PBF Energy 425Business combination disclosure

Good day, everyone, and welcome to the PBF Energy Second Quarter 2022 Earnings Conference Call and Webcast. At this time, all participants have been placed in a listen-only mode, and the floor will be opened for your questions following management’s prepared remarks. [Operator Instructions] Please note that this conference is being recorded.

It’s now my pleasure to turn the floor over to Colin Murray, Investor Relations. Thank you, sir. You may begin.

Thank you, Melissa. Good morning, and welcome to today's call. With me today are Tom Nimbley, our CEO; Matt Lucey, our President; Erik Young, 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 in our press release and those made on this call that express the company's or management's expectations or predictions of the future are forward-looking statements intended to be covered by Safe Harbor provisions under federal securities laws. There are many factors that could cause actual results to differ from our expectations, including those we described in our filings with the SEC.

Consistent with our prior periods, we will discuss our results today excluding special items. In today's press release, we described the non-cash special items included in our quarterly results. The cumulative impact of the special items decrease the net income by an after tax amount of a $116 million or approximately $0.93 per share. For reconciliations of any non-GAAP measures, please refer to the supplemental tables provided in today's press release.

I'll now turn the call over to Tom Nimbley.

Thanks, Colin. Good morning, everyone, and thank you for joining our call. For the second quarter, PBF reported earnings per share of $10.58 and adjusted net income of $1.3 billion. Our strong financial results have provided us with the resources to accelerate the repayment of debt we incurred during the pandemic, and to continue actions to strengthen our balance sheet. To be clear, the work is not complete as we remain highly focused on doing more to recover from the ravages of the pandemic.

The second quarter picked up with the first quarter ended with volatile market conditions and rising energy prices. Refinery margins expanded as available refiners other than Russia and China were called on to run at high utilization levels. The Russian invasion of Ukraine continues to alter trade flows. Russian waterborne crude exports are generally flown to Asia, as western nations continue rejecting Russian crude and feedstocks.

As trade flows reorganized, a couple of themes are appearing. European refiners are lightening their crude rates as the replacement crude for rejecting Russian barrels is generally light sweet crude produced within Europe, West Africa or the United States. Also, for some time, Europe has been facing a natural gas and power crisis that has only been exacerbated by the Russian invasion. High-priced natural gas in Europe has made upgrading units and hydrogen plants very expensive to operate, giving U.S. refiners a significant competitive advantage.

Differentials for light, sweet crude versus heavy sour have been riding for a variety of factors. Light sweet crude struggling for the reasons I just mentioned, plus available upgrading units, coking capacity et cetera are generally full. We are seeing the heavy part of the battle trade at wide discounts to the global benchmarks for light sweet crude, then we have seen in many years. Heavy fuel oil is quite weak and there is some market commentary about support coming from the reemergence of IMO 2020 market dynamics.

The beginning of the third quarter has seen a 15% to 20% correction in oil prices and refining margins. However, underlying fundamentals remain strong, low inventories, tight supply, improving demand and reduced refining capacity. Despite that, there are macroeconomic concerns that all weighing on the market, high inflation, rising interest rates and a rising U.S. dollar. The macro the macro concerns point to contracting oil demand to help bring the energy blockage back into balance as the status quo is simply not sustainable. Inevitably, inventories will need to be replenished from these extraordinary low levels. This will require refineries to continue running at high levels of utilization.

Our valued employees continue working tirelessly to keep our assets running safely and reliably, and we appreciate their contributions to our performance. With our balance sheet improving and the bulk of our 2022 turnarounds complete, we anticipate that our assets will continue generating cash which we will use to further strengthen our balance sheet and reward our investors.

With that, I will turn the call over to Matt.

Thanks, Tom. As Tom mentioned, PBF second quarter is one for the books, and demonstrates earnings power of are refining system and the dedication of our employees. While the extraordinary market conditions seen during the second quarter will eventually normalize, the fundamentals and outlook remain strong.

On the East Coast, we completed work on the Delaware City reformer and other secondary units which began in March, and concluded in April. Additionally, we are in the midst of restarting our idle 50,000 barrels a day crude unit at Paulsboro, which we expect to have long online in mid-august. We are confident that we'll have enough access to feed for the unit and will help us -- help ensure that all of our other secondary units on the East Coast remain full.

On the West Coast, we recently completed a significant turnaround in Torrance of the alkylation and other ancillary units. The work was conducted primarily in June, and wrapped up in the first 10 days of July.

Looking ahead to the third quarter and the remainder of the year, our capital expenditure and throughput guidance is presented in today's press release. We have no significant plan maintenance for the remainder of the third quarter, we do have a plan turnaround in Chalmette in the fourth quarter. In addition to our refining CapEx, we continue to invest in and progress a renewable diesel project in Chalmette. We anticipate startup with full pre-treatment capabilities in the first half of next year. Importantly, the project remains on time and on budget.

In terms of the forward refining market, as Tom said, the market needs to reset as a current high price, low inventory conditions are unsustainable in the long-term. Over time, we expect a product inventories will eventually return to their historical average levels. However, with a global reduction refining capacity as well as natural gas advantages in the U.S., we expect to see above mid-cycle refining margins, which is what we are seeing today. Our assets are running well and position and keep -- and are position to keep the market supplied and capture that margin.

Lastly, this morning, we announced the PBF Energy has agreed to acquire all the common units of PBF Logistics that does not already own. This transactional ultimately allows to simplify our corporate structure and eliminate administrative, compliance and cost burdens of running a separate public company. Following consummation of the merger, we believe will have the significantly enhance financial strength.

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

Thank you, Matt. For the second quarter, we reported adjusted net income of $10.58 per share and adjust EBITDA of approximately $1.9 billion. This brings our trailing 12 months adjusted EBITDA to over $2.8 billion. This financial performance provided the foundation for us to accelerate our deleveraging plan. Over the last 18 months, we have reduced consolidated debt by more than $2.6 billion. In addition to the $900 million pay down of our bank facility during the second quarter, we redeemed the full $1.25 billion of secured notes due 2025 on July 11th.

When we include the more than $250 million of open market purchases at a discount to base value, our unsecured debt is now below the pre-pandemic balance. Importantly, we were able to execute our plan, while maintaining significant liquidity and have a current cash balance of more than $900 million.

On a go-forward basis, we expect to recognize over $165 million of annualized interest expense savings. Simply put, PBF balance sheet is vastly improved with quarter-end net debt to cap of 24%, and net debt of less than $1.1 billion. These statistics represent levels that we have not achieved since 2018.

Consolidated CapEx for the second quarter was roughly $211 million, which includes $157 million for refining and corporate CapEx, roughly $52 million related to continuing development of the RD facility, and $2 million for PBF Logistics.

For the second half of 2022, we anticipate total refining and corporate CapEx to be approximately $200 million to $225 million, excluding the RD project. This reflects a return to our normalized pre-pandemic turnaround schedule.

Operator, we've completed our opening remarks and we'd be pleased to take any questions.

(Question and Answer)

Thank you. In a moment, we'll open the call to question. The company requests that all callers limit each turn to one question and one follow-up. You may rejoin the queue for additional questions. (Operator Instructions).

Our first question comes from the line of Roger Read with Wells Fargo. Please proceed with your question.

Yeah. Thank you. Good morning and congratulations on the quarter guys, nice execution. I guess, the biggest question we keep getting from investors is, where do we sit today in terms of demand? We've had some, I’ll just say, questionable numbers have come to DOE, but overall things still look pretty solid. So, I just curious what you see on demand? And maybe how that fits into some of the discrepancies we're seeing right now in terms of the cash markets, thinking how much stronger the East Coast is then say the Gulf Coast?

Great question, Roger, and thanks for your comments. We share two things kind of thought, so I did there was some aberrant in the – coming out of the July 4 weekend that's always questionable what you do there and then there was some true up, I think between a monthly EIA from June that got flowed into July, and perhaps that has run its course now and yesterday's numbers were a little bit stronger. I'll make another comment. So we're seeing frankly while there's some headwinds and we've seen some decrease in demand. EIA is reporting that, and in our own business and I'm going to turn it over to, Paul Davis, in the moment to talk regionally. Our demand wholesale level is holding up where it's basically the same levels we've been for the last 90 days.

But you made a very good point on the East Coast. The East Coast demand --East Coast is structurally impacted more than any other region in the country by what has happened over the last several years. When you look at the amount of refining capacity that's been shut in or cut back in the Atlantic basin, including PES including come by chance. A disproportionate amount of capacity in the Northeast. At the same time, the pipes are full coming up from the Gulf Coast.

So, we had the only coking capacity on the East Coast. So we think the Atlantic basin is actually had a bigger step forward if you will then the other regions even though the other regions have benefitted from what's been going on then some of the others.

Paul, you want go give, Roger, idea by region.

Well we can start with the East Coast. You said it pretty well. You know, cash markets in New York harbor are very strong and have been very strong, the backward nation is just arguably historic on cash valuations. Gasoline, obviously, leads it distillates early in the second quarter we're leading it. Jet has been incredibly strong. Jet actually pricing inside of diesel with net of Wrens. So the East Coast is really moved up tier and markets for us.

Gulf Coast is as you said it's pricing for tiers. It's running very strong. We see strong export demand. We see arbitrageurs into the Midwest and to the East Coast pricing accordingly. And that's normal, we would call it, a normalized market. Wholesale wise, it's probably the weakest market we have, but it's very normalized. Our July numbers look just like our Q2 numbers did on a month-to-month basis.

West Coast is very strong. They stayed constant all the way through second quarter and into the beginning of the third quarter even with the price challenges at the street. We're seeing our wholesale markets there very strong and remain very strong and supported by the return to work on the West Coast.

And in the Midwest, we have a big wholesale business in the Midwest and that's remain strong throughout.

Great. Thanks for that. And then pivoting a little bit here to you, Erik, obviously tremendous improvement in terms of balance sheet liquidity everything. But at this point, what do you feel is the most important thing to do, right? You going to consolidate PBFX so that's got some debt with it. You've got obviously, some of the environmental obligations that are still out there and

then just the general balance sheet ultimately maybe a reinstatement of the dividend. Just curious as you think about priorities how that flows through?

I think you laid out kind of our plan at this point, number one, we've taken out most of the pre-payable debt at this point in time and we believe the unsecured debt secured debt that we have on the books. We have ample time to deal with the 25 notes that will come do then once PBFX ultimately roles in we will handle that particular debt, but ultimately, we've provided ourselves enough financial flexibility here and quite candidly that that's already consolidated on the balance sheet. So when we talk about our $1.1 billion just shy of $1.1 billion of net debt that includes that level.

So, from our standpoint it is simply a matter of continuing to reduce the overall net debt balance operate well, take advantage of the market when it is afforded to us and ultimately be reliable because otherwise profitability will not translate into free cash flow. So from our standpoint, we've gotten things significantly in order and for us now it's just a matter of execution on the day-to-day business.

And on the various environmental obligations that have been out there is any -- does it make sense to go ahead and fund those? Is there any incentive at all to fund them preemptively?

I'm not so sure that preemptive. We now have significant amount of clarity in terms of when these -- this is an unprecedented time where we have three outstanding periods under the renewable fuel standard. And so we at least have line of sight in terms of dates when we need to actually turn in credits.

Fortunately, I think we've tried. I like for folks. Our 2020 obligation is done, that will be turned in at the end of this year and then we have through Q1, and then into the end of Q3 next year to fulfill the 2021 and 2022 obligation. So, included in our accrued liability line is about $850 million of balance sheet related to accrual for RINs. Investors should expect that those numbers will start to tick down over time and then the remainder is ultimately the combination of AB 32 Cap-and-Trade and LCF that's credits. Those will also trade down or take down over time because again the AB 32 program is a multi-year program that will involve multiple step downs through the remainder of the existing period.

So, I think over time they will absolutely go down, but currently there is zero plan to preemptively take care of any type of RIN related obligation, simply because we need to see more of this renewable diesel come online that will ultimately create more RINs.

Great. Thank you.

Thank you. Our next question comes from the line of Doug Leggate with Bank of America. Please proceed with your question.

Oh thanks. Good morning, everyone. Thanks for taking my questions. So guys you opened up your comments talking about you will see inventories normalize. I guess my question is, what about costs? And I'm thinking specifically about the dynamics on the East Coast. Tom, as you pointed out, opportunities changed dramatically, which presumably makes the U.S. incrementally more dependent on European imports and they're paying $60 per thousand cubic feet for natural gas today. So when you talk about normalized inventories, how do you think about normalized margins?

I'm going to ask, Tom O'Connor, to handle that question. He's been all over this.

Great answers.

Perfect. Makes sense. One quick thing, if you could help us understand. We are seeing something very -- your buyers of both Syncrude and you are also buyers of WCS. Now they tend to move in the same direction generally, but what we are seeing is they're moving a little against each other. Syncrude is going at a premium to WTI and WCS premium discount is widening. So it can't only be aggressive. Help us understand what's driving this almost $30 differential in the two Canadian crude that you buy? Thank you.

I’ll make one comment and turn it over to, Paul Davis. Obviously, it is a big spread, but directionally all lights command a premium because of what we talked about terms of the need to deal with high natural gas prices et cetera, et cetera, and the cutbacks from Russia. So you've got pressure on the light sweet side going up and some pressure on the downside because of the sulfur content of the heavier crude.

Paul, why don't you speak specifically to, Manav's, question?

Yeah. Manav, there is a market pressure on that spread, but primarily it's all maintenance up in Canada. The upgraders have had plant and not an insignificant amount of unplanned maintenance. And that's put a premium on this instance side of the business.

Thank you so much guys.

Thank you. Our next question comes from the line of Theresa Chen with Barclays. Please proceed with your question.

Good morning. Thank you for taking my questions. I actually just wanted to come back to your comment, Tom, about mid-cycle margins being higher and industry needing to replenish inventories overtime. How concerned are you about the incremental capacity coming online either ramping up today in the middle East and Asia or recently ribbon cut it to in Mexico or penciled in to come online in Africa? Hope to get your thoughts there.

Yeah. I think, we actually we need capacity come online to help replenish those inventory. So, I don't think it's going to impact the utilization to your point for our business. We're going to see continued growth today is no doubt about that, they have been delayed some of them delayed rather significantly because of COVID, but ultimately they need to bring that capacity on and as the developed world continues to improve and grow --Asia needs that capacity.

So, we expect that there will be capacity coming online. Mexico wants to be energy independent, that I think will take more time than what is advertised we see these creek in costs associated with some of this refining capacity, but they're certainly moving down in that objective at the same time as I said earlier. There's continued examples of particularly in the U.S. and the West Coast, of refineries are the same they're going through because of the pressures on fossil fuels. And banning of the internal combustion engine in 2035 by the state of California, and Tosco Refining former refinery, Avon is now owned by MPC is going to convert to a renewable.

And the interesting thing is, when you convert going through make a renewable project, yes, you're going to make renewable diesel, but you're not going to make any gasoline or any jet fuel. So, I think while we do expect the capacity to increase worldwide, I don't know that we're going to see much creep in the United States in fact it may go the other way and I suspect utilizations will remain high absent of really pronounced recession or something like that in the U.S.

Thank you.

Thank you. Our next question comes from the line of Connor O'Neill with Morgan Stanley. Please proceed with your question.

Yes. Thanks. I wanted to talk about the buy-in of PBF logistics --excuse me. Just in terms of the strategic thinking, obviously, you highlighted the cost savings some of the mechanical savings and not having to run two separate companies. But just strategically thinking, what's your sort of thought on the on the value creation there?

This is probably less PBF centric, but many of the attributes that existed with having a drop-down MLP of subsided over the last number of years. And so it was an entity that was a performing well in terms of its operations and its financial performance. The many of the benefits that drove us to create the structure and the entity subsided. And so the ability to clean it up now, as a number of other companies have done, seems to make a lot of sense and it's -- I think it's pretty straightforward.

We present as a more simple structure. And so, yes, there are benefits of getting some costs out of the way but that I don't think it's a big driver. PBFX acts as a growth platform and something that was in high demand of yield simply declined over the last couple of years. And so we're happy to bring the assets in all our employees will many of which were serving wearing two hats. So, it simplifies that quite a bit and so we try to create a transaction that was fair for all

parties work with the conference committee at the PBFX went through a full process, but a very fair one and so we were pleased.

Yes. Makes sense. And I just wanted to talk to return to the conversation about the balance sheet. So, understand that you don't want to buyback debt at a high premium. I was trying to parse your comments, it sounded to me like maybe you're thinking there is a sort of a need to run at a lower structurally lower debt level than better than before. Basically could you just help us think through the framework of you're buying in logistics, which can probably support a little bit more leverage and I think you're pointing to flexibility that you demonstrate in the refining system. But just curious, is there an argument to be running at a lower debt level based on what which is gone through or no change to that?

I think it's just inherently based on at least where we are today and what we see in terms of forward curve. There will absolutely be a significantly lower net debt level for PBF consolidated on a go-forward basis. Where we are here at the end of July is ultimately we just write consumed a massive amount of delevering and there is zero pressure to do anything at this point.

So we do have some PBF logistics notes that will be coming due next year. We feel like we have ample capacity between the revolver at PBFX as well as the PBF ABL, we also have a significant cash balance. And so, really what we're prepared to do now is to determine what is the long-term structure in terms of debt. Making a decision now, when quite frankly the high-yield market, I believe the first six months of this year, might be the third worst performance in high yield ever.

So, waiting into a market that is not yet fully recovered. To push out some of these maturities seems a bit premature and quite frankly there is zero pressure and we have the financial flexibility. We are really focused on we should continue to see liquidity improve. Now that our numbers are out and we filed the queue this morning, ultimately we will be sitting down with suppliers in August and September, we should see letters of credit come down the collateral posting.

Right there's really a significant amount of things that compound on themselves as a result of our balance sheet, getting back to again, better than it was as we entered COVID and we are a significantly stronger and quite frankly, bigger business than we work. Let's not forget that we have a real workhorse out on the West Coast and Martinez that now has been added to the portfolio. And we've not been able only with Q2 have we really been able to demonstrate, what that particular asset can do. And we've got high bar internally in terms of what we need to execute on.

So I think the key message right now is that we are flexible and most important, we are patient. We do not have our backs to the wall on anything we've just what we've just lived through. The biggest demand destruction of event that this industry has ever seen and we've come out the other side and we're stronger than we were when we enter.

Yup. Makes sense. Thank you.

Thank you. Our next question comes from the line of John Royall with J.P. Morgan. Please proceed with your question.

Hey, good morning, guys. Thanks for taking my question. I think you made a comment in the opener about IMO-2020 kind of coming back into view. Can you talk through some of those dynamics and the impact you're seeing from IMO now? And I guess, how that could evolve going forward?

Royall, I want to make a comment that just look at the clean dirty spread. The spread between ISO for fuel oil and diesel ultra-low-sulfur diesel and that spread is very wide, but there's a number of factors that are impacting that. Not the least of which in fact perhaps the most important factors right now at this 10 seconds, is the stress to shift crude to sweet crude from sour crude, heavy crude because of high natural gas prices and the costs associated with those natural gas prices on getting the sulfur out of a crude. So, as we talked earlier you've got pressure on the heavier crude, feedstocks being driven down because of that dynamic and you've got pull on the sweet side.

At the same time, what we are seeing is for the last we've been saying one of the advantages strands or PBF for the last I don't know 10 years has been our complexity and we are very complex kit. And we candidly have not been rewarded for that in the past couple of years because of the low spreads between a light sweet and heavy. And that was to certain extent due to the fact that there was ample destruction capacity available coking capacity.

Well that's changed some. Coking capacity is getting full and that's becoming tighter, which means that will be another contributor to the differential between the light sweet and the heavy sours. So it's really a combination of factors, but we have certainly seen and higher utilization of the residual destruction equipment than we've seen over the past several years, and that's being driven incrementally because you've got to get the sulfur added, high sulfur fuel to get it into the bunker fleet.

Okay. That's really helpful. Thank you. And then, can you talk about a recession case? And what that could mean for the industry in for product inventory balances and cracks if it happened in let's say, the next 12 months? Would that change your view on the structural crack being above mid-cycle if we had a bit of a reset due to recession?

Not really. I think it while --it was all depend upon the gravity of the recession. So if we have, we do have basically full employment in the U.S. right now. And I'm not saying that there isn't going to be a correction here recession is no doubt that inflation, is got to be dealt with and is no doubt that the Fed indeed is going to do that. But there are other factors that on the other side of the equation as I said, disposable income.

People had a lot of disposable income coming out of COVID and we do have effectively full employment and there's more job openings than there are people out of work. So hopefully if there is a recession it won't be a drastic recession. It'll hopefully be a little bit more shallow, who know? But the fact is, what we're seeing already is the price of gasoline has dropped over $0.50 down. And what has to happen really to the next steps in this correction is to work the food side and the other things in the supply chain to get those things turned around and bring the rate of inflation down. But there -- maybe impact is no doubt, but I don't think it's going to be an impact that is going to knock us off the need to run the refineries that are very high utilization because of the supply demand balances and the fact that we don't have as much capacity on the ground as we used to.

Thanks very much, guys.

Thank you. Our next question comes from the line of Karl Blunden with Goldman Sachs. Please proceed with your question.

Hi, thanks for time. I just had a question on RIN, I think was helpful when you're broke out the fixed versus floating exposure there. I was curious is there a thought to changing your approach to how much you run fixed versus floating system such a focus for people maybe a distraction away from the core business from time-to-time?

Absolutely. And on a go forward, again this is we're in a very unique position now where we have these three outstanding annual periods. And so the RIN market is not like the regular way securities market for equity and debt. I think we've tried to highlight that for folks along the way. And so as these periods suddenly get put in the rear-view mirror, we do believe that ultimately we will not be talking about both we're happy to disclose what we expense in terms of RIN, but ultimately, we want to put a lot of this noise behind us. It's been a very messy program along the way, but candidly we were also still trying to anticipate what the 2023 program is going to look like for us. Our focus right now is really on making sure that we handle our 2022 obligation and ultimately we comply with the program for 2021 and '22.

Thanks, Erik. The follow-up just on the bond maturity that you have coming up. I think you've been share that you can be patient. As you look forward, do you think the business or the appropriate capital structure could be one where you just take out the 2023 and 2025 debt and don't replace any of it? So, run leaner in terms of how much debt you have on the balance sheet, was that something still kind of thinking through what the appropriate quantum of debt is?

I think, will still have to figure out what the long -- what the long-term debt quantum is. Right now there zero plan to take out that the stub is about $675 million outstanding on the '25s and then we clearly have the 525 for PBF logistics. There is a, there is a longer-term appropriate level going debt free in this business doesn't seem to be extremely responsible.

At the same time, we've seen the type of consternation that it provides when you have an over lever business and refining and so we're trying to find what we deem to be the sweet spot there. As we sit here today, we do have on a trailing 12 months basis. We have less than 0.4 times debt-to-EBITDA.

Understood.

That we've just gone through a period where we generated close to $2 billion in EBITDA during this quarter. However, the forward curve is spitting out numbers, right? Well, north of $1.7 billion, $1.8 billion for our business over the next handful of years. And so, what we are trying to ultimately determine is, what is the right level? But again, we can be patient now, we are -- we're in the driver sit now as opposed to reacting to everything coming at us during COVID.

Stay tuned. Thanks, Erik. Appreciate it.

Thank you. Our last question today comes from the line of Matthew Blair with Tudor Pickering Holt. Please proceed with your question.

Hey. Good morning. Thanks for taking my questions here. First one, could you talk about the product yield and each stocks late for the upcoming RD plant? On the product side, do you anticipate having any SAF flexibility? And then on the feedstock side, I believe you're looking at full pretreatment. But do you think you'll be able to access discounted of waste oils and animal fats or would it be more like a like a crude SBO feed?

So go in reverse order maybe. We are actively building out our commercial operation now. And so, while the project will not come on for you know, not until the second quarter. We're actively staffing up and building the capabilities to source, whatever is the most economic feed available. I do think in regards to our timing was strengths of our project is we're coming on there's a number of projects behind us that will have the advantage of actually being out buying feeds.

But yes, we believe will have access to the market. We're hiring a professional staff to execute on that and we'll have full capability to run whatever is the most economic at any given time. So, we'll have full flexibility and that's where we think the project is so attractive.

In regards to the yields and obviously, there were some news last night, we haven't fully digested what is in the potential compromise with Senator Manchin. But we anticipate that SAF will be demanded project, demanded fuel in the future and we'll have the capability to manufacturers sustainable aviation fuel from the project.

Any initial thoughts on what the SAF yield might be?

You know, I think we could, we could get it up to 20% without much capital and for a modest amount of capital we could get out of them.

Wow. Okay. Great. And then the comment on you expect above mid-cycle refining margins for now. When we think about the math behind it looking at Europe net gas at 50 bucks per MMBTU U.S. call around seven and then we think about generally every $1 per MMBTU in that gas is about $0.25 per barrel and refining margins. And so just doing the math there, that'd be about an $11 margin benefit from just a steeper global cost curve. So that makes sense to you that, how you think about it as well or any different numbers there?

Directly attached the way we look at it as been number of publications that have put out in the scale of what the spread is between European gas and henry hub. If indeed, we wind up holding a $50 spread that is going to be a very big driver for improving margins, because obviously European refiners have got to cover those costs and we will be accosted managed in many ways so, but you directionally correct.

Great. Thank you.

Thank you. Ladies and gentlemen, we come to the end of our time for questions. I'll turn the floor back to, Mr. Nimbley, for any final comments.

Thank you all for joining the call today. We look forward to continuing to recognize our employees and reward our shareholders and talking to you at the third quarter call. Thank you very much.

Thank you. This concludes today's conference. You may disconnect your lines. At this time, thank you for your participation.