Oil and European gas spent the final week of July trading diplomatic statements, military alerts and shipping reports rather than conventional supply-and-demand indicators. Each suggestion that the Strait of Hormuz might reopen removed part of the geopolitical premium. Each renewed attack returned it almost immediately.
Brent had moved above $100 a barrel during the escalation before falling by more than 9% to around $88 when the United States and Iran appeared to pause military operations. The sell-off was not driven by a sudden increase in production or a collapse in consumption. It reflected the market’s willingness to price a faster restoration of Gulf shipping.
That interpretation proved temporary. Crude recovered above $92 a barrel after renewed strikes, missile attacks and incidents involving vessels near Hormuz and the Red Sea. US commercial crude inventories also fell by 7.2 million barrels, while another 3.8 million barrels were withdrawn from the Strategic Petroleum Reserve. By the time the weekly publication went to press, Brent was at $89.58 a barrel and WTI at $83.98.
The price action revealed a market divided between headline risk and physical constraint. Diplomatic news can trigger a large paper-market correction within minutes. Reopening a maritime route, clearing a queue of tankers, restoring insurance coverage and normalising refinery feedstock flows take much longer. Hormuz traffic remained severely restricted, while oil and product movements through the Bab al-Mandab corridor had fallen from around 5.5 million barrels a day in June to 2.6 million barrels a day in July.
Gas showed even greater sensitivity. European benchmark futures dropped by as much as 11% when negotiations appeared to advance, then recovered as Qatar maintained force majeure and fighting resumed. Unlike crude, LNG cannot be redirected without spare liquefaction, shipping and regasification capacity. The route may reopen, but a full restoration of contractual supply remains dependent on vessel availability, terminal operations and the willingness of exporters to resume normal loadings.
The TTF front-month contract stood at €59.785/MWh, equivalent to approximately $19.96/MMBtu, while the Asian JKM benchmark was $21.375/MMBtu. That premium gave sellers a commercial reason to favour Asia when cargoes were movable. Henry Hub, by contrast, remained at only $2.77/MMBtu, underlining the separation between a well-supplied US domestic gas market and a constrained global LNG market.
For crude traders, the near-term range is likely to remain unusually wide. A credible transit arrangement would reduce the immediate war premium, but prices would still reflect low strategic inventories and tight product markets. Partial shipping access would create a volatile middle case in which loadings resume selectively while insurance and security costs remain elevated. Renewed closure would return attention to refinery feedstock shortages, emergency stock releases and demand destruction.
TTF carries a more asymmetric risk. Europe is approaching the winter-storage period with insufficient inventories and stronger competition from Asia. A few LNG transits can improve sentiment, but they do not materially rebuild storage. Gas prices therefore need either sustained export normalisation or a meaningful reduction in European demand before the premium can be removed.
The decisive trading variable is not the tone of negotiations. It is the verified volume of oil and LNG physically passing through the Strait.