Permeability modeling of Upper Cretaceous Bahariya Formation rocks, Abu Sennan field, Western Desert, Egypt

• Published in: Arabian journal of geosciences 2023-03, Vol.16 (3), Article 211
• Main Authors: Abuseda, Hesham Hassan, El Sayed, Abdel Moktader Abdel Aziz, Elnaggar, Osama Muhammad
• Format: Article
• Language: English
• Subjects: Cores; Cretaceous; Diameters; Earth and Environmental Science; Earth science; Earth Sciences; Induced polarization; Magnetic permeability; Mathematical models; NMR; Nuclear magnetic resonance; Original Paper; Parameters; Permeability; Porosity; Prediction models; Predictions; Relaxation time; Reservoirs; Rocks
• ISSN: 1866-7511; 1866-7538
• DOI: 10.1007/s12517-023-11218-2

The present work aims to describe in detail the petrophysical properties of the Bahariya Formation (Abu Sennan field) through processing the core sample data and finding out the possible relations between permeability and other reservoir parameters such as porosity, specific internal surface, formation factor, and nuclear magnetic resonance to obtain reliable permeability prediction model of the Upper Cretaceous formation. The core samples have a length range of 2–4 cm with a diameter of 2.54 cm. Many petrophysical reservoir parameters were measured, such as permeability, porosity, density, formation factor, and special measurements such as spectral induced polarization, nuclear magnetic resonance, and specific internal surface. The samples cover a wide range of porosity (11.82–23.68 %) and permeability (0.06–133.65 mD). The porosity-permeability relationship indicates the increase of the permeability with porosity increase for the studied samples. The reservoir quality index ranges from 0.02 to 0.78 μm. The flow zone indicator ranges from 0.09 to 3.39 μm where pore throat radius ( R 35 ) ranges from 0.10 to 7.40 μm. The reservoir quality index (RQI) and flow zone indicator (FZI) cross-plot show a better understanding of the formation evaluation. The hydraulic flow units are (0.09 μm < FZI ≤ 3.39 μm) and RQI < (1 μm). NMR longitudinal relaxation time T 1 range is 1.21–175 ms, NMR transversal relaxation time T 2(100) range is 0.70–91.77 ms, and T 2(600) range is 0.74–75.86 ms. Models that incorporate porosity and NMR relaxation times will be more accurate and suitable for permeability prediction. Using multiple regression to determine the exponents of the power-law equation and replacing the porosity with the formation factor can improve the permeability prediction for the samples under investigation. The utilizing of NMR in predicting the permeability through a robust model considers an additional value for the Upper Cretaceous rocks in Egypt.