Source rock evaluation and petroleum system modeling of the East Beni Suef Basin, north Eastern Desert, Egypt

Tawfik, Ahmed Y.; Ondrak, Robert; Winterleitner, Gerd; Mutti, Maria

doi:10.1016/j.jafrearsci.2022.104575

Cited by 4 publications

(2 citation statements)

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“…Two most widely significant regional unconformities occur between the Khoman/Apollonia Formational boundary as a result of tectonic rising, which caused the missing of around 200 m (roughly 656 ft), while the second erosion event occurred near the top of the Dabaa Formation, which has an eroded thickness of 400 m (1312 ft) (Abdel‐Fattah et al, 2017; Farouk et al, 2018; Tawfik, Ondrak, et al, 2022; Tawfik, Winterleitner, & Mutti, 2022) (Table 3). Other erosion surfaces are lower in thickness and result from faulting in A/R ‘E’, A/R ‘G’ and Upper Bahariya.…”

Section: Resultsmentioning

confidence: 99%

“…The Beni Suef Basin (BSB) is located on both banks of the Nile Valley, approximately 150 km south of Cairo (Figure 1). In the Nile Valley region, BSB is one of the hotspots for hydrocarbon exploration (Bosworth, 2015; Edress et al, 2021; Makky et al, 2014; Tawfik et al, 2023; Tawfik, Ondrak, et al, 2022, Farouk et al, 2024). The principal aim of this study is to examine the geochemistry of all source rocks from the Cretaceous succession, specifically the A/R and Kharita Formations.…”

Section: Introductionmentioning

confidence: 99%

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Geochemical evaluation and basin modelling of the Cretaceous succession in the Azhar Oil field, West Beni Suef Basin, Egypt

Farouk,

Saada,

Fagelnour

et al. 2024

Geological Journal

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Geochemical analysis was performed on the Cretaceous sequence of the Azhar‐A‐2 well in the West Beni Suef Basin (WBSB), Western Desert, Egypt, utilizing data on total organic carbon (TOC), kerogen composition, vitrinite reflectance (Ro%) and Rock‐Eval pyrolysis. In addition, a 1D basin model was built to investigate the burial and temperature history of the study area. The most important Cretaceous source rocks are predominantly reported within the Albian Kharita Formation and Late Cenomanian‐Santonian Abu Roash (AR) Formation. Based on visual kerogen tests and Rock‐Eval pyrolysis, AR Formation (A, E, F, and G) are mixed oil‐ and gas‐prone source rocks with kerogens ranging from type II to type III, where A/R ‘A and F’ Members show dominant oil‐prone kerogen with the highest generative potential, while A/R ‘E and G’ Members are more gas‐prone kerogen. Most samples of the lower Kh Formation were interpreted as gas‐prone kerogen type III with low generative potential. On the other hand, the high amount of liptinite in the visual kerogen macerals is a strong indicator that the lower Petroleum Formation is an oil‐prone rather than gas‐prone source rock. The thermal maturity of the studied members increases consistently with depth, ranging from immature at the top of the AR Formation to the main/peak oil window at the base of the Lower Kharita Formation, which served as an active source rock for the hydrocarbons generated in the WBSB. The high value of the heat flow in the Beni Suef Basin (57 and 60 mW/m2) is a good indicator for the shallowing of the active source rock depth limit depth. From the study of the basin modeling, the main mature zone reached between 9811 and 11,090 ft in the middle of the Late Cretaceous (84.3–82.5 Ma) is through the L. Kharita Formation with three phases of hydrocarbon generation according to transformation ratio, where the second phase is the main stage in which TR is 5%–50%, showing the beginning of oil expulsion (Ro: 0.73%–0.78%, possibly 0.81%).

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