Review of Methods for Judging Reservoir Fluid Properties
DOI:
https://doi.org/10.54097/w2jgxp28Keywords:
Permeability; saturability; porosity; reservoir fluid property.Abstract
Sand formation has good reservoir conditions due to its relatively developed porosity and permeability and well developed pore throats. After the reservoir is divided from the drilling geological profile, the next step of logging interpretation is to determine the oil, gas and water properties of each reservoir. The oil-bearing property of reservoir can be measured by its saturation, which can be divided into water saturation and oil-bearing saturation. Water saturation refers to the percentage of water-bearing void volume in total void volume of rock, usually expressed as Sw; oil-bearing saturation refers to the percentage of oil-bearing void volume in rock, expressed as Sh. Saturation is usually expressed as percentage ( %). Under ideal conditions, the sum of hydrocarbon saturation and water saturation in reservoir pores is 1 (or 100%). Therefore, water saturation is usually used to describe hydrocarbon bearing of reservoir, and it is particularly important to judge reservoir fluid properties. When logging data are applied, natural potential logging, triple laterolog, neutron gamma logging and ordinary resistivity logging are usually used to judge oil and water layers.
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