There have been few years where it’s been this challenging to be an oil analyst. Brent rose to USD 109.21 per barrel on 15 September to record a more than 20% gain in a single month. The flagship crude is now 60% higher than a year ago, following a supply shock of historic proportions that has also counterintuitively destroyed demand. Saudi output has now dropped to its lowest level since 1990, and Libya has suspended operations in several oilfields, citing force majeure. WTI is trading at USD 102.13 today (15 September), after dipping slightly from USD 104 earlier in the week on news that Saudi Arabia's key East-West pipeline could be restored. However, beneath the endless noise of pipeline repair timelines and diplomatic negotiations, two structural stories are quietly reshaping the medium-term price outlook in ways that will last much longer than any regional ceasefire.
First, we have the irreversible shift in global demand patterns, led by China, and the awkward position in which OPEC+ now finds itself, having completed its three-year production ramp-up at perhaps the most inopportune moment. Both of these narrative threads are incredibly tangled, and together they make forecasting the oil price over the next six to twelve months a truly humbling exercise.
China's structural shift and the seasonal wild card
The most consequential development in global oil demand this year, and perhaps the most difficult to reverse, has nothing to do with the Strait of Hormuz. It is rather the accelerating structural decline in Chinese oil consumption. Sinopec's research department expects China's oil demand to fall by 600,000 barrels per day (-8.9%) in 2026. This marks a third straight annual decline, with gasoline and diesel leading the losses with 8.7% and 11.4% respective reductions. The drivers are structural rather than cyclical: EV penetration has decimated gasoline demand faster than almost any forecast anticipated, while LNG-powered lorries have carved deeply into diesel's share of the cargo trade. Even Chinese mega-refineries are processing crude differently nowadays, with greater emphasis on chemicals as opposed to fuel. In the best-case scenario, China's crude imports are expected to remain 1.0–1.5 million barrels per day below the 2025 average. China only began drawing down its crude inventories in May, resulting in a smaller cumulative draw than Japan and South Korea. Thus, the timing of China’s much-anticipated restocking wave, which could theoretically add up to 1.6 million barrels per day of incremental demand over a 100-day filling period, is still very much uncertain and will likely depend on price levels and confidence in supply route security. The seasonal picture adds a further layer of complexity. The end of the Northern Hemisphere summer driving season traditionally softens gasoline demand across Europe and North America in September and October, before winter heating demand begins to push up demand again around December. This year, that seasonal transition is complicated by the fact that crude imports into China and Japan have declined sharply, each falling by around 40%. This has left Asian refinery throughput so suppressed that the usual seasonal uplift in oil demand may prove considerably more muted than the historical data would suggest, particularly given the warmer winters we’ve observed in recent years. The net result is structural demand that is simultaneously lower than pre-conflict levels. And given the potential cyclical rebound if Hormuz normalises, medium-term movements are genuinely difficult to model with any precision.
OPEC+'s awkward timing and the non-OPEC surge
On the supply side, OPEC+ has finally reached the crossroads it has been approaching carefully for three years, and the timing could hardly be any worse. The cartel has now completed the rollback of its COVID-era voluntary production cuts with a September increase: Seven producers, including Saudi Arabia and Russia, have implemented a final 188,000 barrel-per-day addition to complete the four-phase reversal. OPEC+ has signalled its intention to hold quotas steady throughout the remainder of 2026 in a move that Rystad Energy's Jorge Leon described as “the logical next step”, adding that “OPEC+ has little incentive to rush into further supply changes. Our base case is a fourth-quarter pause while the group prepares for the 2027 quota negotiations." The real issue OPEC+ faces is that its restored quotas exist, for the most part, solely on paper. With conflict-induced export disruptions affecting Gulf producers, Russia, and Kazakhstan, much of the additional supply approved by the alliance this year has yet to reach the market. Luckily for some, this gap has been eagerly filled by non-OPEC producers: The US, Brazil, Canada, Guyana, and Argentina are dominating global output growth, adding 1.4 million barrels per day in 2026 and a further 1 million barrels per day next year. This trajectory will surely create a structural supply overhang the moment Gulf flows begin normalising, regardless of what OPEC+ decides at its next meeting. The OPEC+ final quota increase is therefore best understood not as a supply surge but as the formal conclusion of a defensive policy adopted three years ago: The real supply story for the second half of 2026 will be written by geopolitical events, not quota announcements. What that means for prices over the medium term is a market that remains highly vulnerable to geopolitical headlines in the near term, but also one that faces genuine structural pressure to the downside once supply routes normalise and non-OPEC barrels also make their way to market. The combination of these factors makes the current level above USD 100 look considerably more fragile than the daily drama of pipeline outages and tanker attacks might suggest.