According to WPB, the most important constraint in today’s oil market may no longer be the availability of crude alone. The pressure is increasingly shifting downstream, where damaged plants, reduced refinery runs and limited effective processing capacity are keeping refined-product markets much tighter than headline crude prices suggest. Brent crude was trading around $88 per barrel on August 17, 2026, almost one-third below the roughly $126 reached at the height of the Iran war. Diesel, however, has not followed crude lower at the same speed. That divergence matters for bitumen because a refinery does not decide how much paving material to produce based only on the price of its crude feedstock. It also compares the value of heavy refinery streams with what those same molecules can earn if they are upgraded into higher-value fuels.
The latest downstream data show how wide that gap has become. The International Energy Agency estimates that Middle Eastern refinery throughput during the second quarter of 2026 remained approximately 2.9 million barrels per day below pre-war levels and is expected to remain around 2.2 million bpd below those levels in the third quarter. Russian refining has meanwhile fallen close to a two-decade low following repeated damage to processing infrastructure, while Chinese refinery throughput and fuel exports have also been reduced. On a global basis, refineries processed about 5 million bpd less crude in July than a year earlier.
The effect is particularly visible in middle distillates. Combined diesel exports from Russia, the Middle East and major Asian suppliers were approximately 1.3 million bpd lower in July than one year earlier, according to IEA estimates. That reduction is equivalent to roughly one-fifth of the seaborne trade on which importing markets rely. At the Amsterdam-Rotterdam-Antwerp hub, gasoil inventories were about 24% below their five-year average, while jet-fuel inventories were around 39% below average. European diesel’s premium over Brent, a broad indicator of refinery profitability from producing diesel, has risen from approximately $25 per barrel at the beginning of 2026 to more than $70.
These numbers change the commercial question for the bitumen market.
If crude prices decline but diesel and jet-fuel margins remain exceptionally strong, a complex refinery can have more, not less, incentive to maximize conversion. Heavy fractions produced after atmospheric and vacuum distillation do not automatically become bitumen. Depending on the refinery configuration, suitable streams may be retained for asphalt production, blended into fuel oil, or directed toward delayed cokers, hydrocrackers, visbreakers and other upgrading units that convert heavier material into lighter and potentially more profitable products.
The technical foundation for that competition is straightforward. Delayed coking thermally converts heavy refinery fractions into lighter oils and petroleum coke, while flexicoking and fluid coking can convert heavy hydrocarbons and distillation residues into lighter products. Hydrocracking can also process residual or heavier material into products including jet fuel and other higher-value streams. Solvent deasphalting can remove asphaltic components from heavy petroleum fractions so that recovered material can be directed into fuel-production pathways.
For bitumen traders, this means the market cannot assume that cheaper crude automatically produces cheaper or more abundant bitumen.
The relevant calculation inside a refinery is the opportunity value of the bottom of the barrel. When diesel cracks are ordinary, selling suitable vacuum residue as paving-grade bitumen may offer an attractive return. When diesel margins become exceptionally high, the refinery may obtain greater value by pushing more heavy feedstock through conversion equipment, provided the plant has the necessary configuration and the material is technically suitable. The stronger the return on transportation fuels, the higher the opportunity cost of preserving a heavy stream for bitumen production can become.
This effect is not equal across refineries. A relatively simple refinery with limited residue-conversion capacity has fewer alternatives. It may continue producing substantial quantities of heavy residual material and bitumen even during periods of strong diesel margins. A sophisticated refinery equipped with cokers, hydrocrackers or other deep-conversion units has much greater flexibility. Two refineries processing similar crude can therefore respond very differently to the same diesel price.
Crude slate creates another variable. Heavy and medium-sour crude grades generally generate a different distribution of heavy fractions than light-sweet crudes. But a heavier crude slate does not guarantee more commercial bitumen. If the refinery has strong conversion economics, additional residue can become additional feedstock for upgrading rather than additional asphalt production. Conversely, a refinery using an appropriate crude but lacking deep-conversion capacity may have fewer profitable alternatives for its heavy bottoms.
This is why refinery economics matter as much as crude availability.
The present situation also helps explain why a peace agreement or further decline in Brent would not necessarily normalize bitumen markets immediately. More crude can return to international trade relatively quickly if production and shipping routes recover. Damaged processing units cannot be restored as quickly. Product inventories also take time to rebuild, and refiners facing depleted diesel stocks have a strong incentive to prioritize the products offering the highest margins.
The problem is particularly visible in the Middle East. Some crude flows can partially bypass the Strait of Hormuz through existing pipelines, but crude bypass capacity does not replace lost refinery output and does not create an alternative pipeline for finished diesel, jet fuel or bitumen. A barrel of crude successfully moved around a chokepoint is therefore not equivalent to a barrel of product ready for export.
For Gulf bitumen, that distinction is commercially important. The region can possess crude oil and still experience tighter availability of particular refined products if refinery units are damaged, operating below normal rates or prioritizing other products. At the same time, bitumen exports face their own shipping and insurance constraints. The result is a market where a softer crude benchmark can coexist with firm bitumen replacement costs.
Russia adds another layer. Repeated attacks on Russian refining infrastructure have reduced processing activity close to levels not seen for two decades, removing part of the global product supply that would normally help balance diesel and other fuel markets. The importance for bitumen is indirect but real: if global refiners outside Russia are asked to compensate for missing distillate supply, high cracks can persist for longer, extending the economic incentive to maximize conversion.
China presents a different version of the same problem. Official data for July showed Chinese crude throughput at 53.11 million metric tons, equivalent to approximately 12.5 million bpd. Processing increased slightly from June but remained 15.8% below July 2025 and far below pre-war operating levels. The country has also reduced fuel exports during parts of the disruption in order to protect domestic supply. China therefore remains an important variable for both refined-product availability and Asian bitumen balances.
A global shortage of effective refining capacity can transmit into bitumen in several ways.
The first is physical production. Lower refinery throughput generally means a smaller total pool of atmospheric and vacuum residues is generated. That does not establish an equivalent percentage decline in bitumen output, because refiners can alter crude slates and product yields, but it can reduce the feedstock base from which bitumen is produced.
The second is refinery allocation. Even when heavy residue is available, strong diesel and jet-fuel margins can increase the economic incentive to send suitable material into conversion units instead of maximizing paving-grade production.
The third is pricing. Bitumen sellers know that residue has alternative values. If those alternatives become more profitable, the minimum price required to justify selling material into the bitumen market can rise. Bitumen can therefore remain firm even while crude falls.
The fourth is regional trade. If some complex refineries reduce open-market bitumen availability, buyers may need to source from more distant origins. That can increase freight exposure and alter price spreads among the Gulf, Singapore, South Korea, India and other markets.
The fifth is inventory behavior. When product markets are tight, refiners and traders may be reluctant to release material aggressively until they have greater visibility on refinery operations, crude supply and competing product margins. Lower visible inventories can then reinforce short-term pricing power.
There is already evidence that refining economics are unusually strong. Major U.S. refiners have reported sharply higher margins during the disruption. Marathon Petroleum’s second-quarter refining margin reached $36.33 per barrel, roughly double its year-earlier level, while the company estimated that global planned and unplanned refinery outages had climbed above 9 million bpd, around 4 million bpd above historical levels. Its refineries operated at about 94% utilization during the quarter as fuel markets remained extremely tight.
These figures do not prove that bitumen production at those refineries, or globally, has declined. They demonstrate something different and more useful for the bitumen market: the economic value of functioning refinery capacity has increased significantly.
That distinction must be maintained. The August 17 analysis does not provide evidence of a quantified global decline in bitumen production caused by strong diesel margins. WPB therefore does not interpret the current situation as proof that refiners are universally cutting asphalt output. The impact depends on refinery configuration, crude quality, contractual commitments, local road demand, storage capacity and the availability of conversion units.
The market risk is that these factors are increasingly aligned in a direction that can keep bitumen tighter than crude prices alone would imply.
There is also a longer-term capacity issue. One current estimate expects global refined-fuel demand to expand by approximately 2.5 million bpd during the next three years, while net refining-capacity additions reach only about 1.2 million bpd. Large new refineries can require eight to 10 years to develop. Even though additional facilities and expansions are coming online in Asia, the Middle East and Africa, the current disruption is exposing how little quickly deployable downstream capacity exists when several major refining centers are simultaneously constrained.
That may become one of the defining differences between the current energy market and the earlier phase of the crisis.
During the initial shock, attention centered on whether enough crude could move through Hormuz and whether global producers could replace missing barrels. The next stage may be more complicated. Crude can become available again while the world still lacks enough operating refinery capacity in the right places to turn those barrels into the products consumers actually need.
For bitumen, this changes what traders should monitor.
Brent remains relevant, but it is no longer sufficient. Diesel and jet cracks, refinery utilization, planned and unplanned outages, vacuum-residue values, fuel-oil economics, crude slate and conversion-unit operations can provide earlier signals of bitumen supply pressure than the crude benchmark itself.
A trader looking only at falling Brent may conclude that bitumen should follow lower. A trader looking at a diesel crack above $70 per barrel, depressed refinery runs and limited product inventories may reach a very different conclusion.
Physical offers will ultimately decide which interpretation is correct.
If refinery throughput recovers rapidly, product inventories rebuild and diesel margins normalize, refiners could have less incentive to maximize conversion and more heavy material may become available for bitumen. In that case, lower crude costs could eventually feed through into softer paving-grade prices.
But if effective refining capacity remains constrained while middle-distillate margins stay exceptional, the crude-to-bitumen relationship may remain unusually weak. Producers with flexible conversion units could continue demanding a higher return for releasing suitable residue into the asphalt market, while importers could face firm replacement costs despite a lower Brent benchmark.
This is especially important for buyers negotiating medium-term contracts. A procurement strategy based only on the expectation that “oil is down, so bitumen should be down” could underestimate the refinery component of price formation. Buyers need to understand not only what crude costs, but what a refinery can earn by doing something else with the same heavy stream.
The global energy market may therefore be entering a different phase of the supply crisis.
The first phase was about finding enough crude.The next may be about finding enough refinery capacity.
For the bitumen industry, that transition matters because crude is only the beginning of the production chain. The final availability and price of paving-grade material depend on what happens after crude reaches the refinery and, increasingly, on whether the refinery sees bitumen or conversion into transportation fuels as the more valuable destination for the bottom of the barrel.
Brent can fall while that competition becomes stronger. If refining remains the bottleneck, bitumen may not follow crude lower nearly as quickly as buyers expect.
By WPB
News, Bitumen, Refining Capacity, Refinery Economics, Diesel Margins, Vacuum Residue, Crude Oil, Middle Distillates, Asphalt Supply, Global Refining
