The companies on the Global 500 employ 70.2 million people, and their revenue represents more than one-third of the world’s GDP.

Fortune Global 500

With a combined revenue of $21 trillion and $2.1 trillion in profits, the 2026 Fortune 500 is the definitive list of America's largest companies.

Fortune 500

The corporations on our annual list of the world's 500 largest companies combined to generate $41.7 trillion in revenue over the past year.

Almost $20 trillion in revenue—and a record-breaking $1.87 trillion in profits. Introducing the 2025 Fortune 500, the definitive list of the biggest companies in America.

Energy sector dominated this year for the first time since 2008, with 28 companies featured on the list.

100 Fastest-Growing Companies

The corporations on our annual list posted aggregate revenues of $41 trillion for the second year in a row.

Industries included in the sector are mining, oil and gas exploration and services, pipelines, refining, and utilities.

Fortune Sector Leaders: Energy

The Fortune 500, in its 70th year in 2024, ranks the biggest U.S. companies by revenue.

The corporations on our annual list of the world’s largest companies delivered a record $41 trillion in aggregate revenues.

G500-2023-Valero

Petroleum refining company Valero Energy leaped 42 spots in our ranking this year, bringing in $175.7 billion in revenue, a 53% increase over the previous year. 
<ul> 
 	<li>In May 2023, Valero announced that Joseph W. Gorder would retire as chief executive officer effective June 30, staying on as executive chairman. R. Lane Riggs, Valero’s president and chief operating officer, succeded Gorder.</li> 
 	<li>The company’s refining, renewable diesel, and ethanol segments each reported substantial increases in revenue as of the first quarter of 2023 compared to the year-earlier quarter.</li> 
 	<li>Valero’s Port Arthur Coker project, which the company expects will improve its efficiency by converting residual crude oil into useable fuels, was completed in March 2023 and began operations the month after.</li> 
 	<li>In April 2023, Valero agreed to pay a $1.2 million settlement to the U.S. Environmental Protection Agency after its refinery in Benicia, Calif., violated the federal Clean Air Act.</li> 
</ul>

The Fortune 500, in its 69th year in 2023, ranks the biggest U.S. companies by revenue.

F500 2023-Valero Energy

Petroleum refining company Valero Energy leaped 12 spots in our ranking this year, bringing in $171.2 billion in revenue, a 58% increase over the previous year. 
<ul> 
 	<li>In May 2023, Valero announced that Joseph W. Gorder would retire as chief executive officer effective June 30, staying on as executive chairman. R. Lane Riggs, Valero’s president and chief operating officer, will take Gorder’s place as CEO.</li> 
 	<li>The company’s refining, renewable diesel, and ethanol segments each reported substantial increases in revenue as of the first quarter of 2023 compared to the year-earlier quarter.</li> 
 	<li>Valero’s Port Arthur Coker project, which the company expects will improve its efficiency by converting residual crude oil into useable fuels, was completed in March 2023 and began operations the month after.</li> 
 	<li>In April 2023, Valero agreed to pay a $1.2 million settlement to the U.S. Environmental Protection Agency after its refinery in Benicia, Calif., violated the federal Clean Air Act.</li> 
</ul>

Aggregate sales hit $37.8 trillion last year—an increase of 19%, the highest annual growth rate in the list’s history.

This year’s Fortune 500 marks the 68th running of the list.

F500 2022 Valero Energy Corp

Like other oil and gas companies, refining giant Valero Energy enjoyed a snapback in revenue and earnings in 2021 as pandemic lockdowns eased. Valero has launched a number of low-carbon and renewable fuel projects in recent years, and has pledged to reduce emissions from its refining operations 63% from 2020 levels by 2025. The company’s Diamond Alternative Energy has taken some heat from environmentalists, however, for lobbying for renewable fuels over zero-emissions alternatives; Diamond is a plaintiff in a recent federal lawsuit against Environmental Protection Agency regulations designed to encourage the sale of electric vehicles.

Total revenue for the world’s biggest companies fell 4.8% to $31.7 trillion this year—the first decline in half a decade.

G500-2021-164-VALERO ENERGY

<span data-sheets-value="{&quot;1&quot;:2,&quot;2&quot;:&quot;The U.S. refining sector was battered in 2020 by lockdowns and travel restrictions, pushing the San Antonio–based refiner to a $1.4 billion loss. That compares with 2019’s $2.4 billion profit. One saving grace came from Valero’s renewable fuels business, which capitalized on the push for low-carbon alternatives to fossil fuels. The company now expects to invest half of its growth capital in renewable diesel. As part of its expansion, last year Valero approved a new diesel plant that is expected to begin operations in 2023.&quot;}" data-sheets-userformat="{&quot;2&quot;:12673,&quot;3&quot;:{&quot;1&quot;:0},&quot;10&quot;:2,&quot;11&quot;:4,&quot;15&quot;:&quot;Calibri&quot;,&quot;16&quot;:11}">The U.S. refining sector was battered in 2020 by lockdowns and travel restrictions, pushing the San Antonio–based refiner to a $1.4 billion loss. That compares with 2019’s $2.4 billion profit. One saving grace came from Valero’s renewable fuels business, which capitalized on the push for low-carbon alternatives to fossil fuels. The company now expects to invest half of its growth capital in renewable diesel. As part of its expansion, last year Valero approved a new diesel plant that is expected to begin operations in 2023.

This year’s Fortune 500 marks the 67th running of the list.

F500-2021-53-Valero Energy

This year's Fortune Global 500 generated $33.3 trillion in revenues and $2.1 trillion in profits.

G500-2020-071-Valero-Energy

As CEO Joe Gorder put it when the company released its annual financial report, Valero faced another “challenging environment for the refining business” in 2019. Net income sank 17% year-on-year, to $2.8 billion, even as refinery utilization was at 96% and the company refined record amounts of oil. The business completed a network of central Texas pipelines and terminals, extending the reach of its vast U.S. shale business deeper inland. Its 2020 growth ambitions suffered a blow in late November when its renewable fuels business stumbled: Two ethanol plants were forced to close temporarily, and additional plants went offline in March 2020, as the coronavirus pandemic destroyed demand for any and all types of energy.

This year's Fortune 500 marks the 66th running of the list.

F500-2020-032-Valero-Energy

This year's Fortune Global 500 generated $27.7 trillion in revenues and $1.5 trillion in profits.

This year's Fortune 500 marks the 65th running of the list.

This year's Fortune 500 marks the 64th running of the list.

This year's Fortune 500 marks the 63rd running of the list.

Here are the World's Most Admired Companies for 2016 as ranked in their industries. See who made the list.

World's Most Admired Companies

This year's Fortune Global 500 generated $27.6 trillion in revenues and $1.5 trillion in profits.

This year's Fortune 500 marks the 62nd running of the list.

Business insiders have spoken: Asked which companies they most admire, more than 4,100 executives, directors, and analysts chose these top 50 All-Stars.

The world's 500 largest companies generated $31.2 trillion in revenues and $1.7 trillion in profits in 2014. Together, this year's Fortune Global 500 employ 65 million people worldwide and are represented by 36 countries.

This year's Fortune 500 marks the 61st running of the list. Wal-Mart claims the top spot again. See who made the list.

Global business is back. After limping through a worldwide financial crisis and economic slowdown, the 500 largest companies ranked by revenues shattered all sorts of performance records in 2013: They racked up combined revenues of $31.1 trillion, up 2.5% from 2012, and profits soared 27% to nearly $2 trillion. China’s 95 companies (up from 89 last year) posted $5.8 trillion in revenues. The U.S. has four fewer companies on the list than last year but remains (for now) the country leader, with 128 corporations on the list—including No. 1 Wal-Mart Stores—reporting $8.6 trillion in revenues. 

Wal-Mart stayed on top as its sales crept closer to half-a-trillion dollars. Apple moved into the top five. And UnitedHealth Group continued its steady climb. 

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Valero Energy is an oil refiner with operations in the U.S., Canada, Latin America, and Europe. Founded in 1980, the company sells gasoline, diesel, and ethanol through outlets under the Valero, Beacon, Diamond Shamrock, Shamrock, Texaco, and Ultramar brands.

Q2 2026

Q1 2026

Q4 2025

Q3 2025

Q2 2025

Q1 2025

Q4 2024

Valero Energy (VLO): Company Profile, Stock Price, News, Rankings

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Valero Energy

valero energy

Greetings, and welcome to Valero Energy Corp. Second Quarter twenty twenty five Earnings Conference Call. At this time, all participants are in a listen only mode. A question and answer session will follow the formal presentation. As a reminder, this conference is being recorded.

It is now my pleasure to introduce your host, Homer Volar, Vice President, Investor Relations and Finance. Thank you. Please go ahead.

Good morning, everyone, and welcome to Valera Energy Corporation's second quarter twenty twenty five earnings conference call. With me today are Lane Riggs, our Chairman, CEO and President Jason Fraser, our Executive Vice President and CFO Gary Simmons, our Executive Vice President and COO Rich Walsh, our Executive Vice President and General Counsel and several other members of Valero's senior management team. If you have not received the earnings release and would like a copy, you can find one on our website at investorvalero.com. Also attached to the earnings release are tables that provide additional financial information on our business segments and reconciliations and disclosures for adjusted financial metrics mentioned on this call. If you have any questions after reviewing these tables, please feel free to contact our Investor Relations team after the call.

I would now like to direct your attention to the forward looking statement disclaimer contained in the press release. In summary, it says that statements in the press release and on this conference call that state 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. There are many factors that could cause actual results to differ from our expectations, including those we've described in our earnings release and filings with the SEC. Now, I'll turn the call over to Lane for opening remarks.

Thank you, Homer, and good morning, everyone. We are pleased to report solid financial results for the second quarter, driven by our strong operational and commercial execution. In fact, we set a record for refining throughput rate in our U. S. Gulf Coast region in the second quarter, demonstrating the benefits of our investments in growth and optimization projects.

Refining margins were supported by strong product demand against the backdrop of low product inventories globally. In particular, early July U. S. Diesel inventories and days of supply are at the lowest level for the month in almost thirty years. We continue to see strong demand with our quarterly diesel sales volumes up approximately 10% over the same period last year and gasoline sales about the same as last year.

On the financial side, we continue to honor our commitment to shareholder returns with a payout ratio of 52% in the second quarter and last week we announced a quarterly cash dividend on our common stock of $1.13 per share. On the strategic front, we continue to progress the FCC unit optimization projects at St. Charles that will enable the refinery increase the yield of high value products including high octane alkali. The project is expected to cost $230,000,000 to start up in 2026. Looking ahead, we remain optimistic on refining fundamentals with several planned refinery closures this year and a limited announced capacity additions beyond 2025.

Additionally, we expect our sour crude oil differentials to widen as OPEC plus in Canada continue to increase production during the third and fourth quarters. In closing, we remain committed to maintain our track record of commercial and operational excellence, which has been the hallmark of our strategy for over a decade. And our commitment remains underpinned by a strong balance sheet that also provides us plenty of financial flexibility. So with that Homer, I'll hand the call back to you.

Thanks Lane. For the 2025 net income attributable to Valero stockholders was $714,000,000 or $2.28 per share compared to $880,000,000 or $2.71 per share for second quarter of twenty twenty four. The refining segment reported $1,300,000,000 of operating income for the 2025 compared to $1,200,000,000 for the second quarter of twenty twenty four. Refining throughput volumes in the 2025 averaged 2,900,000 barrels per day or 92% throughput capacity utilization. Refining cash operating expenses were $4.91 per barrel in the second quarter of twenty twenty five.

The renewable diesel segment reported an operating loss of $79,000,000 for the 2025 compared to operating income of $112,000,000 for the second quarter of twenty twenty four. Renewable diesel sales volumes averaged 2,700,000 gallons per day in the second quarter of twenty twenty five. The ethanol segment reported $54,000,000 of operating income for the 2025 compared to $105,000,000 for the second quarter of twenty twenty four. Ethanol production volumes averaged 4,600,000 gallons per day in the second quarter of twenty twenty five. For the second quarter of twenty twenty five, G and A expenses were $220,000,000 net interest expense was $141,000,000 and income tax expense was $279,000,000 Depreciation and amortization expense was $814,000,000 which includes approximately $100,000,000 of incremental depreciation expense related to our plan to seize refining operations at our Benicia refinery by the April.

Net cash provided by operating activities was $936,000,000 in the second quarter of twenty twenty five. Included in this amount was a $325,000,000 unfavorable impact from working capital and $86,000,000 of adjusted net cash used in operating activities associated with the other joint venture member share of DGD. Excluding these items, adjusted net cash provided by operating activities was $1,300,000,000 in the second quarter of twenty twenty five. Regarding investing activities, we made $4.00 $7,000,000 of capital investments in the 2025 of which $371,000,000 was for sustaining the business including costs for turnarounds, catalysts and regulatory compliance and the balance was for growing the business. Excluding capital investments attributable to the other joint venture member share of DGD and other variable interest entities, capital investments attributable to Valero were $399,000,000 in the second quarter of twenty twenty five.

Moving to financing activities, we returned $695,000,000 to our stockholders in the second quarter of twenty twenty five, of which three fifty four million dollars was paid as dividends and $341,000,000 was for the purchase of approximately 2,600,000.0 shares of common stock resulting in a payout ratio of 52% for the quarter. Year to date, we have returned over 1,300,000,000 through dividends and stock buybacks for a payout ratio of 60%. And as Lane mentioned on July 17, we announced a quarterly cash dividend on common stock of $1.13 per share. With respect to our balance sheet, we repaid the outstanding principal balance of $251,000,000 of 2.85% senior notes that matured in April. We ended the quarter with $8,400,000,000 of total debt, 2,300,000,000.0 of total finance lease obligations and $4,500,000,000 of cash and cash equivalents.

The debt to capitalization ratio net of cash and cash equivalents was 19% as of 06/30/2025. And we ended the quarter well capitalized with $5,300,000,000 of available liquidity excluding cash. Turning to guidance, we still expect capital investments attributable to Valero for 2025 to be approximately $2,000,000,000 which includes expenditures for turnarounds, catalysts, regulatory compliance and joint venture investments. About $1,600,000,000 of that is allocated to sustaining the business and the balance to growth. For modeling our third quarter operations, we expect refining throughput volumes to fall within the following ranges.

Gulf Coast at 1,760,000 to 1,810,000 barrels per day, Mid Continent at four and thirty thousand to 450,000 barrels per day, West Coast at two and forty thousand to 260,000 barrels per day and North Atlantic at 465,000 to 485,000 barrels per day. We expect refining cash operating expenses in the third quarter to be approximately $4.8 per barrel. With respect to the renewable diesel segment, we still expect sales volumes to be approximately 1,100,000,000 gallons in 2025, reflecting lower production volumes due to economics. Operating expenses in 2025 should be $0.53 per gallon, which includes $0.24 per gallon for non cash costs such as depreciation and amortization. Our ethanol segment is expected to produce 4,600,000 gallons per day in the third quarter.

Operating expenses should average $0.40 per gallon, which includes $05 per gallon for non cash costs such as depreciation and amortization. For the third quarter, net interest expense should be about $135,000,000 Total depreciation and amortization expense in the third quarter should be approximately $810,000,000 which includes approximately $100,000,000 of incremental depreciation expense related to our plan to seize refining operations at our Benicia refinery by the April. We expect this incremental depreciation related to the Benicia refinery to be included in D and A for the next three quarters, resulting in a quarterly earnings impact of approximately zero two five dollars per share based on current shares outstanding. For 2025, we still expect G and A expenses to be approximately $985,000,000 That concludes our opening remarks. Before we open the call to questions, please limit each turn in the Q and A to two questions.

If you have more than two questions, please rejoin the queue as time permits to ensure other callers have time to ask their questions.

Thank you. The floor is now open for questions. Our first question is coming from Theresa Chen of Barclays. Please go ahead.

Good morning. Now that we are halfway through the summer driving season, how is refined product demand trending across your footprint? Maybe just unpack some of Wayne's opening remarks about sales across your system. Are there any noticeable patterns or shifts? And additionally, what kind of signals are you observing in the export market?

Hey, good morning, Theresa. It's Gary. Overall, I'd tell you the fundamentals around refining continue to look very supportive. Total light product inventory remains below the five year average range, below where we were last year at this time. And demand for transportation fuels remains robust, not only here in The U.

S, but also into our typical export markets. Our view is gasoline demand relatively flat to last year. It looks like vehicle miles traveled are up slightly year over year, but probably only up enough to offset efficiency gains in the automotive fleet, not up enough to really create incremental demand. If you look at our wholesale volumes, they would also indicate flat year over year gasoline demand. In addition to regular relatively strong gasoline demand domestically, we've also seen good export demand to Latin America.

And then on the supply side, the Transatlantic arb to ship gasoline from Europe to The United States has been closed for much of the year. So when you combine relatively good demand with less supply coming from Europe, you would kind of expect inventory to be a little lower than last year, and that's what we saw in the second quarter. So those factors ultimately resulted in a little stronger gasoline margin environment this year compared to last. Going forward, the Transatlantic Arb is marginally open. So supply seems adequate to meet demand.

We're kind of getting to the end of driving season. We'll start RVP transition in some regions soon. So it's hard to see a lot of support for gasoline cracks moving forward. Absent some type of supply disruption, we kind of expect gasoline cracks to follow typical season patterns, remain around mid cycle levels through the end of the year. Dissolate, the story is much different though, where gasoline demand is expected to fall off some, we expect distillate demand to pick up.

First, we'll start to get into harvest season, see agricultural demand pick up and then we'll transition to heating oil season. Overall, diesel demand has continued to trend above last year's level, really strong demand in the first quarter due to colder weather and then increased demand for refinery produced diesel with less imports of bio and renewable diesel. In our system, diesel sales are currently trending about 3% above last year's level. Again, while domestic demand has been good, we see a strong pull of U. S.

Gulf Coast distillate into the export markets. And the export really have kept inventory down near historic lows during a time where restocking typically occurs. We have seen diesel inventory gain in the last couple of weeks, but really that's just a result of an incredibly strong export market in early June. As exports got really strong, freight rates spiked And so it closed some of those export ARBs. Freight rates have come back off.

So the ARBs are open to export both to Latin America and Europe. With those ARBs open, it's difficult to see how we get the normal build in diesel inventory that occurs in the third quarter. So diesel cracks have been strong with low inventory. We expect diesel cracks to remain strong. Heading into hurricane season, if we have some type of supply disruption, I think you'll see a pretty significant market reaction with inventories as low as they are.

Thank you, Gary. And what is your near to medium term outlook for light heavy differentials, taking into account the tailwind from incremental OPEC plus barrels coming to market, but also considering potential headwinds from MX production volatility, the unavailability of Venezuelan barrels, GAM crude quality issues and so on. How do you think these factors play out?

Yes. That's far year to date. I think the quality differentials have certainly been a headwind for us. We thought coming into the year, you'd see less demand with Lyondell going down, but that was kind of offset. The Venezuelan sanction pulled about 200,000 barrels a day out of The U.

S. Gulf Coast market. You had the wildfires that took about 5,000,000 barrels of June supply off the market. But going forward, we do think things will get better. It will probably be the fourth quarter before you really see that.

Canadian production has not only recovered from the wildfires, but it continues to grow. Then as you mentioned, OPEC unwinding their 1,900,000 barrels a day of cuts by August. Really, appears that much of the ramp up in the OPEC production we haven't seen on the market yet so far because there was crude oil burn in the region for seasonal power demand. As we move out of summer, more of those barrels will make their way to the market. And then early summer tensions in The Middle East also caused some countries to front end load fuel purchases that they use for power demand also.

Again, that will unwind fuel coming back off to the market as fuel comes back, that will support wider differentials as well. Additionally, in the fourth quarter with turnaround activity, you should see less demand for those barrels. So all of those should really contribute to wider differentials in the fourth quarter. I think the only unknown here is really what happens with the Russian sanctions. Thus far, we haven't really seen much of an impact.

But if the sanctions are effective and cut some of the Russian barrels, that would obviously differentials.

Thank you. The next question is coming from Manav Gupta of UBS. Please go ahead.

Team, just wanted to understand what's your outlook for the net capacity additions for the remaining part of this year and for 2026? Are you still seeing major capacity additions globally? Or do you think those things are slowing down and given the demand growth, we should be better positioned going ahead, if you could talk about that?

Yes, Manav, this is Gary. I think definitely when we look out on the horizon, there's not a lot of new capacity coming online and a lot of what new capacity there is, is really more geared toward petrochemical production rather than making transportation fuels. If we look at next year, it looks like just over 400,000 barrels a day of new refining capacity coming online. Initially, most consultants were forecasting around 800,000 barrels a day of total light product demand growth, which would have indicated significant tightening starting next year. With some of the economic uncertainty, especially around tariffs, forecasts have fallen off to where a lot of are only forecasting around 400,000 barrels a day total like product demand growth.

And then a lot of consultants are showing a lot of that demand growth being filled by a step change in renewable production. I'm confident we'll see tighter supply demand balances. The question really is when does this occur? Is it next year? Do we actually see some type of economic activity slowdown?

And it isn't until 2027 that things really start to get tight. Thus far, our view is the economy has been fairly resilient. Demand for transportation fuels has remained strong. So I guess I'm a little more optimistic about the economy, and we'll have to see with all the uncertainty on renewables whether we see a ramp up production or not. The other big factor in all this is, will we see additional refinery rationalization?

Although some refinery closures have been announced, certainly the recent announcement around the Lindsay refinery in The UK was fairly unexpected. Hard to believe there aren't others facing a similar situation with other refinery closure or two things could really tighten up a lot faster. But the big driver here is really what happens to the economy and you're probably in a better position to assess that than I am.

A quick follow-up is, I was looking at your Gulf Coast capture. Now that's where heavy light narrowness should hit the capture the hardest, but the capture actually was over 92%. I'm trying to understand few dynamics what allow you to deliver such strong capture. And then coming back to the first question, if heavy lights do widen out, should we expect a tailwind to the Gulf Coast capture because the way your benchmark is constructed, those do not reflect reflected in the benchmark. So if you could talk about that?

Yes, Manav, this is Greg. So I think you hit on some of the points related to heavy light and capture because we do include heavy grades in our reference for the Gulf Coast. So as those move out and contract that's picked up in the reference crack that we use. So not as big of an impact on capture rates because it's built into indicator margin that we use. On our performance in second quarter, a lot of the improvement was driven by really strong operating performance coming out of the heavy maintenance we had in the first quarter.

And that was really highlighted, if you remember by Lane's comment about record quarterly throughput in that region. So good operating performance. We had strong commercial performance as well in that region, particularly on the product side, good exports, great wholesale performance in that part of our business as well. So those were the primary drivers for The Gulf Coast in the second quarter. And again, as those crude differentials widen out to the extent that they're in the indicator that we use, probably not as much of a factor when you think about the capture rate relative to our indicator.

Thank you. The next question is coming from Neil Mehta of Goldman Sachs. Please go ahead.

Yes. Morning, team. I want to spend some time on return of capital. Returned $633,000,000 in the first quarter or second quarter with the payout of north of 70%. So just your perspective on the sustainability of capital returns and how we should be thinking about the buyback in the back half of the year?

Yes, Neil. Hey, it's Homer. Mean, maybe I'll just start with just a framework around buybacks, right. It's guided by a number of things. Obviously, first and foremost, we've got our stated minimum commitment to an annual payout of 40% to 50% of adjusted cash flow, right.

And so you should continue to consider that as non discretionary, we'll honor that in any sort of environment. Then we've got our target minimum cash position of 4,000,000,000 to $5,000,000,000 and we're right at the midpoint there. So we're not looking to build more cash, right. And as a result of that, consistent with what we've been saying for quite some time, we'll continue to use all excess free cash flow to buy back shares. And as you highlighted, second quarter resulted in a payout of 52%.

Keep in mind though that we also used $251,000,000 towards the notes that matured in April in addition to $325,000,000 that was consumed while working capital, right? So looking forward with the balance sheet where it is and discipline around capital investments, I think you can continue to expect us to maintain this posture where all excess free cash is aimed at share buybacks. Longer term, I mean, don't know if you have the investor deck handy, but we've got a slide in there. I think it's Slide 11 that puts all of this into context actually reflecting our actual results. So if you look at the last ten year period through 2024, total cash flow from operations was around 61,000,000,000 includes changes in working capital, which is roughly $6,000,000,000 a year.

If you think about run rate CapEx, right, 2,000,000,000 to $2,500,000,000 so 2,250,000,000.00 at the midpoint with $1,500,000,000 sustaining and then $500,000,000 to $1,000,000,000 of growth. And layer on top, you've got $1,400,000,000 or so to fund the dividend, So $6,000,000,000 of annual cash flow from operations, 2,500,000,000.0 CapEx, dollars 1,400,000,000.0 to dividend that leaves over $2,300,000,000 for buybacks based on our actual results over the past ten years. Hopefully that gives you some context.

Really helpful, Homer. Just the follow-up is around DGD. Obviously, lot of moving pieces and appears to be pretty tough, if not trough conditions. What's the path back to mid cycle here? How do you think about the evolution of this business? And can you talk about your commitment to it?

I think you've already said that it's in a lot of policy clarity vagueness right now. I think you can see really the linchpin in all of this is going to be what the EPA says post their comment period, that are due by August 8. And so what they do in terms of setting the RVO and what they do in terms of SREs and if in any reallocations will set the D4 RIN market and then consequently hopefully set how the rest of the other markets will react versus the D4 RIN. So I mean we see the LCFS market in California is slowly moving up after they pass their 9% obligation increase effective July 1. We see that a lot Europe continues to support its mandate for the 2% SAF requirement.

We see the CFR in Canada is going to continue to go forward. Long term there's still enough tailwind out there that says this segment will continue to be in demand. It's really just a question of when we see these credit prices start to move. You're starting to see the D4 RIN move up. You're starting to see it separate from the D6.

The big question is going to be when you see fat prices adjust to these policies once these policies are clarified. And so once those fat prices start to disconnect then I think you'll see the margins open up for DGD and you'll see more demand for DGD and renewables with the ongoing policy years.

you. The next question is coming from Doug Leggate of Wolfe Research. Please go ahead.

So guys, I think I got to go back to refining school because you guys are embarrassing us here with your distillate yields versus your light sweet crude throughput. I wonder if you could help us reconcile what's going on there. Obviously margins are heat margins were better than gas for most of Q2, I guess. But when we look at the line basically since 2024, I think your light crude is about 10% higher, but your distillate yield is up materially as well. So great result, but can you help us understand what's going on there is my first question. I've got a quick follow-up for Eric.

Yes, Doug, this is Greg. So I would tell you it's pretty simple. We've been for the most part in that period in max distillate production mode. So when you think about how we're adjusting the operation, we're maximizing the yield of jet fuel and diesel fuel. So even though you've got a crude slate that might be a bit lighter, we can do some adjusting within the downstream operation to try to make sure we get all the distillate molecules into that pool that we can.

And we've been pretty successful and effective at doing that in that timeframe.

Sorry for the part B here, but would I assume that that's part of the reason why your capture is doing so well?

Certainly helps it. Certainly, it's helped when you've got that strong distillate crack and then you're maximizing that yield that certainly will have a positive impact on capture.

Thank you for that. So Eric, wanted to follow-up on the other question if you don't mind just on renewable diesel. I see if you can dumb it down for us. When you roll everything together, and you guys are obviously the lowest cost producer with the best feedstock setup, do you see DGD net to Valero as free cash flow positive on a sustainable basis?

I think the answer to that is yes. We're like I said, but it's going to take a little bit of clarity on what the EPA is going to do with RINs, because the numbers they're talking about doing will put a positive tailwind into DGD's production. And so to your point, we still have the best market access both from a feedstock standpoint, a certification of products and access to all the different markets. And it's still a low CI game. I think one of the things that everyone needs to keep in front of them is that Europe and The UK really only accept waste oil, low CI feedstock, certified feedstock.

So as much as there's been a lot of talk about the support of domestic production in soybean oil and Canada's canola oil, those are not acceptable feedstocks to most of the customers that are really interested in lowering their carbon footprint. And so we're still the most advantaged from a feedstock standpoint. I think once you start to see these credit prices move and like I said, we have seen LCFS and RIN prices moving higher. Those factors and credit prices will continue to make DGD an advantage platform and long term it will be a positive cash flow into Valero.

If you can make money, nobody can in this business. So thanks so much guys. I appreciate the time.

Thank you. The next question is coming from Ryan Todd of Piper Sandler. Please go ahead.

Thanks. Eric, maybe one more follow-up on that side of the business. I mean, seems so far that your staff operations, the staff operations have been going well. Can you maybe you're eight or nine months into post start ups of the conversion there, the expansion there. Can you maybe talk about what you've seen so far either operationally, what you've seen in terms of what's maybe surprised or been as expected in terms of the geographic mix of demand, pricing, etcetera, and how that market is evolving?

Yes, thanks. I think, one thing we discovered operationally that I might say was a pleasant surprise was our unit made SAF very, very well and it blended very, very well. There would Prior to our startup, we'd heard through others that had gone down this journey that it was very difficult to make, it was very difficult to blend, it was very difficult to make the certifications and satisfy logistics. We've with the combination of DGD's gear, quality of our project startup team and our overall project design, we've got a lot of capability in on SAF as well as everything between SAF and call it traditional RD. So operationally this thing has been a positive.

The logistics and blendability has been a positive. The ability to move this product through the Valero jet fuel system has been very effective. I think if there is any sort of downward surprises, we thought there would be much more interest in this product particularly from airlines. I think everyone is still feeling out this market. We're seeing a lot of interest in sales.

Obviously, the mandate in The EU and The UK, there's some potential that they have under bought for the first half of the year and they may come back and try to make sure they're hitting their 2% blend in the back half of this year. So we may see some sales pick up in the second half of this year as they stare at their end of year compliance target. So I think this market continues to grow. The demand continues to grow. The interest continues to grow.

The interest in the voluntary credits associated with this continue to grow. That is very small volumes, but everyone's trying to explore that as a way to simplify their carbon offset plan by just going direct to DGD. So, I still see a lot of upside in that. The project is still returning. The returns on our project are still meeting our threshold targets.

So that's going very well. And the credit prices have supported the making of the product. And so, if I add on to that because the next question well, well, the recent reconciliation bill narrowing the benefit of SAF to equal to RD, we still see premiums above that coming out of the market. And as everyone figures out how to readjust with the changes in the PTC, we still see premiums for SAF over RD from the customer standpoint.

Great. Thank you. And then maybe a question for you, Lang. Sorry to ask, but I mean, reports that the California government envisions themselves kind of like brokering a sale of the Venetia refinery. Any comments or any thoughts on anything that could potentially change what would you that would change your mind to close that asset next year?

Hey, this is Rich Walsh. First, yes, we don't respond to speculation in media reports along those lines. And nothing has changed in our plans regarding Venetia right now. But look, there's been a lot of public discussion about reforming the market and in particular the regulatory environment in California to head off refinery closures. And I think you guys all know the CEC has been tasked with evaluating refinery capacity on behalf of the state.

And I think they're working very hard to see what if anything they can do. And for our part, we've been in discussions with the CEC and other elected officials and policy officials regarding Benicia's future. And I think there's a genuine desire for them to avoid the refinery closure, but there's no solutions that have materialized at least not from our perspective.

Thank you. The next question is coming from Paul Cheng of Scotiabank. Please go ahead.

Hey, guys. Good morning. The question that as Saudi is putting more barrels in the market, assume there's going to be more than medium sour grade like the Arab medium. I'm wondering that how you think it's going to impact on the global distillate yield as more of the medium sour is available? That's the first question.

Hey Paul, it's Greg. Yes, so obviously you're right. Those grades have more distillate typically in them than some of the lighter grades. So as we see those come into the market, you would expect that to have a positive impact on distillate yield overall and as a result distillate production would work up a bit. I don't have a good feel for the exact numbers for that, but there's no doubt that's a those are grades that are more rich and distillate than most of the other crews that we have run-in their place over the last few years.

Mean, Great. Know that it's difficult pinpoint an exact number. The Hennig field that you said a 2% increase, 5% or anything that you can share?

Yes. Paul, I don't have those numbers off the top of my head. I'm sure you can contact Homer and we can talk about that more offline. But I don't remember the numbers off the top of my head.

But this is Lane. I think the one thing to add to that is you got to think about the markets you're putting diesel into and the specs around it, whether they're high cetane or ultra low sulfur diesel. So in a global sense, the incremental diesel, it does is there open capacity for the higher valued markets where the stuff's pointed versus does the incremental diesel is produced in the world as these grades gets more sour and more heavy? They end up just sort of as heavy or in the marine market that's sort of one of the things you got to consider with your the way you're thinking about it.

Okay, great. The same question I think is for Eric. Eric, I mean with the PTC and everything that is more in favor of domestic production and also keeping in the local market, I assume. So is that still economic for us that to export, Audi from DGD into I know that previously you guys export quite a lot to Europe. So are those still economic or that the economic now saying that it's going to be majority of the RV production will be staying local?

Yes. I think so we do see the markets in Canada, EU, UK and California are still attractive for foreign feedstocks. The challenge that we have is we haven't most of this is still trading on news. So you've seen as the EPA will talk about what they're doing with the RIN, you'll see most of the fat prices are tracking the D4 RIN. So even though fat prices have moved up, credit prices are slowly moving up, they haven't separated yet to reflect the impacts of some of the other policy comments on lower PTC, half RIN in the RVO and really a lot of the tariffs that have been placed on foreign feedstocks.

So at some point those markets will have to adjust. I think as the policies get papered, get finalized and papered and you'll see there will have to be some reflection in foreign feedstock prices versus domestic feedstock prices to continue keep to continue meeting the demand of all those other markets. And so like I said before, it's still a low CI game and a lot of the customers do not want vegetable oil as their feedstock base. So there will be an increase in the RIN. There will be support of vegetable feedstocks feeding into the RIN.

But when you go into LCFS markets or markets that are based on LCFS and CI, it's still going to want to pull low CI feedstocks. And so you'll have to see the market adjust for that. And I think we're starting to see some of those prices move, but it's probably going to take some time for these credit prices to increase based on the length in the credit banks for both RINs and LCFS. So I think as those banks slowly start to get consumed, the credit prices will move up. You'll start to see foreign feedstocks disconnect from domestic feedstocks.

Both of them need to disconnect from the D4 RIN in order for anyone to increase production, particularly if you look at the a lot of the veg oil BD players, if soybean oil and the D4 RIN just track, there is no margin to run yet. And so I think once you see whatever the EPA comes out with RVO and SREs that will determine when you start seeing BD and RD start to increase in production.

Eric, can we confirm that what percentage of your DGD, how D is currently export to Europe and Canada?

Yes. We're not going to share that level of detail Paul, we are the largest exporter and really one of the largest producer of SAP. And so we're definitely maxing out what we can sell into those markets. But yes, that will always shift around based on feedstock prices and credit prices.

Thank you. The next question is coming from Paul Sankey of Sankey Research. Please go ahead.

Hey, everyone. We've had good high levels of throughput in U. S. Refining this year despite the shutdowns. Can you just talk a little bit about that?

It's been very fairly steady and very high. And I just wondered what the components of that were as well as the outlook for the second half in your view, perhaps ignoring hurricane risks and stuff, but just the general turnaround outlook for the second half? And the follow-up is a very interesting moment in history with The U. S. Becoming a net exporter to Nigeria.

You just of oil, could you just talk a little bit about the impact of Nigerian refining on Atlantic Basin markets? Interesting stuff.

Hey, Paul. Paul, it's Greg. I'll think I'll talk about the first one. Just repeat that for me again. What part of are you looking at?

With the shutdown of Lyondell and stuff, we've just seen, what is it, dollars 17,500,000.0 of throughputs in U. S. Refining seems like a high number. That's been very steady, actually. I just it's a good thing.

I just wondered how come we're so high and holding so high from your perspective and from an industry perspective. The follow through is second half turnarounds and whether or not we'll really sustain this kind of throughput? Thanks.

Valero Energy (VLO) Q2 2025 Earnings Call Transcript

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