Global Diesel Crisis: Refineries at Full Capacity Still Fall 1.5M Bpd Short; US Export Ban Could Backfire

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

What makes this crisis unique: refinery margins are at historic highs, operating plants are running at or near full capacity, yet diesel prices have been pushed above $200 per barrel, with crack spreads briefly reaching $100 per barrel. High prices have not rapidly generated new supply; instead, they are beginning to transmit to 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 via available shipping routes on time.

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

Diesel, jet fuel, and heating oil belong to the same molecular pool produced by refineries. They are widely used in trucks, trains, ships, agriculture, construction machinery, generators, and residential heating. Compared to gasoline, diesel has higher energy density and is more difficult to replace through short-term electrification, making its demand tightly linked to industrial production, freight, and agricultural activity.

Industry experts estimate 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 Strait of Hormuz disruptions and damage to some refineries; the other half is in Russia, primarily related to Ukrainian drone attacks on refineries.

Given that diesel accounts for approximately 40% of refinery output, the corresponding diesel supply gap is about 1.5 million bpd, which must largely be filled by seaborne markets. The problem: the global seaborne diesel market is approximately 8 million bpd. A 1.5 million bpd gap equates to nearly 19% of seaborne diesel supply being withdrawn.

Other operating refineries 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 within weeks or immediately reopen blocked shipping routes. This explains why refining margins are at record highs while diesel supply remains tight.

The U.S. supply position amplifies this gap. CITIC Futures' September 24 Energy & Chemical Strategy Daily Report, citing Kpler data, noted that 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 were approximately 1.331 million bpd. Another media report, using a monthly basis, stated that U.S. diesel exports were about 1.6 million bpd in August and about 1.0 million bpd in February.

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

2. A $100/Barrel Crack Spread Indicates Scarcity Premium Is on the Product Side

To analyze the diesel market, one must look beyond Brent crude oil prices and examine crack spreads. The crack spread is the difference between the price of refined products and crude oil, reflecting the value added by processing a barrel of crude into diesel.

• When the diesel market is weak, crack spreads are approximately $8–10/barrel.
• Under normal supply-demand conditions, they are around $20/barrel.
• In a strong market, they range from $25–30/barrel.
• During the 2022 diesel crisis triggered by the Russia-Ukraine conflict, they briefly reached $60–70/barrel.

Currently, crude oil is around $100/barrel, while diesel's nominal price has exceeded $200/barrel, corresponding to a crack spread of approximately $100/barrel. This level indicates that the scarcity premium is concentrated in middle distillates, not evenly distributed across the 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 approaching $80–100/barrel. While regional prices cannot be mechanically compared, the trend is clear: product tightness has exceeded what simple crude oil price fluctuations would suggest.

(Chart: Diesel crack spreads across major global regions. Source: CITIC Futures)

High crack spreads should normally incentivize increased refinery production, but diesel is not a commodity that can be produced on a dedicated 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 type, unit configuration, and regional demand, determining product yields at the construction stage. During operations, they can adjust the proportions of gasoline, diesel, jet fuel, and other fractions within a few percentage points, but it is extremely difficult to rapidly convert a refinery primarily designed for gasoline or jet fuel into a pure diesel plant.

More critically, industry surveys indicate that currently operable refineries are already running at nearly 100% capacity. To significantly alter product slates would require years of heavy capital investment in unit modifications—impossible in the short term.

Consequently, refineries can often only pursue "diesel maximization": within a fixed total output, they produce more diesel and less gasoline, jet fuel, or petrochemical naphtha. CITIC Futures' daily 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全力 boosting distillate output would squeeze petrochemical naphtha production, further suppressing supply of chemicals such as olefins. Similar transmission effects are visible in the domestic Chinese market: high overseas diesel crack spreads and increased product exports drive refineries to raise diesel yields, with more coking units switching production, thereby diverting asphalt supply.

This is a market where "products compete for feedstock." The stronger diesel becomes, the more refineries are willing to sacrifice other products to increase 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 slate to the entire energy-chemical chain.

4. U.S. Export Ban: A Political Short-Term Fix, a Secondary Shock to Global Markets

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

However, refining structure and inventory constraints determine that this policy is likely to first bring expectations of price declines, followed by reduced production and product supply contraction.

Gulf Coast refineries produce approximately 5.3 million bpd of distillate, while total U.S. 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 were approximately 107.4 million barrels, 12% below the five-year average. Fall maintenance and harvest season demand will increase simultaneously, leaving little inventory buffer.

CITIC Futures, citing EIA data, noted that U.S. refinery utilization for the week ending September 18 fell seasonally to 94% from 96.8% the prior week, while net crude exports decreased by 369,000 bpd. After utilization declined, U.S. gasoline and diesel inventories re-entered a drawdown state. This indicates that the U.S. domestic 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 United States, refineries might cut nearly 1.9 million bpd of crude processing, and utilization could fall to 80–82%.

This is not simply "keeping diesel in the U.S."—it means a decline in total refinery throughput. Since gasoline and jet fuel are co-products, domestic gasoline supply would also decrease, potentially leading to a situation where diesel becomes 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 altering inter-regional prices. U.S. diesel futures briefly fell over 7%, while European diesel futures jumped. CITIC Futures also assessed that if the U.S. significantly reduces exports, domestic diesel inventories would build, but non-U.S. market tightness would intensify further.

The United States does not need to formally enact a ban to create external shocks. As long as the market believes exports may decline, shipping schedules, inventories, and forward contracts will be revalued first.

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

This is a scenario estimate, not a confirmed fact, but it reveals the second-order effects of U.S. policy: the U.S. attempts to push domestic shortage pressure overseas, while overseas markets will re-import inflation back to the U.S. through higher prices, panic buying, and alternative transportation.

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 mobility. Trucks, railways, ships, agricultural machinery, construction equipment, and backup generators all require diesel.

Some U.S. railroads have indicated that high truck diesel costs are prompting increased rail transport to replace road freight. However, rail substitution cannot cover all short-haul delivery, agricultural operations, and construction scenarios.

High prices have not immediately triggered comprehensive demand destruction. Historical experience shows that when diesel prices approach or exceed $200/barrel, some customers delay purchases, reduce operations, or change transportation modes. Currently, some global regions show clear signs of demand destruction, while others are supported by subsidies, inventory buffers, and diesel's short-term irreplaceability. In other words, demand is indeed 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 transmitted from refineries and traders to end users.

A warning from Torsten Slok, Chief Economist at Apollo Global Management, captures the macroeconomic difficulty of this crisis: diesel price increases first raise costs for freight, warehousing, construction, and agriculture, then lagged transmission to goods and services prices means they may enter core CPI components beyond the energy sub-index.

If the supply shock is temporary, the Federal Reserve can wait for it to subside. But if refinery damage, shipping route disruptions, and export restrictions persist for months, the traditional approach of "looking through" energy shocks will be challenged. Austan Goolsbee, President of the Chicago Fed, has also issued reminders about persistent supply shocks, indicating internal Fed disagreement 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 current growth. This estimate covers data center construction, energy demand, software spending, and wealth effects.

Data center construction machinery, logistics, and backup power generation rely heavily on diesel equipment. Therefore, the stronger AI capital expenditure becomes, the less likely diesel demand is to decline rapidly; the more expensive diesel becomes, the higher data center construction and operating costs rise. The energy shock thus forms a feedback loop with the growth theme: AI supports demand, diesel pushes up costs, and costs increase uncertainty for monetary policy and valuations.

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

Supply disruptions are not only changing prices but also reshaping who holds export capacity. After attacks on Russian refineries, Moscow restricted most overseas diesel sales. European refining capacity is shrinking, and Middle East exports are affected by Strait of Hormuz risks. If the U.S. further restricts exports, traditional supply sources will contract 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 approximately 10% of global shipments.

India's Petroleum Minister Puri 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, emphasizing that long-term contracts and on-time delivery are themselves part of export capability.

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

India is developing a supply chain route: "procure crude from restricted sources—refine domestically—sell products globally." On one hand, it captures discounted Russian crude; on the other, it leverages its own refining and port capacity to export diesel. If U.S. exports are restricted and Europe continues to shut refineries, India's marginal pricing power will increase further.

However, India is not an immediately available 1.5 million bpd substitute. New capacity requires crude oil, equipment, vessels, insurance, and stable settlement channels. If the U.S. imposes secondary sanctions, any disruption to shipping insurance or dollar settlement means capacity does not equal deliverable supply.

Additionally, India's domestic fuel demand is still growing, and the government may prioritize the domestic market when prices are high. Whether India can become a "stable seller in turbulent times" ultimately depends on whether capacity, diplomacy, finance, and maritime logistics can operate 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. Strait of Hormuz traffic resumes, 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, providing short-term psychological support for domestic prices, but non-U.S. markets maintain high premiums, and policy reversals amplify volatility.

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

Scenario 4: Gradual Realization of Indian and Other Asian Refinery Expansions. Supply is redistributed in the medium term, regional price spreads narrow, but transportation and policy risks keep the volatility baseline above historical levels.

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

The second clue is logistics and trading. Shipping schedules, insurance, ports, and regional inventory values rise 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 ultimately manifest as inflation or transform into demand collapse.

The fourth clue is monetary policy. If diesel costs persistently enter core goods and services, 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 premium rates
• Recovery of damaged Russian refineries and export policy
• U.S. distillate inventories, refinery utilization, and diesel export volumes
• Actual realization 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 particularly critical: the former signals crisis relief; the latter may be a precursor to economic recession.

Conclusion

The essence of the global diesel predicament is a deliverable fuel crisis caused by simultaneous tightening of capacity, shipping routes, product structure, and policy. Refineries running at full capacity does not mean the market is risk-free; on the contrary, it means any new disruption will directly impact end users.

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

This crisis truly tests 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.