Trinidad and Tobago’s decision to lower the royalty rate on qualifying marginal marine gas fields from 12.5% to 8% should give Guyana reason to reflect on how it debates petroleum fiscal terms.
The measure, included in Trinidad and Tobago’s Finance Bill 2026, applies to certified marginal marine gas fields. These are offshore shallow-water fields with recoverable gas resources of 300 billion cubic feet (bcf) or less, an internal rate of return below 15% as a standalone project, and production starting after January 1, 2026. The field must also be certified by the Minister of Energy and Energy Industries.
That detail matters. Trinidad and Tobago is not a country unfamiliar with oil and gas. It is one of the Caribbean’s most experienced producers. It has decades of institutional knowledge, established infrastructure, a mature energy sector, and a long history of negotiating with international energy companies.
Yet, even with that experience, it has recognized that some resources may not move into production unless the fiscal terms are made more attractive.
That is the point Guyana should not ignore. Oil and gas resources do not develop themselves. The existence of hydrocarbons below the seabed does not automatically mean they will be produced, monetized, or converted into public revenue. Development requires large capital commitments, advanced technology, long timelines, technical certainty, market access, and investor confidence.
Countries also compete for capital. They compete for attention inside the global portfolios of companies that have options across several jurisdictions.
This is often underplayed in Guyana’s public debate. Since the scale of the Stabroek Block discoveries became clear, there has been sustained criticism of Guyana’s 2016 petroleum agreement. Much of that criticism has focused on whether the country should have secured higher royalties, ring-fencing provisions, and a larger overall fiscal take.
Those are legitimate issues. Guyanese citizens have every right to question whether the country is receiving fair value from its natural resources. Cost recovery must be audited. Environmental safeguards must be enforced. Local content must be deepened. Public revenues must be transparently managed. Regulators must have the capacity and independence to act in the national interest.
But the discussion cannot stop at the headline terms.
A petroleum agreement must also be judged by what it delivers in practice. Does it attract investment? Does it move projects from discovery to production? Does it generate revenue for the state? Does it create opportunities for local businesses and workers? Does it help the country build experience, infrastructure, and capacity?
On those questions, the Stabroek Block has produced results that cannot be ignored. Guyana moved from first oil in 2019 to one of the fastest-growing offshore oil developments in the world. Multiple floating production, storage and offloading vessels have been deployed. Production has expanded rapidly. Significant oil revenues have flowed into the Natural Resource Fund. The local economy has also been reshaped by new demand for goods, services, training, logistics, fabrication, and technical support.
None of this means Guyana’s first petroleum agreement should be beyond scrutiny. It should not be. But scrutiny should not become the assumption that tougher terms automatically produce better outcomes.
Trinidad’s royalty reduction is a reminder that fiscal attractiveness can be a strategic tool. When resources are marginal, costly, technically difficult, or commercially uncertain, governments sometimes adjust terms to make development viable. The alternative may be that the resource remains undeveloped, producing no revenue, no jobs, no local contracts, and no energy security benefit.
That reality matters for Guyana.
There is a tendency in some sections of the national conversation to treat investment as guaranteed. The argument often seems to be that because Guyana has oil, companies will come regardless of the terms. That is not how global energy investment works.
Capital is selective. Projects compete. Companies compare fiscal systems, regulatory stability, geological risk, execution timelines, political risk, infrastructure, and expected returns.
Guyana has been fortunate to discover large, high-quality resources in a prolific basin. But strong geology does not remove the need for a stable and competitive investment environment. The challenge is to ensure that Guyana captures increasing value over time while preserving the conditions that allowed rapid development in the first place.
The lesson from Trinidad is not that Guyana should avoid seeking better terms in future agreements. Guyana has already moved to a different model for new offshore blocks, with revised fiscal terms that reflect its changed risk profile. That is appropriate. A country with proven reserves and production history is in a stronger negotiating position than a frontier basin before first oil.
The lesson is that fiscal policy must be grounded in commercial reality.
There is a difference between maximizing the state’s share on paper and maximizing national benefit in practice. A high royalty rate or aggressive fiscal structure may look attractive politically. But if it discourages investment, slows development, or leaves marginal resources stranded, the country may lose more than it gains.
Trinidad’s decision also shows that petroleum fiscal systems are not static. They evolve with basin maturity, project economics, investor appetite, and national priorities. Mature producers may introduce incentives to unlock smaller or stranded resources. Emerging producers may adjust terms as geological risk falls. Successful petroleum provinces understand when to tighten, when to incentivize, and when to preserve stability.
Guyana’s priority should be a more mature conversation.
The country should demand transparency and accountability, but it should also recognize the importance of competitiveness. It should pursue stronger oversight without creating uncertainty. It should seek greater local value without undermining investor confidence. It should learn from its first petroleum agreement without pretending that the circumstances under which it was signed are the same as those that exist today.
The debate should not be reduced to whether Guyana “gave away” too much or whether companies should simply be made to pay more. The more useful question is what fiscal and regulatory framework will deliver the greatest long-term benefit while keeping investment, production, and local capacity growth on track.
Trinidad’s royalty cut helps sharpen that question. It shows that even countries with long oil and gas experience sometimes make terms more attractive to unlock development.
Guyana’s resources are valuable. But their value is only fully realized when they are responsibly developed, efficiently regulated, and converted into lasting national gains.
