Chevron will pour more than $7 billion into Venezuela through 2031, aiming to nearly double its production there to 600,000 barrels a day at a cost the company says will average $20 a barrel. The spending arrives days after the Trump administration unveiled a sweeping oil accord with Caracas, and it keeps the only Western major still operating in the country on a trajectory that could make its Venezuelan barrels among the cheapest in the portfolio.
The political backdrop
On August 31 the White House announced a landmark agreement granting privately held North American Blue Energy Partners 100-year development rights to 17 fields holding an estimated 65 billion barrels. The Pentagon takes a 35 percent stake in the venture, while the State Department secures the right to purchase 20 percent of output at cost. Two days later Chevron disclosed additional acreage awards, Carabobo 1 and Carabobo-2-South-A, in the Orinoco Belt, home to the bulk of the country’s extra-heavy reserves. Venezuela pumped just 1.01 million barrels a day in 2025, roughly a third of its peak from two decades earlier, after years of sanctions, mismanagement and capital starvation.
The cost math
The $7 billion commitment works out to about $1.4 billion a year over five years, less than one-tenth of Chevron’s $18 billion to $21 billion annual capital budget. At a projected $20 per barrel lifting cost, the incremental barrels would generate margin even if crude revisits the lows of the past decade. That arithmetic matters because the company has tied its long-term financial framework to double-digit compound growth in earnings per share and adjusted free cash flow through 2030, supported by 3 percent to 6 percent annual share buybacks and a rising dividend.
The portfolio context
The Venezuelan increment sits alongside high-margin growth in the Permian, offshore Guyana and the Bakken, all amplified by last year’s $53 billion Hess acquisition. Together they form a production base designed to deliver volume without the capital intensity that has historically plagued big-oil reinvestment cycles. If the Orinoco ramp proceeds on schedule, Chevron locks in a low-cost wedge that requires minimal incremental spending relative to the cash it throws off.
The risks
Infrastructure in the Orinoco needs extensive repair before volumes can scale, and the timeline is not guaranteed. Operations remain exposed to shifts in diplomatic relations, regulatory changes and the broader political volatility that has defined Venezuela’s energy sector for a generation. The administration’s deal with NABEP adds a layer of state-backed complexity that has no recent precedent. Chevron’s century-long presence gives it institutional knowledge few rivals possess, but history suggests the contract is only as durable as the politics surrounding it.