A New Chapter for Eocene Exploration in Egypt: Transforming Geological Complexity into Exploration Opportunity

This study aims to unlock the untapped hydrocarbon potential of the Eocene carbonate reservoirs across multiple fields spanning the entire Gulf of Suez province. By integrating petrographic, petrophysical, and structural data, it enhances reservoir characterization and identifies new exploration targets. Emphasis is placed on the impact of fault-associated fracturing in improving reservoir quality and offering strategic insights for optimizing the development of underexplored fractured carbonate reservoirs in a mature petroleum basin. A multidisciplinary approach was applied to evaluate the hydrocarbon potential of Eocene carbonate reservoirs in Egypt's Gulf of Suez. The workflow combined core and petrographic analysis to assess porosity types and diagenetic features, while well-log interpretation quantified porosity and saturation, especially in chert-rich zones. Seismic data were analyzed to map fault systems, structural closures, and migration pathways. Fracture analysis played a crucial role in identifying areas of enhanced reservoir quality near fault intersections. Together, these methods improved reservoir characterization and helped pinpoint high-potential exploration targets in complex geological settings. The integrated study revealed significant untapped hydrocarbon potential in the Eocene carbonate reservoirs of the Gulf of Suez. Petrographic analysis identified extensive diagenetic alterations that produced secondary porosity, a key contributor to enhanced reservoir quality. Fracture density was notably higher near major rift faults, boosting permeability and fluid flow. Well-log data indicated reservoir zones with porosity reaching 13% and net pay thicknesses between 20 and 400 feet. Seismic data revealed structurally controlled traps and migration pathways aligned with extensional fault systems. These findings confirm that the fractured Eocene limestone, despite being underexplored historically, offers viable reservoir targets when properly characterized. The study highlights the importance of focusing on fault intersections and refining diagenetic models to improve hydrocarbon recovery. In certain cases, serve as compelling examples, demonstrating the potential to dramatically increase production—from around 200 BOPD to over 20,000 BOPD—emphasizing the approach's value for more efficient field development in comparable global settings.