Saudi Crude Vanishes From U.S. Imports — Exposing America’s Heavy-Oil Problem

The United States produces more crude than any other country, yet still imports more than 6 million barrels per day (bpd). At the same time, it exports roughly 4 million bpd. The reason is refinery configuration: U.S. shale output is predominantly light crude, while many Gulf Coast plants were built to process heavier grades. Saudi Arabia has historically supplied part of that gap.

From 498,000 bpd to almost zero

Saudi shipments to the U.S. were already declining before the latest disruption.

Annual Saudi shipments fell from 182.3 million barrels in 2020 to 98.3 million in 2025, a decline of about 46%. July then produced an extreme: preliminary data indicated no Saudi crude arrivals for the full month, the first such occurrence since 1985.

The scale matters less than it once did. At the 2025 average of 269,000 bpd, Saudi Arabia supplied only about 4% of total U.S. crude imports.

The mismatch inside the U.S. oil market

America's import dependence cannot be measured simply by comparing domestic production with refinery demand.

Roughly 80% of Lower-48 U.S. crude production consists of light oil with API gravity above 35 degrees. More than 60% of imported crude, meanwhile, falls into heavier grades with API gravity of 27 degrees or below.

The trade therefore works in both directions:

• U.S. shale production → light crude → domestic use + exports

• U.S. refineries → demand for heavier crude → imports

Saudi grades such as Arab Medium and Arab Heavy fit complex Gulf Coast refineries equipped with cokers, hydrocrackers and desulfurization units.

Replacing them with another Permian barrel changes refinery economics even if total crude supply remains unchanged.

Hormuz lost roughly three-quarters of its oil traffic

The abrupt Saudi decline coincides with severe disruption around the Strait of Hormuz.

EIA figures put crude and petroleum-liquid flows through Hormuz at approximately:

The IEA estimates that close to 20 million bpd moved through the strait during 2025. Available pipeline capacity capable of bypassing Hormuz amounts to only about 3.5–5.5 million bpd.

The shipping data show the same contraction. More than 130 vessels per day could transit Hormuz before the conflict. Recent tracking recorded days with only a handful of commodity vessels making the crossing.

Six million barrels looking for buyers

Saudi Aramco has resumed some loadings from Juaymah and Ras Tanura and offered Arab Medium and Arab Heavy cargoes to Asian refiners through ship-to-ship transfers near Fujairah. Three VLCCs loaded between August 12 and August 16.

A typical VLCC carries approximately 2 million barrels, putting the combined cargo at roughly:

3 VLCCs × 2 million barrels = 6 million barrels

Those barrels exist. Moving them safely and economically has become the harder part. Saudi Arabia also has its East-West pipeline, which can send crude toward the Red Sea rather than through Hormuz. But disruption around Yanbu has reduced the usefulness of that route.

Aramco has consequently increased reliance on Egypt's Sidi Kerir terminal.

• Expected August Sidi Kerir loadings: ~670,000 bpd

• Previous Yanbu export capacity: ~4 million bpd

The Egyptian route is equivalent to only about 17% of that capacity.

U.S. inventories tell a different story

Saudi imports can collapse while U.S. crude inventories rise. Commercial crude stocks recently increased by 17.4 million barrels in one week, the largest weekly build since January 2023.

Canada provides the main buffer. It accounts for roughly 62% of U.S. crude imports, equivalent to about 4 million bpd using recent total-import levels. Much of that supply consists of heavier crude suitable for complex U.S. refineries.

Compare the scale:

• Canada: ~4.0m bpd

• Saudi Arabia, 2025 average: 269,000 bpd

Canadian supply is roughly 15 times larger. That makes a Saudi disruption manageable at the national level even if individual refiners have to replace specific grades.

The replacement market is mostly outside U.S. shale

The closest substitutes for Saudi medium and heavy crude are not necessarily additional Permian barrels.

The relevant supply pool includes:

• Canada — large and relatively secure heavy-crude flows through pipelines.
• Mexico — heavy Maya crude, although declining domestic production limits additional export capacity.
• Venezuela — very heavy crude compatible with several Gulf Coast refinery configurations.
• Other medium and heavy grades available through the Atlantic Basin.

The competition created by lower Saudi shipments is therefore primarily within the medium/heavy crude market, not the overall crude market. That distinction can widen crude-grade differentials even when headline inventories remain high.

A $6 gap between Brent and WTI

Oil prices also reflect the geographic split.

Around August 19:

• Brent: ~$91.20/bbl

• WTI: ~$85.10/bbl

• Spread: ~$6.10/bbl

Brent has greater exposure to internationally traded barrels and Middle Eastern shipping risk, while WTI reflects a U.S. market with substantial domestic production. The EIA has raised its Q3 Brent forecast to approximately $85/bbl, citing continued disruption around Hormuz.

The premium is therefore not simply a measure of how much oil exists globally. Freight costs, tanker availability, insurance, crude quality and access to export routes increasingly determine the effective price of individual barrels.

Saudi Arabia's role in the U.S. market has already changed

The 91% fall accelerates a shift visible well before the latest disruption. Saudi crude supplied the U.S. at an average rate of 498,000 bpd in 2020. By 2025, that had fallen to 269,000 bpd.

Meanwhile:

• U.S. crude imports: ~6.3–6.6m bpd

• Canadian share: ~62%

• Canadian supply: ~4m bpd

• Saudi 2025 supply: 269,000 bpd

• Saudi share: ~4%

Saudi Arabia is no longer a major source of U.S. crude by volume. Its importance is increasingly concentrated in crude quality and refinery optimization.

The United States can replace several hundred thousand missing Saudi barrels without facing a physical oil shortage. What it cannot do as easily is replace every barrel with domestic shale while preserving the same refinery yields and economics.

That is what the 91% decline exposes: the U.S. has reduced its dependence on Saudi oil, but its refining system still depends on imported heavy and medium crude.