الفهرس 
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Abstract
The study area, Tut Field, lies between Latitudes 30° 45’ - 30° 48’ to the North and Longitudes 26° 57’ 45” – 26° 59’ 50” to the East. The studied oil field was investigated using core analysis results of 753 subsurface core samples and well logging data of 10 wells that represent the Alam El-Bueib Formation rocks. The Alam El-Bueib Formation has a huge thickness in general, while the lithology has been subdivided into six units from bottom to the top: AEB-6, 5, 3, 2 & 1. The petrophysical studies of the Alam El-Bueib reservoir data lead to: The relationships between permeability and porosity show a positive trend which means that the permeability increases with the increasing of porosity. The relationship between horizontal permeability and vertical permeability reflects a strong correlation coefficient. The horizontal permeability is greater than the vertical permeability in all the studied wells, Digitizing well Logs involves converting field analog prints into digital data to estimate the volume of clay, porosity, water saturation and net pay thickness. Crossplots used as a convenient way to demonstrate how various combinations of logs respond to lithology and porosity. The log-derived reservoir parameters are interpolated in three dimensions X, Y and Z, to construct of a 3D- model for each parameter. Three methods have been utilized for determining permeability from well logs. The comparisons of the correlation coefficient values indicate that the artificial neural net work is the most advantageous method for prediction the permeability from logs.