Abstract
Reservoir characterization, which could be broadly defined as the process describing various reservoir characters based on the all available data. The data may come from diverse source, including the core sample experiment result, the well log data, the well test data, tracer and production data, 2D, 3D and vertical seismic data, well bore tomography, out crop analogs, etc. Ideally, if most of those data are analyzed and included in the characterization, the reservoir description would be better. However, not all the data are available at the same time. This paper provides a reservoir characterization analysis in the early-stage application, which means before the production, based on real oil filed data by using the SGeMS (Stanford Geostatistical Modeling Software).
Highlights
The properties involved in the reservoir description may include the permeability, porosity, saturation, thickness, faults and fractures, rock facies and rock characteristics [1]
This paper provides a reservoir characterization analysis in the early-stage application, which means before the production, based on real oil filed data by using the SGeMS (Stanford Geostatistical Modeling Software)
The reservoir characterization gives a proper global reservoir prediction of these diverse reservoir properties as a function of special based on the limited local information, which could be generally understood as a process to describe the reservoir heterogeneity and solve the upscaling problem
Summary
The properties involved in the reservoir description may include the permeability, porosity, saturation, thickness, faults and fractures, rock facies and rock characteristics [1]. It is easier to understand the reservoir properties in small scale, for example, the permeability and porosity are to be obtained from core tests. A large amount of work has been done by the scholars to join the simulation approached and solve the upscaling description and multivariable attributes problem. According to the well information, ten flow units that capture changes in geologic description and variation of petrophysical properties. The flow units data was described at different well locations by analyzing several geological cross sections throughout the field, including top and thickness, porosity, permeability (in log form) from cores and logs. Two and eight to ten are located at the top and bottom of the reservoir which are less productive, while flow unit three to seven are in the middle of the reservoir, which are most productive and provide best petrophysical properties [1]
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