The Price of Hormuz

Oil companies in our Global Ranking Model: market, price scenarios and who wins

The disruption around the Strait of Hormuz has produced one of the largest oil-market shocks on record.

But the most important question is no longer simply how much production has been lost.

It is how the market absorbed that loss, how much spare buffer remains, what oil price is already embedded in company estimates — and which producers would actually retain the benefits of higher prices once taxes, royalties and hedging are taken into account.

In The Price of Hormuz, LFG+ZEST examines the oil market from both a macro and company-level perspective, mapping four Brent scenarios onto 25 oil-weighted companies in our Global Ranking Model.

Our base case places Brent between $85 and $95 per barrel over the next twelve months, with a negotiated reopening of Hormuz representing the principal downside scenario.

The initial supply shock has already been extraordinary.

Global oil supply is estimated to be down approximately 5.7 million barrels per day in 2026. The market balanced that loss through two mechanisms: a major drawdown in inventories and a substantial decline in demand.

Between February and August, observed stocks fell by approximately 507 million barrels, while global demand is estimated to be down around 2.5 million barrels per day for the year. Those adjustments prevented a much larger price spike. But they also consumed the market's safety margin.

The remaining pressure is particularly visible in refined products.

US strategic petroleum reserves remain materially below pre-war levels, distillate inventories are below their five-year average, and Gulf diesel exports continue to lag the recovery in crude exports.

The result is a market where diesel has become the principal pinch point.

A new disruption would therefore be absorbed less through inventories and more directly through prices. The analysis considers four possible twelve-month outcomes. A negotiated deal that restores Hormuz flows could move Brent toward $65–75. Our base case of partial normalization and intermittent disruption produces $85–95.

A prolonged conflict supports $100–120, while a further escalation affecting processing infrastructure or alternative export routes could push prices above $130.

Importantly, the downside and upside are not symmetrical. Even after a deal, inventories would need to be rebuilt.

Depending on the scale and speed of restocking, this additional demand could add several dollars per barrel to equilibrium prices, preventing Brent from simply returning to pre-war levels. Oil also feeds back into monetary policy.

The report maps each price scenario into inflation and central-bank responses, highlighting how sustained oil prices above the base case could force the Federal Reserve and the ECB to tighten further even as economic growth weakens. This is particularly important because refined-product prices transmit differently across regions, with the US consumer relatively more exposed to refining margins through gasoline. At the company level, the first question is what oil price consensus is already assuming. Using current revenue forecasts and each producer's historical sensitivity to Brent, the analysis estimates that 2027 consensus revenues imply an oil price of approximately $84 per barrel across the group.

This places consensus slightly below our base case.

If Brent remains between $85 and $95, estimates therefore retain some upside. A negotiated deal, however, could imply approximately 10–20% downside to revenues for more oil-sensitive producers.

But gross exposure to the oil price is only the first step.

A company may appear highly sensitive to Brent while retaining far less of the incremental revenue because of government taxation, production-sharing arrangements or hedging programmes. Once these effects are included, the ranking changes materially. Ovintiv, APA, Permian Resources, Occidental and EOG retain some of the strongest after-tax exposure to an additional $10 per barrel.

Norwegian producers move in the opposite direction: high marginal government take means that much less of the incremental oil price ultimately reaches shareholders. The analysis therefore produces different beneficiaries under different scenarios. A lower-price outcome rewards hedged producers and stronger balance sheets. The base case favours relatively unhedged, low-cost North American producers.

More extreme upside increasingly benefits US and Canadian production outside the conflict zone, while refiners, integrated companies and highly taxed producers face more complicated outcomes. Rather than selecting a single directional bet on crude, the analysis closes with a diversified first-pass shortlist: EOG, Suncor, Ovintiv, Cenovus and Whitecap. The five names represent different combinations of oil-price sensitivity, reserves, balance-sheet strength and hedging. Tenaris and GTT provide additional read-across exposure to higher producer spending and LNG investment without depending directly on the spot oil price.

The central conclusion is straightforward.

The oil market has already spent much of the buffer that absorbed the first Hormuz shock. Consensus still embeds an oil price slightly below our base case. But the most important company-level distinction is not simply who produces the most oil. It is who actually retains the incremental price after taxes, royalties, hedges and balance-sheet constraints. The full video presents the principal findings of the analysis.

For readers interested in the underlying scenarios, company-level comparisons and supporting data, the complete analysis is available on request.

This material is provided for informational and research purposes only and does not constitute investment advice, a recommendation, an offer or a solicitation.