U.S. Unlocks Venezuelan Oil as Iran War Pushes Brent to $105

The Trump administration lifted sanctions on Venezuela’s interim president Delcy Rodríguez on April 1, clearing U.S. companies to invest in the country’s oil sector as Brent crude trades at $105 per barrel—elevated by an Iran war that has closed the Strait of Hormuz and disrupted 20% of global supply.

The sanctions relief follows the January 3 U.S. military operation that captured Nicolás Maduro and transported him to New York to face drug trafficking charges, according to public records. Maduro is currently detained in U.S. federal custody. The U.S. installed Rodríguez as interim leader and has since moved rapidly to normalise ties: Treasury issued broad authorisation in March allowing state oil company PDVSA to sell directly to U.S. firms and global markets, per WSLS News. Rodríguez called the April 1 decision “a step toward normalising and strengthening relations,” though Trump warned that “if she doesn’t do what’s right, she is going to pay a very big price, probably bigger than Maduro.”

The timing creates a complex energy market dynamic. Venezuelan crude production reached 1.02 million barrels per day in February, up from 924,000 bpd in January, according to Trading Economics. That output—constrained for years by sanctions and infrastructure decay—sits well below the country’s historic 2.5 million bpd capacity. Venezuela holds 300 billion barrels in proven reserves, 17% of the global total.

Iran War Premium Reshapes Oil Arithmetic

Brent crude has surged 51% since January—from $76 to a late-March peak of $115—driven by the February 28 onset of direct U.S.-Israeli military operations against Iran and Tehran’s subsequent closure of the Strait of Hormuz, which normally carries 20% of global oil flows. The strait closure has disrupted Persian Gulf production and created severe supply tightness. Current pricing reflects this sustained geopolitical risk premium.

Venezuelan barrels entering U.S. Gulf Coast refineries—rather than sailing to China via shadow tankers—could partially offset the Iran supply shock. But infrastructure constraints limit how quickly production can scale. Goldman Sachs projected in early January that Venezuelan output would remain flat at 900,000 bpd through 2026, forecasting Brent averaging $56 and WTI at $52 for the year. Those estimates now look obsolete: the Iran premium has fundamentally altered the supply-demand balance, and Venezuelan production has already exceeded Goldman’s static projection.

India Replaces China as Top Buyer

Indian refiners have emerged as the largest buyers of Venezuelan crude, filling the gap left by reduced Chinese purchases, according to Bloomberg. China historically accounted for 80% of Venezuelan oil exports—746,000 bpd flowing to Chinese ports as recently as November 2025, according to Anadolu Agency shipping data. The shift toward Indian buyers signals a broader realignment: as U.S. companies gain direct access under the new Treasury authorisation, petrodollar flows that once fed Beijing now bypass China entirely.

The Energy Secretary announced in February that oil sales to Venezuela have reached $1 billion since January, with projections of $5 billion in coming months. That figure reflects U.S. crude and refined product shipments to Venezuela to restart idled refining capacity, not Venezuelan exports to the U.S.—but it underscores the scale of commercial re-engagement already underway.

Critical Minerals Add Strategic Depth

The January 29 oil privatisation law enacted by Venezuela’s interim government not only opened the petroleum sector to foreign investment but created a legal framework for mining partnerships—critical for unlocking the country’s mineral wealth. This legislative foundation justifies the accelerated timeline for U.S. commercial engagement beyond crude extraction.

Beyond oil, Venezuela holds verified deposits of bauxite (99.4 million metric tons), iron ore (3.6 billion metric tons in proven reserves), nickel (408,000 metric tons), gold, and coltan, according to a 2018 government catalog. Claims of rare earth element reserves remain unverified—the U.S. Geological Survey does not list Venezuela among countries with confirmed REE deposits, and geological mapping remains incomplete.

The mineral question adds a second dimension to U.S.-China competition in the hemisphere. China controls over 90% of global rare earth refining capacity and 60-95% of processing for most Critical Minerals. Even if Venezuelan rare earth deposits were confirmed and extracted, they would likely require Chinese refining infrastructure to reach usable form—limiting Washington’s leverage. Bauxite and coltan, however, have more diversified processing networks, making them viable targets for supply chain reshoring initiatives.

Petrodollar Flows and Strategic Realignment

China’s energy dependence on the Persian Gulf—50% of oil imports and 33% of LNG—has become a strategic vulnerability as the Strait of Hormuz remains closed. Russia has positioned itself to fill the gap through overland pipelines and Arctic LNG, but Venezuelan crude offers Beijing a Western Hemisphere hedge. The U.S. move to redirect Venezuelan exports toward American and Indian refineries directly challenges that hedge.

The geopolitical arithmetic is straightforward: every barrel that flows to Houston or Mumbai instead of Shanghai reduces China’s energy diversification and shifts petrodollar recycling away from yuan-denominated trade. PDVSA earned $17.52 billion from oil sales in 2024, nearly all of it from Chinese buyers. If U.S. companies capture even 30% of Venezuelan output under the new authorisation, that represents a $5 billion annual swing in capital flows—and a corresponding reduction in Beijing’s ability to use energy purchases as diplomatic leverage in Caracas.

Infrastructure Decay Limits Near-Term Upside

Venezuelan oil fields, refineries, and export terminals have deteriorated significantly. Restoring production to even 1.5 million bpd—half the historic peak—will require multi-billion-dollar capital investment in well maintenance, pipeline rehabilitation, and refinery overhauls. Sanctions prevented Western oil service companies from operating in Venezuela for years, and Russian and Chinese contractors filled the void with limited technical capability.

U.S. oilfield service firms can now re-enter, but the timeline for meaningful production gains extends into 2027 at the earliest. The Energy Information Administration had forecast global oil oversupply for 2026 before the Iran war; that projection no longer holds with 20% of supply disrupted, but Venezuelan barrels cannot bridge the gap immediately. The market is pricing in structural tightness through year-end, which explains why Brent has held above $100 despite Venezuelan sanctions relief.

What to Watch

The first indicator of progress will be U.S. oil service company contract announcements—Schlumberger, Halliburton, and Baker Hughes returning to Venezuelan fields signals capital deployment is underway. Second, track monthly production data from PDVSA: sustained output above 1.1 million bpd would confirm that new investment is translating to barrels. Third, monitor Indian refining margins: if Venezuelan heavy crude displaces Middle Eastern grades in South Asian refineries, that will pressure Saudi Arabia’s Aramco pricing and indicate a genuine supply rebalancing.

On the minerals front, joint venture announcements in bauxite or coltan mining—particularly partnerships involving U.S. or allied firms—would confirm that the strategic competition extends beyond crude. Finally, watch China’s response: if Beijing accelerates infrastructure lending or offers preferential trade terms to Caracas, it signals recognition that Venezuela is now a contested asset in the broader U.S.-China decoupling. The Iran war has created a window for Venezuela.