GLIAG-GSB-2026-1107-01 · Revision 1.1 · 7 November 2026
Marcel P.T. Chin-A-Lien · GLIAG GSB Intelligence Platform (GIP) · Zoetermeer & Paramaribo · ORCID 0009-0007-1649-602X
DOI: 10.5281/zenodo.24035532 · Licence CC BY-NC-ND 4.0
Summary. The Guyana–Suriname Basin became a working petroleum system because four events lined up in time and space: Jurassic to Early Cretaceous rifting built the container, Albian–Turonian marine anoxia laid down the ACT source, Late Cretaceous canyon-fed turbidites delivered the reservoirs, and Cenozoic burial started oil generation about 55 million years ago in the deep kitchen and about 34 million years ago on its flanks (Schwarzer and Krabbe, 2009). The Liza-1 discovery of May 2015, with more than 90 m of oil-bearing sandstone, and the GranMorgu final investment decision of 1 October 2024 are the commercial proof of that alignment (ExxonMobil, 2015; TotalEnergies, 2024).
This essay links nine conceptual palaeogeographic panels to those events and to the questions an appraisal team must still answer. It is a literature-based interpretation that builds on the author’s earlier GLIAG work on the Golden Lane kitchen and the Tambaredjo migration route. It is not a quantitative plate reconstruction, a calibrated basin model or a resource assessment.
The basin occupies the northeastern margin of South America beside the Guiana Shield, where two Atlantic openings meet. Saul and Nicholson (2026) divide its fill into five megasequences. MS-0 (Late Triassic to Middle Jurassic) records Central Atlantic rifting and transform-margin development. MS-1 (Middle Jurassic to Aptian) is the Central Atlantic post-rift, with low sediment input of about 122 km³/Myr. MS-2 (Aptian to Albian) records Equatorial Atlantic rifting, transform motion along the Equatorial Atlantic Fracture Zone and a step up in supply to about 2,000 km³/Myr. A single breakup age therefore hides real along-strike differences in crustal thinning and accommodation.
Inheritance is visible in the earliest regional seismic synthesis. Using about 3,000 km of 2D seismic and 16 offshore wells, Yang and Escalona (2011) placed the main Cretaceous depocentre in the southeast, over a free-air gravity low that they read as a basement depression inherited from Jurassic rifting. Rouby et al. (2023) add the sediment-supply side: Late Jurassic Central Atlantic rifting produced little relief and favoured carbonate platforms, whereas Early Cretaceous Equatorial Atlantic rifting raised relief and siliciclastic supply.
The first four panels progress from a Gondwana context at 220 Ma, through Central Atlantic opening at 170 Ma and equatorial rifting at 125 Ma, to the post-separation configuration at 105 Ma. These dates are illustrative snapshots, not the onset or completion of every local tectonic event. The 170 Ma panel shows the broader Central Atlantic context; on the Guiana margin itself, the rift-to-drift transition spans the Middle to Late Jurassic in the sources cited above. The two continental outlines convey relative separation only and do not fix palaeolongitude, palaeolatitude or rotation.
The 94 Ma panel marks the Cenomanian–Turonian transition and Oceanic Anoxic Event 2 (OAE2). The event has a local record: Ocean Drilling Program Leg 207 recovered tens of metres of laminated black shale on the Demerara Rise, spanning the Cenomanian to Santonian and including OAE2 (Shipboard Scientific Party, 2004). Offshore Suriname, the North Coronie-1 well sampled a thick, immature Upper Albian–Cenomanian section of good to excellent, oil-prone Type II marine shale. Its bulk kinetics matched the time-equivalent La Luna Formation of Venezuela (Schwarzer and Krabbe, 2009), the source rock the author revisited in Maracaibo Continued (Chin-A-Lien, 2026d).
OAE2 is a time anchor, not the whole source succession. Staatsolie’s GeoAtlas overview names the Albian–Cenomanian–Turonian (ACT) and Late Aptian source rocks as proven, identifies the ACT as the primary contributor to both the onshore fields and the recent offshore discoveries, and classes Early Cretaceous and Jurassic source rocks as unproven (Staatsolie, 2026). Source quality, thickness, preservation and maturity vary laterally; the purple band in panel 5 is an interpretive category, not a mapped facies boundary.
The 75 Ma panel represents Late Cretaceous deepwater sediment dispersal. Kelly and Doust (2016) list four elements shared by the Suriname–Guyana and Ghana–Ivorian basins: erosional canyons that carried coarse shelf clastics into deep water, a broad shelf whose longshore currents sorted sand into the canyon heads, a mature Cenomanian–Turonian source in the basin centre, and shelf-margin fault networks that link the rift and drift sequences. Their analogue is Mahogany, discovered offshore Ghana in June 2007 and developed as the Jubilee field. Saul and Nicholson (2026) measure the matching supply signal: about 3,000 km³/Myr during MS-3A (Albian to Oligocene), routed through large canyon systems. Liza-1, drilled to 17,825 ft in 2015, found more than 295 ft (90 m) of high-quality oil-bearing sandstone reservoirs, the first significant oil find offshore Guyana (ExxonMobil, 2015).
Sediment supply was episodic. Rouby et al. (2023) describe alternating carbonate development and stronger siliciclastic delivery, controlled by rift relief, lateritic weathering and drainage reorganization. They attribute Late Cretaceous sand delivery to drainage reorganization over a steadily eroding shield, and the tapping of Andean sediment through the present-day Orinoco and Amazon rivers to the Plio-Pleistocene. Marine records place the onset of the transcontinental Amazon at about 9.4–9 Ma (Hoorn et al., 2017). On the Guyana margin, MS-4 begins at about 11.6 Ma and raises supply to about 17,000 km³/Myr, roughly an order of magnitude above MS-3; it holds about 41% of the basin’s sediment budget (Saul and Nicholson, 2026). The modern Amazon must therefore not be projected backward as the supplier of the Cretaceous reservoirs. The 15 Ma panel shows a shield-fed Miocene margin shortly before that step change, not an established Amazon routing system.
The 40 Ma and 15 Ma panels emphasize burial and charge. In their offshore Suriname model, Schwarzer and Krabbe (2009) placed significant generation from about 55 Ma (Late Paleocene) in the deeper kitchen and from about 34 Ma (Late Eocene) on its flanks. By 23 Ma about 75% of the convertible kerogen in the deep kitchen had reacted, against about 25% on the flanks; expulsion began at about 50 Ma, and migration into the present shelf break started at about 25 Ma and accelerated from the Late Miocene. The 40 Ma panel therefore shows an Eocene stage between those two onsets, not a basin-wide first-generation date. The timings are model-dependent and apply to the modelled area only.
The author’s earlier GLIAG work points in the same direction. A 0 Ma top-ACT maturity screen places a 0.6–1.3 %Ro belt beneath the Golden Lane, from Stabroek southeast through Block 58 and Block 52, which makes the fairway both kitchen and receiver of charge (Chin-A-Lien, 2026b). The Tambaredjo study places oil generation mainly on the southern kitchen flank after 35 Ma, followed by about 150 km of migration in Upper Cretaceous carriers into Paleocene sands (Chin-A-Lien, 2026c), consistent with the 100–150 km updip migration inferred by Schwarzer and Krabbe (2009). Both are screening-grade interpretations, not calibrated basin models. The post-11.6 Ma MS-4 loading step and its mass-transport deposits may also have changed pressure and maturation at depth; GLIAG treats that link as a working hypothesis (Chin-A-Lien, 2026e).
Source deposition, generation, expulsion, migration and accumulation are separate events. Their overlap with trap formation and seal survival determines charge efficiency. A mature source interval does not by itself prove that a nearby trap received, retained or preserved an economic accumulation. Older charge may also be redistributed by later fault movement, remigration or leakage.
The practical appraisal question is how this geological history controls connected reservoir volume and producibility. Suriname’s first offshore development will test that directly: GranMorgu on Block 58 is designed around a 220,000 bbl/d FPSO producing the Sapakara and Krabdagu fields, with first oil planned for 2028 (APA, 2024; TotalEnergies, 2024). Channel stacking, fan-lobe amalgamation and mudstone barriers should be tested against pressure communication, fluid contacts, core description and well-test response. These are proposed evaluation steps, not measured outcomes in this synthesis. Depositional continuity on a palaeogeographic sketch is insufficient evidence of dynamic connectivity.
GLIAG’s view is that basin-scale success depends on the sequence and spatial alignment of events. Prospect ranking should pair reservoir prediction with calibrated burial history, source-specific kinetics, migration access and preservation. Production forecasts then require reservoir-scale evidence for permeability, compartmentalization and pressure support. Regional geological art can organize that reasoning; it cannot replace the measurements.
Evidence summary
FACT. Five megasequences with dated supply rates (Saul and Nicholson, 2026). OAE2 black shale on the Demerara Rise (ODP Leg 207, 2004). Proven ACT and Late Aptian sources (Staatsolie, 2026). Modelled generation onset at about 55 Ma (deep kitchen) and 34 Ma (flanks) offshore Suriname (Schwarzer and Krabbe, 2009). Liza-1 discovery, May 2015. GranMorgu FID, 1 October 2024.
MISSING. No plate-rotation files or restored palaeogeography were used. No public, calibrated basin-wide burial and kinetics model exists for both countries. The complete Staatsolie GeoAtlas was not reviewed. Oil-family evidence separating Late Aptian from ACT charge is not public at basin scale. The Jurassic and Early Cretaceous systems remain unproven.
GLIAG JUDGEMENT. GLIAG’s view is that the basin works because container, source, reservoir and burial aligned in the southeast, and that appraisal value now lies more in pressure and connectivity data than in further regional mapping.
TRIGGER. A well proving Jurassic or Early Cretaceous charge outboard of the Golden Lane; published oil-family geochemistry separating Aptian from ACT oils; release of the full GeoAtlas kinetics; GranMorgu production and pressure data after first oil.
Keywords: Guyana–Suriname Basin; Equatorial Atlantic; Central Atlantic; palaeogeography; ACT source rock; Late Aptian; OAE2; Demerara Rise; turbidites; charge timing; burial history; Amazon; reservoir connectivity.
Figure 1. Conceptual artistic synthesis of relative continental separation and later margin evolution, conceived by Marcel P.T. Chin-A-Lien and produced as AI-assisted illustration for this essay. Panels are not drawn to a common scale or projection. Land, shelf, ocean, source-facies and sand colours are interpretive categories; their boundaries are not mapped observations. GSB dots are schematic locators; fan symbols do not delineate discoveries. The 0 Ma panel denotes the present geological configuration.
Reconstruction limits. No plate-rotation files, restored well coordinates, quantitative palaeobathymetry or eustatic sea-level curve were used. Ages are rounded snapshots. Exact coastlines, motions, basin outlines and source or reservoir extents require independently validated geospatial reconstruction. A nine-panel geological poster format informed the layout only; no palaeogeography or sea-level values were taken from it.
| Panel | Age | What it shows | Main support | Caveat |
|---|---|---|---|---|
| 1 Gondwana | 220 Ma | Inherited shield basement before opening | Saul and Nicholson (2026), MS-0 | No rotation or latitude implied |
| 2 Central Atlantic | 170 Ma | Northern rifting and opening | Rouby et al. (2023); Saul and Nicholson (2026) | Local rift-to-drift spans Middle–Late Jurassic |
| 3 Equatorial rifting | 125 Ma | Faults and segmented accommodation | Saul and Nicholson (2026), MS-2 | Snapshot, not onset date |
| 4 Transform breakup | 105 Ma | South America separates from Africa | Saul and Nicholson (2026), MS-2/MS-3 | Separation diachronous along strike |
| 5 Source rock seas | 94 Ma | OAE2 and ACT marine source | ODP Leg 207 (2004); Staatsolie (2026) | OAE2 is not the whole ACT |
| 6 Deepwater sands | 75 Ma | Canyons, fans, mudstone seals | Kelly and Doust (2016); ExxonMobil (2015) | Fans are symbols, not discoveries |
| 7 Burial and charge | 40 Ma | Deep kitchen active, flanks about to start | Schwarzer and Krabbe (2009) | Model-specific timing |
| 8 Margin progradation | 15 Ma | Shield-fed Miocene margin | Yang and Escalona (2011); Rouby et al. (2023) | Precedes Amazon step at about 11.6–9 Ma |
| 9 The modern basin | 0 Ma | Multiple plays and active kitchens | Staatsolie (2026); Chin-A-Lien (2026b) | Screening maturity, not calibrated |
| # | Revision 1 | Revision 1.1 |
|---|---|---|
| 1 | Title read “Guyana Suriname Basin”. | En dash restored: “Guyana–Suriname Basin”. |
| 2 | Byline without titulatuur, ORCID or location; platform named “GLIAG Intelligence Platform”. | Standard GLIAG byline, ORCID, Zoetermeer & Paramaribo; platform name “GLIAG GSB Intelligence Platform (GIP)”. |
| 3 | Yang and Escalona (2011) cited for normal and transform segments. | That point is not in their abstract; it is now cited to Saul and Nicholson (2026). Yang and Escalona are cited for the inherited southeastern depocentre. |
| 4 | Yang and Escalona pages 1339–1369. | Corrected to 95(8), 1339–1368. |
| 5 | Rouby et al. without issue or co-authors; Kelly and Doust without issue. | Geosphere 19(3); co-authors named; Netherlands Journal of Geosciences 95(4). |
| 6 | Staatsolie “less firmly demonstrated older possibilities”. | Staatsolie’s own terms: ACT and Late Aptian proven, Early Cretaceous and Jurassic unproven, ACT the primary contributor. |
| 7 | Schwarzer and Krabbe timing described only qualitatively. | Model numbers added: generation about 55 Ma (deep) and 34 Ma (flank), 75% versus 25% conversion by 23 Ma, expulsion about 50 Ma, 100–150 km migration to Tambaredjo. |
| 8 | No local OAE2 evidence. | ODP Leg 207 Demerara Rise black shales added. |
| 9 | Amazon caution without dates. | Hoorn et al. (2017) onset 9.4–9 Ma and Saul and Nicholson (2026) MS-4 from about 11.6 Ma added; the 15 Ma panel is described as shield-fed. |
| 10 | “West Africa” analogue. | Specified as the Ghana–Ivorian basins and Mahogany/Jubilee (2007). |
| 11 | No discovery or development evidence. | Liza-1 (May 2015) and GranMorgu FID (1 October 2024) added. |
| 12 | No link to the author’s earlier research. | Petroleum-systems, Golden Lane kitchen, Tambaredjo, mass-transport and Maracaibo work cited and linked. |
| 13 | No evidence box. | FACT · MISSING · GLIAG JUDGEMENT · TRIGGER box added. |
| 14 | No panel guide. | Reading guide to the nine panels added. |
| 15 | Editorial note “prepared for” the author and reference to “the supplied France poster”. | Standard research-integrity and AI disclosure; poster-format note rewritten. |
| 16 | No licence, legal notice, author profile or citation line. | Full GLIAG publication back matter added; CC BY-NC-ND 4.0. |
Information and no advice. This publication is independent GLIAG research for professional discussion and education. It is not investment, securities, legal, tax, accounting, reserves, engineering, environmental, technical or public-policy advice. No reader should acquire, sell, finance or value an asset, licence, security or project on this publication alone. Obtain independent professional advice and perform full technical, commercial, legal and regulatory due diligence.
Evidence and forward-looking statements. Public data may be incomplete, delayed, revised or inaccurate. Model timings, maturity screens, schedules and development plans are conditional and may change. Nothing in this essay is a prospect valuation, reserves or resources estimate under SPE-PRMS, a competent-person report or an investment recommendation.
Independence and third parties. GLIAG is not represented here as a sponsor, operator, licence holder or equity investor in the projects or acreage discussed. References to AAPG, SPE, Staatsolie, the Ocean Drilling Program, operators and authors are for attribution and context. No endorsement, partnership, approval or affiliation is implied.
Copyright and proprietary rights. Copyright © 2026 Marcel P.T. Chin-A-Lien and GLIAG Intelligence B.V. The text and figure of this edition are released under the CC BY-NC-ND 4.0 licence stated below; all other rights are reserved. The licence does not extend to the GIP platform, its software, databases, models, workflows or interface. GLIAG, GIP, Golden Lane, GBW and ASK Marcel are proprietary names and marks claimed by their owner. Third-party facts, data and publications remain the property of their respective owners and are used with attribution.
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The essay uses public sources and the author’s own earlier publications. No confidential data were used. Interpretation and all GLIAG judgements are attributed to Marcel P.T. Chin-A-Lien. Perplexity Computer, an AI agent system, assisted with source verification, drafting, editing, illustration and document preparation under the author’s direction; it is not an author, and the named author is responsible for every claim. For each external reference, the abstract or public record was consulted, as noted below. This essay has not undergone journal peer review and implies no AAPG or SPE endorsement.
APA Corporation (2024). APA announces final investment decision for first oil development offshore Suriname. Press release, 1 October 2024. https://investor.apacorp.com/news-releases/news-release-details/apa-announces-final-investment-decision-first-oil-development/
ExxonMobil (2015). ExxonMobil announces significant oil discovery offshore Guyana. Press release, 20 May 2015. https://investor.exxonmobil.com/company-information/press-releases/detail/493/exxonmobil-announces-significant-oil-discovery-offshore
European Union (2019). Directive (EU) 2019/790 on copyright and related rights in the Digital Single Market, Article 4(3). https://eur-lex.europa.eu/eli/dir/2019/790/oj
Hoorn, C., Bogotá-A, G.R., Romero-Baez, M., Lammertsma, E.I., Flantua, S.G.A., Dantas, E.L., Dino, R., do Carmo, D.A. and Chemale, F. (2017). The Amazon at sea: onset and stages of the Amazon River from a marine record, with special reference to Neogene plant turnover in the drainage basin. Global and Planetary Change, 153, 51–65. Abstract consulted. https://doi.org/10.1016/j.gloplacha.2017.02.005
Kelly, J. and Doust, H. (2016). Exploration for Late Cretaceous turbidites in the Equatorial African and northeast South American margins. Netherlands Journal of Geosciences, 95(4), 393–403. Abstract and Utrecht University record consulted. https://doi.org/10.1017/njg.2016.36
Rouby, D., Loparev, A., Chardon, D., Bajolet, F., Dall’Asta, M., Paquet, F., Fillon, C., Roig, J.-Y. and Ye, J. (2023). Sediment routing systems to the Atlantic rifted margin of the Guiana Shield. Geosphere, 19(3), 957–974. Abstract consulted. https://doi.org/10.1130/GES02561.1
Saul, D. and Nicholson, U. (2026). Tectonostratigraphic evolution of the Guyana Basin: implications for sediment routing and slope stability. Basin Research, 38(2), e70097. Open-access article (CC BY) consulted. https://doi.org/10.1111/bre.70097
Schwarzer, D. and Krabbe, H. (2009). Source rock geochemistry and petroleum system modeling in the Guyana Basin, offshore Suriname. AAPG Hedberg Research Conference, Napa, California, 3–7 May 2009. Search and Discovery Article #90091. Extended abstract consulted; modelling results retain their original geographic and methodological limits. https://www.searchanddiscovery.com/abstracts/html/2009/hedberg/abstracts/extended/schwarzer/schwarzer.htm
Shipboard Scientific Party (2004). Leg 207 summary. In Erbacher, J., Mosher, D.C., Malone, M.J., et al., Proceedings of the Ocean Drilling Program, Initial Reports, 207. College Station, TX. https://doi.org/10.2973/odp.proc.ir.207.2004
Staatsolie (2026). Petroleum Geological Atlas (GeoAtlas), online geological overview. Staatsolie Maatschappij Suriname N.V. Accessed 7 November 2026; the complete atlas was not reviewed for this essay. https://www.staatsolie.com/en/open-door-offering/geoatlas/
TotalEnergies (2024). Suriname: TotalEnergies announces final investment decision for the GranMorgu development on Block 58. Press release, Paramaribo, 1 October 2024. https://totalenergies.com/newsroom/suriname-totalenergies-announces-final-investment-decision-granmorgu/
Yang, W. and Escalona, A. (2011). Tectonostratigraphic evolution of the Guyana Basin. AAPG Bulletin, 95(8), 1339–1368. Abstract and bibliographic record consulted. https://doi.org/10.1306/01031110106
Chin-A-Lien, M.P.T. (2026a). Petroleum Systems Analysis of the Guyana–Suriname Basin with the GLIAG methodology. GLIAG-PS-GSB-20261030-001, Revision 1.1. Zenodo. https://doi.org/10.5281/zenodo.23815989
Chin-A-Lien, M.P.T. (2026b). Golden Lane: kitchen and receiver of ACT charge. Petroleum & Energy Insights, 7 October 2026. https://petroleumenergyinsights.com/golden-lane-kitchen-and-receiver-of-act-charge/
Chin-A-Lien, M.P.T. (2026c). Hydrocarbon generation, migration and trapping in Suriname’s Tambaredjo. Petroleum & Energy Insights, 12 October 2026. https://petroleumenergyinsights.com/hydrocarbon-generation-migration-and-trapping-in-surinames-tambaredjo/
Chin-A-Lien, M.P.T. (2026d). Maracaibo Continued: generation and migration of hydrocarbons, revisited after 42 years (1984–2026). GLIAG-MAR-PS-1984-2026-001, Revision 1.1. Zenodo. https://doi.org/10.5281/zenodo.23887976
Chin-A-Lien, M.P.T. (2026e). Mass transport complexes as four-dimensional petroleum system modifiers: sediment routing, burial, pressure, generation, migration, trapping and development strategy in the southeastern Golden Lane, offshore Suriname. Revision 10, 19 October 2026. Zenodo. https://doi.org/10.5281/zenodo.23481005. Web essay: Mass-transport effects on Suriname’s petroleum systems, Petroleum & Energy Insights, 16 October 2026. https://petroleumenergyinsights.com/mass-transport-effects-on-surinames-petroleum-systems/
Petroleum & Energy Insights, the author’s essay library. https://petroleumenergyinsights.com/
Drs. Marcel P.T. Chin-A-Lien, MBA, M.Sc., Ing., geologist, is Principal Founding Partner and Chief Architect of GLIAG. AAPG Certified Petroleum Geologist #5201-1996; EFG European Geologist #92-1996; AIEN Energy Negotiator. He works from Zoetermeer and Paramaribo on the petroleum systems, fiscal design and development strategy of the Guyana–Suriname Basin, and designed GIP. Scan the code for his essay library, Petroleum & Energy Insights.
GLIAG (Golden Lane Investments Advisory Group) is an independent petroleum, energy and strategic-advisory platform focused on Suriname, Guyana and the wider Caribbean–South American region. It acts as Owner’s Engineer, project-management consultant and strategic adviser to governments, national oil companies, development-finance institutions and investors, and develops the GLIAG GSB Intelligence Platform (GIP).
The author leads GLIAG, which develops GIP and intends to license it commercially. GLIAG is not a sponsor of, or equity investor in, any project or licence discussed.
© 2026 Marcel P.T. Chin-A-Lien and GLIAG Intelligence B.V. Released under the Creative Commons Attribution-NonCommercial-NoDerivatives 4.0 International licence (CC BY-NC-ND 4.0), https://creativecommons.org/licenses/by-nc-nd/4.0/. Third parties keep their rights in the data, statements and publications cited.
Cite as: Chin-A-Lien, M.P.T. (2026). Geological evolution of the Guyana–Suriname Basin: from inherited continental architecture to a working petroleum system. GLIAG-GSB-2026-1107-01, Revision 1.1, 7 November 2026. GLIAG, Zoetermeer & Paramaribo. Zenodo. https://doi.org/10.5281/zenodo.24035532
Revision history: Revision 1 (7 November 2026) was the author’s review edition and was not deposited. Revision 1.1 (7 November 2026) is the first public edition; its changes are listed in the amendment register.
Text and data mining. The author expressly reserves the rights of reproduction and extraction of this work for text and data mining, including the training of artificial-intelligence systems, under Article 4(3) of Directive (EU) 2019/790.
Correspondence: info@gliag.com · petroleumenergyinsights.com
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