The G7 can flood the market with reserve barrels — but it still cannot tell refiners where the next reliable crude will come from. If the Iran war drags on and the initial stock draw begins to lose impact, the harder question takes over: where do replacement barrels come from if Gulf flows remain impaired beyond what emergency buffers can absorb?

Band-aid barrels? The International Energy Agency (IEA) is already calling this the largestdisruption in oil market history, and without a swift resolution to the conflict, reserves risk becoming little more than a stopgap.

IEA eyeing even deeper reserve releases: The IEA is weighing anotheremergency oil release as the Middle East war keeps choking supply. The agency is currently consulting governments in Asia and Europe on whether more barrels need to be pulled from emergency reserves. Asia is bearing the brunt of the shock given its dependence not just on crude, but also on other critical products moving through Hormuz.

The regional fallback

The first layer of alternatives is still partly inside the region. Saudi Arabia and the UAE can bypass Hormuz through existing pipelines, and Saudi Aramco has already been rerouting barrels to the Red Sea and offering Arab Light cargoes out of Yanbu. But that relief is limited, as the US Energy Information Administration (EIA) estimates only about 2.6 mn bbl / d of available Saudi and UAE pipeline capacity could bypass Hormuz in a disruption.

Not nearly enough: “Saudi Arabia and the UAE do have alternative export routes to the Red Sea and Fujairah, but that is still not enough to offset what is lost through the strait,” global oil markets analyst Harry Tchilinguirian told EnterpriseAM.

Who can replace Gulf barrels — and who can’t?

West Africa is the fastest external option — but it only solves part of the problem. Nigeria has lifted output to about 1.7 mn bbl / d and is pitching itself as a diversification partner. Nigerian and Angolan grades could also see stronger East-of-Suez demand as buyers hunt for light sweet alternatives.

But there’s the catch, “West Africa is short on spare capacity,” head of Energy Trends and Analysis at Welligence Energy Ruaraidh Montgomery told EnterpriseAM.

Brazil is one of the few non-Opec producers big enough to matter — but not enough to cover a global energy shock. Output is forecast to average 4 mn bbl / d in 2026.

The constraint is logistics and crude fit: Brazilian barrels take longer to reach Asia, and cargo offers into China have already jumped to USD 13-14 above Brent, showing that replacement supply exists but gets expensive once Asian buyers start chasing it.

And the crude isn’t a perfect match: Much of it is lighter than the medium-sour Gulf grades many refiners are built for. On top of that, Brazil’s growth is already baked into market expectations — meaning it doesn’t offer a fresh pool of emergency barrels, Montgomery added

Guyana is part of the backup story — but it’s too small and too specific to be a substitute. It is expected to average around 840k bbl / d in 2026, with another offshore project due later this year. Exxon’s installed capacity is already above 900k bbl / d and targeting 1.15 mn bbl / d.

But again, it’s mostly light sweet crude — useful at the margin, not a like-for-like replacement for Gulf supply.

Can North America fill the gap?

North America is more important than how it looks — especially for sour-crude refiners. The loss of Gulf medium sour supports heavier substitutes like Canada’s WCS and US Gulf sour grades because complex refiners still need to feed cokers and keep distillate yields up.

The barrels can soften the shock, but they do not replace the Gulf. US output is still forecast to rise only modestly — from 13.6 mn bbl / d in 2026 to 13.8 mn bbl / d in 2027, while Canada’s TMX-linked exports add some extra room without changing the bigger supply picture.

Washington’s case is different: US producers may be able to bring on some additional barrels if producers see higher prices, but any increase would still be too small to make up for the barrels currently offline, Montgomery said.

The market will be forced to look to its neighbors — like Canada, Brazil, Guyana, and Argentina if Hormuz stays shut, even though Canada's export route to Asia has little room left to expand, Tchilinguirian added.

The market leans back on Russia

Is there room for the Russians? Moscow is emerging as the market’s most usable emergency fallback for Asia as its barrels are already flowing and can be redirected faster than new supply can be developed.

India isn’t waiting: Refiners have returned to Russian crude as Gulf disruption tightens supply, while Moscow says it can redirect more cargoes toward Indian buyers. Russia may also have some room to lift output and exports if its own flows remain unaffected, Tchilinguirian added.

Where does the pressure really land?

Asia takes the hit: Asia remains the main pressure point rather than Europe or the US as the market waits to see whether secure transit through Hormuz can be restored, Tchilinguirian explained, because the bulk of the liquids moving through the strait is destined for Asian buyers, with China and India being the largest takers.

…but they are holding up: Short-term pressure is softened by the fact that China built up strategic reserves through 2025 and early 2026 and continues to receive Iranian crude, while India, under a US waiver, is still able to take Russian barrels. Japan and South Korea are also exposed, but both stand to benefit from the IEA stock release, Tchilinguirian said.

Tags: