for September delivery fell 1.5% to $87.05 a barrel on Tuesday, with West Texas Intermediate down 1.2% to $81.59. Intraday reads through the European session put Brent as low as the $85 handle and WTI near $80.11, that the level you quote depends entirely on the hour you quote it.
This is the third consecutive session of losses, and it follows the largest single-day decline in more than three months. Monday closed Brent at $88.36, down 8.7%, and WTI at $82.61, down 7.5%. Friday had already delivered a 3% decline. Across three sessions, Brent has surrendered roughly 10% and WTI slightly more.
The catalyst is diplomatic rather than fundamental. The US quietly halted its campaign of strikes against Iran late Friday after nearly two weeks of hostilities, without any formal announcement. Tehran said it had suspended retaliatory operations in response and entered talks with Oman regarding navigation through the Strait of Hormuz. President Trump has described the talks as going well and said a deal is possible, while stating plainly that strikes resume if negotiations fail.
Tuesday added a further diplomatic layer. Iran’s foreign minister held separate calls with his Saudi and Omani counterparts, with the stated agenda being the removal of insecurity imposed on the Strait of Hormuz. That is three regional parties coordinating on the same chokepoint, which is the first genuinely constructive signal since the ceasefire collapsed at the start of July.
Supply conditions improved independently of the diplomacy. Crude loadings resumed at the Caspian Pipeline Consortium terminal on Russia’s Black Sea coast, a primary export route for Kazakh barrels that had been shut by drone strikes.
The number that reframes the entire move: crude is still up roughly 25% this month even after the three-session collapse, and was up nearly 40% at the peak. Brent traded below $70 on July 1 — approximately where it sat when the conflict began in late February — before the ceasefire broke and the market repriced a closed strait for a second time.
What has happened over three days is the unwinding of a war premium, not the establishment of a new price level. Nothing in the physical balance has materially changed since Thursday. The barrels that were not flowing on Thursday are still not flowing today.
That distinction is the whole trade from here.
The July Round Trip: Sub-$70 to $97 and Back to $87
The path this month has been violent enough that the monthly change disguises what actually happened.
A memorandum of understanding signed on June 18 was supposed to end the conflict and reopen Hormuz, which had been effectively closed since February 28. It worked, briefly. Brent averaged $85 a barrel in June, $22 below the May average of $107, and daily spot prices fell below $70 on July 1 — back to pre-conflict levels. Tanker traffic through the region picked up sharply to both load and deliver crude and products.
Then it collapsed. By early July the ceasefire was over, with the administration stating so explicitly, and US Central Command resumed strikes. By July 24 that campaign had run thirteen consecutive nights, targeting Iranian military infrastructure and maritime capabilities. A naval blockade was reimposed on Iran’s ports and coastal areas.
The price response tracked the escalation almost linearly. WTI closed at $79.34 on July 14 with Brent at $84.73. By July 20, Brent had jumped nearly 4% overnight to break $90 and settled at $89.22, with WTI at $83.23 — a roughly 20% monthly gain at that point. The peak came late in the week of July 20, with Brent above $96 and WTI near $92 before Friday’s 3% retreat.
At least three American service members died during the fighting, which drove one of the sharper single-session advances.
One negotiating detail carried disproportionate price weight. Iran had sought to collect tolls for safe passage through Hormuz, and the US had opposed any fee. Under the June 17 interim deal, Tehran agreed not to impose a toll for 60 days. During the July escalation, Trump abandoned his own demand that ships pay a 20% fee on cargo to transit the strait — a reversal that removed one friction point from the reopening path.
From the $96-plus peak to Tuesday’s $87.05, Brent has given back roughly 10%. From July 1’s sub-$70 print, it remains 25% higher.
Both facts are load-bearing. The market has unwound the most recent escalation premium and retained the structural premium from a strait that has been disrupted for five months. Which of those two the next move addresses is what the Oman talks decide.
One-Fifth of Global Supply Runs Through a Strait That Still Has Mines in It
The physical constraint underneath every price move this year is a single waterway, and the reopening is not a switch.
Roughly one-fifth of global oil supplies transited the Strait of Hormuz before the conflict began. That flow collapsed when Iran began targeting vessels in early March, and it has only partially recovered since. Shipments through the strait fell to a May low of 9.6 million barrels per day before rising to around 12 million by early June, supported heavily by ship-to-ship transfers staged in the Gulf of Oman rather than by direct transit.
A full recovery will not be immediate even under the most favourable diplomatic outcome. Mines have to be cleared from the main shipping lanes. Supply chains, tanker scheduling, and insurance markets all take time to normalise after five months of disruption. Marine war-risk premiums do not fall the day a communiqué is signed.
The damage this produced was historic. Global oil supply plummeted by 10.1 million barrels per day to 97 million in March — the largest single-month disruption on record. OPEC+ production fell 9.4 million barrels per day month-over-month to 42.4 million, while non-OPEC+ supply declined 770,000 barrels per day to 54.7 million as lower Qatari output offset gains in Brazil and the United States.
For 2026 as a whole, global oil supply is projected to fall 3.9 million barrels per day to 102.4 million, with Gulf losses only partly offset by continued non-OPEC+ growth. World petroleum production is forecast at roughly 99 million barrels per day for the year, against a record 106.1 million in 2025.
That is a seven-million-barrel hole in a market where a one-million-barrel imbalance historically moves price by ten dollars.
The reopening scenario embedded in most institutional forecasts assumes flows through Hormuz gradually resume from the third quarter onward. Under that assumption, the market remains in deficit until the final quarter of the year — supply recovers more slowly than demand returns, which is the standard asymmetry after an infrastructure shock.
Iranian exports are the additional variable. Those can fully resume only once the US blockade is lifted, and the blockade is a bargaining instrument rather than a technical constraint. It comes off when a deal is signed, not before.
The Red Sea Is Now the Risk the Market Is Underpricing
The most consequential warning issued Tuesday concerns a waterway nobody was watching three weeks ago.
Analysts at a major commodities desk published a note Tuesday arguing Brent should moderate to $80 a barrel by year-end if Hormuz fully reopens by the final three months of 2026. The same note added a caveat that deserves more weight than the target: Red Sea disruptions and attacks on Saudi oil infrastructure may pose a new source of upside risk for crude and refined product prices.
The mechanism is straightforward and dangerous. As Hormuz became unreliable, the Red Sea became the alternative export route for Saudi Arabian crude, carrying millions of barrels each day. That elevated a secondary corridor into a primary one — and put it directly in range of forces that have spent two years demonstrating the capability to strike shipping and coastal infrastructure.
Houthi militants claimed responsibility over the weekend for attacks on facilities associated with Saudi Aramco at the Red Sea ports of Jizan and Yanbu. Neither the Saudi government nor Aramco has confirmed the strikes. Confirmation matters less than capability: the claim itself reprices insurance and routing decisions regardless of what actually landed.
Yanbu is the western terminus of the East-West pipeline, the infrastructure specifically built to bypass Hormuz by moving crude across the peninsula to the Red Sea. Jizan hosts a major refining complex. Damage to either would eliminate the primary workaround the market has been relying on since March.
Trump has warned of severe retaliation if Tehran backs further Houthi attacks on vessels in the Red Sea, and has said he was considering an unprecedented military response. That linkage — Houthi action triggering escalation against Iran — is the specific mechanism by which the current pause unravels.
The market is currently pricing the Hormuz de-escalation and discounting the Red Sea escalation. Those are the same conflict expressed through two chokepoints, and treating them as independent is the error most likely to produce a violent repricing.
Roughly one-fifth of global supply through Hormuz plus millions of daily barrels through the Red Sea means the two corridors together account for a quarter of seaborne crude. Neither is currently secure.
Inventories Have Drawn at a Record Clip and the Deficit Runs to 900 Million Barrels
The stock picture is what makes the current price level defensible even as the war premium deflates.
Global oil inventories fell by an average of 5.1 million barrels per day during the second quarter of 2026. Observed stocks drew by 129 million barrels in March and a further 117 million in April. On-land inventories dropped 170 million barrels in April alone — a rate of 5.7 million barrels per day — while oil on water rebounded by 53 million as cargoes waited out the disruption.
The regional distribution is what should concern policymakers. OECD on-land stocks plummeted by 146 million barrels in April, a 4.9 million barrel per day draw, while visible non-OECD stocks fell by 24 million. The developed world absorbed the overwhelming majority of the depletion, which means the buffer that would cushion a future shock has been substantially spent.
Cumulative stock deficit estimates run to roughly 900 million barrels. That is not a number that rebuilds in a quarter.
The forecast turn is expected in the fourth quarter. Official projections put global inventories building by an average of 2.7 million barrels per day in the fourth quarter of 2026 and 5.0 million barrels per day across 2027, as supply grows faster than consumption. Under that trajectory, downward pressure on prices dominates from year-end onward.
The critical qualifier: even with rising Middle East production and exports in the coming months, it will take considerable time to replenish reduced global inventories and for regional production to fully recover. A market that has drawn 900 million barrels needs several quarters of surplus before the cushion is restored, and until it is, every supply headline lands on a thinner market than it would have in 2025.
Compare where the market stood before the conflict. Observed global inventories built by 225 million barrels between January and August 2025, reaching a four-year high of 7.9 billion barrels, with more than a third of that increase in Chinese crude stocks sitting 30% above 2019 levels. The 2025 problem was an untenable surplus approaching 4 million barrels per day.
Eighteen months later the problem is a record deficit. The speed of that inversion is the single best argument against confidence in any twelve-month price forecast.
Demand Destruction Is Doing Half the Rebalancing
The demand side has adjusted more violently than any forecaster expected entering the year, and it is a substantial part of why prices have not gone higher.
Official projections now show global oil consumption decreasing by an average of 1.2 million barrels per day across 2026, with 800,000 barrels per day of that decline coming from non-OECD countries. Separate estimates put the contraction at 420,000 barrels per day year-over-year. Either figure represents a genuine demand recession — global oil consumption has contracted in only a handful of years since the 1980s, and almost always during financial crises rather than supply shocks.
The mechanism is price. Sustained crude above $90, with Brent averaging $107 in May, destroys marginal demand in exactly the places that can least afford it. Non-OECD consumers carry the largest share of price-sensitive demand, and they are carrying 67% of the total contraction.
The rebound assumption is where forecasts diverge from observation. Consumption is expected to grow by 2.0 million barrels per day in 2027 to 104.8 million — 800,000 barrels per day above the 2025 average — once prices fall and supply flows fully return. That is a sharp V, and it assumes demand destruction is entirely price-driven and fully reversible.
Some of it will not be. Five months of disrupted supply and elevated prices accelerates substitution, efficiency investment, and behavioural change that does not reverse when crude falls back to $80. The share of the 1.2 million barrel per day contraction that is structural rather than cyclical is unknowable in real time and will be the largest source of forecast error through 2027.
For price formation right now, weak demand is the counterweight to a 900 million barrel inventory deficit. That is why Brent at $87 rather than $120 is the equilibrium despite the largest supply disruption on record.
The peak summer demand period is currently underway in the northern hemisphere, which is why the market has been describing further volatility as likely regardless of diplomatic progress. Seasonal demand meeting depleted inventories is the configuration that produces spikes.
Chinese officials have grown increasingly concerned that attacks on Gulf states and Hormuz disruptions are damaging their economic interests, which is what motivated the Pakistani-brokered effort to revive negotiations with Chinese support.
Refining Is Where the Real Damage Sits
The product market has been tighter than the crude market throughout this conflict, and it is the part of the complex most exposed to the Red Sea.
Refinery crude throughputs were forecast to plunge by 4.5 million barrels per day in the second quarter to 78.7 million, and by 1.6 million barrels per day to 82.3 million for 2026 as a whole, as operators contended with infrastructure damage, export restrictions, and reduced feedstock availability. In April, Middle East refineries and feedstock-constrained Asian plants cut runs by roughly 6 million barrels per day to 77.2 million.
Global crude runs are now expected to decline by around 1 million barrels per day on average across 2026 to 82.9 million.
The consequence has been extraordinary margins. Refining margins have remained at historically high levels, supported by record middle distillate cracks — diesel, jet fuel, and heating oil. Middle distillate cracks reached all-time highs during the March disruption and have not normalised since.
That matters for the inflation transmission more than crude does. Diesel prices flow directly into freight costs, agriculture, and construction. Jet fuel flows into airfares. A crude price that falls 10% while distillate cracks stay at record levels delivers far less consumer relief than the headline suggests, which is why energy-driven inflation has been stickier than the crude chart implies.
Refiners have adapted, with new trade flows emerging to compensate for lost Gulf product exports. Those workarounds carry higher freight costs and longer voyages, which is itself inflationary and which embeds a structural premium into product prices that persists after crude normalises.
The Jizan complex sits at the intersection of both problems. It is a major Red Sea refining asset, and it was among the facilities Houthi forces claimed to have targeted over the weekend. Damage there would tighten an already record-tight product market rather than a crude market that carries at least some inventory buffer.
For anyone modelling the inflation path into Wednesday’s Federal Reserve decision, the crude collapse is the headline and the distillate cracks are the substance. Crude has fallen 10% in three sessions. Product cracks have not.
That gap is why policymakers are unlikely to treat this week’s oil move as resolving the inflation question.
OPEC’s Spare Capacity Fell to 2.5 Million Barrels When the UAE Walked
The structural change that received almost no attention when it happened is now the most important variable in any upside scenario.
The United Arab Emirates announced its departure from OPEC effective May 1, 2026. Because the UAE held significant spare crude production capacity, that exit reduces OPEC’s projected spare capacity for 2027 from 3.8 million barrels per day to just 2.5 million.
Spare capacity is the market’s shock absorber. It is the volume producers can bring online within roughly 90 days and sustain, and it is the only mechanism by which a supply disruption gets offset without price doing the work. A 1.3 million barrel per day reduction in that buffer — a 34% cut — meaningfully limits the cartel’s ability to stabilise the market in any future shock.
The timing could hardly be worse. OPEC lost a third of its shock-absorbing capacity three months before the largest supply disruption in history entered its most acute phase.
The comparison to the prior cycle sharpens it. Following five years of production restraint, OPEC+ had been on track to boost output by an average of 1.4 million barrels per day in 2025 and a further 1.2 million in 2026 — unwinding cuts into what was projected as an untenable surplus approaching 4 million barrels per day. The group was managing an oversupply problem with ample flexibility.
That flexibility is now largely spent. Production is being constrained by damaged infrastructure and blockades rather than by voluntary agreement, which means it cannot be reversed by decision.
The forward risk this creates runs in both directions. On the upside, any new disruption meets a market with no meaningful buffer. On the downside, when Gulf production does return, it returns alongside restored Iranian exports and continued non-OPEC+ growth into a market with 1.2 million barrels per day less demand than in 2025 — and OPEC has less capacity than before to withhold barrels and defend price.
One institutional warning puts that scenario at a reset toward the $30s in 2027 if OPEC+ mismanages the returning oversupply. That is an outlier, but the mechanism it describes is real.
Non-OPEC Supply Keeps Growing Regardless of the War
The offsetting structural force has been remarkably indifferent to the conflict, and it sets the medium-term floor under any bearish case.
US crude oil production is projected to average 13.6 million barrels per day in 2026, rising to 14.1 million in 2027 as higher prices support continued drilling in the Permian Basin. That is a half-million barrel per day increase arriving precisely as Gulf supply returns.
Brazil, Guyana, and Argentina lead the rest of non-OPEC+ growth, accounting for a 0.6 million barrel per day rise in 2026. In 2027, South American output growth is expected to represent roughly two-thirds of the global non-OPEC+ increase. Those are long-cycle projects with sunk capital and no responsiveness to short-term price — Guyanese and Brazilian pre-salt barrels arrive on schedule regardless of what Brent does in any given quarter.
The pattern from the prior cycle is instructive. The United States, Brazil, Canada, Guyana, and Argentina accounted for the large majority of non-OPEC+ supply growth in 2025 and were forecast to do the same in 2026, with non-OPEC+ growth of 1.6 million barrels per day in 2025 and 1.2 million in 2026. That growth continued through the conflict.
The implication for 2027 is uncomfortable for bulls. A market that adds 500,000 barrels per day of US supply, roughly 400,000 from South America, restores Gulf production, unblocks Iranian exports, and faces demand that has structurally adjusted downward is a market heading toward substantial surplus.
Official projections capture this directly: inventories building 5.0 million barrels per day across 2027 with sustained downward pressure on prices for the remainder of the forecast horizon.
Against that, the 900 million barrel cumulative deficit and reduced OPEC spare capacity keep the market structurally tighter than it was before the conflict, even in surplus. Rebuilding depleted stocks absorbs supply that would otherwise pressure price, and several countries are reviewing energy strategies with new strategic reserve construction under consideration.
That reserve-building demand is the underappreciated floor. Governments that just watched a chokepoint close for five months are unlikely to run inventories as thin as they did in 2025.
