Relative Permeability Module
Purpose
The Relative Permeability module allows users to evaluate the fractional flow of oil and water from a reservoir.
Primary Output
The following curves are the primary interpretations made in this module.
| Curve Name | Description |
|---|---|
| FFW | Fractional flow of water |
| FFHC | Fractional flow of hydrocarbon |
Discussion
The relative permeability module allows users to calculate the fractional flow of oil and water from a reservoir based on either a Brooks-Corey or Power-law relationship.
This module requires an irreducible water saturation and residual hydrocarbon as inputs. The irreducible Sw can be pulled from the Saturation Height modeling module. The residual HC can either be a user value or can come from a flushed zone saturation.
Related Insights
Quick Start Module
Purpose The Quick Start module is designed to help users quickly set dozens of common parameters by selecting a handful of basic options from dropdown menus. Parameters There are three parameters that are set on a zone-by-zone basis and two parameters that are set on a full-well basis. These are as follows. Discussion The parameters are linked to what are called named_defaults in the software. These are collections of defaults that can be set through assigning a single parameter.
Sample data to get started
Need some sample data to get started? The files below are from data made public by the Wyoming Oil and Gas Commission. These will allow you to get started with petrophysics, mapping, and decline curve analysis. Well header data Formation tops data Deviation survey data Well log data (las files) Production data (csv) or (excel) Wyoming counties shapefile and projection Wyoming townships shapefile and projection Haven’t found the help guide that you are looking for?
NMR Interpretation Module
Purpose The NMR interpretation module allows users to calculate porosity, bound and free fluids from the measure T1 and T2 distributions from NMR tools. Primary Outputs Discussion In oil and gas well logging, the $T_2$ distribution is used as a high-resolution "map" of the formation's pore system. While a standard porosity tool tells you how much fluid is there, NMR tells you where that fluid is trapped and whether it will flow.