When discussing Suriname’s emerging oil and gas industry, two critical terms often shape public and policy conversations — and getting their definitions wrong can lead to major misinterpretations of the country’s resource potential. Petroleum and energy advisor Marcel Chin-A-Lien breaks down these key concepts and outlines the scale of Suriname’s offshore hydrocarbon reserves in this second op-ed, making the case for planned onshore refining and gas pipeline projects.
First, Chin-A-Lien distinguishes between proven (P1) and prospective (P50/P90, yet-to-find) reserves. Proven reserves are deposits that have already been confirmed by drilling, with geologists measuring their properties and confirming they can be extracted profitably using existing technology at current market prices. These reserves qualify as tangible assets on a company’s or nation’s balance sheet. Prospective reserves, by contrast, are strong geologically-based estimates supported by seismic data and geological knowledge, but have not yet been verified by drilling. They are a guide for planning exploration activities, not a confirmed asset to base borrowing on. The expert stresses both categories matter, but they must be communicated transparently and honestly to avoid misleading the public.
Turning to confirmed reserves currently documented in Suriname, the numbers paint a transformative picture. For Block 58 oil discoveries including Maka Central, Sapakara, Krabdagu, Kwaskwasi and Keskesi, published data from operators and independent evaluators places total recoverable reserves between 2 billion and 4 billion barrels of oil equivalent. The standalone GranMorgu project alone targets production of roughly 220,000 barrels per day starting in 2028 — a production scale never before seen in Suriname’s history. For natural gas in Block 52, discoveries at Sloanea-1, Sloanea-2, SAC-1 and adjacent wells have confirmed 2.0 to 2.5 trillion cubic feet of reserves in the P50 scenario. At realistic production rates, this volume is enough to support a 33 to 35-year domestic gas program. Additional blocks, including Block 53, Block 65 and multiple deepwater blocks, have seen partial drilling with encouraging early results, placing these resources in the prospective reserve category for now.
Independent geological research focused on the shared Guyana-Suriname Basin makes clear that current proven reserves are unlikely to be the end of Suriname’s resource story. The estimate that billions more barrels of oil equivalent and tens of trillions of cubic feet of gas remain untapped beneath Suriname’s offshore waters is not speculative: the same prediction methods correctly forecast the scale of Guyana’s major discoveries between 2015 and 2024. To put this in context, neighboring Guyana has already confirmed more than 11 billion barrels of oil equivalent in less than a decade. Suriname sits in the same geological province, with the same source rock and seabed geological structure, giving geologists good reason to expect significant additional discoveries over the next 10 years, rather than poorer resource outcomes than its neighbor.
To put these large, abstract reserve numbers in human and economic terms, Chin-A-Lien offers relatable comparisons. Two billion barrels of oil equals roughly 150 years of Suriname’s current domestic oil consumption; even with significant growth in domestic energy use, that volume still equals decades of domestic fuel security. Two trillion cubic feet of gas is enough to provide electricity to every household in Suriname for multiple generations, or to power a substantial domestic industrial base including fertilizer production, chemical manufacturing and aluminum processing for decades. In short, Suriname holds enough offshore energy resources to drive a full domestic energy and industrial transformation, while still retaining enough volume for exports — a model successfully deployed for decades by Trinidad and Tobago, and built carefully by Norway since the 1970s.
This large reserve base is the core reason why two major planned projects — a new domestic refinery (NR) and a gas-to-shore (GtS) pipeline project — are economically justified, the expert argues. If reserves were only large enough to support 10 years of production, the high fixed costs of building a refinery and onshore pipeline infrastructure would never be recouped, making the projects unviable. That is not Suriname’s situation. Even conservative estimates confirm decades of producible oil and gas reserves, with additional prospective reserves that only expand the total resource base. At this scale, domestic processing of hydrocarbons, rather than exporting all raw crude and gas, makes solid financial sense, not just ideological sense.
The math supports this conclusion: A modular 30,000-barrel-per-day refinery can operate at full capacity for 20 to 30 years on a base of hundreds of millions of barrels of combined sovereign reserve access and import options — a scale Suriname already has. A 100-kilometer gas pipeline with onshore processing facilities can support decades of offtake from the 2 to 2.5 trillion cubic feet of proven gas reserves, which is also a scale Suriname already possesses. The country currently holds exactly the resource base a small nation needs to justify onshore hydrocarbon conversion, a point that has been largely missing from public debate to date, according to Chin-A-Lien.
Chin-A-Lien outlines the tangible economic benefits the two projects can deliver for Suriname, using indicative estimates that will be refined during pre-feasibility and feasibility studies. The new refinery is projected to save Suriname hundreds of millions of dollars annually in fuel import costs, while also generating tax revenue and dividends for the state. In the baseline scenario, this would improve Suriname’s balance of payments by $400 million to $700 million per year, compared to the current status quo where all fuel is imported. The gas-to-shore project would replace expensive diesel and fuel oil power generation with low-cost gas power in its early years, saving the national electricity company EBS tens to hundreds of millions of dollars annually, while also generating government revenue from royalties and taxes.
While exact figures will be refined as planning progresses, the overall scale of benefit is clear: upfront investment in the two projects over four to five years will be repaid in later decades through lower energy costs, new local jobs, increased government revenue and greater macroeconomic stability. Most importantly, this economic value stays within Suriname rather than flowing entirely abroad.
In closing, Chin-A-Lien emphasizes that the goal of this essay is not to mandate that the refinery and gas-to-shore projects must move forward. Instead, it is to demonstrate that Suriname’s proven reserve base is large enough to support building a structural, long-term domestic energy industry with smart planning. Claims that Suriname is too small or lacks sufficient scale to pursue these projects refer to the Suriname of 30 years ago. Today’s Suriname sits atop one of the world’s major hydrocarbon provinces. The geology has already delivered the resource potential; the final outcome depends entirely on the policy choices Suriname makes going forward.