Porosity and permeability distribution and their impaction on fluid production in carbonate reservoir rocks

الملخص

Reservoir parameters including porosity and permeability are predominantly influence fluid flow movement and production rate in carbonate reservoir rocks. This impaction is corresponding to heterogenous distribution of these reservoir parameters which leading to anisotropic fluid production in the same reservoir intervals. In this work, the magnitude of matrix porosity and permeability were measured from core plug samples and available wireline log data was used for the porosity calculations in Baba Formation from Bai Hassan field. Besides of the petrophysical examinations, fluid loss data and formation test repeater results were used for evaluation of the impaction of porosity and permeability distribution on fluid flow and rate of hydrocarbon production. The rock types in the Baba Formation are characterized by a comprehensive distribution of measured matrix porosity and permeability. The magnitude of the effective porosity is started from 0.01 as the minimum value to 0.45 as the maximum with an average of 0.20 throughout the studied intervals which have been used for this study. The magnitude of measured matrix permeability is ranged from 0.01 mD to 827.04 mD with an average of 123.52 mD. The magnitude of average fracture porosity was 0.0036 and average fracture permeability was 0.394 mD. The rate of production is frequently controlled by the magnitude of matrix permeability throughout the studied wells. The highest rate of oil production is coincided with the highest magnitude of average matrix permeability and the lowest level of oil production was recorded was derived from the lowest magnitude of an average matrix permeability.