I went to Caracas for Venezuela’s new oil deals: what stood out

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I Went to Caracas for Venezuela’s New Oil Deals. Here’s What Stood Out

Venezuela’s National Assembly approved a sweeping hydrocarbons reform in early 2026 that allows private and foreign companies to operate oil fields under production-sharing agreements for the first time in nearly two decades. I traveled to Caracas in the weeks that followed to sit in on licensing briefings, talk to energy ministry officials, and visit the state oil company’s headquarters. What I found was a country betting its economic future on reopening oil fields at the exact moment the global vehicle fleet is beginning to turn away from the fuel those fields produce.

Why this matters

Venezuela holds an estimated 303 billion barrels of proven crude reserves — the largest on Earth, according to OPEC data — but produces only a fraction of what it did in the 1990s. The new deals aim to reverse that decline. For EV owners and buyers, the story matters in three concrete ways:

Oil supply expectations shape fuel prices. If Venezuela adds 500,000 to 1 million barrels per day to global markets over the next five years, that puts downward pressure on gasoline prices in the U.S. and Europe — which historically slows EV adoption at the margin.
The timing is awkward for oil. Global EV sales exceeded 17 million units in 2024, and EV adoption is accelerating in markets that once imported Venezuelan crude, including China and parts of Latin America.
The investment math is uncertain. Analysts at several firms have noted that oil majors are wary of long-payback projects in a country with a history of expropriation, sanctions, and infrastructure decay.

I went to Caracas for Venezuela’s new oil deals. Here’s what stood out

The deals themselves: what was actually signed

The reform, passed by the National Assembly and signed into law in January 2026, replaces the 2001 Hydrocarbons Law that underpinned former President Hugo Chávez’s nationalization drive. Key provisions include:

Provision	What it does	Why it matters
Production-sharing contracts	Allows foreign firms to book reserves and recover costs in crude	Reverses the 2007 expropriation framework that pushed out ExxonMobil and ConocoPhillips
Royalty rates	Set at 15–20%, down from 30%	Improves project economics for heavy crude upgraders
Arbitration	Permits international arbitration under ICSID rules	Addresses the single biggest investor complaint
License terms	25 years, extendable by 10	Long enough to justify $10B+ investments
State participation	PDVSA retains minority stakes with operatorship options	Keeps nationalist politics intact while ceding control

I sat through a two-hour briefing at the energy ministry where officials walked through these terms. The room was full of lawyers and trade attachés from at least a dozen countries. What struck me was how much of the conversation centered on speed — how fast fields could be brought back online, how fast pipelines could be repaired, how fast the Orinoco Belt’s upgraders could restart.

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What stood out on the ground

Three things.

First, the infrastructure decay is worse than the headlines suggest. A drive through parts of Zulia state, once the heart of Venezuelan oil production, shows pumpjacks sitting idle, rusting in place. Engineers I spoke with estimated that restoring output to 1.5 million barrels per day — roughly half of the 1998 peak — would take five to seven years and tens of billions of dollars.

Second, the workforce has hollowed out. PDVSA once employed over 40,000 people, many of them highly trained engineers. Decades of emigration have scattered that talent across Colombia, Spain, and the U.S. Gulf Coast. One former PDVSA engineer now working in Houston told me he would not return “for any salary” until the legal framework survived at least one change of government.

Third, the international response is cautious, not enthusiastic. Chevron has maintained a limited license to operate in Venezuela since 2022. Other majors — Shell, Repsol, and several Asian state oil companies — have sent delegations but have not committed capital at scale. The reason is simple: a 25-year license is only as good as the government that honors it.

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The EV connection nobody in Caracas wanted to discuss

Here is the part of the story that Venezuelan officials consistently deflected when I raised it. The global oil industry is not investing in new supply the way it once did, and the reason is demand uncertainty — not geology. The International Energy Agency’s 2025 World Energy Outlook projected that oil demand from road transport could peak before 2030 in its stated-policies scenario, driven largely by EV adoption in China, Europe, and increasingly Latin America.

That matters for Venezuela’s bet. If the country spends a decade and $50 billion rebuilding its oil industry only to find that global demand has flattened, the returns will be far lower than the models assume. Several countries are already taking notes and reducing their reliance on imported oil. EV sales have tripled in Australia. Ethiopia, Nepal, and Pakistan have pushed aggressive electrification policies. Even oil exporters are hedging.

I asked a senior official at the energy ministry whether Venezuela had considered investing in lithium or EV supply chains instead. Venezuela has known lithium deposits in the Amazonas region, though they remain largely unexploited. The answer was polite but firm: oil is what Venezuela has, and oil is what Venezuela will sell.

The counterargument: why the deals might still work

To be fair, there is a coherent case for the reform that does not depend on oil demand growing forever.

Heavy crude has a floor. Even in aggressive decarbonization scenarios, petrochemicals, aviation, and shipping keep demand for certain crude grades alive for decades.
Venezuela’s barrels are cheap to lift once infrastructure is repaired. The Orinoco Belt’s extra-heavy crude has some of the lowest lifting costs in the world.
Geopolitics favors diversification. Buyers in Asia and Europe want non-Russian, non-Middle Eastern supply, and Venezuela fits that profile.
The alternative is worse. Without investment, Venezuela’s production continues to decline, and the country loses even the revenue it currently earns.

FAQ

What are Venezuela’s new oil deals?

They are production-sharing agreements enabled by a January 2026 hydrocarbons reform that allows foreign companies to operate Venezuelan oil fields, book reserves, and recover costs in crude. It replaces the 2001 law that nationalized much of the industry.

Will these deals lower gas prices?

Not immediately. New production from Venezuela would take three to seven years to reach meaningful volumes. If it arrives, it would add supply to a global market where demand growth is slowing, which could modestly soften prices.

How does this affect EV adoption?

Indirectly. Cheaper gasoline reduces the running-cost advantage of EVs, which can slow adoption in price-sensitive markets. But the effect is small compared to EV price declines, charging infrastructure buildout, and government policy.

Is it safe for foreign companies to invest in Venezuela?

That is the central question. The new law includes international arbitration and longer license terms, but investors remain wary after the 2007 expropriations and years of U.S. sanctions. Chevron’s limited license is the only major foreign presence at scale.

Does Venezuela have lithium or other EV minerals?

Yes. Venezuela has known lithium deposits in Amazonas state, but they are undeveloped and lack the infrastructure, water, and technical workforce needed for commercial production.

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The takeaway

Venezuela’s oil reform is a genuine opening — the most significant since the 1990s — and the country’s reserves are real. But the timing places it in direct tension with the global energy transition. The deals will likely attract enough capital to stabilize production and generate revenue, but the era in which Venezuelan crude could reshape global supply is probably behind us. For EV owners and buyers, the more useful signal is this: even a country with the world’s largest oil reserves is being forced to compete for investment in a market that is no longer certain its product will be needed at scale in 2040. That uncertainty is the strongest argument for electrification that I heard in Caracas — and I heard it from the people selling the oil.

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