Geochemical Maturity and Paleo-Weathering Indices of Sedimentary Succession in JV Field Greater Ughelli Depo-Belt Niger Delta Basin

Lucas, F.A.; Fregene, T.J.

doi:10.4314/jasem.v25i5.12

Cited by 2 publications

(2 citation statements)

References 2 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The findings of this study are consistent with previous research conducted in the Niger Delta Basin, which has established the presence of source rocks, reservoir rocks, and cap rocks within the sedimentary sequence [25][26][27][28][29]. However, the detailed characterization provided by the microscopic examination enhances our understanding of the specific lithofacies units and their potential as hydrocarbon-bearing formations.…”

Section: Cap Rock or Seal Rocksupporting

confidence: 90%

Lithostratigraphic Characterization and Petroleum System Elements of the MI Well, Niger Delta Basin

Efetobore,

Owenvbiugie

2023

CJAST

View full text Add to dashboard Cite

This study presents a comprehensive lithostratigraphic characterization of the MI Well in the Niger Delta Basin through microscopic examination of ditch cutting samples. The aim was to identify the lithological units and assess the presence and distribution of petroleum system elements. A total of seventy-two samples ranging in depth from 4500ft-11460ft (1372m-3493m) were analyzed, revealing four lithological units: sandstone, shale, sandy shale, and shaly sand. Through interpretation of the lithological log, the cap/seal rock, reservoir rock, and probable source rock units were identified. The lithostratigraphic model generated from the study provides a comprehensive understanding of the depth intervals and lithological properties of the identified units. The cap/seal rock, with a thickness of approximately 460ft, was found to be the top-most shale lithology. The reservoir rock, comprising sandstone, sandy shale, and shaly sand lithologies, has a thickness of around 1920ft. The lowermost massive shale lithology, approximately 3540ft thick, is interpreted as the probable source rock for the petroleum system. These findings have significant implications for hydrocarbon exploration and production in the Niger Delta Basin. The identification of lithological units and their respective roles as cap/seal, reservoir, and source rocks allows for a better assessment of the hydrocarbon potential in the MI Well. The lithostratigraphic model, along with the established lithozones, offers valuable insights for regional correlation and comparison with other wells in the basin.

show abstract

Section: Cap Rock or Seal Rocksupporting

confidence: 90%

Lithostratigraphic Characterization and Petroleum System Elements of the MI Well, Niger Delta Basin

Efetobore,

Owenvbiugie

2023

CJAST

View full text Add to dashboard Cite

show abstract

“…93.61), and 59.98-98.58 (avg. 92.07), respectively, suggest a moderate to a high degree of source area weathering (Godo et al, 2017;Lucas et al, 2021;McLennan et al, 1993).…”

Section: Discussionmentioning

confidence: 99%

Depositional Environment and Reservoir Prospect Analysis of Barail Sandstone Exposed in the Northeastern Part of Bangladesh

Alam,

Rahman,

Gazi

et al. 2024

Dhaka Univ J Earth Env Sci

View full text Add to dashboard Cite

The study characterized the Oligocene Barail sandstone in the Surma Basin from a reservoir perspective. Data were collected by direct field observations; rock samples were collected from outcrops for detailed sedimentological, petrographic, and geochemical analysis. Collected sedimentary logs are analyzed to delineate the facies associations, sandbody architecture, and depositional environment. A total of ten facies were identified, which were further grouped into three facies associations: FA1: Tidal-influenced multistorey channel-fill deposits, FA2: Fluvial multistorey channel-fill deposits, and FA3: Overbank deposits. Facies analysis suggests that the Barail sandstone was deposited in the tidal-influenced paralic to fluvial depositional settings, and channel body dimensions increase towards the top. A petrographic study shows that these sandstones are mostly litharenite (Q70F4L26) in type, and sediments were derived from quartzose recycled orogens. The average porosity of the sandstones is 16.9%; the pore spaces are of both primary and secondary origin and are mostly interconnected. Porosity distribution in the fluvial multistory channel-fill deposits (FA2)—the upper part of the sandstone succession, is less heterogeneous, while that in the tidal-influenced channel-fill deposits (FA1), occurs in the lower part is more heterogeneous. Both the depositional process and diagenesis influenced the porosity of Barail sandstones. Geochemical analysis suggests that the sandstones are chemically stable and moderately matured. The study demonstrates that the Barail sandstones may be a good petroleum reservoir. The Dhaka University Journal of Earth and Environmental Sciences, Vol. 12(1), 2023, P 69-88

show abstract

Geochemical Maturity and Paleo-Weathering Indices of Sedimentary Succession in JV Field Greater Ughelli Depo-Belt Niger Delta Basin

Cited by 2 publications

References 2 publications

Lithostratigraphic Characterization and Petroleum System Elements of the MI Well, Niger Delta Basin

Lithostratigraphic Characterization and Petroleum System Elements of the MI Well, Niger Delta Basin

Depositional Environment and Reservoir Prospect Analysis of Barail Sandstone Exposed in the Northeastern Part of Bangladesh

Contact Info

Product

Resources

About