Crude oil markets have rallied sharply through July 2026, with WTI trading at $89.08/bbl and Brent at $97.24/bbl on July 24. The rally has been driven by a potent combination of geopolitical risk, OPEC+ supply discipline, and demand that has proven more resilient than most forecasts anticipated at the start of the year.
The geopolitical catalyst is the escalation of US-Iran tensions in the Middle East. Military engagements in the Persian Gulf region have raised the specter of disruptions to oil transit through the Strait of Hormuz, through which approximately 20 million barrels per day of crude and petroleum products pass. While no major supply disruption has occurred, the risk premium has added $8-12/bbl to crude prices, by most market estimates.
OPEC+ has maintained its production discipline through 2026 despite repeated calls from importing nations to increase output. The alliance's cumulative production cuts of approximately 5.86 million barrels per day remain largely in place. Saudi Arabia has signaled that it will not pre-emptively increase supply to offset potential disruptions, insisting that market stability requires predictable policy. This has effectively placed a floor under prices.
Global oil demand has surprised to the upside. The International Energy Agency's latest monthly report estimates global oil demand at 104.2 million bpd in 2026, up 1.3 million bpd from 2025. Non-OECD demand growth, particularly from China and India, has more than offset flat-to-declining OECD consumption. The aviation sector has been a key driver, with global jet fuel demand finally exceeding pre-COVID levels.
Natural gas markets are defined by extreme regional divergence. US Henry Hub prices at $2.80/MMBtu reflect ample domestic production, robust storage levels at 3.1 Tcf (above the five-year average), and limited LNG export capacity relative to the resource base. The US remains the world's largest gas producer, with output running at approximately 104 Bcf/d.
European TTF gas at $13.66/MMBtu reflects a structurally different reality. Europe's loss of Russian pipeline gas since 2022 has been partially replaced by LNG imports, but at a significant cost premium. Storage levels entering the 2026-27 injection season are healthy at approximately 75% of capacity, but the margin for error is thin. Any disruption to LNG supply -- whether from Australian strikes, US Freeport-type outages, or Asian demand competition -- would send TTF sharply higher.
Asian LNG prices are the highest in the global gas complex. The Japan-Korea Marker (JKM) at $21.03/MMBtu reflects intense competition for spot LNG cargoes between price-sensitive Asian buyers and European buyers who need to refill storage. This competition is structural: both basins are competing for the same flexible LNG supply, primarily from the US and Qatar.
Refined products markets are also under pressure. NY Harbor ULSD diesel at $4.118/gallon reflects tight global diesel supplies, driven by low refinery runs in Europe and strong demand from trucking, agriculture, and industrial users. RBOB gasoline at $3.133/gallon is elevated heading into the summer driving season. Both are adding to inflationary pressure in the broader economy.
Coal markets remain elevated despite the energy transition narrative. Newcastle thermal coal at $130.60/t reflects continued demand from Asian power generators, particularly in China and India, where coal-fired generation continues to grow in absolute terms even as renewable capacity expands. Coking coal, used in steelmaking, has also found support from robust steel production in Asia.
The crude oil market is pricing in a geopolitical risk premium that could widen or collapse depending on Middle East developments. Military engagements in the Persian Gulf have raised the specter of Strait of Hormuz disruptions, through which approximately 20 million barrels per day of crude and petroleum products pass. While no major disruption has occurred, the risk premium is estimated at $8-12/bbl.
OPEC+ supply discipline has been a critical price support. The alliance's cumulative production cuts of approximately 5.86 million barrels per day remain largely in place despite repeated calls from importing nations for increased output. Saudi Arabia has signaled it will not pre-emptively increase supply to offset potential disruptions, effectively placing a floor under prices.
Global oil demand has proven more resilient than expected. The IEA estimates 2026 global oil demand at 104.2 million bpd, up 1.3 million bpd from 2025. Non-OECD demand growth, particularly from China and India, has more than offset flat OECD consumption. Aviation has been a key driver, with global jet fuel demand finally exceeding pre-COVID levels for the first time.
Natural gas markets show extreme regional divergence that reflects fundamentally different supply-demand structures. US Henry Hub at $2.80/MMBtu benefits from abundant domestic production at approximately 104 Bcf/d and robust storage at 3.1 Tcf (above the five-year average). The US remains the world's largest gas producer with the lowest costs.
European TTF at $13.66/MMBtu reflects the structural loss of Russian pipeline gas since 2022. Europe has partially compensated with LNG imports, but at a significant cost premium. Storage at 75% capacity entering the 2026-27 injection season is healthy, but the margin for error is thin. Any LNG supply disruption would send TTF sharply higher.
Asian LNG at $21.03/MMBtu is the highest in the global gas complex, reflecting intense competition for spot LNG cargoes between Asian and European buyers. This competition is structural: both basins compete for the same flexible supply, primarily from the US and Qatar. The JKM premium over TTF reflects Asia's willingness to pay more for energy security.
Refined products markets remain under structural pressure. NY Harbor ULSD diesel at $4.118/gallon reflects tight global diesel supplies driven by low European refinery runs. RBOB gasoline at $3.133/gallon is elevated heading into the summer driving season. Both add inflationary pressure to the broader economy and create cost headwinds for logistics and transportation procurement.
Newcastle thermal coal at $130.60/t reflects continued demand from Asian power generators. Despite the energy transition narrative, China and India continue to increase coal-fired generation in absolute terms as renewable capacity expands. Coking coal has found support from robust Asian steel production. Coal remains structurally supported by Asian demand growth.
Energy procurement teams face a genuinely complex market in July 2026. The crude complex is pricing in a geopolitical risk premium that could either evaporate or explode depending on events in the Middle East. For diesel and gasoline buyers, the refined product tightness is structural and not easily resolved -- European refinery closures have permanently reduced capacity. For natural gas buyers, the key decision is whether to buy protection against a TTF/JKM spike this winter. The regional divergence means hedging strategies must be location-specific. A US manufacturer with Henry Hub exposure should be flat to short on hedges; a European buyer should be locking in winter TTF prices at current levels, which are well below the $30+/MMBtu crisis levels of 2022 but still elevated historically. For crude buyers, the floor is solid at $80/bbl WTI due to OPEC+ discipline, but the ceiling is an open question. Consider collar strategies: buy puts at $80 and sell calls at $105-110 to fund the downside protection.