article · Geological Journal
An assessment of ninety-two shale ditch samples from the Abu Gharadig Basin in Egypt's Western Desert provides detailed insights into regional hydrocarbon potential. Pyrolysis data shows organic richness varying between 0.53% and 4.1% by weight, with kerogen types II and III acting as fair to good oil sources. Burial history reconstruction demonstrates that sedimentation and subsidence were modest during the Late Jurassic to Early Cretaceous, high during the Late Cretaceous to Early Tertiary, and moderate during the Oligocene and Late Miocene. Basin modelling identifies the Apollonia Formation alongside the Abu Roash 'D' and 'F' members as effective source rocks that reached early oil and wet gas generation windows at distinct geological intervals. Reservoir potential occurs within the Kharita and Abu Roash 'C', 'E', and 'G' members, sealed by the Abu Roash Shale within three-way dip closure traps shaped by northwest to southeast normal faults.
Understanding when and where oil and gas formed helps geoscientists map subsurface energy resources accurately. By detailing source rock quality, burial timing, and trapping mechanisms in the Abu Gharadig Basin, this analysis clarifies how geological formations generated and contained hydrocarbons over millions of years, improving the geological understanding of oil-bearing regions.
This research provides applied geological data that can assist petroleum exploration companies and basin modellers in identifying viable drilling targets in the Western Desert. The findings define specific source, reservoir, and seal intervals alongside structural trapping mechanisms. While the analysis is an applied subsurface evaluation, it serves as early-stage exploration intelligence rather than a direct commercial product.
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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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DOI: 10.1002/gj.4938
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