The primary objective of this study is to identify and analyze the petrophysical properties of the newly investigated AEB_IIIG member reservoir in Meleiha West Deep (MWD) Field and to classify it into different rock types. Additionally, this research intends to develop mathematical equations that may be utilized to estimate permeability in uncored sections of the same well or in other wells where core samples are unavailable. The analysis focused on the pore hole records of ten wells that were drilled in MWD Field. The reservoir levels were identified, and their petrophysical parameters were evaluated using well logs and core data. We were able to recognize seven different types of rocks (petrophysical static rock type 1 (PSRT1) to PSRT7) using petrography data, the reservoir quality index (RQI), the flow zone index (FZI), R35, hydraulic flow units (HFUs), and stratigraphy modified Lorenz (SML) plots. The analysis of the petrophysical data shows that AEB_IIIG has unsteady net pay thicknesses over the area. It has a range of 8–25% shale volume, 12–17% effective porosity, and 72–92% hydrocarbon saturation. The RQI results show that psrt1, psrt2 and psrt3 have a good reservoir quality as indicated by high R35 and helium porosity, respectively. They contribute with more than 75% of the reservoir production. The equation derived for each rock type of AEB_IIIG reservoir can be employed to forecast the permeability value distribution inside the reservoir.

The Gulf of Suez is a sedimentary rift-basin with thick evaporites and complex structural settings that presents challenges to achieving quality imaging based on seismic reflection data. Such subsurface settings and the lack of 3D seismic data poses challenges in building reservoir models to guide hydrocarbon exploration and development, especially in southern parts the Gulf of Suez. This study attempts to overcome the challenges of both 2D seismic interpretation and building a static reservoir model of two Miocene reservoir formations, Ras Ghara Field, Southern Gulf of Suez. Integration of well log data analysis of nine wells and regional-tectonics cognizant 2D seismic interpretation of nineteen 2D seismic lines enabled a reliable 3D static reservoir model. The Miocene reservoir characterization reveals heterogeneity in lithofacies distribution, with thick evaporite sequences causing seismic reflection distortions. Significant hydrocarbon accumulations are associated with horst fault blocks. The Miocene reservoirs demonstrate effective porosity of 14-33%, water saturation of 16-65%, and hydrocarbon saturation of 35-84%. Two new prospects are identified based on structure, facies distribution, and petrophysical results, with estimated original oil in place (OOIP) of 2,002,404 stock tank barrels (STB) and 1,175,580 STB for the Kareem Formation, and 6,302,916 STB and 2,841,894 STB for the Rudeis Formation.

The West Delta Deep Marine concession offshore Egypt’s Simian field was exposed to simultaneous pre-stack inversion to test its quantitative interpretation potential. In heterogeneous submarine channel reservoirs, characterising reservoir lithology and fluid distribution and isolating gas sand, brine sand, and background shale are the key Simian field challenges. Due to poor water sand mapping, numerous Simian field wells had surprising early water production rates. Therefore, this study may investigate if pre-stack seismic data and sophisticated inversion techniques can precisely pinpoint Simian field lithology, facies changes, and fluid distribution. Concurrent pre-stack inversion estimates rock parameters, including acoustic or P-wave impedance (Zp), shear impedance or S-wave impedance (Zs), and density (ρ), which are strongly related to lithology. Before the inversion procedure, two wells were analysed in a rock physics investigation, and three angle gathers (0–15°, 15–30°, and 30–45°) were pre-stacked inverted for Zp, Zs, P-wave velocity (Vp), S-wave velocity (Vs), Vp/Vs ratio, and ρ. Lambda-Mu-Rho (LMR) analysis involves obtaining Lamé parameters by inverting Zp and Zs simultaneously, resulting in Lamda-Rho (Incompressibility) (λρ) and Mu-Rho (Rigidity) (µρ) volumes. The training process involved pre-stack inversion analysis employing angle stack seismic data and well log data, cross-validation, and Vp, Vs, and Vp/Vs volumes. Vp/Vs and Zp volumes predicted Sw values that matched well gas-water contact. The study used a test well (Simian-Di) and validated the result at a blind well location (Simian-Dj) to evaluate a pre-stack inversion approach. It found accurate predictions, suggesting better output and economic efficiency.

Fractured basement reservoirs represent critical contributors to global hydrocarbon production, with lithologically heterogeneous systems such as weathered granites serving as economically viable targets. In the tectonically active Gulf of Suez rift basin, fractured basement units are increasingly recognized as high-potential reservoirs for hydrocarbon exploration. This study investigates the Geisum Oil Field, a prolific southern Gulf of Suez hydrocarbon province, where basement-hosted production challenges conventional reservoir paradigms. A multidisciplinary approach combining advanced geophysical well logs (including Formation MicroImager [FMI] and resistivity anisotropy analysis) with 2D seismic interpretation was employed to (1) delineate conductive fracture networks, (2) quantify fracture aperture distributions, and (3) resolve structural controls on reservoir heterogeneity. Results identify three dominant fracture orientations—NE–SW, NW–SE, and ENE–WSW—aligned with regional stress regimes. Quantitative analysis reveals a maximum fracture aperture of ~ 0.7 mm within the uppermost basement interval, correlating with enhanced porosity (φ) and permeability (k) zones. Fault intersection geometries were found to amplify fracture density, creating interconnected conduits that optimize reservoir quality. However, kinematic analysis of fault systems highlights potential compartmentalization risks, as insufficient fault seal integrity may permit hydrocarbon migration along reactivated fault planes. These findings underscore the dual role of tectonic fracturing in basement reservoirs: while fracture networks enhance storage and flow capacity, dynamic fault systems necessitate rigorous seal evaluation to mitigate leakage hazards. This work provides a framework for de-risking basement reservoir exploration in rift-related settings globally.