Integrated Petrophysical Analysis, Seismic Interpretation, and <scp>3D</scp> Static Reservoir Modelling for Rock Typing and Geomechanical Characterisation of Cretaceous Reservoirs in the Arcadia and Dorra Oil Fields, Western Desert, Egypt

ABSTRACT This study comprehensively evaluates the petrophysical properties and seismic characteristics of the Cretaceous reservoirs in the Arcadia and Dorra hydrocarbon oil fields in the Western Desert, Egypt. The focus is on the Alam El Bueib Formation, specifically its AEB‐3D, AEB‐3E and AEB‐3G sub‐members, which exhibit significant heterogeneity in lithology, comprising sandstone, limestone and shale. The analysis reveals that these sub‐members have varying net pay thicknesses, effective porosity and hydrocarbon saturation levels. AEB‐3D has a net pay thickness of 2–19 ft, a shale volume of 4%–24%, an effective porosity of 11%–17% and a hydrocarbon saturation of 55%–68%. AEB‐3E shows a net pay thickness of 7–18 ft, a shale volume of 6%–16%, an effective porosity of 9%–15% and hydrocarbon saturation of 49%–64%. AEB‐3G exhibits a net pay thickness of 10–43 ft, a shale volume of 4%–11%, an effective porosity of 9%–15% and hydrocarbon saturation of 46%–80%. Core data were utilised to validate the log‐derived parameters, showing a strong correlation between log‐derived and core‐derived porosities (R 2 = 0.957). Four distinct rock geomechanical and flow types were identified, using techniques such as the Reservoir Quality Index (RQI), Flow Zone Indicator (FZI) and Hydraulic Flow Units (HFUs). This study also assesses the elastic moduli and rock strength parameters, revealing high variability across the formations due to lithological heterogeneity. The Abu Roash G Member was found to be the least stable, with a high Poisson's ratio, indicating lower stiffness. In contrast, the Bahariya Formation demonstrated moderate to high bulk moduli, suggesting better stability, while the AEB‐3D Member showed the highest mechanical strength. Integrating well logs, seismic reflection data and geomechanical data enabled the construction of detailed 3D models, improving the reduction in drilling risk and the determination of reservoir petrophysical properties, thus informing future exploration and development strategies. The workflow presented in this study demonstrates the value of integrating petrophysical, geomechanical and seismic interpretation techniques to enhance understanding of reservoir quality controls. This approach is essential for developing target reservoirs in the study area and can be applied to similar geological settings elsewhere.