Abstract The Late Miocene Abu Madi Formation in the Nile Delta Basin, Egypt, represents a promising target for hydrocarbon extraction from shaly sand gas reservoirs. However, the complexity and heterogeneity of these clastic systems necessitate a rigorous and systematic evaluation approach. This study aims to conduct a comprehensive assessment of the Abu Madi Formation within an onshore gas field, focusing on the detailed analysis of wells X1 and X2. By integrating advanced petrophysical and sedimentological techniques, the research seeks to enhance reservoir characterization and optimize hydrocarbon recovery from these geologically intricate formations. The study utilized a well-integrated workflow, employed reservoir characterization, facies analysis, Petrophysical evaluation, and rock typing techniques using thirty-five core plugs, extracted from two cores in well-X1. Core analysis and well log data provided crucial insights into pore systems, mineralogy, and textures. Hydraulic flow units (HFUs) were established using well logs and core data. Additionally, flow zone indicators (FZIs) derived from well logs further characterized flow behavior within the reservoir. Core analysis techniques like thin section petrography, XRD, and SEM complemented the well log interpretation. Petrographic analysis confirmed that the sandstones in well-X1 are predominantly quartz arenites, with minimal clay and carbonate content, exhibiting porosity values between 20% and 30%. In contrast, well-X2 showed significantly higher clay content. Well log evaluation of the Abu Madi Formation revealed that well-X1 possesses more extensive pay zones (16.6 m) and higher porosity sandstones (30.35%) compared to well-X2, which has thinner pay zones (7.3 m) and lower porosity (23.3%), with increased water saturation. Four distinct rock types were identified in well-X1, with Rock Type-4 exhibiting the highest reservoir quality (3.24 ≤ RQI ≤ 4.13 µm) due to superior porosity and minimal clay content, whereas Rock Type-1 demonstrated the lowest reservoir quality (0.14 ≤ RQI ≤ 1.22 µm). This classification facilitated the identification of specific reservoir facies with significant gas potential. The recognized rock units delineate zones with comparable fluid flow characteristics, aiding in the prediction of gas deliverability. This integrated method enables the optimization of reserves and production by prioritizing zones with high FZI and low clay content can enhance hydrocarbon recovery. These findings refine exploration strategies in the Nile Delta Basin, promoting more efficient and sustainable resource development.
A. Wafik Abdelwareth (Mon,) studied this question.