Global Diesel Shortfall Hits 1.5M Bpd as Refineries Run Full; US Export Ban May Backfire

From disruptions at the Strait of Hormuz and attacks on Russian refineries, to U.S. discussions on restricting diesel exports and India expanding its refining capacity, the global diesel market is experiencing a crisis driven by a confluence of supply chain disruptions, structural industry constraints, and geopolitical tensions.

What makes this crisis unique is that refinery margins are at historic highs, and operating plants are running at or near full capacity — yet diesel prices have surged past $200 per barrel, with crack spreads briefly reaching $100 per barrel. High prices have not rapidly generated new supply, but have instead begun to spill over into gasoline, jet fuel, petrochemical feedstocks, freight costs, and core inflation.

The market is not short of crude oil underground. It is short of middle distillates that can be refined into diesel and delivered to end users on time via available shipping routes.

1. The Shortage Is Not Crude Oil, but Deliverable Diesel

Diesel, jet fuel, and heating oil all come from the same molecular pool in refinery output. They are widely used in trucks, trains, ships, agricultural and construction machinery, generators, and residential heating. Compared to gasoline, diesel has higher energy density and is far more difficult to replace with electrification in the short term. As a result, its demand is tightly linked to industrial production, freight, and agricultural activity.

Industry estimates indicate that the global refining system normally processes approximately 85 million barrels per day (bpd) of crude oil. Currently, there is an operational shortfall of 4–5 million bpd, representing 5–6% of normal throughput. Roughly half of this gap is in the Middle East, due to disruptions at the Strait of Hormuz and damage to some refineries. The other half is in Russia, primarily linked to Ukrainian drone attacks on refineries.

Given that diesel accounts for about 40% of refinery output, the corresponding diesel supply gap is approximately 1.5 million bpd — and this must largely be filled by seaborne trade. The problem is that the global seaborne diesel market is only about 8 million bpd. A 1.5 million bpd shortfall means nearly 19% of seaborne diesel supply has been removed.

Other refineries still operating are already near full capacity. There is no readily available "spare capacity pool" that the market can quickly tap. Prices can reward existing capacity, but they cannot repair damaged units in weeks or reopen blocked shipping routes overnight. This explains why refining margins are at record highs while diesel supply remains tight.

The U.S. position as a key supplier amplifies this gap. According to Kpler data cited in a CITIC Futures report on September 24, U.S. diesel exports accounted for 26.7% of global diesel exports in August 2026. The same report showed that for the week ending September 18, U.S. diesel exports stood at approximately 1.331 million bpd. Another media report, using monthly data, indicated U.S. diesel exports of about 1.6 million bpd in August and roughly 1 million bpd in February.

While the statistical periods and denominators differ across sources, they all point to the same fact: the United States is a critical marginal supplier in the global diesel market. Any change in export policy is not merely a domestic issue.

2. $100/Barrel Crack Spread Shows Scarcity Premium Is in Refined Products

To understand the diesel market, one cannot look only at Brent crude oil prices. The crack spread — the difference between the price of refined products and crude oil — reflects the value added by processing a barrel of crude into diesel.

When the diesel market is weak, the crack spread is around $8–10 per barrel. Under normal supply-demand conditions, it is about $20. In a strong market, it ranges from $25–30. During the diesel crisis triggered by the Russia-Ukraine conflict in 2022, it briefly reached $60–70 per barrel.

Currently, with crude oil at approximately $100 per barrel and diesel nominal prices exceeding $200 per barrel, the crack spread is around $100 per barrel. This level indicates that the scarcity premium is concentrated in middle distillates, not evenly distributed across the entire crude oil value chain. End users are paying not only for crude oil costs but also for refinery processing capacity, inventory location, shipping schedules, and geopolitical risk.

Crack spreads for Singapore 10ppm diesel, ICE diesel, and U.S. Gulf Coast low-sulfur diesel have surged significantly in 2026, with multiple regions reaching $80–100 per barrel. While regional prices cannot be mechanically compared, the trend is clear: the tightness in refined products has surpassed what can be explained by crude oil price fluctuations alone.

(Global diesel crack spreads by region — Source: CITIC Futures)

High crack spreads should normally incentivize refineries to increase production. But diesel is not a commodity that can be produced on a separate production line. Its scarcity precisely exposes the structural constraints of the refining industry.

3. "Diesel Maximization" Cannot Create More Diesel

Refineries are designed based on crude oil type, unit configuration, and regional demand, determining their product yield from the outset. During operations, they can fine-tune the proportions of gasoline, diesel, jet fuel, and other fractions within a few percentage points — but it is extremely difficult to quickly convert a refinery primarily designed for gasoline or jet fuel into a pure diesel plant.

More importantly, current industry surveys show that operating refineries are already running at nearly 100% capacity. To significantly alter the product mix would require years of heavy capital investment in unit modifications — impossible in the short term.

As a result, refineries can only pursue "diesel maximization": squeezing more diesel out of a fixed total output by reducing gasoline, jet fuel, or light petrochemical naphtha. The CITIC Futures report noted that after diesel strengthened in September, U.S. refineries shifted to diesel maximization, causing gasoline supply to contract and gasoline crack spreads to also show unusual strength. As gasoline prices rose, pressure on aromatics costs and supply became apparent.

The report also assessed that refineries pushing to maximize refined product output would squeeze light petrochemical feedstock production, further suppressing supply of chemicals such as olefins. Similar transmission effects have been observed in the domestic Chinese market: high overseas diesel crack spreads and increased refined product exports prompted refineries to raise diesel yields, with more coking units switching production, thereby diverting asphalt supply.

This is a market dynamic where "products compete for feedstock." The stronger diesel becomes, the more refineries are willing to sacrifice other products to boost diesel yields. But as gasoline and petrochemical feedstocks decrease, prices for gasoline, aromatics, and olefins are pushed higher. Diesel's strength thus spreads through the refinery product structure to the entire energy-chemical chain.

4. U.S. Export Ban: A Short-Term Political Fix with Global Second-Order Shocks

Discussions about restricting U.S. diesel exports occur against a backdrop of high domestic diesel prices and rising cost pressures for agricultural states and truck drivers. For policymakers, restricting exports appears straightforward: keep more diesel in the U.S., lowering domestic spot and futures prices.

However, refinery structure and inventory constraints mean this policy is likely to first bring expectations of price declines, followed by reduced production and tighter refined product supply.

Gulf Coast refineries produce approximately 5.3 million bpd of distillate fuels, while total U.S. daily demand is about 3.6 million bpd. The surplus of roughly 1.7 million bpd must be exported. U.S. storage tanks and pipeline capacity cannot absorb this surplus for long. If diesel cannot be exported, inventories will rise rapidly, forcing refineries to reduce crude processing.

EIA data shows that for the week ending September 18, U.S. distillate inventories stood at approximately 107.4 million barrels, 12% below the five-year average. With autumn maintenance and harvest season demand both increasing, the inventory buffer is not ample.

CITIC Futures, citing EIA data, noted that U.S. refinery utilization fell from 96.8% the previous week to 94% for the week ending September 18, while net crude exports decreased by 369,000 bpd. After the utilization rate decline, U.S. gasoline and diesel inventories re-entered a drawdown phase. This indicates that the domestic U.S. balance is already tight. If export policy swings sharply, inventories and refinery runs will reflect the impact faster than export volumes alone.

S&P Global scenario estimates suggest that if exports were fully restricted, approximately 1.5 million bpd of diesel would be trapped in the U.S., potentially forcing refineries to cut crude processing by nearly 1.9 million bpd, with utilization rates falling to 80–82%.

This is not simply a matter of "keeping diesel in the U.S." — it means a decline in total refinery throughput. Since gasoline and jet fuel are co-products, domestic U.S. gasoline supply would also decrease. The result could be diesel becoming cheaper in the short term while gasoline becomes more expensive. This is the economic reason some U.S. energy officials and refining industry representatives oppose a full ban.

The policy discussion itself is already reshaping regional prices. U.S. diesel futures fell more than 7% at one point, while European diesel futures jumped. CITIC Futures also assessed that if the U.S. significantly reduces exports, domestic U.S. diesel inventories would build, but non-U.S. markets would face further tightening.

The U.S. does not need to formally sign an export ban to create external shocks. As long as the market believes exports may decline, shipping schedules, inventories, and forward contracts will be revalued preemptively.

The destinations of U.S. exports also illustrate the spillover risk. According to Kpler, the largest destination in 2025 was Mexico, receiving an average of about 220,000 bpd, or roughly 17% of U.S. diesel exports. Imports by Chile increased about 15%, while Brazil received about 103,000 bpd, more than double year-on-year. If the U.S. imposed a full embargo, estimates suggest global seaborne diesel supply could decrease by another 30%.

This is a scenario estimate, not a confirmed event, but it reveals the second-order effects of U.S. policy: by attempting to push domestic shortage pressure overseas, the U.S. may see inflation re-imported through higher prices, panic buying, and alternative shipping routes.

5. Diesel Is Entering U.S. Core Inflation — AI Makes This Shock Harder to "See Through"

Diesel prices are more likely than gasoline to become a macroeconomic problem because they are embedded in transportation and production, not just personal travel. Trucks, railways, ships, agricultural machinery, construction equipment, and backup generators all require diesel.

Some U.S. railroad companies have already indicated that high truck diesel costs are prompting a shift from road to rail transport. However, rail cannot replace all short-haul deliveries, farm operations, and construction site work.

High prices have not immediately triggered a full demand collapse. Historical experience shows that when diesel prices approach or exceed $200 per barrel, some customers delay purchases, reduce operations, or change transportation modes. Currently, some regions globally are showing signs of significant demand destruction, but others are supported by subsidies, inventory buffers, and diesel's short-term irreplaceability. In other words, demand is adjusting, but not fast enough to offset the supply gap.

Bloomberg data indicates that as of late September, the average U.S. diesel price had risen 83% year-to-date to $6.50 per gallon, while gasoline prices rose 59%. These figures are U.S. retail prices and cannot be directly compared with international diesel prices per barrel, but they demonstrate that the diesel shock has moved from refineries and traders to end users.

Torsten Slok, Chief Economist at Apollo Global, captured the macroeconomic difficulty of this crisis: diesel price increases first raise costs for freight, warehousing, construction, and agriculture, then lagging transmission to goods and services prices. This means diesel could enter core CPI components beyond just energy.

If the supply shock is temporary, the Federal Reserve can wait for it to fade. But if damaged refineries, blocked shipping routes, and export restrictions persist for months, the traditional approach of "looking through" energy shocks becomes challenging. Chicago Fed President Austan Goolsbee has also issued warnings about persistent supply shocks, indicating internal debate within the Fed on this issue.

The AI boom adds another layer of resilience to diesel demand. Slok estimates that AI-related activities currently contribute about one percentage point to U.S. GDP growth, roughly half of total growth. This estimate covers data center construction, energy demand, software spending, and wealth effects.

Data center construction relies heavily on diesel-powered equipment for site work, logistics, and backup generation. Therefore, the stronger AI capital expenditure becomes, the harder it is for diesel demand to decline rapidly. The more expensive diesel becomes, the higher the costs for data center construction and operation. This creates a feedback loop between the energy shock and the growth narrative: AI supports demand, diesel raises costs, and costs increase uncertainty for monetary policy and asset valuations.

6. Russia Retreats, India Advances: Global Diesel Pricing Power Is Being Redistributed

Supply disruptions are not only changing prices — they are also shifting who holds export capacity. After attacks on Russian refineries, Moscow restricted most overseas diesel sales. European refining capacity has contracted, and Middle Eastern exports face risks from the Strait of Hormuz. If the U.S. further restricts exports, traditional supply sources would shrink simultaneously.

India is filling part of the gap. Citing Kpler, media reports indicate that after Russian supply constraints, India has surpassed Russia this year to become the world's second-largest seaborne diesel supplier, accounting for about 10% of global shipments.

India's Petroleum Minister Hardeep Singh Puri has stated that India will not withdraw existing diesel export commitments, citing a five-year supply agreement between Indian Oil Corporation and Mauritius as an example of how long-term contracts and on-time delivery are themselves part of export capability.

India's advantage is not just current production but its expansion trajectory. India's refining capacity is approximately 267 million tonnes per year, with the market expecting it to approach 290 million tonnes within a year, targeting 320 million tonnes by 2030–2032. Investment talks between Saudi Aramco, Abu Dhabi National Oil Company (ADNOC), and Indian refiners also indicate that Middle Eastern capital is viewing India as a downstream hub for Asia, Europe, and Africa.

India is developing a supply chain model: "procure crude from restricted sources — refine domestically — sell refined products globally." On one hand, it takes advantage of discounted Russian crude; on the other, it leverages its own refining and port capacity to export diesel. If U.S. exports are constrained and European refineries continue to close, India's marginal pricing power will increase further.

But India is not an immediately available 1.5 million bpd replacement. New capacity requires crude oil, equipment, vessels, insurance, and stable settlement channels. If the U.S. imposes secondary sanctions, any disruption in shipping insurance or dollar settlement would mean capacity does not translate into deliverable supply.

Additionally, India's domestic fuel demand is still growing, and the government may prioritize the domestic market during periods of high prices. Whether India can become a "stable seller in turbulent times" ultimately depends on whether capacity, diplomacy, finance, and maritime logistics can all function simultaneously.

7. What the Market Should Watch Next Is Not a Single Oil Price Number

Based on the current situation, the future market can be broadly divided into four scenarios.

Scenario 1: Geopolitical Easing. The Strait of Hormuz reopens, damaged Russian refineries are repaired, the U.S. continues exporting, inventories rebuild, diesel crack spreads fall rapidly, and refinery margins and related asset valuations face compression.

Scenario 2: Limited Policy Intervention. The U.S. adopts voluntary export reductions, quotas, or phased measures. Domestic prices gain short-term psychological support, but non-U.S. markets maintain high premiums. Policy reversals amplify volatility.

Scenario 3: Full Export Ban Combined with Unresolved Middle East and Russian Supply. The global seaborne diesel gap widens. Gasoline, jet fuel, and petrochemicals come under simultaneous pressure. Prices eventually find equilibrium through demand destruction and economic slowdown.

Scenario 4: Gradual Capacity Expansion by India and Other Asian Refineries. Supply is redistributed in the medium term, regional price spreads narrow, but transportation and policy risks keep the volatility center higher than in the past.

For investors, the first clue is refinery margins — but not just nominal crack spreads. What truly matters is whether a company can secure crude oil, maintain high diesel yields, deliver products to high-price markets, and manage inventory amid export policy changes.

The second clue is logistics and trade. The value of shipping schedules, insurance, ports, and regional inventories rises during supply disruptions, but these links are also most vulnerable to sanctions and policy restrictions.

The third clue is downstream margins. Whether trucking, agriculture, construction, chemical, and asphalt companies can pass on costs will determine whether high diesel prices manifest as inflation or trigger demand collapse.

The fourth clue is monetary policy. If diesel costs persistently enter core goods and services, the pressure on interest rates and valuations may be broader than a simple energy stock rally.

At least five indicators are worth tracking going forward:

• Strait of Hormuz transit volumes and insurance premiums
• Recovery of damaged Russian refineries and export policy
• U.S. distillate inventories, refinery utilization rates, and diesel export volumes
• Actual delivery of Indian diesel exports and new refining capacity
• Whether diesel crack spreads decline due to supply recovery or because demand is crushed by high prices

The last distinction is especially critical: the former signals crisis relief; the latter may be a precursor to economic recession.

Conclusion

The essence of the global diesel crisis is a deliverable fuel shortage caused by the simultaneous tightening of capacity, shipping routes, product structure, and policy. Refineries running at full capacity do not mean the market is risk-free — on the contrary, any new disruption directly impacts end users.

A U.S. export ban can change inventory locations but cannot create diesel out of thin air. India's capacity expansion can reshape medium-term supply but cannot fill the gap overnight.

The true test of this crisis is not which country can temporarily suppress domestic prices, but whether the global energy system can restore stable production, transportation, and delivery of middle distillates. Until this chain is repaired, diesel will continue to send the same signal — through crack spreads to gasoline, chemicals, freight, inflation, and interest rate markets:

The world is not short of a barrel of crude oil. It is short of a barrel of diesel that can arrive on time.