Innovative 3D Reservoir
Innovative 3D Reservoir Petrophysical Modelling.
In any hydrocarbon field, there is usually at least one exploration well and a 3D seismic data survey of the entire field. Algorithms developed by iRPM calibrate the 3D seismic data to the petrophysical well results, from one or more exploration wells. The algorithms then populate the petrophysical properties in 3D space constrained to the 3D seismic.
This means that hydrocarbon volumes of STOIIP (oil) and GIIP (gas) can be determined constrained to the 3D seismic. This identifies the drill locations that will generate the highest production from the field.
These algorithms are blind tested against the petrophysical results from existing well logs and predict new results from wells yet to be drilled. Blind testing is a critical step that validates the 3D model, but we have found that this is rarely ever done. All predictions can also be refined and calibrated against static and dynamic, core rock measurements if available.
Benefit#1: The iRPM methodology can remove the need for additional well log data to appraise the potential of the discovered field, resulting in cost savings of $100million per unneeded appraisal well. The entire prediction process takes 2-4 weeks, and can significantly increase the NPV of the project because development of the project can start much sooner and significant capital can be saved and invested in additional projects.
Benefit#2: Additionally, for mature brownfield sites, the dynamic algorithms developed by iRPM can be used to determine the ultimate recovery of the field. These dynamic algorithms help identify flushed zones and bypass hydrocarbons in an existing producing field.
Petrophysical Uncertainty using Averages and Upscaling
How to address Petrophysical Uncertainty? You must understand the uncertainty of the processes used when populating properties into the 3D space. Averages will never predict variations in Reservoir Quality. Watch this 1/2 hr presentation.