According to WPB, at least four Asian refiners have purchased U.S. crude oil for delivery later this year as the normal flow of Middle Eastern supply through the Strait of Hormuz remains disrupted. The transactions show that feedstock security is no longer simply an operational concern. Asian refiners are now paying substantial premiums to obtain crude that can reach their plants without relying on the Gulf’s most vulnerable shipping route.
South Korea’s GS Caltex reportedly purchased 2 million barrels of Mars crude for November delivery at a premium of approximately $13–$14 per barrel over the October Dubai benchmark. Japan’s Cosmo Energy also bought Mars, while Eneos purchased 2 million barrels of West Texas Intermediate crude for November delivery at a premium exceeding $10 per barrel over the October WTI price. Taiwan’s CPC acquired another 2 million barrels of WTI and additional West African crude.
U.S. crude exports to Asia reached a record 2.35 million barrels per day in July. Before the current disruption, Asian refiners obtained more than half of their crude supply from the Middle East. The record U.S. flow therefore represents more than a temporary trade. It indicates a rapid attempt to redesign refinery supply routes around a chokepoint that can no longer be treated as commercially reliable.
The reported premiums should not be interpreted as one directly comparable price spread. The Mars transaction was assessed against Dubai, while the Eneos purchase was described relative to WTI. The pricing dates, crude qualities, freight exposure, and benchmark structures differ. Nevertheless, both transactions demonstrate that refiners are accepting a high additional cost to secure alternative feedstock.
For the bitumen market, the central issue is not simply that more U.S. crude is moving to Asia. The more important question is what these barrels will do to each refinery’s crude slate and product yields. Bitumen production begins with the heaviest fractions remaining after crude distillation, but the volume and quality of that material vary substantially between crude grades.
WTI is generally classified as a light, sweet crude. Lighter crudes contain a higher proportion of components suitable for gasoline, jet fuel, and middle distillates and normally produce a smaller share of heavy residual material through simple distillation. A refinery replacing a medium or heavier Middle Eastern crude with WTI may therefore process the same number of barrels without obtaining the same quantity or quality of vacuum residue suitable for bitumen production.
Mars is different. It is a medium-sour U.S. crude with a significantly heavier profile than WTI. It can generate more heavy fractions than a typical light-sweet barrel, although its actual residue yield and suitability for paving-grade production depend on the crude assay, blending strategy, refinery configuration, and final product specifications. It would therefore be inaccurate to claim that every U.S. crude cargo automatically reduces bitumen output.
This distinction is especially relevant to GS Caltex. The company operates approximately 800,000 barrels per day of crude-processing capacity and lists asphalt among its refined products. It also has about 275,000 barrels per day of heavy-oil upgrading capacity. The refinery can therefore direct heavy streams toward asphalt, fuel oil, or conversion units that transform lower-value residue into lighter transportation fuels.
That flexibility creates the real commercial competition. Higher refinery runs do not automatically produce more marketable bitumen. If gasoline, diesel, and jet-fuel margins are stronger, a complex refinery may send additional heavy material into cokers, hydrocrackers, or other conversion units. If bitumen provides a better netback and road demand is firm, the refinery may retain more suitable residue for asphalt production.
Paying an additional $10–$14 per barrel for secure crude does not mean that the full premium will be transferred directly to bitumen customers. Refiners recover feedstock costs across the entire product barrel. Gasoline, diesel, jet fuel, petrochemicals, fuel oil, petroleum coke, and bitumen can each absorb part of the cost, depending on yields, market prices, taxes, and contractual arrangements.
However, bitumen buyers may still face an indirect increase. A refinery will compare the return from selling residue as bitumen with the value it could obtain by processing the same stream into higher-priced fuels. As the acquisition cost of crude rises, the minimum acceptable return from every part of the barrel may also rise. Bitumen prices can therefore strengthen even without a physical shortage if refinery replacement costs and the opportunity value of residue increase.
The pressure may first appear in export availability rather than posted prices. Asian refiners could continue supplying domestic road programs while reducing spot export cargoes. Alternatively, they could maintain export volumes but shorten quotation validity, adjust differentials, or become less willing to commit material several months forward. These changes would matter to import-dependent buyers in Southeast Asia, Australia, and other regional markets.
The freight effect also requires careful separation. Transporting additional crude from the United States to Asia increases long-haul tanker demand and raises the delivered cost of refinery feedstock. That does not automatically increase freight for specialized heated bitumen carriers by the same amount. Crude tankers and bitumen tankers operate in different vessel segments. The connection develops through refinery costs, wider shipping-market pressure, and changes in regional trade flows rather than through an identical freight rate.
India has added another layer to this competition between fuels and bitumen. Effective August 15, the country reduced its export levy on gasoline from ₹3.5 per liter to zero. The duty on diesel exports declined from ₹25.5 to ₹24 per liter, while the levy on aviation turbine fuel fell from ₹22 to ₹19.5 per liter.
These changes marginally improve the economics of exporting transportation fuels. The removal of the gasoline levy creates the clearest incentive, while the smaller reductions for diesel and aviation fuel also improve refinery netbacks. The policy does not require Indian refiners to reduce bitumen production, but it increases the relative attractiveness of exporting fuels when international margins support that decision.
The timing matters because India’s bitumen consumption rose 8.5% year on year in July, despite remaining 16.9% below June as the monsoon restricted paving activity. Demand normally strengthens after the rains, when delayed highway, municipal, and maintenance projects return to execution. Refiners may therefore face stronger domestic bitumen demand at the same time that fuel-export economics become more attractive.
For Indian bitumen buyers, the risk is not necessarily an immediate national shortage. The more probable pressure would come through tighter refinery allocations, reduced spot availability, or higher replacement values during the post-monsoon recovery. If domestic supply becomes insufficient, imports may help balance the market, but Gulf-origin cargoes remain exposed to Hormuz disruption, insurance costs, vessel acceptance, and elevated delivered prices.
The commercial question is therefore broader than asking whether fuel buyers or bitumen buyers will pay the crude premium. Part of the cost may be absorbed by refinery margins. Part may be transferred to gasoline, diesel, or jet-fuel buyers. Part may appear in higher bitumen prices, reduced export availability, or firmer regional differentials. Government tax adjustments can also change how the burden is distributed.
There is currently no confirmed evidence that the latest U.S. crude purchases have caused an Asian refinery to reduce bitumen production, cancel a bitumen cargo, or raise a specific quotation. The immediate development is a feedstock-security shift. Its effect on bitumen will depend on the qualities of the replacement crudes, refinery configurations, fuel margins, road demand, and the allocation of heavy residual streams.
Traders and buyers should now monitor more than crude prices alone. The most important indicators will include Asian refinery run rates, changes in average crude quality, fuel-export margins, vacuum-residue allocation, bitumen cargo availability, and the spread between domestic and export quotations. A refinery can process more crude while producing less bitumen, and that is the risk hidden behind Asia’s record purchases of U.S. oil.
By WPB
News, Bitumen, Crude Oil, Asia, Strait of Hormuz, Refining, Vacuum Residue, WTI, Mars Crude, Fuel Exports
