Eni takes control of Venezuela’s 35bn-barrel Junín-5 field under 25-year contract

Eni S.p.A. (BIT: ENI; NYSE: E) has signed a 25-year hydrocarbon production contract with Petróleos de Venezuela S.A. that makes the Italian energy major exclusive operator of the giant Junín-5 heavy-oil field in the Orinoco Belt, shifting technical, financial and commercial management to Eni as Venezuela attempts to restart investment across an oil industry that has operated far below its historic capacity. Junín-5 contains 35 billion barrels of certified oil in place but currently produces only around 12,000 barrels per day.

The agreement replaces the previous Petrojunín operating structure, under which PDVSA held 60% and Eni 40%, with the new contractual regime established under Venezuela’s revised hydrocarbons legislation. Eni’s exclusive operatorship is strategically significant because the company is no longer merely a minority partner relying on the state company to manage field execution; it now controls the technical and commercial decisions that determine whether the enormous in-place resource can be converted into meaningful production.

How can a field with 35bn barrels in place be producing only 12,000 bpd?

Oil in place and commercially recoverable oil are fundamentally different concepts. The 35 billion-barrel figure describes hydrocarbons estimated to exist in the reservoir, not reserves that can automatically be produced profitably.

Junín-5 contains heavy oil, which is more difficult and expensive to produce, transport and process than conventional light crude. Reservoir development requires wells, gathering infrastructure, upgrading or blending solutions and reliable access to markets, while field economics must absorb political, fiscal and operating risk.

That helps explain why an enormous geological resource can coexist with very modest current production. The field is not constrained by lack of molecules underground; it is constrained by the capital, infrastructure, operating capability and commercial framework required to move those molecules to market.

Eni has previously indicated a development ambition around a materially higher Junín-5 production plateau, although the September contract announcement did not restate a formal new production target. Investors should therefore judge the new operatorship by future approved development plans rather than simply applying a recovery percentage to 35 billion barrels.

Why does exclusive operatorship change Eni’s economic position?

Operatorship gives Eni responsibility for technical execution, field development planning, financial management and commercial organisation. That allows the company to apply its own project-management standards while reducing dependence on PDVSA’s operating systems.

The change can materially affect capital efficiency. A minority non-operator has limited ability to control drilling schedules, procurement, maintenance and contractor performance. An operator can decide how rapidly to drill, which reservoir zones to prioritise and how infrastructure should be phased.

With control comes greater responsibility. Eni will be more directly exposed to cost overruns, development delays and operational underperformance. Venezuela also remains an unusually complex political and sanctions environment, meaning commercial success depends on legal and financial conditions remaining sufficiently stable for long-duration investment.

The 25-year term reflects that reality. Heavy-oil developments require large upfront investment and long production periods to earn acceptable returns, so contractual durability is central to whether international capital can be committed.

Could Junín-5 become a second Venezuelan pillar alongside Eni’s Perla gas business?

Eni already has a meaningful operating position in Venezuela through Cardón IV, the 50:50 venture with Repsol that operates the Perla offshore gas field. Eni said its Venezuelan equity production averaged around 64,000 boe/d in 2025, mainly from Perla, which supplies approximately 35% of the country’s total gas consumption.

That existing position matters because Eni is not returning to Venezuela as a new entrant. It already operates infrastructure, manages local relationships and understands the country’s energy system.

Junín-5 adds oil exposure to that gas foundation. If production can be expanded materially, Venezuela could evolve from a largely gas-weighted Eni position into a broader upstream growth platform.

The company also retains a 26% interest in PetroSucre, which operates the offshore Corocoro field, providing another oil asset with potential redevelopment optionality.

Does Venezuela also offer Eni a route to recover billions of dollars owed by PDVSA?

Reuters reported that expanding production could improve Eni’s prospects of recovering more than US$2.3 billion owed by PDVSA, giving the company’s renewed investment an important balance-sheet dimension beyond future production growth.

Debt recovery and project investment can become intertwined in countries where state energy companies lack sufficient cash. New production creates additional revenue streams that can potentially support repayment mechanisms, while international operators gain access to resources that would otherwise remain underdeveloped.

The risk is that commercial arrangements depend on the stability of political and sanctions frameworks. A receivable may have accounting value, but actual recovery ultimately requires cash or hydrocarbons that can legally be marketed.

For Eni, Venezuela consequently represents both an upstream opportunity and a legacy-value recovery exercise.

Why did Eni shares fail to re-rate after the Junín-5 agreement?

Eni’s Milan-listed shares closed at €23.81 on September 2, when the contract was announced after the European market session, edged 0.2% higher to €23.86 on September 3 and then fell 3.3% to €23.08 on September 4. The stock remained above its €22.79 August 28 close despite the Friday decline.

That muted immediate response is understandable. Junín-5 offers enormous geological scale, but investors still lack a definitive updated development budget, production schedule and cash-flow framework.

There is also significant country risk. An oilfield can hold tens of billions of barrels and still deserve a discount if investors are uncertain about fiscal stability, sanctions, export routes or contractual enforceability.

The opportunity therefore depends on execution rather than acreage headlines. Eni has received something strategically valuable: operational control and 25 years to work on one of the world’s largest heavy-oil accumulations. The next challenge is proving that control can transform 35 billion barrels in place into commercially attractive production without allowing political and capital risk to overwhelm the resource opportunity.