Abstract
This Naturally Fractured Reservoir (NFR) is become challenging to identify the behavior of performance in fluid flow in producing well at SF oil Field. Generally, this unique of mechanism that cannot be treated as homogenous reservoir, because has two porous media in this reservoir such as matrix and fracture, the dominantly fluid flow comes from the networks of fractures, but for matrix porous media as function of source that transfer fluid to the fractures. This complexity of reservoir needs deepest investigate the characteristic of this reservoir and estimating the reservoir parameter such as permeability fracture, storativity coefficient ratio (omega) and interporosity flow coefficient (lamda) of SF production wells at SF oil Field are the main objective of this study. There are two wells that are analyzed in this study, and the result of this study yields significant interpretation by analyzing the production data in order to approximate the characteristic of dual porosity in naturally fractured oil reservoir by applying the decline rate type curve matching.
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