The World's Largest Reserve and Two Rigs.. Venezuela Is Not the Safety Valve

The question echoing in trading rooms for months: Who will fill the void left by Gulf oil?

And the answer provided by the White House is clear: Venezuela.

In August, President Donald Trump announced what he described as the largest oil deal in world history, granting North American Blue Energy Partners concessions in 17 fields with proven reserves of nearly 65 billion barrels. The company spoke of a near-term goal to raise production above one million barrels per day, along with talks of investments around $100 billion.

Deals followed in rapid succession. Chevron pledged more than $7 billion over five years and doubled its production to nearly 600,000 barrels per day. Italy's Eni became the operator of the giant Junín-5 field. Continental Resources signed a memorandum of understanding to develop the Ayacucho-2 block. Meanwhile, Halliburton and SLB signed agreements to reactivate drilling rigs.

On paper, this appears to be the perfect recipe: the world's largest proven oil reserve opening up to Western investment at the exact moment the market needs extra barrels.

But a single number is enough to dismantle this narrative: in August, Venezuela had only two active rigs, according to Baker Hughes data.

The Difference Between What Is in the Ground and What Is in the Market

Take the Junín-5 field as an example. It contains 35 billion barrels of proven heavy oil in the reservoir, yet currently produces only about 12,000 barrels per day.

This is not a passing paradox; it is the entire story. Reserves are a geological figure, while production is an engineering and financial figure. Between the two lie drilling rigs, gathering lines, compressors, ports, skilled labor, and electricity.

Venezuela currently produces around 1.25 million barrels per day. Even in the bullish scenario from consultancy Rystad Energy, production reaches 1.6 million barrels per day by 2028, 1.8 million by 2030, and 2.58 million by 2035.

To reach these figures, the country needs about 50 active rigs by 2028, and nearly 80 by 2030.

Meaning that what is required is a twenty-five-fold increase in the number of rigs within two years, in a country whose oil infrastructure is dilapidated after decades of mismanagement and underinvestment.

The Price Crisis Will Not Wait Until 2030

Here lies the common misreading.

Today's crisis is a matter of months, not decades. Ever since the effective closure of Hormuz in February, Brent has been trading above $100, tanker traffic through the strait has dwindled to single digits on some days, and supertanker charter rates have jumped to record levels.

As for the first additional Venezuelan barrel of impactful volume, it is a 2028 project at best.

Even if capital flows tomorrow, the trajectory is known: reactivating stalled projects first, then repairing dilapidated infrastructure, and then developing new fields that take years and additional billions. Rystad described the pace of recovery as contingent on actual capital expenditure and the country's capacity to rebuild drilling, service, and infrastructure capabilities.

In other words: Venezuela is a solution to next decade's problem, not this winter's problem.

And One Hundred Billion Dollars Is Not Earmarked

The headline figure deserves a second look.

Rystad warned that the $100 billion figure represents a long-term financing need, not near-term committed capital, and that the company has not disclosed a detailed financing structure. It added that it prefers investment programs linked to established operators and specific assets over grander ambitions requiring massive external capital.

The difference is fundamental: an announced billion is not the same as a deposited billion.

The Risk Nobody Talks About: The Price Itself

Suppose everything goes smoothly, rigs arrive, and money flows.

Then a harsh paradox emerges: the International Energy Agency expects global production to rebound by nearly 8 million barrels per day in 2027 with the return of the Gulf, while the US Energy Information Administration sees average Brent dropping to $74 next year.

This means that heavy, high-cost Venezuelan barrels will hit the market at the exact moment cheaper-to-produce Gulf oil returns. Who will finance a field with high production costs today, hoping to sell in a market that might be oversupplied five years from now?

This is not pessimism; it is precisely why companies are talking about memorandums of understanding more than final investment decisions.

And Politics Above All That

The legal environment is no less complex.

The concessions were granted by an unelected transitional government led by Delcy Rodríguez following the arrest of President Nicolás Maduro by US forces on January 3. The government passed a new law opening the sector to privatization on January 29, then began restructuring nearly $150 billion in sovereign and oil debt in May. No date has yet been set for presidential elections.

Accounts conflict even over the duration of the concession itself: the White House spoke of 100 years, while Rodríguez described it as 25 years.

On top of that, old arbitration claims by companies that left the country following the 2007 nationalizations remain unresolved. Investor memory is long: those who were nationalized once calculate the probability of nationalization twice.

What Does This Mean for the Region?

First, in the short term, nothing. Anyone betting that Venezuelan barrels will curb 2026 prices is betting on the wrong timeline. The variables driving prices this year remain the same: Hormuz, Bab al-Mandab, and bypass pipeline capacity.

Second, in the long term, the impact is real. Venezuelan crude is heavy, and its natural destination is US Gulf Coast refineries designed for heavy crudes—the very same market where Gulf and Iraqi heavy crudes compete. Every Venezuelan barrel arriving in Texas in 2030 is a Gulf barrel looking for a buyer elsewhere.

Third, capital and expertise move. When major service companies sign on to reactivate rigs in Latin America while Gulf activity is halted, equipment and technical crews follow contracts. Bringing them back is not a push-of-a-button matter.

Conclusion

Venezuela possesses the world's largest proven oil reserves. This is an indisputable geological fact.

However, the market does not buy reserves; it buys barrels delivered on time. Between the two lie rigs, money, law, and politics.

This is the very lesson Hormuz taught us this year, but from the opposite direction: there, oil exists and is produced, but is trapped behind a strait. Here, oil exists, but is not even produced in the first place.

So which is faster to market: a barrel waiting for a strait to open, or a barrel waiting for eighty rigs?