to the sourcing of California crude, you referenced your advantageous pipeline into Torrance. More specifically, how would you see any San Pablo Bay Pipeline restart changing crude sourcing at Martinez? Just with the election coming up, how would you characterize the current regulatory environment in California and any expectation whether this could change for better or worse depending on the outcome of the governor election?
Yeah, the pipeline one is a funny one only because, as I mentioned before, we have space on our M70 pipeline. Now, I think the San Pablo pipeline has been sold, so I do not yet know what the new owner's whole intent is. From PBF's perspective, we get this a fair amount in California. "Well, when are we going to open San Pablo?" It is like, if you own a hotel in a town and you have got 20% vacancy, and someone is saying, "Well, are you going to build a new hotel?" Well, when vacancy becomes a problem, we will look to increase flows. Obviously, Martinez sits at the end of the San Pablo Bay pipeline. To the degree that our M70 pipeline is full, we would certainly love to bring crudes up to Martinez.
But at the moment, you have gotten a lot of legislation through California, which has decreased the friction in getting permits for the producers. To the degree that production increases, I think the San Pablo Bay pipeline is sitting there in a perfect spot to take incremental grades that cannot be taken south. Simply, egress is not the constraint at the moment. It is production. In regards to the election, it is not worth me prognosticating, but I do not see any material shift in the California political environment. I do think there has been a great awakening in terms of how important and impactful and how necessary our products are to the economy and to the welfare of all the people that live there.
So I think that is a very good thing. I do not see that backtracking, and clearly, California was a microcosm of what the world is going through now. So we'll see where the election goes. We've had a tremendous partnership with the state over the last couple of years, sort of navigating all the changes that have existed. And we look forward to working with them going forward, regardless whoever the administration is.
Very helpful. Thank you.
Your next question comes from the line of Josiah Knight with Goldman Sachs. Please go ahead.
Yeah, good morning, team, and thanks for taking our question. Maybe just circling back on freight rates, can you talk about how exposed your system to the elevated rates we're seeing in the system or in the market right now? And then additionally, what steps have you been taking to mitigate these impacts?
So, if you think about freight rates for PBF, you think about supplying crude into the East Coast and Northern California. We have about half of our fleet on time charter, which has obviously insulated us from the massive gyrations that are occurring. And we have closer proximity than much of the rest of the world in regards to where we are delivering our crude from. And obviously, we are in a freight firestorm at the moment. So I do not envision any material changes to that because this is not the time when you want to go out and get more time charters. So to a great degree, and it is PBF for certain, and to a great degree, U.S. refining is dramatically in a better place than, say, Asia in that regard because of the distance that they have to go.
As Tom O'Connor always points out, the Atlantic Basin has crude avails. And so our transit time is much shorter.
That is helpful. And then the follow-up is just on the delayed turnarounds at Chalmette and Toledo. Can you just remind us of the decision-making process here? And then additionally, how should we be framing out the impacts of 2027 throughput and then 2027 CapEx?
So we are not going to get into specific CapEx guidance yet. We usually put that out at a different time, and we will follow that. In regards to the turnarounds, it is no different than how we run our business every single day, which is evaluating the condition of our units, which are continuously and meticulously evaluated on a day-by-day basis. And to the degree that we can optimize our turnarounds and our operations, that is what our job is. Mike, do you want to comment in regards to anything else in regards to the turnarounds?
I think you nailed it right there. In particular in Toledo, as we stated on the call the last time, we had some unplanned downtime in May, and we took advantage of going after a few things during that downtime to set us up to be in a position to defer this turnaround into next year. So there's an example of we're applying rigor and discipline, analyzing the performance of the unit, fixing things, and then moving forward.
That's helpful. Thank you.
Your next question comes from the line of John Royall with Piper Sandler. Please go ahead.
Hi, good morning. Thanks for taking my question. My first question's on the performance of SBR. Obviously, it's a very positive macro for RD, but looks like a really strong quarter on that equity earnings line for 3Q. Can you talk about that unit kind of operationally, how it's running and what feedstocks look like? Secondly, are you taking any dividend out of that JV right now? Just trying to understand the cash impact given that business is having a more meaningful contribution right now.
Sure. I'll start with the dividend. We did receive our first dividend distribution from SBR during the quarter of about $20 million. That is reflected in the results. As far as operations, it's been running well. You can see we're at the top end of our throughput guidance for Q3, so everything going well there. Our feedstock slate obviously changes over time, although we try to source the most economic feed there, and it'll move between the higher and lower CI, and I think for Q3 it was more on the lower CI. It's kind of level which helped from a margin capture standpoint. But overall, as I said in my remarks, just the strong margins there, the tightening of the HOBO spread and the RINs price kind of maintaining at high levels has helped to really charge the earnings of that business.
Great. Thank you. My follow-up is on bringing the hydrogen plants back in-house, and I realize you touched on this in 2Q a little bit, but how should we expect to see the returns on that kind of investment? Is it just about reliability and reducing downtime? Does it reduce OpEx overall? Just trying to understand maybe how to model that acquisition. Also, I think there were a few others that were sold to Air Products when you did that initial transaction a few years ago. Was there any thought to bringing those back in-house as well?
Just on your last piece. Just on the last piece. I don't expect there to be any other. Torrance was a bit unique because of where it was situated within our refinery and the way it was being operated. Mike, why don't you walk through it?
Yeah. I'll jump on that point. The uniqueness of it was that they were so integrated to the operation of the facility, where we shared utilities. The hydrogen plant was a major steam producer, for instance, for the refinery, and so any impact to the operation of the hydrogen plant, and because of that refinery is so beholden to hydrogen in terms of being able to perform and maximize the refinery, had all kinds of impacts. I would look at it like this. When we did the acquisition, it was firmly just based on increasing the utilization of the refinery. In the past, because of either planned or unplanned downtime associated with those hydrogen plants and the lack of integrated plans really drove the performance in the refinery. So I would look at it's mainly just the utilization.
One thing I would add from a modeling standpoint is nothing changed with the transaction as far as the cash flows go or overall cash flows. It is just really a change in the classification with now. In the past it was classified as operating leases and would flow through as such in the P&L. Now it is going to be a debt promissory note that will flow through financing activities. But the cash flows themselves remain the same.
Thank you.
We have reached the end of the question and answer session, and I will now turn the call over to Matt Lucey for closing remarks.
Thanks for everyone's attention today, and we look forward to speaking to you after a very solid Q4. Have a great day.
This concludes today's conference, and you may disconnect your lines at this time. Thank you all for your participation.