Brent’s retreat to about $80 a barrel captures a market weighing diplomatic optimism against a still-disrupted physical oil system. Comments from US Treasury Secretary Scott Bessent and Qatar’s Foreign Ministry raised hopes for a draft US-Iran agreement, easing some of the geopolitical premium. Yet shipping constraints, lost production and strong refining margins remain visible in prices and company results.
For refiners, the decline offers some relief from crude costs as President Donald Trump presses the industry over fuel prices and profits. For producers, the key question is whether diplomacy can restore supply and transit capacity quickly enough to change the balance of the market. The reported scale of lost output suggests that even a rapid reopening of the Strait of Hormuz would not immediately reverse the disruption.
Refining profits draw political attention
Trump criticized ExxonMobil and Chevron for earning what he described as too much money, and urged them to return some of it to the public. He also challenged the companies over their failure to credit his administration’s support for the oil industry. His comments came as US oil majors reported strong second-quarter results, putting refining gains back in the political spotlight.
The distinction between production and refining helps explain the earnings picture. ExxonMobil’s output was affected by closures in the Middle East, while Chevron has faced continuing disruption at the CPC operation in Kazakhstan. Refining margins, by contrast, have been exceptionally strong since the conflict began in March.
The US 3-2-1 crack spread, a commonly used measure based on turning three barrels of crude into two barrels of gasoline and one barrel of distillates, has doubled since early March to about $60 a barrel. Crude prices have risen by roughly $11 a barrel over the same period, despite this week’s diplomatic push. That gap points to how sharply refining economics have diverged from the price of the feedstock itself.
Consumers are still paying more than they were a year ago. The average US gasoline price stood at $4.08 a gallon on August 4, according to AAA, a 30% increase year over year. Trump has called on retailers to lower pump prices as soon as possible, while the industry’s high margins give his criticism a clear financial target.
OPEC+ completes its planned supply unwind
Seven remaining OPEC+ members agreed to raise their combined September output targets by 188,000 barrels a day. That move completes the group’s phased unwinding, on paper, of 1.65 million barrels a day in voluntary cuts first announced in 2023. The increase adds planned supply just as Brent has weakened, although targets do not by themselves establish how much additional crude will reach buyers.
Saudi Aramco’s second-quarter earnings show how high prices have cushioned producers amid lower output. The company reported profit of $33.4 billion, up 33%, and an average realized price of $108.10 a barrel. Chief Executive Amin Nasser said lost production since February had reached 2.6 billion barrels—equivalent to about a month of global crude output. He estimated that replenishing that volume would take 18 months at an average pace of 2.1 million barrels a day, even if Hormuz reopened immediately.
That estimate puts the market’s diplomatic optimism in perspective. A draft agreement could reduce fears of further disruption, but the production deficit and the time required to replace it remain material. Aramco’s results also show why crude-price direction alone doesn’t tell the whole story: realized prices and output volumes both shape earnings.
Oil flows and shipping routes remain constrained
Hormuz transits fell to their lowest level since June after the Liberia-flagged dry-bulk vessel Minoan Pioneer was targeted early Tuesday. One seafarer was missing and the crew abandoned the ship. The incident came two days after a very large crude carrier carrying Iraqi oil was hit. Lower traffic through the strait keeps pressure on the movement of crude and other energy cargoes, even as market sentiment responds to signs of diplomacy.
Iran says it has discussed with Oman a single shipping corridor through Hormuz, with separate lanes for inbound and outbound traffic. That account differs from early media reports that Tehran had rejected the proposal. The details matter commercially: a workable route could change how ships navigate the strait, though the source provides no timeline or operating plan.
Elsewhere, the Panama Canal has become a costly alternative for some energy cargoes. With both the Suez Canal and Hormuz disrupted, average auction prices for Neopanamax passage reached a record $2.5 million, and some bids hit $3.8 million. Those costs have undermined the economics of moving liquefied petroleum gas from the US Gulf Coast to Asia.
Russia’s seaborne crude exports also eased. Weekly shipments slipped to 3.9 million barrels a day, below 4 million for the first time in six weeks, while a relative lull in Ukrainian drone strikes allowed refinery runs to recover to 4 million barrels a day. The shift illustrates how changes in refinery activity can redirect crude away from export markets.
Companies adjust pricing and portfolios
ADNOC will price all its crude grades against Platts Dubai from November 1, leaving behind the futures-based IFAD Murban mechanism. Buyers have sought pricing that reflects prompt market conditions during Hormuz disruptions. The change is a notable adjustment to how Abu Dhabi crude is benchmarked and sold.
Shell has agreed to sell its European onshore renewables portfolio to TotalEnergies for an undisclosed amount. The assets include 0.5 gigawatts in operation and a project pipeline of 3.5 gigawatts. BP, meanwhile, completed the sale of its Gelsenkirchen refinery in Germany to Klesch Group. It now has five operating refineries: two in the United States and three in Europe.
In Azerbaijan, state oil company SOCAR bought Itochu’s 3.65% operating interest in the Azeri-Chirag-Guneshli offshore field, marking the fourth exit from the project. In Nigeria, Dangote’s refinery is reportedly preparing for an October initial public offering that could become Africa’s largest listing. Owner Aliko Dangote is seeking participation from regional capital markets.
Production projects face different timelines
Petrobras now expects to finish drilling the Morpho well in Brazil’s Foz do Amazonas basin in September, later than its original May target. The company’s announcement described the well as being within 500 metres of the Morpho reservoir. The basin has been presented as a potential 30-billion-barrel oil frontier, but the delayed drilling means its prospects remain a question of exploration rather than established production.
Qatar’s North Field East expansion is advancing again, with contractors Chiyoda and Technip Energies resuming construction. The project is designed to add 32 million tonnes a year of capacity. Its first train is undergoing commissioning, the second is complete, and traders expect initial volumes by summer 2027.
In Iraq and Turkey, a one-year agreement preserves crude exports through the Kirkuk-Ceyhan pipeline, which carries Iraqi oil to the Mediterranean. The arrangement provides for a potential fourfold increase in flows, to 750,000 barrels a day. Syria, by contrast, has agreed to drastically reduce Russian crude imports, which have averaged about 60,000 barrels a day in 2026 to date.
Two other developments carry implications beyond crude. Mexico’s Pemex closed the Krem-1 exploratory well about five months after an accident caused a fire and prolonged flaring. The gas burned may have reached 300 million cubic metres, and environmental monitoring is continuing. Indonesia resumed exports of minerals containing rare-earth by-products after mandatory testing delayed nickel shipments; the three-month London Metal Exchange nickel contract fell to $17,000 a tonne after the move.
The market’s near-term signal is mixed: diplomatic progress has pulled Brent lower, while constrained shipping and a substantial production shortfall keep the physical picture tight. For oil companies, the split between crude prices, refining margins and operating volumes will matter as much as the headline benchmark in the next round of results.