Can the U.S., Canada and Venezuela replace lost Middle East oil?

Bottom line

North America can cushion a Middle East oil shock, but it cannot quickly replace a major Gulf disruption. Existing U.S., Canadian and Venezuelan output roughly matches total Strait of Hormuz flows (~20 mb/d). Yet those barrels are already produced, already committed, and constrained by timing, export infrastructure, crude quality and refinery fit.

Key judgement

• A full Hormuz-style disruption is a ~20 mb/d oil trade shock, while bypass routes have only 3.5–5.5 mb/d spare capacity (IEA, 6 Feb 2026).
• U.S. shale executives say meaningful incremental supply requires sustained high prices for more than a quarter, then six months to a year to appear (Reuters, 24 Mar 2026).
• Trans Mountain is already running in the high-90s of utilisation (Reuters, 25 Mar 2026; Trans Mountain; CER).
• Venezuela's upside is real but requires operational rehabilitation of extra-heavy crude systems and legacy infrastructure (EIA, 2024; Reuters, 19 Feb 2026).

1. The arithmetic trap

At first glance the replacement thesis looks plausible. U.S. crude production hit 13.6 mb/d in 2025, Canada averaged 5.3 mb/d, and Venezuela reached roughly 1.1 mb/d in March 2026 — almost exactly the 19.9 mb/d that moved through the Strait of Hormuz in 2025.

This is the wrong comparison. Existing North American and Venezuelan output is not spare supply; most of it is already sold, processed or exported under long-term patterns. The real policy question is whether these three countries can add enough incremental barrels — and move them to the right refineries — fast enough to offset a Gulf disruption.

For article framing, the cleanest formulation is this: the Americas can help re-price and redistribute a shock, but they cannot make a 10–20 mb/d Middle East disruption simply disappear. On a 0–6 month horizon, the gap is primarily physical. On a 6–18 month horizon, it becomes a capital, infrastructure and crude-quality problem.

2. Country comparison: barrels, infrastructure, and constraints

3. United States: large base, fast logistics, but not an instant spigot

The United States is the essential first responder in any Atlantic Basin oil shock. EIA data show U.S. crude production rose to a record 13.6 mb/d in 2025, while crude exports were still 4.0 mb/d even after a slight annual decline. That means the U.S. already has a very large production base and a deep export machine. Reuters also reports that U.S. clean petroleum product exports hit a record 3.11 mb/d in March 2026 as Europe, Asia and Africa scrambled to replace disrupted Middle East supplies.

The problem is timing. Reuters reported from CERAWeek that U.S. shale executives do not see oil above $100 as enough, by itself, to trigger a meaningful output surge unless those prices persist for more than a quarter. Even after operators decide to increase activity, industry executives said it typically takes six months to a year to get meaningful new barrels to market, with nine months described as a very best case. In other words, the U.S. can re-route exports quickly, but it cannot conjure millions of new barrels in a few weeks.

There is also a quality issue. EIA notes that the U.S. refining system is highly capable of running heavier, more sour crude oils, while much of incremental U.S. production is lighter. That does not make U.S. barrels unhelpful—far from it—but it does mean a light-sweet export stream is not a one-for-one physical substitute for the mix of medium and heavy sour barrels many refineries historically processed from the Gulf.

4. Canada: the heavy-barrel substitute with an egress ceiling

Canada produces the heavier barrels that many refineries can run as a close substitute for lost Middle East grades. Its short-term replacement potential is limited by egress. Trans Mountain, the country's only direct pipeline to international markets, is already operating in the high-90s of utilisation (Reuters, 25 Mar 2026). The expanded system has a nominal capacity of 890 kb/d; the Westridge marine terminal can load up to 630 kb/d. Those are useful volumes, but not Gulf-outage scale.

The Canadian story is therefore not "there is no oil." It is "the oil cannot be scaled and redirected fast enough." For a UK or European audience, that matters because Canada helps most when it is already flowing and already connected to tidewater. New export capacity is a multi-year issue, not a 90-day one.

5. Venezuela: the biggest reserve base, but a rehabilitation case—not a sprint

Venezuela is the most seductive part of the replacement thesis because the reserve base is enormous. EIA still describes Venezuela as holding the world's largest proven crude reserves, much of it in the extra-heavy Orinoco Belt. But reserve size is not the same thing as deliverable short-term supply.

Reuters reported in February 2026 that early expansions could add as much as 500 kb/d in as little as six months from a current 1.0 mb/d, with the first phase focused on reactivating existing rigs, refurbishing wells and upgraders, and repairing ports and pipelines. That is the bullish operating case. The same Reuters report stresses that even these "easy" projects are hard. The EIA Venezuela country brief says the country had 25 operational pipelines as of 2023, many estimated to be more than 50 years old, and that pipeline modernisation alone would require around $8 billion to return production to late-1990s levels.

Venezuela's crude quality compounds the problem. Much of the country's oil is extra-heavy and requires diluent, blending or upgrading before it can move cleanly into export channels and refinery systems. Reuters reported that March 2026 exports rose to 1.09 mb/d of crude and fuel, showing real improvement. But even if the country adds several hundred thousand barrels per day, that is still a meaningful increment within a tight market—not a fast substitute for a Gulf-scale outage.

6. Why bypass routes do not solve the problem

Even before considering the Americas, the Gulf producers themselves have only limited alternatives to the Strait of Hormuz. The IEA estimates that nearly 19.9 mb/d of oil moved through the strait in 2025, but available bypass capacity on alternative routes through Saudi Arabia and the UAE is only about 3.5–5.5 mb/d. This matters because replacement demand from Europe and Asia will spill into Atlantic Basin markets almost immediately once Hormuz flows are disrupted.

7. Europe angle: direct crude dependence is lower than price exposure

The IEA estimates that only about 600 kb/d—roughly 4%—of crude flowing through Hormuz in 2025 was routed directly into Europe. So Europe's exposure is less about direct physical dependence on Gulf crude than about price, freight, refinery economics, and competition for Atlantic Basin barrels. Reuters reported on 6 April 2026 that Asian and European refiners were already bidding aggressively for U.S. barrels, pushing spot premiums to record highs.

This is a critical editorial point for EuroOilWatch. Europe may not lose huge direct volumes from Hormuz compared with Asia, but it still gets hit by the global clearing price and by the scramble for replacement cargoes. That is why a North American cushion can still be valuable to Europe without amounting to full replacement.

For context on how this affects European fuel reserves and prices, see the EuroOilWatch dashboard and country-by-country price comparison.

8. Scenario test

9. Conclusion

The replacement thesis makes sense only in a loose geopolitical sense — the Americas can supply part of a replacement barrel complex if the Gulf is impaired. It does not hold as a short-term physical replacement claim.

Reserves are not replacement barrels. On a short time horizon the U.S. is a re-router and exporter more than a miracle growth engine, Canada is a heavy-oil supplier trapped by egress, and Venezuela is a repair project. The proposition makes sense in a loose geopolitical sense — North America (and Russia) can supply part of a replacement barrel complex if the Gulf is impaired. It does not hold as a short-term physical substitute for a major Middle East outage.

Selected source list

• EIA, 'U.S. crude oil production rose in 2025, setting new record,' Today in Energy, 2 Apr. 2026.
• EIA, 'Annual U.S. crude oil exports decrease for first time since 2021,' Today in Energy, 10 Mar. 2026.
• EIA, Short-Term Energy Outlook, March 2026 (U.S. crude production outlook).
• EIA, 'Amid regional conflict, the Strait of Hormuz remains critical oil chokepoint,' Today in Energy, 16 Jun. 2025.
• IEA, 'Strait of Hormuz,' 6 Feb. 2026.
• Canada Energy Regulator, 'Trans Mountain Expansion eases pipeline constraints and increases exports to overseas markets,' 3 Sep. 2025.
• Trans Mountain Corporation, 'Trans Mountain Launches Binding Open Season for Firm Service on Existing Pipeline Capacity,' 25 Mar. 2026.
• Reuters, 'Canada oil producers say little can be done to boost oil production in the short term,' 11 Mar. 2026.
• Reuters, 'Canada's Trans Mountain running nearly full on global oil disruptions,' 25 Mar. 2026.
• Reuters, 'US shale firms unlikely to drill at $100 a barrel unless high prices last longer,' 24 Mar. 2026.
• Reuters, 'Oil companies jostle for projects to boost Venezuelan output quickly; a real grind awaits,' 19 Feb. 2026.
• Reuters, 'Venezuela's oil exports surpassed 1 million bpd for the first time in 6 months,' 1 Apr. 2026.
• EIA, Country Analysis Brief: Venezuela, updated 8 Feb. 2024.
• Reuters, 'US fuel exports hit record in March as Asia, Europe sought to replace Middle East supplies,' 1 Apr. 2026.
• Reuters, 'US crude premiums climb to record levels as Asia, Europe compete for supply,' 6 Apr. 2026.