“…On this basis the analyzed samples are more likely to have been deposited in a lacustrine environment consistent with earlier findings (e.g. Schull (1988), Dou et al (2002), Tong et al (2004), Makeen et al, 2015).…”
Section: Biomarker Parameters and Sulfursupporting
confidence: 91%
“…The yellow fluorescencing alginite is prominent in the abundant liptinite and would have oil generative characteristics consistent with Type I kerogen as classified by pyrolysis analysis (e.g. Makeen et al, 2015), while amorphinite likely has Type II characteristics. Both are consistent with, but not proof of lacustrine deposition.…”
“…On this basis the analyzed samples are more likely to have been deposited in a lacustrine environment consistent with earlier findings (e.g. Schull (1988), Dou et al (2002), Tong et al (2004), Makeen et al, 2015).…”
Section: Biomarker Parameters and Sulfursupporting
confidence: 91%
“…The yellow fluorescencing alginite is prominent in the abundant liptinite and would have oil generative characteristics consistent with Type I kerogen as classified by pyrolysis analysis (e.g. Makeen et al, 2015), while amorphinite likely has Type II characteristics. Both are consistent with, but not proof of lacustrine deposition.…”
“…2, 3, Table 1). The upper Albian to Cenomanian witnessed the deposition of the essentially thick sandstone sediments of the Bentiu formation from braided and meandering streams 1,[3][4][5][7][8][9] .…”
Section: Geological Setting the Evolution Of The Central And Southermentioning
confidence: 99%
“…2 ). A chronicle of published literature in the Muglad Basin shows that extensive studies have been carried out on the organic richness of the source rocks in the basin, kerogen types have been determine as well, maturity, oil-source rock correlation and hydrocarbon generative potential of the Abu Gabra formation have been studied in details 4 – 9 , 12 – 15 . Figure 2 The main stratigraphic column of the Northeastern region of the Muglad Basin.…”
The Zarga and Ghazal formations constitute important reservoirs across the Muglad Basin, Sudan. Nevertheless, the sedimentology and diagenesis of these reservoir intervals have hitherto received insignificant research attention. Detailed understanding of sedimentary facies and diagenesis could enhance geological and geophysical data for better exploration and production and minimize risks. In this study, subsurface reservoir cores representing the Zarga formation (1114.70–1118.50 m and 1118.50–1125.30 m), and the Ghazal formation (91,403.30–1406.83 m) were subjected to sedimentological (lithofacies and grain size), petrographic/mineralogic (thin section, XRD, SEM), and petrophysical (porosity and permeability) analyses to describe their reservoir quality, provenance, and depositional environments. Eight (8) different lithofacies, texturally characterized as moderately to well-sorted, and medium to coarse-grained, sub-feldspathic to feldspathic arenite were distinguished in the cored intervals. Mono-crystalline quartz (19.3–26.2%) predominated over polycrystalline quartz (2.6–13.8%), feldspar (6.6–10.3%), and mica (1.4–7.6%) being the most prominent constituent of the reservoir rocks. Provenance plot indicated the sediments were from a transitional continental provenance setting. The overall vertical sequence, composition, and internal sedimentary structures of the lithofacies suggest a fluvial-to-deltaic depositional environment for the Ghazal formation, while the Zarga formation indicated a dominant deltaic setting. Kaolinite occurs mainly as authigenic mineral, while carbonates quantitatively fluctuate with an insignificant amount of quartz overgrowths in most of the analyzed cores. Integration of XRD, SEM, and thin section analysis highlights that kaolinite, chlorite, illite, and smectite are present as authigenic minerals. Pore-destroying diagenetic processes (e.g. precipitation, cementation, and compaction etc.) generally prevailed over pore-enhancing processes (e.g. dissolution). Point-counted datasets indicate a better reservoir quality for the Ghazal formation (ɸ = 27.7% to 30.7%; K = 9.65 mD to 1196.71 mD) than the Zarga formation (17.9% to 24.5%; K = 1051.09 mD to 1090.45 mD).
“…The basin is composed by three rift cycles: Early Cretaceous (140-95 Ma), Late Cretaceous (95-65 Ma) and Paleogene (65-30Ma) and is well-known for its hydrocarbons accumulations [20]. The largest oilfields until now discovered are Heglig and Unity [17] (Figure 1a): the first is outside Block 5A and the second adjoins the block. Inside Block 5A we find the Mala and Thar Jath oilfields [18,27] (Figure 1) that are well known for their Nile Blend, a medium low-sulfur waxy crude oil [27].…”
Hydrocarbons are nonrenewable resources but today they are the cheaper and easier energy we have access and will remain the main source of energy for this century. Nevertheless, their exploration is extremely high-risk, very expensive and time consuming. In this context, satellite technologies for Earth observation can play a fundamental role by making hydrocarbon exploration more efficient, economical and much more eco-friendly. Complementary to traditional geophysical methods such as gravity and magnetic (gravmag) surveys, satellite remote sensing can be used to detect onshore long-term biochemical and geochemical alterations on the environment produced by invisible small fluxes of light hydrocarbons migrating from the underground deposits to the surface, known as microseepage effect. This paper describes two case studies: one in South Sudan and another in Mozambique. Results show how remote sensing is a powerful technology for detecting active petroleum systems, thus supporting hydrocarbon exploration in remote or hardly accessible areas and without the need of any exploration license.
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