The Question Got Answered
On October 7, 2023, Hamas attacked Israel and set off a war that drew in Hezbollah and the Houthis and kept the region on edge for more than two years. Oil barely noticed. Brent rose for a few sessions and then drifted back to where supply and demand fundamentals put it. Analysts spent the following years explaining why: no producing country was directly involved, OPEC+ was sitting on curtailed output, and the market had learned to price the probability of a disruption rather than the disruption itself.
That lesson looked sound right up until February 28, 2026, when the United States and Israel opened an air war on Iran. Within hours, according to the account assembled on Wikipedia’s page on the 2026 Strait of Hormuz crisis, Iran’s Revolutionary Guard was warning ships by radio that nothing would be allowed through the strait, and tracking data showed traffic down about 70 percent. Brent, which had closed at $72.48 on February 27, crossed $100 on March 8. The International Energy Agency’s April Oil Market Report called March “the largest-ever monthly gain” in oil prices, and said global supply had fallen by 10.1 million barrels per day in a single month, “the largest disruption in history.”
Nearly eight months later, as this is written on October 22, the strait is still only partly open, Brent futures closed at $109.86 on October 16, and the IEA’s October report, published on October 14, put the physical North Sea Dated benchmark around $134 a barrel. The old puzzle, why some crises move oil and others do not, now has a clear worked example on each side of the ledger.
Eight Months of Price Discovery
The first days were fast but not panicked. Brent jumped more than 10 percent on March 2, the first trading day after the strikes, and closed at $81.49 on March 3, according to Wikipedia’s chronology of the 2026 oil market. That was a war premium of the familiar kind: a bet on probabilities. The regime change came as the strait stayed shut. QatarEnergy declared force majeure on gas contracts on March 4, insurers withdrew protection and indemnity cover on March 5, and on March 8 Brent crossed $100 for the first time in four years. On Monday, March 9, it traded near $120 intraday, CNBC’s April timeline records, before closing at $88.43. By the week ending March 20 it was at $112.19 after Iraq declared force majeure, and it ended March up 51 percent on the month.
The physical market ran even hotter than the futures screen. The IEA’s April report said North Sea Dated was trading around $130, “$60/bbl above pre-conflict levels,” with some physical grades changing hands near $150. Dubai crude, the benchmark for Gulf barrels, hit $166 on March 19 according to the Wikipedia crisis page. Dated Brent reached $144.50 on April 7, Rigzone reported, while the June Brent futures contract closed below $100 on April 13. J.P. Morgan analysts including Natasha Kaneva, head of global commodities strategy, wrote in a note reported by Rigzone that the gap between dated and front-month prices is normally narrow, and that the much wider spread signalled “a market struggling to source barrels for delivery now.”
April was whiplash. A temporary US-Iran ceasefire on April 8 knocked Brent down more than 13 percent to $94.75. Talks in Islamabad failed, the US Navy began blockading Iranian ports on April 13, and SEB’s chief commodities analyst Bjarne Schieldrop wrote the next day that “the Strait of Hormuz is now essentially fully closed.” Iran’s foreign minister declared the strait open on April 17 and crude fell more than 10 percent in a day; by the following weekend Iran had reimposed its restrictions and prices jumped again. On April 29 Brent closed at $118.03 after President Trump threatened to keep the blockade in place until a nuclear deal, and on April 30 it briefly touched $126, the wartime high, before settling at $114.01. ING strategists Warren Patterson and Ewa Manthey described a market “losing hope for any quick resumption in oil flows.”
Then came the long slide. Brent fell almost 19 percent in May, CNBC reported on May 29, as the two sides moved toward a memorandum of understanding; it was signed on June 17 and extended the ceasefire by 60 days. The Treasury issued a 60-day waiver on Iranian oil sales on June 22, tankers began transiting again, and Brent closed at $73.74 on June 24, its lowest since the war began. It closed at $71.57 on July 1, within a dollar of the pre-war price.
The truce collapsed on July 8 after Iran struck several commercial ships, and Brent closed back above $100 on July 23. It eased again in August, trading at $84.64 on August 10 as traders priced a deal that did not come, then climbed through September as the stalemate hardened. The US Energy Information Administration’s October Short-Term Energy Outlook puts the September Brent spot average at $114 a barrel, $23 above August. Brent closed at $102.31 on October 1, $104.28 on October 8 after a wave of tanker attacks, and $109.86 on October 16.
The shape is clear: a first-day repricing of risk, a much larger repricing once the barrels physically stopped, a near-complete retracement when flows looked set to resume, and a renewed climb when they did not. Each leg tracked the physical situation in the strait, not the headlines about the war.
What the Shocks That Stuck Had in Common
The 2026 episode belongs to a short list of crises that removed large volumes from the market for months. The earlier entries share its signature.
In 1973, the Organization of Arab Petroleum Exporting Countries imposed an embargo on October 19 and followed it with production cuts. The Federal Reserve’s history of the episode records the price of oil going from $2.90 a barrel before the embargo to $11.65 in January 1974, and notes that the US oil industry had no spare capacity with which to offset the cuts. The embargo was lifted in March 1974; the prices stayed.
The 1979 shock came from the Iranian Revolution. By January 1979 Iranian output had fallen by about 4.8 million barrels per day, roughly 7 percent of world production, according to the Federal Reserve’s account, and prices more than doubled between April 1979 and April 1980. The Fed’s essay makes a point worth remembering in 2026: it argues that fear of further shortages and “speculative hoarding” may have done more to lift prices than the lost barrels themselves.
Iraq’s invasion of Kuwait on August 2, 1990, produced a cleaner test of what happens when a shock is resolved quickly. Figures from the 1991 Economic Report of the President, as quoted by economist David Henderson at EconLog, show spot crude at about $17 in June 1990, about $28 by August 6, as high as $40 in mid-October, and back to about $20 once Operation Desert Storm began in mid-January 1991. The IEA’s first-ever coordinated stock release came in 1991. The premium lasted exactly as long as the uncertainty about Gulf flows did.
Libya in 2011 is the smallest entry on the list, and the one that shows the buffers working. An IFRI analysis puts Libyan production at a little over 1.5 million barrels per day in 2009 and 2010 and at 169,000 barrels per day in May 2011. The IEA said that 132 million barrels of light, sweet crude had been removed from the market by the end of May and announced a 60 million barrel coordinated release on June 22, 2011, its third collective action. Prices rose, Saudi Arabia raised output, and the market calmed within months.
The common thread is physical. In every case barrels that the market had counted on stopped arriving, and the price had to rise until enough demand went away or enough other supply appeared to close the gap. 2026 differs from these mainly in scale. The IEA’s June 22 commentary on how supplies readjusted says flows through Hormuz averaged 2.7 million barrels per day in March, April and May against about 20 million before the war, and that cumulative supply losses from Middle East producers had already passed 1.3 billion barrels, ten times the Libyan loss the IEA cited in 2011.
The Crises That Faded
The other side of the ledger is longer, and the entries have their own shared signature: the threat was real, the barrels kept moving.
When the United States left the Iran nuclear agreement in 2018 and reimposed sanctions, Brent climbed to a four-year high, settling at $86.29 on October 3, 2018, Reuters reported. The rally then unwound through the rest of the year as it became clear that Iranian exports would fall by less than feared and that other producers had room to fill the gap. The sanctions did reduce Iranian supply, but gradually, and the market absorbed the change.
The September 14, 2019, drone and missile attack on Saudi Arabia’s Abqaiq processing plant and Khurais field is the most instructive of the non-shocks, because it did take barrels off the market. Widely cited estimates put the loss at about 5.7 million barrels per day, around half of Saudi output. Brent opened at $71.57 when trading resumed on September 15 and the EIA calculated a 12.7 percent daily move, the largest it found in 29 years of data. Yet the Congressional Research Service noted that prices were only about a dollar above pre-attack levels two weeks later, and Bloomberg reported in early October that Brent was 4 percent below where it had been before the strike. Aramco restored output within weeks. A temporary outage with a credible recovery timeline is a very different thing from a closed waterway with no timeline at all.
Russia’s invasion of Ukraine in February 2022 sits in between. Brent traded above $130 in early trading on March 7, 2022, surpassing its 2012 high, and the IEA carried out two coordinated stock releases that year. But Russian crude was never physically removed; it was rerouted to India and China at a discount, and the price fell back as the new trade map settled.
And then there is October 2023, the episode that opened this piece. Neither Israel nor Gaza produces meaningful volumes, Iran’s exports to China continued, Chinese demand was weak and OPEC+ held a reservoir of curtailed output. Every mediating variable pointed toward a muted response, and the response was muted.
In all four cases the market priced the probability of lost barrels, and the probability turned out to be low or the loss short. Nothing about that was irrational. It simply left no defence against the one scenario in which the probability went to one.
Buffers, and Where They Ran Out
If spare capacity, inventories, alternative routes and demand elasticity are the shock absorbers of the oil market, 2026 has been a stress test of each.
Spare capacity failed first, for a reason the old framework never had to confront: almost all of it sits behind the strait. OPEC+ had agreed on March 1, a day into the war, to add 206,000 barrels per day, a decision CNBC reported was constrained by what RBC’s Helima Croft called a “lack of production capacity outside Saudi Arabia.” Once Hormuz shut, the extra capacity became irrelevant. The IEA’s April report calculated that effective OPEC+ spare capacity had fallen to 0.32 million barrels per day in March, the lowest on record. When OPEC+ agreed another 188,000 barrels per day for June, Al Jazeera described the move as “largely symbolic”: Saudi Arabia’s quota was rising to 10.291 million barrels per day at a time when its actual March output was 7.76 million. By August, the IEA reported, Saudi output was down to 5.97 million barrels per day.
Bypass pipelines helped, within hard limits. The IEA’s June commentary says Saudi exports from the Red Sea port of Yanbu rose from 2 million barrels per day before the war to more than 5 million by early June, and that the UAE’s Habshan-Fujairah line, with 1.8 million barrels per day of capacity, lifted total UAE exports to 4.3 million barrels per day, about 85 percent of pre-war levels. Alternative-route exports from the region rose from under 4 million barrels per day to 7.2 million by early April, according to the April report. That is roughly a third of what the strait used to carry.
Stockpiles were the second line. On March 11, the 32 IEA members agreed to release 400 million barrels, the largest collective action in the agency’s history and only the sixth since 1974. The United States committed 172 million of them over about 120 days, from a reserve CBS News put at about 415 million barrels at the time; by August, CNBC reported, the US Strategic Petroleum Reserve had fallen below 300 million barrels for the first time since 1983. The release was adding about 2.5 million barrels per day to the market in May, the IEA said. “It buys time, but it does not solve the crisis,” Bernstein analysts wrote in March. On October 16, gCaptain reported, the IEA agreed to accelerate about 100 million barrels of remaining releases, more than 20 million of them diesel, after roughly 330 million barrels had already gone out.
Inventories absorbed the rest, and they are nearly spent. The IEA’s October report says global observed stocks were 509 million barrels lower than at the end of February and that on-land stocks were at their lowest since at least 2016. The EIA estimates global inventories fell by 1.9 million barrels per day in the third quarter.
The final buffer was demand, and here the numbers are the most telling. In February the IEA expected 2026 demand to grow by 850,000 barrels per day. By October it expected a decline of 2.6 million barrels per day, the first annual drop since 2020. Chinese crude imports fell 40 percent, or 4.6 million barrels per day, between February and May, the IEA says, and the agency’s August report cited that collapse as one reason the feared global shortage had not fully materialised. Diesel carried the sharpest adjustment: the IEA recorded prices around $220 a barrel in Europe and the United States in September, and the EIA put US retail diesel at $6.29 a gallon that month, with East Coast distillate stocks 32 percent below their five-year average.
The one buffer the 1970s did not have, US shale, did what it could. The EIA expects US crude output of 13.9 million barrels per day this year, and the IEA recorded record US crude and product exports of 13.1 million barrels per day in May. It could not substitute for 20 million barrels per day of Gulf exports.
The Calculus Now
What should an informed reader take from the record as it stands on October 22?
First, the old rule was right, and that is exactly what made 2026 so expensive. Markets price the probability of lost barrels, not the worst case. From 2018 through 2025 that approach produced fear premiums that faded within weeks, because the barrels kept coming. In 2026 the probability resolved to certainty, and the premium became a shortage price.
Second, the gap between financial and physical prices is where the real information lives. Futures gave back the whole war premium in late June; by mid-October, according to the IEA, Dated Brent was around $134 while the futures strip sat near $107. Rory Johnston of Commodity Context told CNBC in April that a reopening would trigger an immediate $10 to $20 drop because of speculative positioning, and that is more or less what happened in June. “This is still the largest oil supply shock in the history of the oil market,” he said at the time, and he expected Brent to settle in the $80 to $90 range rather than return to pre-crisis levels once the strait reopened. The IEA’s inventory numbers suggest a great deal of restocking stands between here and there.
Third, geography trumps arithmetic. Spare capacity is only a buffer if it can reach a tanker. A headline figure of several million barrels per day of OPEC spare capacity proved worth close to zero with the strait closed; the real spare capacity of the system was whatever could leave through Yanbu, Fujairah and the Atlantic basin. Future assessments of market vulnerability will have to count barrels by exit route, not by country.
Fourth, the recovery, when it comes, will not look like the shock in reverse. The EIA’s October outlook assumes convoys and workarounds gradually restore Gulf exports, forecasts Brent averaging $105 in the fourth quarter and $84 in 2027, and expects Middle East production shut-ins to fall from 4.5 million barrels per day this quarter to 2.7 million in the first quarter of next year. Kpler data reported by Al Jazeera on October 5 put Middle East crude exports above pre-war levels in late September, thanks to bypass routes and ship-to-ship transfers in the Gulf of Oman, even as tanker attacks increased. That progress coincided with Brent closing near $110 in mid-October, because the market is now pricing depleted stocks, a drained strategic reserve and a strait that has opened and closed more than once since April.
For years, the mistake was to assume every Middle East headline would move oil. The 2026 version was to assume that because the last dozen headlines had not, the next one would not either. Both errors come from reading the headline instead of the flows. A crisis moves oil when it removes barrels, in proportion to how many it removes, for as long as the buffers that stand between the loss and the consumer hold out. In 2026 the barrels were removed, the buffers were tested one by one, and the price did what it was always going to do.