One Billion Barrels, Zero Refined

Why the Guyana–Suriname Basin needs its own refinery — and why 2028 is the last realistic window to build it

Drs. M.P.T. Chin-A-Lien, MBA, M.Sc., Ing. Geologist
Certified Professional Geologist Nr. 5201-1996 (AAPG) · Chartered European Geologist Nr. 92-1996 (EFG) · Energy Negotiator, June 2021 (AIEN)
Principal Founding Partner & Chief Architect, GLIAG – 11 July 2026

GLIAG-WP-2026-REFINERY-002 · Paramaribo / Delft · 11 July 2026

A basin that exports every barrel it produces has not yet built an economy. It has only rented out its geology.

01 – The Silent Export

Since Liza-1 first oil in December 2019, the Guyana–Suriname Basin has moved from frontier province to top-ten global producer. By November 2025, daily production had crossed 900,000 barrels per day from four FPSOs in the Stabroek Block. Full-year 2025 output averaged roughly 716,000 bpd — about 260 million barrels for the year alone.

Cumulative production since first oil is now approaching one billion barrels. Not one of them has been refined in the basin itself.

~1 bn bbl – PRODUCED SINCE 2019, ZERO REFINED LOCALLY

~12 bn bbl – REMAINING RECOVERABLE RESOURCE, BASIN-WIDE

US$17.8 bn – GUYANA CRUDE EXPORT EARNINGS, 2025

The reserve base ahead is larger still. Stabroek alone holds an estimated 11 billion barrels of oil-equivalent recoverable resource. Add Suriname’s Block 58 GranMorgu — 760 million barrels sanctioned — plus the follow-on discoveries at Sapakara, Krabdagu, Longan and Baja, and the basin’s remaining producible resource sits near 12 billion barrels of light, sweet crude: the highest-value molecule in the Atlantic Basin.

The Natural Resource Fund had accumulated more than US$7.8 billion by September 2025. Every one of those dollars came from crude sold as crude. Every incremental dollar of refined-product value — gasoline, jet, diesel, naphtha, LPG — was captured somewhere else.

02 – Tracing the Liftings

Guyana’s commercial grades — Liza, Unity Gold, Payara Gold — are premium light, sweet crudes ideally suited to European Atlantic Basin refineries and US Gulf Coast complex refiners. That is exactly where they go.

DESTINATION	SHARE OF EXPORTS	NOTES
Europe	~60–66%	Rotterdam hub, Fawley (UK), Spain, Italy, France, Germany
United States	~20%, rising	~60% to West Coast, ~37% to Gulf Coast complex refiners
East Asia	New in 2025 — 24 cargoes	China, India, Malaysia, Thailand; Panama as transshipment hub
Other	Marginal, growing	Turkey, Brazil, occasional West Africa

The map is unmistakable: the basin’s crude flies past the region it is drilled in. Suriname’s only functioning refinery — the Staatsolie Tout Lui Faut plant — runs a 15,000–16,200 bpd nameplate on domestic Saramacca heavy crude, not on light sweet offshore molecules. It is a fine legacy asset. It is not an answer to a twelve-billion-barrel reserve base.

03 – Quantifying the Leakage

The value a refiner captures above the crude price is the refining margin. Published 2025 benchmarks for light, sweet Atlantic Basin crudes ran roughly US$14–16/bbl on the US Gulf Coast, US$1–10.5/bbl in Northwest Europe, and US$4–7/bbl in Singapore.

Applying a conservative blended margin of US$12/bbl, weighted to the actual destination mix, the arithmetic is stark:

• Already captured elsewhere: ~900 million barrels shipped × US$12/bbl ≈ US$10.8 billion in refining margin — booked in Fawley, Rotterdam, Corpus Christi, Los Angeles and Jamnagar, not in Georgetown or Paramaribo.
• At stake on remaining reserves: ~12 billion barrels × US$12/bbl ≈ US$144 billion. Under a realistic upside case — US$15/bbl blended margin across 13 billion barrels including future exploration success — the figure rises to ~US$195 billion.
• The petrochemical premium: naphtha, LPG and middle-distillate cuts feeding integrated petrochemicals typically add a further US$3–8/bbl of net-back — a second layer of leakage beyond the fuel slate alone.

Before geopolitics of import dependence, before the FX outflow every time refined product is bought back from Trinidad, Curaçao or the US Gulf Coast, and before any local-content multiplier, the basin is quietly exporting somewhere between US$140 billion and US$200 billion of downstream margin over the life of its light-sweet reserve.

Twelve billion barrels of geology. Zero barrels of refining capacity built to meet them.

04 – GranMorgu 2028 Changes the Argument

Until the Final Investment Decision on Block 58 GranMorgu — taken 3 October 2024 by TotalEnergies (operator, 50%) and APA Corporation (50%) — the case for a Suriname refinery rested on borrowed feedstock and aspirational reserve numbers. It no longer does.

PARAMETER	VALUE
First oil	2028
FPSO nameplate	220,000 bpd, all-electric, sub-16 kg CO2e/boe
Sanctioned reserves	760 million barrels, 20–25 year producing life
Staatsolie equity share	20% ≈ ~44,000 bpd peak equity oil
Total project capex	US$10.5–13.2 billion
Suriname lifetime state revenue	US$8–32 billion, depending on US$45–85/bbl price path

The number that matters for refinery planners is the 44,000 bpd of Staatsolie equity oil — before Block 52, Block 42 and further discoveries add sovereign barrels on top. This is the anchor feedstock a modular refinery has been waiting for: light API, low sulfur, high middle-distillate yield, mapping cleanly onto a simple to medium-complexity hydroskimming-plus-hydrotreating configuration.

05 – The Modular Economics

The standard objection — that the basin is too small and too remote to host a competitive refinery — does not survive the 2025 modular-refinery cost curve.

• Capex per bpd: US$20,000–40,000 for skid-mounted modular units, versus multiples of that for grassroots conventional refineries.
• Deployment window: 12–18 months from EPC award to first product, versus 4–6 years conventional.
• Scalability: built in 5,000–10,000 bpd blocks; start at 30,000–50,000 bpd for regional self-sufficiency, scale toward 100,000–150,000 bpd as GranMorgu tie-backs and Block 52 gas-condensate feed mature.
• Configuration: hydroskimming, naphtha reforming, middle-distillate hydrotreating, LPG recovery — no coker required, because the feed is 32° API sweet, not a heavy sour crude.

A 50,000 bpd modular unit costs on the order of US$1.0–1.5 billion. At a US$12/bbl blended margin, gross refining revenue runs near US$219 million per year — a payback profile of 5–7 years at conservative assumptions, within reach of DFI blended finance, particularly when structured against Staatsolie’s 44,000 bpd of equity crude as a physical off-take contract.

The right question is not whether a Suriname modular refinery can match Rotterdam’s scale. It cannot, and does not need to. The right question is whether it can capture US$10–14/bbl of margin, displace roughly US$1 billion a year of refined-product imports across Suriname, Guyana and the eastern Caribbean, and monetize Staatsolie’s equity crude at a higher net-back than raw export. On the 2025 numbers, the answer is yes on all three counts.

06 – Five Moves Before First Oil

1. Lock in feedstock now. Staatsolie should ring-fence its GranMorgu 20% equity oil under a long-term crude supply agreement to a to-be-formed refining SPV, priced on a Dated Brent-linked formula with a transparent netback. Every barrel not committed by 2027 is a barrel marketed away to Rotterdam or Corpus Christi.
2. Structure the refinery as a self-funding SPV. Equity from Staatsolie, a strategic partner, and regional sovereign wealth; debt from a DFI syndicate; off-take underpinning senior debt. The GranMorgu FID makes this bankable now — 2028 is the deadline, not an aspiration.
3. Integrate the Gas-to-Shore corridor. Associated gas from Block 58, Block 52 and the basin’s emerging gas-condensate system provides the cheapest possible refinery utility — process heat, hydrogen feedstock, firm grid power.
4. Regionalise the off-take. Suriname, Guyana and CARICOM together import over 200,000 bpd of refined product at premium Caribbean freight-inclusive pricing. A regional supply pact turns the refinery from a national asset into a Guyana–Suriname–Caribbean energy-security instrument — the move Trinidad made a generation ago with Atlantic LNG.
5. Fix the fiscal envelope in law. The margin math only holds under a predictable regime — VAT and import-duty carve-outs on refinery inputs, ring-fenced income tax, PSC-consistent transfer pricing.

GLIAG DOCTRINE

A reserve base is potential value. A refinery is captured value. Between the two sits every dollar a basin will either keep or export.

07 – Bottom Line

One billion barrels of Guyana–Suriname light sweet crude have already been landed in refineries on three other continents. Twelve billion more are scheduled to follow. The refining margin already captured elsewhere is roughly US$10.8 billion. The margin still at stake is US$140–200 billion — before petrochemicals, before FX savings, before jobs.

GranMorgu’s 220,000 bpd FPSO and Staatsolie’s 20% equity share move this from theory to bankable transaction. A 50,000–100,000 bpd modular refinery, built in 12–18 months, financed as an SPV against Staatsolie’s equity crude, integrated with Gas-to-Shore, and supplying the Guyana–Suriname–CARICOM product pool, is now the single highest-return infrastructure decision available to the basin between now and 2030.

Not one barrel refined at scale in Suriname. Not one barrel refined at all in Guyana. That is the definition of value leakage — and 2028 is the last realistic window to close it before the reserve base is fully committed on export contracts.

Soso Lobi.

SOURCES & COMPANION ESSAYS

Production & FPSO status: ExxonMobil (900k bpd milestone, 12 Nov 2025; Stabroek reserves overview; seventh development, 22 Sep 2025); OilNOW / Kaieteur; Kaieteur News.
Exports & destinations: Reuters (8 Jan 2025); Argus Media (2026); Brazil Energy Insight (Jan 2026); OilNOW; Council on Foreign Relations.
Refining margins: Argus RGV benchmark; Reuters (8 May 2025); Statista NW Europe series; Compass International modular refinery EPC benchmarks.
GranMorgu / Block 58: TotalEnergies project page; Staatsolie FID announcement (Oct 2024) and financing updates (2025); LatinFinance (2 Oct 2025); Staatsolie SHI FAQ.
Legal & fiscal context: Legal 500 Guyana energy guide; Tout Lui Faut refinery historical baseline.

Companion essays on petroleumenergyinsights.com: Invest in Suriname: A Self-Funding Modular Refinery · How a Suriname’s New Refinery Can Ensure Energy Security · Why Gas-to-Shore Infrastructure and New Refinery Are Key · Transforming Suriname’s Petroleum into Productive Power · Liza Crude: Guyana’s High-Value Light Oil Explained · The Golden Lane Corridor · Suriname Horizon 2050 and Beyond · Gas as Geopolitical Fuel · Repricing the Guyana–Suriname Basin.

© 2026 GLIAG — Golden Lane Investments Advisory Group. Paramaribo · Delft.
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This essay is intended for strategic and educational purposes and does not constitute investment advice.