#TITLE_ALTERNATIVE#

• Main Author: HESTI (NIM : 12214082), KARUNIA
• Format: Final Project
• Language: Indonesia
• Online Access: https://digilib.itb.ac.id/gdl/view/28401
• Institution: Institut Teknologi Bandung

In naturally fractured reservoir, it may exist three or more porosity system those are more complex than homogeneous reservoir. Conventional dual porosity model sometimes can’t model the complexities of those reservoir precisely so that the behavior of multi porosity system aren’t well understood. <br /> <br /> This study develops an improved model of triple porosity system in naturally fractured reservoir for representing multi porosity system using commercial simulator. Type curve diagnostic was carried out to learn the pressure transient behavior of multi porosity system. <br /> <br /> Multi porosity system behavior indicates a series of parabolic shape in pressure derivative curve and some anomalous slope change in semi-log plot which describe transition period from fracture-controlled flow to each matrix contributed flow until total system flow. Each transition period is controlled by two parameters, fluid capacitance coefficient and inter porosity flow coefficient for each matrix system. <br /> <br /> In general, it can be concluded that multi porosity system can be modeled from improved idealized triple porosity model and each matrix system gives different flow contribution to fracture that may be diagnosed from the parabolas number in pressure derivative curve. But, in some condition, multi porosity system can behave as triple porosity or dual porosity system.