Organic Geochemistry and Palynofacies Insights Into Source Rock Potential and Oil–Oil Correlation in the Matruh–Shushan Basin, North Western Desert, Egypt

ABSTRACT This study evaluates the petroleum potential of the Matruh–Shushan Basin in the north Western Desert of Egypt based on 17 crude oil and 60 rock samples. Analytical approaches included total organic carbon (TOC), Rock‐Eval pyrolysis, palynofacies analysis, and detailed biomarker characterization using gas chromatography (GC) and gas chromatography–mass spectrometry (GC–MS). Source rocks exhibit predominantly interbedded vertical enrichments. The Khatatba Formation is thick, laterally continuous, and TOC‐rich, whereas the Abu Roash‐G Member is thinner with lower TOC, indicating a more limited source potential. Kerogen in the Khatatba Formation is predominantly Type‐III, indicative of gas‐prone potential, with subordinate Type‐II/III kerogen in localized intervals suggesting limited oil‐generative capacity. Thermal maturity indicators, including T max , production index, and thermal alteration index (TAI), suggest that the Khatatba Formation is mostly mature to overmature, while the Abu Roash‐G Member remains immature to marginally mature. Palynofacies analysis identified two depositional settings: a proximal fluvio‐deltaic Khatatba association and a distal, marginal marine Abu Roash‐G association. Palynostratigraphic data constrain the Khatatba Formation to the Middle–Late Jurassic (Bathonian–Oxfordian) and the Abu Roash‐G Member to the Cenomanian. The results highlight the Khatatba Formation as the primary gas‐prone source rock in the region, whereas the Abu Roash‐G Member exhibits limited hydrocarbon potential. Bulk properties, stable carbon isotope data, and biomarker geochemistry indicate that the Matruh–Shushan oils are light and sweet as indicated by high API gravity and low sulfur content. The geochemical signature indicates deposition in a marginal marine to deltaic, clastic‐dominated setting, characterized by high pristane/phytane ratios, abundant C 29 steranes, elevated C 19 tricyclic and C 24 tetracyclic terpanes, and low C 23 tricyclic terpanes and homohopane indices, with minor marine input also evident. Biomarker maturity parameters are consistent with peak oil‐window generation ( R o ≈ 0.8% ± 0.1%). Integrated correlation demonstrates that these oils constitute a single cogenetic family assigned to the terrigenous‐enriched facies of the Jurassic Khatatba source rock. This integrated multidisciplinary approach refines the petroleum system model of the Matruh–Shushan Basin and provides improved constraints for future hydrocarbon exploration in the northern Western Desert, Egypt.