Three-Dimensional Integrated Geo-Static Modeling for Prospect Identification and Reserve Estimation in the Middle Miocene Multi-Reservoirs: A Case Study from Amal Field, Southern Gulf of Suez Province

• Published in: Natural resources research (New York, N.Y.) N.Y.), 2023-12, Vol.32 (6), p.2609-2635
• Main Authors: Amer, Mohammed, Mabrouk, Walid M., Soliman, Khaled S., Noureldin, Ahmed M., Metwally, Ahmed
• Format: Article
• Language: English
• Subjects: Chemistry and Earth Sciences; Computer Science; Drilling; Earth and Environmental Science; Earth Sciences; Fossil Fuels (incl. Carbon Capture); Geography; Hydrocarbons; Mathematical Modeling and Industrial Mathematics; Mineral Resources; Miocene; Original Paper; Physics; Porosity; Reservoirs; Shale; Static models; Statistics for Engineering; Structural models; Sustainable Development; Three dimensional models; Zonation
• ISSN: 1520-7439; 1573-8981
• DOI: 10.1007/s11053-023-10253-w

Middle Miocene reservoirs in the southern part of the Gulf of Suez province are characterized by geometrical uncertainties due to their structural settings, lateral facies change, different lithologies, and diverse reservoir quality. Therefore, in this study, detailed 3D geo-static models were constructed by integrating multiple datasets, including 2D seismic sections and digital well-logs. The 3D models were constructed for the Belayim Formation (Hammam Faraun Member), Kareem Formation (Markha Member), and Rudies Formation (Upper Rudies Member) with detailed structuration, zonation, and layering for Amal Field in the southern Gulf of Suez province to assess the hydrocarbon potential, calculate accurate reserves, recommend development and exploration plans, and propose locations for future drilling. The resultant structural model exhibited a compartmentalized area of major and minor normal faults trending NW–SE, forming structurally high potential hydrocarbon trapping locations in the study area. The petrophysical models indicated the good potentiality of Hammam Faraun as a reservoir with porosity values of 15–23%, increasing towards the central part of the area, volume of shale ( V sh ) of 21–31%, water saturation ( S w ) of 34–49%, and sand thickness increasing toward the northeastern part of the area. The Markha Member was also interpreted as a good reservoir, with porosity values of 15–22%, increasing towards the southeastern part of the area, V sh of 13–29%, S w of 16–38%, and sandy facies accumulating in the central horst block. Upper Rudies exhibits good reservoir properties with porosity values of 16–23%, V sh of 29–37%, S w of 35–40%, and good sandy facies in the central horst block of the area. The study results showed hydrocarbon potential in the central horst block of the study area for the Middle Miocene multi-reservoirs.