Chevron Nears Deal for Heavy Oil Field Investment in Venezuela
Sources told The Wall Street Journal that Chevron and other U.S. energy companies are close to reaching an agreement to invest billions of dollars in Venezuelan oil fields, with Chevron expected to secure two heavy oil fields.
Chevron is currently the only major U.S. oil company still operating on a large scale in Venezuela, maintaining three joint ventures with state-owned oil company PdVSA, which account for about one-fifth of the country's crude oil production. The company plans to integrate the two heavy oil fields into its existing portfolio, requiring billions in capital expenditures to develop these blocks, as a significant portion of the assets lack pipelines, electricity, and surface facilities. Oilfield service provider Halliburton is also negotiating to supply equipment and services to local producers.
Several oil and gas executives plan to travel to Caracas to sign production agreements, with U.S. Energy Secretary Chris Wright expected to accompany them. After months of negotiations, the talks are nearing conclusion, seen as a phased result of the Trump administration's push for U.S. companies to return to Venezuela's oil industry. Concurrently, Washington is discussing long-term leases for about 17 key oil fields in the country, with estimated proven reserves of approximately 9 billion barrels, with lease terms potentially extending up to 100 years.
ExxonMobil and ConocoPhillips are not yet following suit. Both companies are still pursuing billions in compensation from the Venezuelan government following the nationalization of assets by the Chávez administration in 2007, with unresolved financial terms and legal stability requirements. In August of this year, Hunt Oil signed a production agreement with PdVSA, and oilfield service provider SLB secured exploration and service contracts, marking one of the earliest U.S. commercial arrangements following Maduro's ousting.
In April, Chevron completed an asset swap with PdVSA, increasing its stake in the Petroindependencia joint venture from approximately 35.79% to 49%, and exchanged offshore gas rights for development rights in the Orinoco Belt's Ayacucho 8. At that time, the company's production was approximately 260,000 barrels per day, with a target to increase by about 50% to around 375,000 barrels per day within 18 to 24 months, primarily funded by existing local cash flow rather than an increase in annual capital guidance. The Venezuelan government claims proven reserves exceed 300 billion barrels; national production has been around 900,000 to 1.1 million barrels per day in recent years, peaking at 3 million barrels per day.
From a market mechanism perspective, this represents a redistribution of upstream assets following the political switch, rather than an immediate impact on crude oil supply and demand. Buyers include Chevron, which needs heavy oil feedstock for Gulf Coast refineries, and Halliburton and SLB, which require workover and surface engineering orders, while sellers are PdVSA, which urgently needs external capital to repair its well network, and the interim authorities seeking political achievements. If funding materializes, it will flow from U.S. oil services and integrated oil companies' capital expenditures to surface engineering in the Orinoco heavy oil region; beneficiaries will be Chevron and Gulf Coast heavy oil refineries, while Exxon and Conoco, still entangled in compensation lawsuits, and the Venezuelan national ownership structure potentially rewritten by long-term leases, will be under pressure. Oil prices have reacted limitedly to the "upcoming signing" itself, as the reconstruction of production capacity is estimated by the industry to take a decade and cost over $100 billion.
In supplementary metrics, Chevron exported approximately 293,000 barrels per day from Venezuela in the second quarter, up from 223,000 barrels per day in the previous quarter; the U.S. Department of Energy stated earlier this year that Venezuelan crude oil sales amount to about $2 billion to $3 billion per month, with about half going to the U.S.
Source: Public Information
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Chevron's ability to sign first is due to its presence in Venezuela since 2007, when Chávez expelled Exxon and Conoco. The company returned in 1996 as a joint venture and maintained exports during Maduro's era with U.S. Treasury licenses. CEO Mike Wirth's strategy is to leverage "preventing China from taking over strategic oil fields" to renew Washington's permits, while keeping the wells on the books with three joint ventures and around 3,000 local employees. After Maduro's ousting, Trump demanded U.S. companies invest $100 billion in infrastructure immediately, but Chevron publicly stated it would not increase its capital expenditure guidance for 2026 from $18 billion to $19 billion, instead aiming to boost production by half using existing cash flow. Securing positions first and then increasing investment is Chevron's key advantage over later entrants.
Capital mobilization occurs on three levels: Chevron locks in Orinoco heavy oil through joint venture equity swaps; Halliburton, SLB, and Hunt Oil sell equipment and operational services, converting risks into short-term contracts; the White House discusses 17 oil fields and long-term leases of up to 100 years, attempting to convert national reserves directly into U.S.-auctionable mineral rights. The real financial stakes lie not in the signing fees for the current two fields, but in heavy oil upgrading, electricity, and pipelines, with industry estimates suggesting that restoring historical production levels will require $100 billion to $220 billion and take over ten years. Former Chevron Latin America head Ali Moshiri is concurrently raising $2 billion in private equity, indicating that large companies are cautious while smaller capital is eager to fill gaps, with funding entering in layers according to risk preference, rather than a one-time total assault as suggested in White House press releases.
The analogy is with post-war oil field tenders in Iraq and the restart in Libya: political switches can open overnight, wellhead production rises quarterly, and reserve pricing power can be rewritten over a decade. Chevron is in a control phase rather than an exploration expansion phase; it aims to turn existing joint ventures into gateways to new blocks. Exxon and Conoco are stuck at the door, repeating the logic of claims after the 2007 expropriation—without financial stability clauses, they refuse to expose their balance sheets to the same sovereign risks again. SLB and Hunt signing first positions them closer to the role of oil services in post-war Iraq: first collecting engineering fees, then assessing whether mineral rights are executable.
Structural changes reflect a reconstruction of the industry chain and a transfer of pricing power. Heavy oil is being re-integrated into the Gulf Coast refinery feedstock pool from "sanctioned national goods"; whoever controls the Orinoco surface facilities will control supply to the complex refineries in the Gulf. The mechanism is that the party willing to clear political risks first gains operational rights, while the party with unresolved compensation is locked out. The national oil company exchanges reserves for well repair capital, while Washington uses long-term leases to incorporate reserve statistics into "hemispheric energy security." Production will not immediately flood the market due to an almost finalized agreement, but once mineral rights are written into a century-long lease, the next round of pricing power will not reside in Caracas's export window, but with companies capable of fronting hundreds of billions for surface engineering.