Shell’s decision to ink a fresh suite of commercial and technical agreements with Venezuela’s government this week is being read in energy circles as a straightforward gas deal. It is not. It is a signal, about Washington’s Venezuela strategy, about the future of Caribbean LNG, and about how far a post-Maduro government is willing to go to reshape the conditions for foreign capital. Reading it as anything less misses the actual story.
The centrepiece is the Dragon offshore gas field, which straddles the maritime boundary between Venezuela and Trinidad and Tobago. With proven reserves of approximately 4.2 trillion cubic feet, Dragon has been fully developed on paper for years. The engineering surveys are done. Shell completed a marine survey in 2024 to determine drilling locations and pipeline design. Three wells have been scoped. A 22- kilometre subsea pipeline connecting Dragon to Shell’s Hibiscus platform in Trinidad has been designed. What has consistently stopped the project from proceeding is not geology or engineering. It is Washington.
The January 2026 oil reform passed by Venezuela’s legislature changes the investment calculus in ways that go beyond the Dragon project specifically. The new law lowers royalty rates from 30% to as little as 15% for undeveloped acreage, allows private companies to assume technical and operational management of joint ventures, a significant departure from the Chávez-era model in which PDVSA retained operational primacy and permits direct commercialisation of crude by private operators without routing everything through the state company. It also opens access to international arbitration, which had been effectively unavailable to foreign investors for nearly two decades.
Analysts from Al Jazeera’s energy desk and the Venezuelan International Centre for Energy and Environment have noted the reform is necessary but stops short of what would maximise investor confidence. PDVSA’s mandatory majority stake in joint ventures remains intact, and the company’s financial position, saddled with roughly $190 billion in outstanding foreign obligations according to the Americas Quarterly post-Maduro analysis, means it is structurally unable to meet its own capital commitments on almost any project. That creates a practical tension: the law invites foreign operators in, but the partner they must work with is effectively bankrupt.
Wood Mackenzie estimates that the Orinoco Belt joint ventures alone would require $15 billion to $20 billion in upstream investment just to add 500,000 barrels per day. The infrastructure has not simply been underinvested. Much of it has been actively degraded, by years of mismanagement, by the departure of experienced PDVSA engineers who left during the Maduro years and have not returned, and in some cases by physical looting of equipment and materials. Rebuilding production capacity from under 1 million barrels per day to anything approaching the country’s historical peak is not a matter of turning valves back on. It is a decade-long reconstruction project.
The agreements Shell has signed this week, covering offshore gas, onshore oil and gas opportunities, and technical partnerships with VEPICA, KBR, and Baker Hughes, suggest the company is moving methodically rather than rushing. The inclusion of Baker Hughes and KBR as technical partners signals the kind of services-intensive approach that a deteriorated infrastructure environment demands. These are not exploration agreements. They are rehabilitation agreements. Shell is not betting on a windfall. It is pricing in complexity.
*Chloe Maluleke
Associate at BRICS+ Consulting Group
Russia & Middle East Specialist
**The Views expressed do not necessarily reflect the views of Independent Media or IOL.
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