The energy complex is experiencing a rare collision of forces: severe supply disruption from the Strait of Hormuz closure and simultaneous demand destruction as high prices crush consumption. WTI bounced 5.1% on July 8 to $74/bbl after President Trump declared the Iran ceasefire over and warned of additional strikes and a blockade. Brent surged 5% to $78. But both benchmarks remain dramatically below their April 2026 peaks above $110, reflecting the market's recognition that demand is cracking under the weight of $100+ oil.
The EIA's July Short-Term Energy Outlook is blunt: global oil consumption is forecast to decrease by 1.2 million barrels per day in 2026, with 0.8 mb/d of that coming from non-OECD countries. Non-OPEC supply continues to grow, and the EIA assumes the Strait of Hormuz will incrementally reopen, bringing Brent back toward $79/bbl by 2027. The demand destruction is not a forecast - it is already happening. US gasoline retail peaked above $4.20/gal in Q2 and has fallen to around $3.80 as consumers adjust driving behavior.
Natural gas markets are telling a different story. US Henry Hub at $3.22/MMBtu reflects comfortable storage - inventories were 6% above the five-year average at end of June. EIA forecasts Henry Hub averaging $3.60/MMBtu through 2026-2027, supported by rising LNG exports and data center power demand but capped by record Permian-associated gas production. European TTF remains elevated relative to US gas, with 2026 futures averaging around $12.4/MMBtu on lower storage levels (49% vs 60% a year earlier) and lingering supply concerns despite a growing LNG surplus globally.
The LNG market is undergoing a historic supply expansion. 2026 marks the start of the largest LNG supply wave in history, with more than 90 billion cubic meters per year of new liquefaction capacity coming online, mostly from North America. This has shifted the global gas market decisively toward a buyer's market. Asia spot LNG (JKM) averages are forecast around $9.5-10/MMBtu, down sharply from crisis levels. European LNG demand stabilizes around 145 Mt in 2026 as Russian pipeline gas is fully phased out, but supply is growing faster than demand can absorb.
Refined products are where the real action is. Diesel crack spreads have surged to 70-75% of crude value, up from just 27% at the start of 2026. This is the market's way of saying that while crude is abundant, refining capacity to turn it into diesel is not. The Strait of Hormuz closure hit diesel and jet fuel supplies hardest, as Middle East refineries are major suppliers of middle distillates to Europe and Asia. US Gulf Coast refiners are running at 93-95% utilization to fill the gap, but any hurricane disruption would have outsized impact on diesel prices.
Coal markets remain elevated despite the energy transition. Newcastle thermal coal at $128/t is down 15% month-over-month but still up 16.8% year-over-year. Japan and South Korea increased coal consumption during the Hormuz crisis to replace disrupted gas supplies, creating a temporary demand spike. Coking coal at $234/t is being driven by Indian steel demand growth and constrained new mine investment. Methanol at 2,368 CNY/t in China has fallen 24% over the past month on weak downstream demand and ample supply.
The Strait of Hormuz disruption is the dominant short-term price driver but the medium-term story is about demand destruction. EIA data shows that global oil demand in April-June 2026 was approximately 2-3 mb/d below pre-conflict expectations, as $100+ Brent crushed consumption in price-sensitive emerging markets. India, the world's third-largest oil consumer, saw gasoline and diesel demand fall 8-10% year-on-year in Q2 as retail fuel prices hit record highs. The EIA now forecasts global oil demand will decrease by 1.2 mb/d in full-year 2026 - a dramatic revision from the pre-conflict projection of 0.5-1.0 mb/d growth.
The non-OPEC supply response is accelerating. US crude production has held above 13.2 mb/d despite initial concerns about the Iran conflict disrupting Gulf of Mexico operations. Brazilian production is ramping with new FPSOs in the Santos Basin pre-salt fields. Guyana's production has exceeded 1 mb/d. The EIA projects non-OPEC supply growth of 1.5-2.0 mb/d in 2026, more than offsetting demand growth even in a recovery scenario. The underlying structural imbalance that existed before the Iran war - the OPEC+ surplus production capacity - has not gone away and will reassert itself as the Hormuz situation resolves.
The refining and product market dislocation is the most consequential secondary effect. Diesel and jet fuel cracks have surged because the Strait of Hormuz closure disproportionately affects middle distillate supply. Middle East refineries, particularly in Saudi Arabia, the UAE, and Kuwait, are major suppliers of diesel to Europe and Asia. The loss of these volumes, combined with already-tight global diesel capacity (after several years of underinvestment in hydrocracking capacity), has pushed diesel crack spreads to 70-75% of crude value. For comparison, the five-year average is roughly 25-30%. This means that while crude has fallen from $110 to $78, diesel prices have not fallen proportionally.
The natural gas market is undergoing a structural transformation. The 2026 LNG supply wave - more than 90 bcm/yr of new capacity, mostly from US LNG export projects including Plaquemines, Corpus Christi Stage 3, and Golden Pass - is shifting global gas markets from a seller's market to a buyer's market. Asian spot LNG (JKM) at $9.5-10/MMBtu is roughly half the crisis level of 2022. European TTF at $12.4/MMBtu is higher than Asian spot due to the loss of Russian pipeline gas, but the growing LNG surplus is gradually closing the spread. The IEA expects global LNG supply to exceed demand by 15-30 bcm in 2026, creating downward pressure on prices across all regional markets.
The demand-side adjustment to high energy prices is accelerating faster than many analysts anticipated. US gasoline demand in June 2026 was approximately 4% below the same period in 2025, despite the summer driving season. European diesel demand has contracted by 6-8% as industrial activity slows under the combined weight of high energy costs and weak export demand. The IEA estimates that global oil demand elasticity has increased since the pandemic, meaning consumers and businesses respond more quickly to price signals than in previous cycles. This increased elasticity is a structural change: working-from-home patterns, more fuel-efficient vehicle fleets, and improved energy efficiency mean that each successive oil price spike destroys demand faster than the last one.
The energy complex in July 2026 demands a region-specific, product-specific procurement strategy. For crude oil buyers: the forward curve is in contango, suggesting lower prices ahead as demand destruction and non-OPEC supply growth outweigh Hormuz disruption. Do not fix long-term volumes at current prices. For natural gas buyers in North America: Henry Hub at $3.22 with 6% storage surplus is comfortable. Lock winter strip at $3.50-3.60 if available - data center demand is a slow-burn structural support. European gas buyers face the opposite problem: TTF at $12.40 is elevated but likely to ease as the LNG supply wave builds. Use Q1 2027 TTF futures to fix a ceiling if you have winter exposure. The diesel situation is critical: crack spreads at 70-75% of crude value are unsustainable, but there is no immediate relief in sight. Secure diesel volumes for Q3-Q4 2026 now via term contracts with refineries. Any hurricane in the US Gulf Coast will spike diesel prices another 15-20%. For coal buyers: thermal coal at $128 is above equilibrium; the gas-to-coal switching that supported prices will reverse as LNG supplies come online. Do not over-contract beyond immediate needs.