Brent is approaching $100 a barrel again as renewed US-Iran escalation slows traffic through the Strait of Hormuz. Yet the more interesting question is why it is not already considerably higher. Gulf exports remain severely disrupted, global inventories have fallen by 410 million barrels since the conflict began and the IEA estimates a 1.8 million bpd global oil deficit for the third quarter. But Hormuz flows have partially recovered, alternative export routes are carrying more oil, non-OPEC supply is increasing and high prices are already destroying demand. OPEC+ has meanwhile paused further output increases for October. In a market where the binding constraint is increasingly the ability to move barrels rather than permission to produce them, quota policy has temporarily become less important than shipping, refining and inventory.
TL;DR
- Brent traded around $97.49/bbl on 8 September, after settling at $97.31 on Monday and reaching an intraday high above $98.
- OPEC+ held October output policy unchanged at its 6 September meeting, pausing after six consecutive monthly increases. The next meeting is 4 October.
- September completed the unwinding of a 1.65 million bpd voluntary cut introduced in 2023. A separate layer of around 2 million bpd of restraint remains until the end of 2026.
- Hormuz remains severely impaired rather than completely shut. EIA estimates flows fell from 21.6 mb/d in Q4 2025 to 4.9 mb/d in Q2 2026; Reuters says recent throughput has partially recovered to around 4–5 mb/d.
- The IEA estimates a 1.8 mb/d global oil deficit in Q3 2026, more than double its previous estimate of roughly 800 kb/d.
- Global observed oil stocks fell 410 million barrels between the end of February and end of July, an average draw of 2.7 mb/d.
- Refining remains one of the tightest parts of the market: global refinery throughput was nearly 5 mb/d below year-earlier levels in July and Atlantic Basin refining margins reached record highs.
- Brent remains below $100 because reduced Gulf supply is being partly offset by alternative export routes, higher non-OPEC output, reserve and inventory buffers and weakening demand.
- The next major OPEC+ argument is increasingly about 2027 production baselines, not another small monthly quota increase.
Market Overview
Brent crude traded around $97.49 a barrel on Tuesday morning, extending gains as renewed confrontation between the US and Iran again raised fears around Gulf supply.
Monday's session had already taken Brent as high as roughly $98 before a $97.31 settlement. The benchmark is therefore back within striking distance of $100, but still below the levels reached during the most acute phase of the disruption earlier this year.
The scale of the physical shock would ordinarily suggest an even higher benchmark price.
The Strait of Hormuz carried an average 21.6 million barrels per day of crude oil and petroleum liquids in the fourth quarter of 2025, according to the US Energy Information Administration. By the second quarter of 2026, that had collapsed to 4.9 mb/d.
Flows have subsequently recovered somewhat. Reuters estimates current Hormuz throughput at around 4–5 mb/d, while total pre-conflict Gulf flows of roughly 18 mb/d have fallen to around 11 mb/d as producers increasingly use alternative routes.
The distinction matters.
Hormuz is not literally closed. It is severely constrained, dangerous and operating at only a fraction of its previous capacity.
That partial recovery helps explain why Brent is approaching $100 rather than trading dramatically through it.
OPEC+ Pauses
Seven core OPEC+ producers met on Sunday 6 September and left October output policy unchanged.
Saudi Arabia, Russia, Iraq, Kuwait, Algeria, Kazakhstan and Oman had increased production targets for six consecutive months. September's final 188,000 bpd increase completed the unwind of a 1.65 mb/d layer of voluntary cuts introduced in 2023.
October will be the first month without another increase.
A separate layer of approximately 2 million bpd of cuts agreed earlier remains in place across most of the broader group until the end of 2026.
The pause is significant, but not primarily because it removes a large volume of prospective supply.
OPEC+ has spent much of 2026 operating in a market where the relationship between quota and export volume has broken down.
Production targets tell a country how much it is permitted to produce. They cannot guarantee that the oil reaches the international market.
That distinction is particularly important for Gulf members whose normal export routes depend heavily on Hormuz.
When shipping capacity is the binding constraint, approving another nominal production increase has considerably less physical effect.
The group's September statement also gave no commitment on November or December. The pause is therefore confirmed for October, not necessarily the entire fourth quarter.
The seven producers meet again on 4 October.
Why Isn't Brent Above $100?
That is now the more interesting oil-market question.
One of the world's most important energy chokepoints has suffered a historic reduction in traffic. Physical crude markets remain tight. Refined-product shortages are severe. Inventories have been drawn down rapidly.
Yet Brent remains below three figures.
There are several reasons.
The first is that some Gulf oil is still moving.
Hormuz flows have recovered from their worst levels to around 4–5 mb/d, according to Reuters. Producers are also making greater use of routes that bypass the strait.
Saudi Arabia can move crude west through its East-West pipeline towards the Red Sea. Other volumes are being redirected through Egypt and alternative Gulf infrastructure. Those routes are more expensive and capacity-constrained, but they prevent the disruption becoming a complete export shutdown.
The second is non-OPEC supply.
Production growth from the US, Canada, Guyana and other non-Gulf producers is providing an increasingly important offset. The IEA expects growth from the Americas to partially counter the sharp Middle Eastern losses.
The third is inventory and strategic stocks.
The market entered the crisis with buffers. Governments and commercial holders have drawn on them extensively.
Those buffers are now substantially smaller, but they have prevented every lost Gulf barrel translating immediately into an equivalent shortage in consumption.
The fourth is demand destruction.
High oil and fuel prices are changing behaviour.
The IEA now expects world oil demand to decline by 1.6 mb/d in 2026, a 510 kb/d larger reduction than it forecast only a month earlier. It expects demand to contract by 2.8 mb/d year-on-year during the third quarter before returning to growth later in the year.
China is an important part of that adjustment, with weaker crude-import demand and greater utilisation of domestic inventories helping absorb some of the shock.
The market is therefore balancing an extraordinary supply disruption against an equally unusual combination of rerouting, inventory drawdown, new supply and weaker consumption.
That is why $100 has become a test rather than an inevitability.
The Inventory Buffer Is Being Used
The fact that Brent remains below $100 should not be confused with an absence of physical tightness.
The IEA's August Oil Market Report estimates that global observed oil inventories declined 410 million barrels between the end of February and the end of July.
That equates to an average draw of 2.7 mb/d.
July alone saw another 69 million barrels removed from observed inventories, or around 2.2 mb/d.
Total stocks fell below 7.9 billion barrels for the first time since April 2025.
This is an important distinction in understanding the current price.
The market has not balanced solely because underlying supply has recovered. It has partly balanced by consuming inventory accumulated previously.
That works while the buffer exists.
The longer severe Gulf disruption persists, the less capacity inventories have to absorb another shock without a larger price response.
Refining Is Where the Stress Is Clearest
Crude prices also understate the pressure developing further downstream.
Global refinery crude throughput reached 80.9 mb/d in July, according to the IEA. That was an improvement from previous months but remained nearly 5 mb/d below the same period a year earlier.
Refined-product trade has been hit even harder.
Diesel exports from Russia, the Middle East and Asia were approximately 1.3 mb/d lower year-on-year, equivalent to around 20% of global seaborne diesel trade.
Jet-fuel exports were down about 670 kb/d, equivalent to 34% of global trade.
Atlantic Basin refining margins consequently reached record highs in July as diesel, jet fuel and gasoline cracks widened.
That helps explain an apparently contradictory feature of the present market.
Brent is below $100.
Parts of the physical oil and refined-product market are effectively pricing considerably more acute scarcity.
The benchmark alone therefore understates the severity of the disruption.
OPEC+ Is Less Powerful While Shipping Is the Constraint
None of this means OPEC+ has ceased to matter.
It means its traditional policy instrument currently has reduced leverage.
For much of the past decade, analysts could treat an OPEC+ quota change as a reasonable proxy for a change in expected market supply.
That relationship is much weaker when producers cannot fully export existing production.
An additional Saudi production entitlement has limited value if additional barrels cannot reach customers. The same applies to other Gulf producers dependent on constrained export infrastructure.
That gives the current OPEC+ pause an unusual character.
Ordinarily, a pause following six months of increases would be interpreted primarily as a deliberate tightening decision.
Today it is partly an acknowledgement that headline quotas are not the market's most important supply variable.
Shipping is.
The Real OPEC+ Fight Is Moving to 2027
The more consequential negotiation is taking place further out.
OPEC+ is reassessing member countries' maximum sustainable production capacity in order to establish the baselines that will underpin 2027 quotas.
Baselines matter because cuts and increases are calculated relative to them.
A country that secures a larger baseline has more room to produce under future agreements. A country whose assessed capacity falls can lose influence and market share.
Those negotiations have repeatedly proved contentious.
Iraq has argued for recognition of increased capacity. Other producers face the prospect of lower assessments. Angola's dispute over its quota contributed to its departure from OPEC in 2024, while the UAE left OPEC and OPEC+ in May this year.
The current disruption makes the process more complicated still.
Actual exports during a period of severe shipping constraints do not necessarily reveal underlying production capacity.
That means the group needs to distinguish between barrels a producer cannot produce and barrels it can produce but cannot export normally.
For the oil market, that argument could matter much more in 2027 than whether November's nominal production target moves by another 100,000 or 200,000 barrels per day.
Once Hormuz normalises, the amount of spare capacity each producer is permitted and able to bring back becomes important very quickly.
Emerging Markets: The Oil Shock Is Not Symmetrical
The macro transmission is highly uneven.
For major oil importers, Brent near $100 creates an immediate deterioration in terms of trade.
Higher fuel-import bills can widen current-account deficits, weaken currencies, lift inflation and limit central-bank flexibility.
India is already displaying some of that pressure. The rupee remains caught between rising oil costs and intervention by the Reserve Bank of India.
Pakistan and Egypt are potentially more exposed because higher imported energy prices interact with narrower fiscal and external buffers.
For exporters away from the immediate Gulf disruption, the effect can be very different.
Nigeria is particularly interesting.
Higher crude prices improve the country's export backdrop at the same time as the Dangote refinery is materially changing its refined-products balance. Nigeria historically experienced an unusually weak transmission from high oil prices because it exported crude while importing large quantities of refined fuels. Dangote is beginning to change that structure.
The timing is particularly notable. Dangote Petroleum Refinery signed its IPO documents on 7 September, with the offer scheduled to run from 14 September to 13 October ahead of an indicative late-November listing. The company plans to sell 4.1 billion shares at ₦525, potentially raising around ₦2.15 trillion ($1.63 billion), as it seeks to finance an expansion from 700,000 bpd to 1.4 million bpd by 2029.
That does not make Nigeria immune to the inflationary consequences of expensive energy, nor does it eliminate domestic production and fiscal problems. But it means the current oil shock reaches Nigeria through a structurally different channel than previous episodes.
Outlook
Base case: Brent remains elevated and volatile while Hormuz traffic remains severely constrained. Partial recovery in Gulf flows, alternative export routes, non-OPEC supply and weaker demand prevent the physical shortage translating one-for-one into the benchmark. OPEC+ quota decisions have less influence than usual while export capacity remains the binding constraint.
Upside risk: A further deterioration in Hormuz traffic, attacks on major export or refining infrastructure, or interruption of alternative routes could overwhelm the remaining inventory buffer. The combination of already depleted stocks and severe refined-product tightness would make another supply shock considerably harder to absorb.
Downside risk: Sustained improvement in Hormuz transit, a durable de-escalation or faster restoration of Gulf exports would remove a substantial geopolitical and physical premium. Weak global demand could then become more visible, particularly if non-OPEC supply continues to grow.
What would change the view: A sustained recovery in physical Gulf exports is more important than diplomatic announcements alone. Conversely, another persistent fall in tanker flows while inventories continue to decline would indicate that the market's remaining buffers are being exhausted.
Key Risks
- Further Hormuz deterioration. Current traffic is already a fraction of the pre-conflict norm. Another sustained reduction would directly tighten the crude balance.
- Alternative routes are disrupted. Red Sea, Egyptian and Gulf bypass routes are now more valuable because Hormuz is impaired; disruption there would remove an important pressure valve.
- Inventory buffers become insufficient. Observed stocks have already fallen 410 million barrels since the end of February.
- Refined-product stress intensifies. Crude benchmarks may understate shortages in diesel, jet fuel and gasoline.
- Demand destruction accelerates. The IEA has already cut its 2026 demand outlook materially. Continued high prices could weaken consumption further and cap crude prices despite tight supply.
- The 2027 baseline process fractures OPEC+. Capacity assessments determine future market share and have historically generated significant internal disputes.
- A rapid de-escalation reverses the market. Significant improvement in Gulf export flows could expose the extent to which today's price is supported by physical disruption and geopolitical risk.
Intelligence Monitoring Points
- Hormuz vessel traffic: seven commodity vessels transited on Monday, versus eight on Sunday. More importantly, Kpler's 10-day moving average had fallen to around 10 vessels per day by Sunday, from more than 15 on Friday — its lowest level since May. Vessel counts should be read alongside estimated oil volumes, since the two measures are not directly interchangeable.
- Hormuz oil volumes: compare current 4–5 mb/d flows with the 21.6 mb/d Q4 2025 baseline.
- OPEC+ meeting — 4 October: whether the October pause extends into November and what the group says about 2027 baselines.
- 2027 capacity assessments: particularly disputes involving Iraq and other producers seeking higher baselines.
- IEA Oil Market Report: the next report is due 11 September; watch revisions to the current 1.8 mb/d Q3 deficit and inventory assumptions.
- EIA Short-Term Energy Outlook: updated Gulf-flow and production-shut-in assumptions will be important as September traffic data become available.
- Observed oil inventories: whether the 410 million-barrel cumulative draw continues.
- Refining margins and product cracks: particularly diesel and jet fuel, where physical tightness is currently more pronounced than the Brent benchmark suggests.
- Non-OPEC production: the extent to which US, Canadian, Guyanese and other supply growth continues to offset Gulf losses.
FAQ
What did OPEC+ decide? The seven core producers kept October output policy unchanged at their 6 September meeting, ending six consecutive monthly increases. The next meeting is scheduled for 4 October.
Does that mean OPEC+ has stopped unwinding cuts? One layer has been unwound. September completed the return of 1.65 mb/d of voluntary cuts introduced in 2023. A separate layer of around 2 million bpd of restraint remains across much of the broader group until the end of 2026.
Is the Strait of Hormuz closed? No. It is severely constrained. EIA estimates crude and petroleum-liquid flows averaged 4.9 mb/d in Q2 2026 compared with 21.6 mb/d in Q4 2025. Reuters says recent flows have recovered to roughly 4–5 mb/d, but remain dramatically below normal levels.
Why isn't Brent above $100? Some Gulf oil is still moving, alternative export routes are carrying additional supply, non-OPEC production is growing, inventories and strategic stocks have absorbed part of the shortage and high prices are weakening demand.
Is the physical oil market still tight? Yes. The IEA estimates a 1.8 mb/d global deficit in Q3 and says observed inventories have fallen 410 million barrels since the end of February. Refined-product markets are particularly tight.
Why does OPEC+ matter less at the moment? Because increasing a production quota does not necessarily increase exports when shipping is constrained. The group's influence rises again if Gulf export routes normalise.
What matters most for OPEC+ next? The 2027 production baselines. They determine the reference capacity against which future quotas and cuts will be calculated.
What is the main signal to watch now? Sustained Hormuz transit and Gulf export volumes. A few improved days are less meaningful than a persistent recovery towards normal flows.
Data and sources: OPEC+ ministerial decision and Reuters reporting, 6–8 September 2026; International Energy Agency Oil Market Report, August 2026; US Energy Information Administration Short-Term Energy Outlook and world oil transit-chokepoint data; Kpler vessel-transit data; ICE Brent market pricing, 8 September 2026.
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