President Donald Trump says the United States will “run” Venezuela until a “safe” transition and wants American oil majors to spend billions restoring production after the capture of Nicolás Maduro. The Guardian and Reuters report that the UN Security Council will meet on Monday to discuss the operation and Washington’s intentions.

For investors trying to size the oil story: Venezuela still holds roughly 303 billion barrels of proven reserves, the biggest on paper, but most of it is extra‑heavy crude that is costly to produce and process. Actual output has hovered around 0.9–1.0 million barrels per day in late 2025-well under 1% of global consumption-according to the IEA and US EIA.

The engineering obstacle is substantial. Extra‑heavy, sour crude needs diluents and upgrading capacity before it can flow to market at scale. Chevron’s Petropiar project in the Orinoco Belt, for example, is designed to upgrade extra‑heavy into a lighter synthetic crude-illustrative of the kit required to move the needle. Analysts quoted by Reuters say there are no quick wins: restoring meaningful output takes 5–10 years and tens of billions of dollars.

The contractual and political risk is just as large. Oil companies cannot sign binding deals until a recognised government is in place, and any fiscal terms would have to survive the next administration. Kpler’s Homayoun Falakshahi told the BBC the hurdles are legal and political first, operational second. In short, even with a friendlier regime, months of paperwork precede years of capex.

On the ground, Venezuela’s export machine is faltering. Reuters reports shipments have halted and PDVSA has asked several joint ventures-including those with Chevron and CNPC-to curb output as storage fills and sanctions bite. If cargoes cannot move, wells will be shut in and decline rates will quicken, pushing recovery further to the right.

Market reaction has been measured. Brent started 2026 near $61 a barrel after an 18% slide in 2025, and OPEC+ kept output policy unchanged on 4 January. The IEA’s December assessment described crude and NGL supply as amply available, even if refining capacity is tight in places. That combination helps cap the immediate risk premium.

That is why forecasters expect limited price impact this year. Capital Economics’ Neil Shearing told the BBC that the number of hurdles and the long timeframe mean little change to oil prices in 2026, a view consistent with the market’s calm start to January.

Chevron remains the most relevant U.S. operator in the country, with minority stakes in key projects and decades of in‑country experience. Company filings show long‑dated joint‑venture agreements across Boscan, LL‑652, Petropiar and Carabobo 3, though shipments have been stop‑start under sanctions and, per Reuters, are currently paused. Expect any restart to prioritise safety, legal clarity and cash‑neutral structures.

For a UK lens, exposure is limited. BP and Shell have no meaningful oil production in Venezuela, although Shell has been working to bring offshore gas from the Dragon field to Trinidad as early as 2026-an effort that depends on U.S. authorisations and regional politics, Reuters has reported. That is a gas story for Atlantic LNG rather than a near‑term driver of Brent.

Heavy‑sour versus light‑sweet matters for refiners more than for headline prices. Venezuelan grades are suited to complex refineries-especially on the U.S. Gulf Coast-whereas Europe and the UK depend more on light sweet and product imports. In practice, the quality mix blunts the pass‑through to UK pump prices unless Brent itself moves materially. The EIA’s profile of Venezuela underscores that quality and upgrading challenge.

What to watch next: clarity from Washington on what “running” Venezuela actually means for governance and contracts; any easing or tightening of sanctions that allows cargoes to resume; and whether OPEC+ holds its line into February. The UN Security Council session on Monday and any update on PDVSA/chevron loadings are the first signposts.