Financial news outlets love a simple war story. When conflict flares in the Middle East or Eastern Europe and pump prices tick upward, mainstream commentators breathlessly report that American refiners are pushing facilities to the limit to save the global market from disaster. They point to refinery utilization figures hovering around 95% and call it an unprecedented operational triumph driven by global fuel supply deficits.
They are completely misdiagnosing the situation.
Running a complex oil refinery above 93% capacity for sustained periods is not a victory lap. It is a desperate, short-sighted gamble. I have spent decades analyzing energy infrastructure, watching executive suites burn through mechanical integrity just to capture transient crack spreads. The narrative that high run-rates are an elastic, heroic response to geopolitical turmoil hides a dark industry reality: the United States refining footprint has shrunk so severely that plants must run red-hot just to prevent localized supply collapses.
The industry is not flexing its muscle. It is running on a treadmill that keeps getting turned up, waiting for the first major piece of steel to fail.
The Shrinking Capital Base Illusion
Commentators looking at percentage utilization rates miss basic arithmetic. A high percentage of a shrinking number is not growth; it is structural decay.
Over the past six years, the US lost over one million barrels per day of operable refining capacity. Facilities like Philadelphia Energy Solutions in Pennsylvania, Shell’s Convent refinery in Louisiana, and Marathon’s plant in Gallup, New Mexico, were permanently retired, converted to renewable diesel facilities, or destroyed by industrial accidents.
When media outlets report that US refineries are operating at 95% capacity today, they are measuring against an aggregate capacity baseline that is significantly smaller than it was in 2019.
Year US Operable Refining Capacity Average Utilization Rate Total Daily Crude Input
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2019 ~19.0 Million Barrels/Day 89.5% ~17.0 Million Barrels/Day
2024 ~18.1 Million Barrels/Day 93.5% ~16.9 Million Barrels/Day
The absolute volume of refined petroleum products hitting the market has barely moved, even as headline utilization rates soared. Wall Street misinterprets this metric as operational strength. In reality, the margin of safety in the system has vanished.
When total capacity contracts, any minor disruption—a Gulf Coast hurricane, an electrical trip on a fluid catalytic cracker, or an unseasonable freeze in Texas—causes an outsized price spike. Refiners run at breakneck speed not because foreign wars squeezed supplies, but because domestic capacity is so tight that missing an operational beat triggers localized stockouts.
Geopolitics Is a Scapegoat for Mechanical Debt
The foreign conflict argument is a convenient narrative mask. Financial pundits claim that drone strikes and maritime blockades in the Red Sea created an absolute shortage of middle distillates like diesel and jet fuel. They argue that American plants are stepping in to fill a geopolitical vacuum.
That claim ignores how physical oil trading actually works.
Crude oil and refined products are fungible commodities that follow price differentials, not geopolitical outrage. When Western sanctions restricted direct shipments of Russian crude to Western Europe, global trade flows did not evaporate—they re-routed. Russian barrels moved to India and China, where high-complexity refiners processed them into diesel and gasoil, which were then legally exported to European markets.
The physical volume of global refined output did not drop off a cliff; the transit routes simply lengthened, raising freight tariffs and widening localized arbitrage spreads.
The domestic refining constraint is not caused by foreign artillery. It is caused by domestic maintenance debt.
Refining Profitability Trap:
High Crack Spreads -> Defer Planned Maintenance -> Run Units Above Nameplate Capacity
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| v
Unplanned Outage / Industrial Accident <------------------- Equipment Degradation
During periods of high refining margins—the difference between the price of crude oil and the market value of the refined products extracted from it—refinery managers face immense pressure to print cash. Every day a 200,000-barrel-per-day refinery sits offline for scheduled maintenance costs millions in lost margin opportunity.
Managers respond by pushing back turnaround schedules. They delay vessel inspections, stretch heat exchanger cleaning cycles, and operate hydrocrackers far above design specifications.
You cannot cheat metallurgy. Running heavy crude through desulfurization units at maximum heat and pressure accelerates high-temperature hydrogen attack and naphthenic acid corrosion. Pushing throughput yields short-term earnings beats at the cost of long-term asset integrity.
When an unmaintained hydrocracker trips unexpectedly six months later, forcing an emergency shutdown during peak summer driving season, executives point at foreign wars or ocean shipping delays to explain the resulting gas price surge. The media repeats the narrative without checking the maintenance logs.
The Jones Act Friction Nobody Wants to Discuss
If war were the primary driver of domestic fuel tightness, refiners on the US Gulf Coast would easily ship excess production to supply-deprived consumers in the US Northeast. The Gulf Coast represents roughly half of all US refining capacity and routinely produces more fuel than the regional market can absorb.
Yet, New England and the Mid-Atlantic frequently face severe fuel price spikes and low inventories, forcing those states to import diesel and gasoline from Europe or Africa at elevated freight rates.
Why can't Texas diesel flow freely to New York?
The answer is a century-old protectionist law: the Merchant Marine Act of 1920, commonly known as the Jones Act.
The Jones Act mandates that any goods shipped between US ports must be transported on vessels that are built in the United States, owned by US citizens, and crewed by US mariners. The foreign-flagged tanker fleet operating globally is vast, efficient, and cheap. The domestic Jones Act-compliant tanker fleet is minuscule, aged, and insanely expensive.
Cost Factor Jones Act Tanker (Domestic) Foreign-Flagged Tanker (International)
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Daily Charter Rate $60,000 - $90,000 $25,000 - $40,000
Crew Operating Costs High (US Maritime Labor) Competitive Global Rates
Fleet Availability Extremely Limited Abundant
Moving a barrel of diesel from Houston to Rotterdam on a foreign-flagged vessel is often cheaper than moving that same barrel from Houston to Boston on an American-flagged vessel.
Because domestic shipping is economically paralyzed by policy, US refiners cannot easily smooth out regional imbalances. When an East Coast supply crisis emerges, Gulf Coast refiners cannot simply send a fleet of coastal tankers north. Instead, they must run their plants even harder to supply international buyers while East Coast markets bid up foreign cargoes.
Blaming foreign wars for domestic fuel market fragility while ignoring federal shipping laws that isolate internal markets is either profound ignorance or deliberate misdirection.
The Crude Slate Mismatch
The final flaw in the "breakneck speed" narrative is the fundamental structural mismatch between what US shale fields produce and what US refineries were designed to consume.
Over the past decade, the American shale revolution turned the country into the world's largest crude oil producer. However, shale oil is predominantly light, sweet crude—low in density and low in sulfur.
The multi-billion-dollar refining complexes along the Texas and Louisiana coasts were engineered decades ago to process heavy, sour crude from places like Venezuela, Mexico, Canada, and the Middle East. These heavy crude units feature massive coking units and hydrocrackers designed to strip sulfur and break down thick, tar-like molecules into high-value diesel and gasoline.
Crude Type Density (API) Sulfur Content US Refining Infrastructure Fit
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Light Sweet Shale High (>35°) Low (<0.5%) Sub-optimal (Overwhelms light-ends)
Heavy Sour Low (<25°) High (>1.5%) Ideal (Maximizes complex conversion)
Feeding pure light shale oil into a complex refinery designed for heavy crude is like running high-octane racing fuel through a diesel engine. It chokes the light-ends processing units while leaving expensive heavy-bottom processing units underutilized.
To run at high throughput rates, US refiners must execute complex blending strategies:
- Import heavy crude from Canada or Latin America at a premium to balance the processing slate.
- Export light domestic shale crude to foreign refiners in Asia or Europe who have excess light-ends capacity.
- Run domestic units at non-optimal thermal balances, which increases energy consumption per barrel processed.
This structural mismatch means that even when US crude production reaches record highs, US refiners cannot instantly or efficiently translate those domestic barrels into cheap fuel. Running at 95% capacity under a sub-optimal crude slate generates higher internal operating costs, more heat degradation, and lower net yields of middle distillates per barrel than the market assumes.
The Downside of Challenging the Status Quo
Advocating for a realistic approach to refining strategy is not without cost. Wall Street rewards short-term cash flow generation above almost all else.
Refining executives who choose to reduce utilization rates to 85%, conduct thorough, preventative turnarounds, and invest heavily in long-term asset integrity face immediate backlash from activist investors. Capital discipline in the refining sector today is defined by returning cash to shareholders via buybacks and dividends, not reinvesting in steel in the ground.
If an executive suite decides to build new refining capacity or undertake massive capital retrofits to better align facilities with domestic light crude, the market punishes the stock. Environmental regulations, permitting delays, and the multi-decade timeline required to recoup billions in refining capital make new construction an economic non-starter.
The system is locked in an unhealthy equilibrium:
- Refiners cannot build new capacity due to regulatory and capital constraints.
- Existing plants must run at near-maximum speed to cover shrinking baseline margins and supply a tight market.
- Deferred maintenance builds up, increasing the statistical probability of major operational failures.
Investors who treat high utilization rates as a sign of industry health are pricing in best-case scenarios while ignoring mechanical reality.
The Reality Check
The next time you read that US oil refineries are running at breakneck speeds to save the world from foreign supply shocks, look past the PR releases and high-level statistics.
High run-rates are not a sign of operational dominance or a flexible response to global conflict. They are the symptoms of a fragile, capacity-constrained domestic system pushing aging infrastructure past safe operating windows while protected by distortionary trade policies.
Stop celebrating 95% utilization rates. Start worrying about what happens when the steel finally gives out.
