Volumetrics Module
Purpose
The Volumetrics module enables users to calculate critical reservoir summary properties such as original oil in place, original gas in place, hydrocarbon pore volume and porosity thickness.
Primary Outputs
| Curve Name | Description |
|---|---|
| OOIP | Original oil in place |
| OGIP | Original gas in place |
| HCPV | Hydrocarbon pore volume |
| PHIH | Porosity thickness |
Discussion
This module is intended to allow the user to calculate OOIP (Original Oil in Place) and OGIP (Original Gas in Place) on a per unit area basis. The user should first set if the zone is oil or gas, if they want to do the analysis using the Net Reservoir or Net Pay as thickness, and if they want to use the total or effective porosity.
Danomics will ensure consistency by using a SwT if a total porosity is selected and a SwE if effective porosity is selected - this way the user doesn't have to worry about the saturation method selected.
The calculations are in general performed as given below
OOIP = 7758*area*thickness@porosity*(1-sw)/Bo
where 7,758 is the conversion from acre-ft to barrels, thickness is either the net reservoir or net pay flag, and porosity is either the effective or total porosity. When Oil is the selected phase, associated gas is determined via the gas-oil ratio.
OGIP = 43560*area*thickness*porosity*(1-sw)/Bg
where 43,560 is the conversion from acre-feet to scf, thickness is either the net reservoir or net pay flag, and porosity is either the effective or total porosity. When Gas is the selected phase, associated liquids are determined via the liquids yield.
For the formation volume factors (Bo / Bg) users can either choose to enter a fixed value by zone or use the Hall-Yarborough and Vasquez and Beggs correlations.
When the Vasquez-Beggs option is selected the Bo (Oil FVF) and GOR is determined via the methods outlined by Vasquez and Beggs (“Correlations for Fluid Physical Property Prediction”, M.E. Vasquez and H.D. Beggs, JPT 968 – 70, June 1980.) using the pressure and temperature conditions at every depth step. To determine the Bg (Gas FVF) correlations from Hall and Yarborough (1974) are used in conjunction with the coefficients outlined by Whitson and Brule (SPE Monograph vol. 20, Phase Behavior, 2000).
For QC'ing the interpretaiton the following maps are useful:
| Map Name | Description |
|---|---|
| OOIP_SUMMARY | Original oil in place for selected zone |
| OGIP_SUMMARY | Origina gas in place for selected zone |
| HCPV_SUMMARY | Hydrocarbon pore volume for selected zone |
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.