Integration of seismic interpretation and well logging analysis of Abu Roash D Member, Gindi Basin, Egypt: Implication for detecting and evaluating fractured carbonate reservoirs

Sarhan, Mohammad Abdelfattah; Basal, Ahmad Mohammad Kamal; Ibrahim, Ibrahim Mohamed

doi:10.1016/j.jafrearsci.2017.08.010

Cited by 28 publications

(4 citation statements)

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“…Additionally, numerous formations act as source rocks based on subsurface geologic settings and F I G U R E 1 (a) 2D map illustrating the main E-W sedimentary basin and major tectonics in the North Western Desert, Egypt (modified after Bayoumi, 1996), (b) location map of the study area, illustrating the Karam and Assil oil concessions and the selected studied wells (GPAA-4 and ASSIL-1X wells), Abu Gharadig Basin, northern Western Desert, Egypt. geochemical analysis parameters, including the Oligocene Dabaa Formation, Lower Eocene Apollonia Formation, Late Cretaceous ARD and ARF members, Late Cretaceous Upper Bahariya Formation, Early Cretaceous Kharita and Dahab shale formations (Abdel-Fattah et al, 2018;Gawad et al, 2019;Mamdouh et al, 2023;Reda et al, 2022;Sarhan et al, 2017;Shehata et al, 2023). Notably, the Jurassic Khatatba shales are believed to be the primary source of hydrocarbons, predominantly free gas with minor associated condensates (Abdel-Fattah, 2015;Gawad et al, 2021a;Gawad et al, 2021b;Reda et al, 2022).…”

Section: Introductionmentioning

confidence: 99%

“…The basin exhibits diverse reservoir rocks, including the Early Cretaceous Alam El‐Bueib, Alamein and Kharita formations. Additionally, numerous formations act as source rocks based on subsurface geologic settings and geochemical analysis parameters, including the Oligocene Dabaa Formation, Lower Eocene Apollonia Formation, Late Cretaceous ARD and ARF members, Late Cretaceous Upper Bahariya Formation, Early Cretaceous Kharita and Dahab shale formations (Abdel‐Fattah et al, 2018; Gawad et al, 2019; Mamdouh et al, 2023; Reda et al, 2022; Sarhan et al, 2017; Shehata et al, 2023). Notably, the Jurassic Khatatba shales are believed to be the primary source of hydrocarbons, predominantly free gas with minor associated condensates (Abdel‐Fattah, 2015; Gawad et al, 2021a; Gawad et al, 2021b; Reda et al, 2022).…”

Section: Introductionmentioning

confidence: 99%

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Integrated analysis of source rock evaluation and basin modelling in the Abu Gharadig Basin, Western Desert, Egypt: Insights from pyrolysis data, burial history, and trap characteristics

Reda,

Abdel‐Fattah,

Fathy

et al. 2024

Geological Journal

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Source rock evaluation and basin modelling play crucial roles in understanding hydrocarbon potential. In this study, pyrolysis data from 92 shale ditch samples were employed to assess the source rocks in the Abu Gharadig Basin (Western Desert, Egypt). The organic richness ranged from 0.53% to 4.1% by weight, indicating varying hydrocarbon‐generating capabilities. Specifically, kerogen types II and III exhibited the potential to generate hydrocarbons, ranging from fair to good oil sources. The burial history analysis provided insights into the sedimentation and subsidence rates during different geological periods. The Late Jurassic‐Early Cretaceous period witnessed modest rates of sedimentation and subsidence. In contrast, the Oligocene and Late Miocene periods experienced medium burial rates, while the Late Cretaceous‐Early Tertiary period exhibited high burial rates. Specific formations were examined in detail, with the Apollonia Formation standing out as a significant hydrocarbon reservoir. It entered the early oil window at approximately 17.87 Ma and the wet gas window at about 17.41 Ma in the ASSIL‐1X well. However, it didn't reach the GPAA‐4 well. The Abu Roash ‘D’ member also showed promise, entering the early oil window at 38.20 and 47.38 Ma, and the wet gas window at 37.40 and 43.64 Ma. Similarly, the Abu Roash ‘F’ member exhibited favourable hydrocarbon generation, entering the early oil window at 39.90 and 54.86 Ma, and the wet gas window at 39.70 and 51.62 Ma in both the ASSIL‐1X and GPAA‐4 wells. Based on the analysis, the Apollonia, Abu Roash ‘D’ and ‘F’ members were identified as source rocks, while the Kharita, ‘C’, ‘E’ and ‘G’ members were recognized as reservoir rocks. The Abu Roash Shale acted as an effective seal rock. The geological structure of the region revealed the presence of NW‐SE normal faults, forming a three‐way dip closure trap. This research substantially enhances our comprehension of the hydrocarbon system within this basin. It achieves this by thoroughly investigating source rock evaluation, basin modelling and delivering invaluable insights into the mechanisms that govern hydrocarbon generation, expulsion and trap age.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Integrated analysis of source rock evaluation and basin modelling in the Abu Gharadig Basin, Western Desert, Egypt: Insights from pyrolysis data, burial history, and trap characteristics

Reda,

Abdel‐Fattah,

Fathy

et al. 2024

Geological Journal

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“…It is located in northern Western Desert and underwent inversion and dextral shearing during the Late Cretaceous time (Moustafa 2008;Sarhan 2017;Sarhan and Collier 2018). The main hydrocarbon reservoirs in Southwest Qarun (SWQ) Field are the sandstones of Bahariya Formation and Kharita Formation (Sarhan et al 2017a;Sarhan 2019) and the fractured carbonates of Abu Roash D Member (Sarhan et al 2017b). The SWQ-25 well located at longitude 30°31ʹ 14.410" E and latitude 29°46ʹ 18.611" N, Southwest Qarun field, Gindi Basin.…”

Section: Introductionmentioning

confidence: 99%

Total organic carbon content deduced from resistivity-porosity logs overlay: a case study of Abu Roash formation, Southwest Qarun field, Gindi Basin, Egypt

Sarhan

Basal

2020

NRIAG Journal of Astronomy and Geophysics

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The present work evaluates the hydrocarbon potentiality of Abu Roash Formation in SWQ-25 well, Southwest Qarun (SWQ) Field, Gindi Basin, Egypt. The estimation of total organic carbon content (TOC) has been deduced using the overlay between deep resistivity and porosity logs. The results show that Abu Roash A Member is fair to good source rock (TOC ranges from 0.50 to 1.28 wt. %). While, Abu Roash D Member contains fair to very good TOC values (from 0.77 to 2.92 wt. %). In contrast, Abu Roash B and E members display poor to good source rocks, with TOC varies between 0.36 to 1.74 wt. % and 0.32 to 1.42 wt. %, respectively. However, Abu Roash C Member (with TOC varies between 1.50 and 2.19 wt. %) and Abu Roash F Member (with TOC differs from 1.54 to 3.16 wt. %) indicate a good to very good source rock intervals. The neutron porosity-resistivity overlay matches the density-resistivity overlay in carbonate members (A, B, C, D and F members) but a lack of resemblance in clastic units (E and G members).

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“…Pore networks are especially important in carbonate hydrocarbon reservoirs because they control fluid flow, reservoir quality, and production results. Fractured carbonate reservoirs are a major contributor to many massive fields and play a significant role in the world's oil and gas production (Sarhan and Selim, 2023;Sarhan et al, 2017). The formation of different kinds of fractures adds to the natural heterogeneity found in rocks that contain hydrocarbons in carbonate formations.…”

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confidence: 99%

Integration of seismic interpretation and well logging analysis of Abu Roash D Member, Gindi Basin, Egypt: Implication for detecting and evaluating fractured carbonate reservoirs

Cited by 28 publications

References 1 publication

Integrated analysis of source rock evaluation and basin modelling in the Abu Gharadig Basin, Western Desert, Egypt: Insights from pyrolysis data, burial history, and trap characteristics

Integrated analysis of source rock evaluation and basin modelling in the Abu Gharadig Basin, Western Desert, Egypt: Insights from pyrolysis data, burial history, and trap characteristics

Total organic carbon content deduced from resistivity-porosity logs overlay: a case study of Abu Roash formation, Southwest Qarun field, Gindi Basin, Egypt

Editorial: Advanced techniques and applications for characterizing the hydrocarbon potential in carbonate reservoirs

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