Brent crude oil traded at $90.95 per barrel on July 26, up 23% month-on-month and 31% year-on-year, according to Trading Economics data. The rally reflects OPEC+'s continued production discipline, escalating Middle East geopolitical tensions, and strong global demand particularly for refined products. WTI crude has been trading in a $75-80/bbl range, maintaining the typical discount to Brent driven by export infrastructure constraints.
The refined product market is where the most extreme tightness is visible. RBOB gasoline futures on NYMEX traded at $3.42 per gallon on July 24, up 63% year-on-year. The gasoline market is being squeezed by low refinery runs globally, with maintenance outages and unplanned shutdowns combining with strong driving season demand. ULSD diesel is equally tight, supported by industrial demand, data center construction, and agricultural sector consumption during the northern hemisphere growing season.
OPEC+ production management remains the dominant factor in crude pricing. The alliance has maintained disciplined output cuts through 2025 and into 2026, with Saudi Arabia shouldering the largest share of voluntary reductions. The group's next ministerial meeting is expected to review the production strategy for Q4 2026 and 2027. Market expectations are for a gradual unwinding of cuts beginning in 2027, but the pace remains uncertain.
Middle East geopolitical tensions have added a material risk premium to all crude and product prices. Escalating conflict has raised concerns about Strait of Hormuz transit, through which approximately 20 million barrels per day of oil and petroleum products pass. While no direct disruption has occurred, the insurance and freight cost implications are already reflected in delivered crude prices to Asian and European refineries.
Henry Hub natural gas at $3.21/MMBtu reflects a market transitioning from the winter storage withdrawal season into summer injection season. US natural gas storage levels are near the five-year average, providing a comfortable buffer for summer cooling demand. However, LNG export demand, particularly from new liquefaction capacity coming online in 2026-2027, is providing a structural floor under gas prices.
European natural gas at TTF ($13.66/MMBtu) continues to trade at a significant premium to Henry Hub, reflecting the structural shift in European gas supply following the loss of Russian pipeline volumes. The premium incentivizes US LNG cargoes to flow to Europe, creating a direct linkage between Henry Hub and TTF prices. LNG Asia JKM prices are also elevated, creating competition for flexible LNG cargoes.
Other energy commodities are experiencing their own dynamics. Newcastle coal prices remain elevated as Asian demand for coal-fired power generation continues despite renewable energy growth. Methanol prices are supported by strong downstream demand from the chemicals sector and the emerging marine fuel market as IMO 2023 regulations continue to drive fuel switching. OPEC+ spare capacity estimates range from 4-6 million barrels per day, concentrated in Saudi Arabia and the UAE, providing a theoretical ceiling on price spikes but one that is increasingly questioned given years of underinvestment in new production capacity.
Energy procurement teams are facing the most challenging pricing environment since 2022. Brent at $91/bbl with 23% month-on-month appreciation signals a market where supply is struggling to keep pace with demand. For crude buyers, the key risk is further escalation in Middle East tensions that could threaten Strait of Hormuz transit. Hedging Q4 2026 and Q1 2027 crude requirements at current levels is expensive but prudent given the asymmetric risk profile. For refined product buyers, the situation is more acute. Gasoline at $3.42/gal with 63% year-on-year appreciation is consuming an increasing share of operational budgets. Buyers should secure term supply agreements with refineries to lock in margins and avoid spot market exposure during peak demand periods. ULSD/diesel buyers face similar dynamics. Natural gas buyers should use the Henry Hub-TTF arbitrage to their advantage: US buyers have the luxury of relatively cheap gas ($3.21/MMBtu) with limited export linkage risk, while European buyers should consider longer-term fixed-price LNG contracts to reduce exposure to TTF volatility. The broader lesson from the current market is that years of underinvestment in upstream production capacity have created a system with limited spare capacity. This means any demand shock or supply disruption produces outsized price moves. Procurement strategies should prioritize supply security over marginal cost optimization.