Donald Trump's July 8 directive to suspend trade with Spain has not yet materialized into an energy embargo, but Madrid can no longer treat the warning as mere political posturing. It marked the second such threat since March 2026, this time communicated directly to Treasury Secretary Scott Bessent after Spain declined to allocate 5% of its GDP to defense spending and refused to back US military operations against Iran. Washington is reportedly reviewing products that could face restrictions, even as EU customs regulations prohibit the isolation of a single member state from the bloc's unified trade policy.

Over the past two years—spanning the height of the Middle East crisis—Spain has steadily deepened its energy reliance on the very nation now threatening to weaponize commercial ties. This shift mirrors a broader European pattern: after Russia's 2022 invasion of Ukraine collapsed decades of pipeline dependence on Moscow, EU member states turned heavily toward US LNG, which helped make the United States the world's largest LNG exporter by 2023.

Crude Oil: A Diversified but Not Painless Exposure

The vulnerability is most apparent in crude oil. In 2025, the United States supplied Spain with an average of approximately 250,000 barrels per day (b/d), primarily WTI Midland, out of total imports of 1.2 million b/d. The US has recently alternated with Mexico as Spain's largest crude supplier. Spain's crude portfolio remains relatively diversified, with significant volumes also sourced from Brazil, Nigeria, Libya, and Kazakhstan, making an outright supply shortage unlikely. However, losing US barrels would still carry tangible costs.

When the effective closure of the Strait of Hormuz upended Middle Eastern trade flows, Spain's crude imports surged 15.8% year-on-year in April. The disruption triggered a refined products shortage across European markets, pushing product crack spreads to multi-decade highs and forcing Spanish refineries to operate at maximum throughput. By June, imports had risen to roughly 1.25 million b/d, up from 1.07 million b/d a year earlier. Spain was comparatively fortunate: apart from Iraq—which had been averaging nearly 100,000 b/d but effectively vanished from the import slate in April—it carried limited exposure to Middle Eastern barrels. Kazakh CPC Blend arrivals quadrupled to approximately 140,000 b/d, while Mexican supply climbed to 155,000 b/d from 90,000 b/d.

In this environment, US crude has become a cornerstone of Spain's supply strategy—abundant, geographically accessible, and priced against WTI rather than the distorted Middle Eastern benchmark.

Repsol: The Largest US Crude Buyer

Among Spanish refiners, Repsol is the predominant purchaser of American crude. The company operates five refineries in Spain with approximately 896,000 b/d of distillation capacity, accounting for roughly 62% of the national total. Cargo-tracking data identify Repsol as the leading importer of US crude into Spain, with barrels purchased in the United States and delivered directly to its own facilities. WTI Midland dominates these flows because its light, sweet characteristics make it straightforward to process.

Repsol has also imported heavy sour Canadian Cold Lake Blend, shipped via US Gulf terminals, and Southern Green Canyon, a medium-sour US grade, for its more complex Cartagena and Petronor refineries. At those facilities, light WTI barrels are balanced against heavier Canadian and US feedstock. Any disruption to US supply would therefore require sourcing a precise combination of light sweet and discounted heavy sour grades to match individual refinery configurations.

Spain could replace those volumes, but likely at greater expense. Increasing CPC Blend imports would deepen exposure to the Russian Black Sea export corridor. Mexican supply is constrained by declining output from mature fields and growing domestic refinery demand, as the Mexican government has prioritized national refineries over foreign buyers. The most straightforward substitutes would be West African or Brazilian grades, with Brazilian crude particularly appealing to Atlantic Basin refiners due to rising availability from recent discoveries and relatively short shipping distances to Spain.

Natural Gas: The Strategic Weak Point

Natural gas represents Spain's more strategic vulnerability. US LNG accounted for approximately 30% of Spain's total gas imports in 2025—nearly double its 2024 share—and still represented 29% in the first half of 2026, ranking second only to Algeria's pipeline exports, which held roughly 40%. Unlike Yamal cargoes linked to Naturgy's long-term Russian contract, American supply blends long-term offtake agreements with flexible portfolio and spot cargoes that shift in response to relative pricing. That flexibility proved valuable during the crisis months from March to June, but it also means cargoes can be diverted to Asia whenever the Japan Korea Marker (JKM) offers a stronger netback.

Russian LNG has served as an additional buffer. Naturgy's 2013 Yamal contract includes take-or-pay commitments of 3.2 billion cubic meters (bcm) per year through 2041, and Spain's Russian receipts surged during the 2026 crisis. Russia supplied 21% of Spanish gas in June, but that option will disappear on January 1, 2027, when the EU's full ban on Russian LNG takes effect. Naturgy faces €10.95 billion in remaining Russian purchase commitments and may need to invoke force majeure.

June illustrated both Spain's risk mitigation strategy and its constraints. Total gas imports reached approximately 2.45 bcm, while domestic demand stood at 2.26 bcm. LNG accounted for 51% of supply, while pipeline gas rose to nearly 49%, up from 31% year-on-year. Algeria delivered 0.94 bcm, predominantly through the Medgaz pipeline.

Pipeline Expansion and Infrastructure Limits

Spain is working to reinforce its pipeline buffer. Madrid and Algiers began discussions in March regarding a potential increase of up to 10% in Medgaz deliveries, while Naturgy indicated in July that an additional 0.6–1 bcm of annual capacity could be added before winter. The pipeline's current capacity of 10 bcm/year was achieved by increasing pressure through additional compression, but further expansion is limited by the pipeline's physical diameter. Algeria can offer greater contractual security, but it cannot rapidly replace Spain's entire US LNG exposure without additional compression, upstream supply growth, and broader infrastructure upgrades.

Spain's six operating LNG regasification terminals—among the largest such networks in Europe—give it more flexibility than many neighbours to receive cargoes from virtually any producing region. However, limited pipeline interconnection with France across the Pyrenees, long a structural bottleneck on the Iberian Peninsula, means Spain cannot easily share surplus gas with the wider European market, nor draw on it in reverse when needed.

Reducing gas dependence in power generation would bolster energy security. Renewable generation rose 12% in June and supplied 58.4% of electricity, while combined-cycle plants still produced 15.7%. Gas is being displaced from baseload generation, yet it remains a critical backup when wind, solar, hydro, or interconnections underperform, making it unlikely to disappear entirely from the country's energy mix.

Looking Ahead to 2027

The looming expiration of Russian LNG cargoes at the start of 2027 alters the strategic calculus behind Trump's trade threat. In crude markets, Spain can reroute trade flows and absorb narrower refinery margins. In gas, the elimination of Russian LNG leaves Madrid navigating between a nearly saturated Algerian pipeline and a US supplier already providing nearly one-third of imports.

Spain's extensive regasification infrastructure shields it from a physical supply cutoff, but terminals alone do not generate cargoes. If Washington translates political pressure into export restrictions—or if US sellers simply redirect flexible volumes toward higher-paying Asian buyers—Spain would need to outbid competitors for Nigerian, Qatari (if available), or other Atlantic LNG, while pressing Algeria to push Medgaz beyond its current operational limits.

The immediate risk is not empty storage tanks. Rather, it is that Spain enters 2027 with fewer supply options, higher replacement costs, and a US administration increasingly inclined to treat energy access as leverage in a broader political negotiation—one in which the EU's collective trade policy, rather than Spain's alone, may ultimately determine how far Washington is willing to push.

By Natalia Katona for OilPrice.com