Par Pacific Q2 2024 Earnings Call Transcript

Quartr
Provided by Quartr
August 7, 2024

There are 10 speakers on the call.

Operator

Good day, and welcome to the Para Pacific Second Quarter 20 24 Earnings Conference Call. All participants will be in a listen only mode. And please note that this event is being recorded. I would now like to turn the conference over to Ashimi Patel, Vice President of Investor Relations. Please go ahead.

Speaker 1

Thank you, Cole. Welcome to Par Pacific's 2nd quarter earnings conference call. Joining me today are Will Monteleone, President and Chief Executive Officer Richard Creamer, EVP of Refining and Logistics and Sean Flores, SVP and Chief Financial Officer. Before we begin, note that our comments today may include forward looking statements. Any forward looking statements are subject to change and are not guarantees of future performance or events.

Speaker 1

They are subject to risks and uncertainties, and actual results may differ materially from these forward looking statements. Accordingly, investors should not place undue reliance on forward looking statements, and we disclaim any obligation to update or revise them. I refer you to our investor presentation on our website and to our filings with the SEC for non GAAP reconciliations and additional information. I'll now turn the call over to our President and Chief Executive Officer, Will Montalione.

Speaker 2

Thank you, Hashimi, and good morning, everyone. 2nd quarter adjusted EBITDA was $82,000,000 dollars and adjusted net income was $0.49 per share. These financial results reflect strong reliability and crisp planned maintenance execution. Notably, the billings turnaround planning and performance was excellent. In addition, our retail and logistics segments continued to deliver steady earnings.

Speaker 2

The completion of the billings maintenance positions us to push utilization rates in the 3rd quarter in order to meet market demand. Each of our markets is short refined product in the summer months, requiring long haul imports to balance supply and demand. Shifting to the broader refining environment. Global product inventories are approaching below our end of the 5 year range. The combination of elevated utilization rates and relatively flat refined product demand have allowed for modest inventory restocking.

Speaker 2

Margins have responded in our near mid cycle levels in most regions. Regional dynamics in PADD IV have largely returned to typical premiums versus the Gulf Coast. However, the Southern Rockies has been slightly less attractive as excess midcontinent inventories have pressured markets like Denver and Rapid City. Our retail brands continue to gain market share with same store fuel and merchandise sales growth of 1.3% and 1.8%, respectively. Retail team is focused on growing foodservice gross margin, enhancing systems to better manage in store costs and building a pipeline of remodel and new to industry sites.

Speaker 2

Our young brands continue to be well received in the local markets we serve. On the strategic front, our growth initiatives are progressing. Billings reliability initiatives are delivering encouraging early results. In Hawaii, our renewable hydrotreater conversion is on budget and the renewable fuel cogeneration project is progressing towards potential power purchase agreement with Hawaiian Electric. On the financial side, we further reduced our cost of debt capital and we repurchased more than $65,000,000 of our stock.

Speaker 2

Our balance sheet remains strong, affording us the flexibility to both opportunistically repurchase stock and pursue our strategic objectives. In closing, we are focused on safe and reliable operations and crisp project execution. While the margin environment is moderated, focus on these key areas will allow us to generate strong free cash flow and healthy returns to the cycle. I'll now turn the call over to Richard to discuss our refining and logistics operations.

Speaker 3

Thank you, Will. The refining segment's 2nd quarter combined throughput was on plan at 180 1,000 barrels per day. In Hawaii, throughput was 81,000 barrels per day and production costs were $4.50 per barrel. Refinery operations performed well delivering 99 percent operational availability. With Hawaii's consistent throughput and strong catalyst performance, we will be extending the scheduled 2025 turnaround into 2026.

Speaker 3

Shifting to Wyoming, throughput was a new record of 19.9 1,000 barrels per day and production costs were $7.08 per barrel. This represents great work by the Wyoming team to sustain nameplate capacity throughout the quarter. Moving to Washington, 2nd quarter throughput was 41,000 barrels per day and production costs were $3.66 per barrel. Washington team did an excellent job of safely restarting in April, following their planned outage in March. Finally, I'm pleased to report that the Billings executed one of their largest turnarounds on record, successfully meeting all health, safety and environmental targets, and as Will stated finishing on schedule and on budget.

Speaker 3

The plant restart went well and has met or exceeded all operational objectives. Given the turnaround downtime in billings, Q2 throughput and production costs were 38,000 barrels per day $16.18 per barrel. We do have planned maintenance of the Billings coker in the Q3 and Sean will cover those financials. Looking to the 3rd quarter, we expect throughput in Hawaii between 7,800,000 barrels per day, Wyoming between 1820, Washington between 3841 and Billings between 5559, resulting in system wide throughput between 190,200,000 barrels per day. I'll now turn the call over to Sean to cover the financial results.

Speaker 4

Thank you, Richard. 2nd quarter adjusted EBITDA and adjusted earnings were $82,000,000 $29,000,000 or $0.49 per share. The refining segment reported adjusted EBITDA of $60,000,000 compared to $81,000,000 in the Q1. In Hawaii, the Singapore index averaged 12 $0.49 per barrel and our landed crude differential was $5.08 resulting in a combined index of $7.41 per barrel. Hawaii margin capture was 136%, including a product crack hedge gain of $12,000,000 and continued margin support from elevated clean product freight.

Speaker 4

Looking ahead to the Q3, we expect the Hawaii crude differential to land between 6.25 and $6.75 per barrel and we have hedged approximately 10% of our 3rd quarter sales at an average crack of $18 per barrel. In billings, our U. S. Gulf Coast index averaged $17.93 per barrel, gross margin capture was 94%, reflecting seasonally strong clean product differentials in the upper Rockies and benefits from our lag cost accrued differentials. Offsetting the improved margin backdrop was an approximate $25,000,000 impact from the crude unit turnaround activities, driven by reduced clean product sales and higher purchased product.

Speaker 4

Looking ahead to the Q3 in billings, clean product premiums to the Gulf Coast remain strong, trending slightly above Q2 levels quarter to date. Costly crude differentials in the 3rd quarter are expected to increase by approximately $5 per barrel, reflecting tighter heavy and send crude differentials during the Q2. As a reminder, feedstock costs and billings will typically lag prompt crude pricing by 1 quarter under our FIFO inventory accounting. 3rd quarter operating costs will reflect an incremental $7,000,000 to $8,000,000 related to the maintenance activities on the coker unit. In Wyoming, capture to the Gulf Coast Index was 82%, reflecting softer premiums in the Southern Rockies.

Speaker 4

Local demand continues to strengthen into the Q3 and clean product spreads to the Gulf Coast have returned to typical summer levels. Lastly, in Washington, the P and W index averaged $22.54 per barrel in the 2nd quarter, margin capture was 21%, driven by narrow heavy crude differentials and lower secondary product margins. Looking ahead, quarter to date heavy crude Prompt secondary product margins have also improved with the recent decline in flat price. The Logistics segment reported adjusted EBITDA of $26,000,000 in the 2nd quarter compared to $28,000,000 in the Q1, down slightly due to reduced pipeline throughput related to the billings turnaround. Our retail segment reported adjusted EBITDA of $19,000,000 during the 2nd quarter compared to $14,000,000 in the 1st quarter.

Speaker 4

Strong retail performance was driven by expanded fuel margins and continued growth in same store fuel volumes and merchandise revenue. Corporate expenses and adjusted EBITDA were $23,000,000 in the 2nd quarter compared to $29,000,000 in the 1st quarter. Reduced costs

Speaker 5

were

Speaker 4

$5,000,000 including a $61,000,000 working capital outflow related to a temporary increase in inventories and deferred turnaround expenditures of $29,000,000 Excluding these items, cash from operations was $85,000,000 during the Q2. Cash used in investing activities totaled $35,000,000 including $37,000,000 of capital expenditures, partially offset by $1,500,000 annual tax distribution from Laramie. Moving to financing activities, we recently completed the working capital refinancing in Hawaii, replacing the legacy inventory intermediation with a combination of borrowings under the expanded ABL and a crude only intermediation. In connection with the refinancing, total intermediation liabilities decreased by $412,000,000 offset by an increase in ABL funding of $420,000,000 As previously announced, the Hawaii refinancing is expected to reduce funding costs by approximately $10,000,000 per year. We continued our opportunistic approach to share repurchases with $66,000,000 during the Q2 and $116,000,000 year to date through August 5.

Speaker 4

Since completing the Billings acquisition last June, we have repurchased a total of 5,600,000 shares or equivalent to 10% of our current shares outstanding. Total liquidity as of June 30 was $520,000,000 made up of $180,000,000 in cash and $340,000,000 in availability. With a strong balance sheet, we are well positioned to advance our strategic growth priorities, while maintaining an opportunistic approach to share repurchases. This concludes our prepared remarks. Operator, we'll turn it to you for Q and A.

Operator

Thank you. And at this time, we will now begin the question and answer And our first question today will come from Neil Mehta with Goldman Sachs.

Speaker 5

This is Adam Wajaya on for Neil Mehta. Wanted to first get your thoughts on Singapore margins and a key area of focus in our recent conversations that center around more disappointing Asia demand and as a result Singapore margins and it looks like based on the par market indicators seen a tick up in margins over recent weeks. So what are you guys seeing in terms of real time demand and then how do you see that margin environment evolving over the coming months? Thank you.

Speaker 2

Sure, Adam. Good morning. So I think on the Singapore front, we're probably hovering between $11 $13 a barrel for the Singapore 312, and I think those are levels we characterize as mid cycle. I think on the supply side, you're looking at levels where the simpler refining fleet in Asia is up against negative gross margins. So I think you have some supply side support with respect to where the clean product margins are and I think importantly where secondary products are trading like fuel oil and naphtha.

Speaker 2

I think importantly, I think you've seen limited exports of refined product out of China despite some of the concerns on the demand side. And ultimately, I still think you're seeing the world operated in a connected fashion where barrels are arbitraging between Asia and Northwest Europe. So again, I think that's the net driver of ultimate refining throughput in the Northeast Asian market. And no major changes and with elevated freight impacting both inputs and the cost of arbitrage. I think the supply side has limited incentive to ratchet rates up further.

Speaker 5

Got it. Okay. That's super helpful. And then I guess my next question is just on capital returns. The buyback number came in really strong this quarter, which is good to see continued progress on the buybacks thus far into 3Q.

Speaker 5

So I wanted to get the team's updated thoughts on capital returns expectations in the context of the current refining margin environment and also where the share price is as well? Thank you.

Speaker 2

Sure, Adam. So I think on the share repurchase cadence, I think we'll remain opportunistic in how we think about it. And ultimately, our approach is going to be influenced by our cash generation, our outlook, the share price relative to our view of intrinsic value and ultimately our liquidity position. So we'll continue to look at all those factors and ultimately work to deliver a share repurchase cadence that I think is consistent with driving maximum shareholder

Speaker 5

returns. Got it. Super helpful. Thank

Operator

Our next question will come from John Royall with JPMorgan. Please go ahead.

Speaker 6

Hi, good morning. Thanks for taking my question. So my first question is on billings. You've got the 2024 work now behind you. It sounds like it went quite well.

Speaker 6

Can you talk about the work you have scheduled for 20 25 and how it compares in scope and in cost to this year's work?

Speaker 2

Sure, John. I think as we've messaged, our intent with billings is really over the course of 2024 and 2025 to turn around every major unit in the refinery. And again, the major work that was completed this year was a first step in the right direction. I think ultimately when you look at our expected amortized turnaround cycle and billings, it's about $120,000,000 over a roughly 4 to 5 year period. And so again, I think you can expect for us to spend the total amount between $24,000,000 $25,000,000 in that range.

Speaker 2

And there's probably an incremental $10,000,000 to $20,000,000 of work that we're focusing on to ensure that we get a solid run time out of the cat cracker, which is the major focus area for 2025.

Speaker 6

Great. Thank you. And then just sticking with the Rockies region, I was hoping for a little more color on the drivers of the crack basis between Rockies and Gulf Coast and how that's improved and maybe your expectations for the second half? And in particular, Will noted the southern market not doing quite as well. If you can just give some more detail on that bifurcation you're seeing there, that would be helpful.

Speaker 2

Sure. So I think ultimately, the Southern Rockies has a fair amount of interconnectivity with the Mid Continent. And I think our observation would be in June July, while you typically expect to see significant rail borne imports into Southern Rockies. Ultimately, we didn't see the spreads that you would typically expect in those markets. As you've moved later into July August, I would say it's beginning to normalize to higher levels.

Speaker 2

That would be more consistent with rail borne imports into PADD IV to balance supply and demand during peak demand season. The Northern Rockies again, I think is more principally served by rail. And ultimately demand seasonality is more pronounced, I think in the Northern Rockies. So I think those are the biggest factors that are driving the distinctions and differences. And ultimately, I think we're seeing good demand across our system.

Speaker 2

And ultimately, we're still seeing demand well in excess of supply in the summer periods.

Speaker 6

Thank you.

Operator

And our next question will come from Jason Gabelman with TD Cowen. Please go ahead.

Speaker 7

Yes, hey, morning. Thanks for taking my questions. I wanted to go back to billings and it sounded like I just wanted to confirm there was going to be some work on the coker in 3Q 'twenty four, if I heard correctly. Was that part of the initial plan for this year? Or was that related to something you perhaps saw in while you had the asset down in 2Q and had expect that to impact capture in 3Q?

Speaker 2

Sure, Jason. So this is consistent with our plan. It impacts OpEx, not CapEx and turnarounds. And again, this is largely due to the typical maintenance cycle lengths on our fluid coker. So ultimately, this is something that is going to be a 9 to 18 month interval.

Speaker 2

And we did accelerate the downtime based on some performance, but I wouldn't say it was a material reduction in the planned run time. So again, this is a really 9 to 18 month impact. And so I think you should really spread out those costs over that timeframe and think about it as amortized costs for running that unit.

Speaker 7

Okay. And then you have exposure to West Coast cracks both from Washington and then what you export from Hawaii to the West Coast. Could you just remind us on specifically Hawaii what that exposure is and how that impacted your results in 2Q and kind of how you're thinking about that impacting your results in 3Q?

Speaker 2

Sure. Jason, I don't think it'd be appropriate to specifically provide a percentage on our contract index exposure, but I would tell you that Hawaii does have a smaller percentage influence by both Pacific Northwest and Los Angeles markets. So again, I think Singapore is the main factor and that's why the index for Hawaii is set based on Singapore. That said, we are observing really the unusual weakness in the West Coast margin environment. That's reflected in our PMW Index, especially for summer periods.

Speaker 2

Again, I think that has more to do with influx of refined product imports in the May timeframe that when you look at them on a standalone basis appear to be very uneconomic given where the markets trended. And again, that's a very difficult arbitrage to capture value. And ultimately, when you look forward, the quantity of imports appears to be reducing, particularly on the gasoline side of the equation. That said, I think the West Coast is in a challenging environment given the material increases in renewable diesel into the market and the marginal barrel of conventional petroleum diesel being exported consistently. So again, I think we're in a good position as a low cost operator in Washington and ultimately are well positioned with our Hawaii business to capture opportunities when they emerge.

Speaker 7

Okay, great. If I could just sneak one more in. As you've absorbed billings and gone through the 1st major turnaround, how do you think about M and A moving forward? It sounds like you're still growing the retail business. There's been some public activity from one of your peers there?

Speaker 7

Are you still a buyer of retail and just more broadly on the M and A environment?

Speaker 2

Sure. So I think we've grown our business over the years through an active M and A program. And ultimately, I think it's one of our core competencies. That said, I think we're disciplined and thoughtful on value at all times. And I think we'll continue to weigh really the opportunity for us to redeploy capital to repurchase our shares as well as additional C store development and really the opportunities to invest in organic projects inside of our existing refining fleet to improve the efficiency of our operations.

Speaker 2

We'll weigh all those pieces and evaluate the opportunity set. And I think try and make the most thoughtful capital allocation decision. So again, I think it will remain dynamic. I would say ultimately the M and A market is still highly influenced by the last 24 months, which I think makes it difficult for a buyer and seller to agree on value. That said, given the outlook, I think you're likely to see a more rational framework emerge as concerns of or the return towards mid cycle environment becomes more evident.

Speaker 7

Got it. Makes sense. Thanks for the color.

Operator

And our next question will come from Matthew Blair with TPH. Please go ahead.

Speaker 8

Thank you and good morning. On the refining side, could you talk about WCS availability on the West Coast with TMX starting up? And for your Washington refinery, is that still entirely accrued by rail supply arrangements or are you able have you started running some of these TMX WCS barrels at Washington?

Speaker 2

Sure, Matthew. Thanks for the question. So we are seeing increasing availability of Canadian grades along the West Coast. And I think ultimately in Washington, we do have the capability to receive waterborne cargoes. And so we do have a great logistics system there that affords us the flexibility to both deliver rail as well as waterborne.

Speaker 2

Ultimately, I think the WCS market or the availability of Canadian crude is beginning to impact A and S pricing and broader West Coast crude alternatives. We are seeing lighter Canadian grades offered And I think that's presenting a new opportunity for our Hawaii business. Again, I think that's going to be dynamic over time. I think the winter period will be a good test as really the first cargoes loaded in May and you've seen volumes increase as we've gotten to June. But I think that's a dynamic factor and the Trans Mountain barrels are learning to offer in based on the typical waterborne trade cycle, which is different than the inland market trade cycle.

Speaker 8

Sounds good. And then in Hawaii, we thought the capture trend was pretty encouraging. I think the release mentioned a tailwind from the fuel lagged contract. But could you talk about some other drivers here? I guess, in particular, any benefit from your product crack hedging in Hawaii and any benefit from the pretty robust clean product tanker market?

Speaker 8

Thanks.

Speaker 4

Matthew, it's Sean. Q2 capture in Hawaii was 136%, so well above our 100 percent guidance. And I called out the $12,000,000 crack hedge gain. We also called out in the release $2,000,000 price hike benefit. So I think when you back out those sort of tailwinds that are working in our favor in Q2 captures about 110%.

Speaker 4

I think that sort of delta, the 110 versus the 100 is really reflective of the elevated clean product freight that we're continuing to see.

Speaker 8

Great. Thanks for your comments.

Operator

And our next question will come from Manav Gupta with UBS. Please go ahead.

Speaker 9

Sorry, if I missed this earlier, I just wanted a little bit of update on your Hawaii's renewable project, like what's the progress over there? You were already conducting an initial engineering design on the Cogen facility. Any updates you could provide over there?

Speaker 2

Sure, Manav. So the project there remains on track. Again, as a reminder, it's a $90,000,000 capital project that we're targeting to bring online in the second half of twenty twenty five. And ultimately, I think major equipment has been ordered. We've completed at least 2 of the feedstock tanks that will be necessary.

Speaker 2

And again, I are working on and have major bids in hand from critical vendors and providers to begin executing that and are awaiting 1 or 2 critical permits, but I think feel confident on the timeline there to receive and move ahead with those items. So feel good about where that project is. And on the renewable cogen project, again, moving through the power purchase agreement negotiation with Hawaiian Electric. And that's something that is targeted to be completed, I think, by the end of this year. And so I think from there, we'll have firmer estimates on our engineering and ultimately the power purchase agreement timeline and can make a final investment decision.

Speaker 9

Thank you so much. I'll turn it over.

Operator

And this will conclude our question and answer session. I'd like to turn the conference back over to Will Monteleone for any closing remarks.

Speaker 2

Great. Thank you all for joining us today. We're pleased with the strong operational performance of each of our teams and in particular, the well executed turnaround activities. Have a good day.

Operator

The conference has now concluded. Thank you for attending today's presentation and you may now disconnect your lines at this time.

Powered by Quartr
Earnings Conference Call
Par Pacific Q2 2024
00:00 / 00:00