How do you initialise fluid saturation in 3D, such that you honour the wells, the reservoir properties and fluid-rock physics simultaneously? This course teaches you how to leverage petrophysical, geological and reservoir engineering insights to produce physically-coherent saturation models: reducing reserve uncertainty, improving permeability models, and identifying reservoir compartments.
Geoscientists with some knowledge of reservoir modelling software; reservoir engineers and petrophysicists who work with static reservoir models, and team leaders who wish to have a deeper understanding of the principles behind modelling and how to QC models made by others.
Duration
Learning Level
Fluid distributions are controlled by the interaction of buoyancy and capillary pressures with the pore structures. Saturation-height functions address buoyancy pressure, but ignore capillary and pore geometry effects – resulting in inconsistencies with observed data. Geostatistical distribution of saturation enforces a match to the logs, however; the 3D realisation rapidly deviates from physical reality away from the wells.
This course teaches how to reduce the largest uncertainty in proven reserve volumes: pore volume saturation. You will learn how to work together, as an interdisciplinary team of petrophysicists, geoscientists & reservoir engineers, to hone assumptions in individual workflows with insights from peer disciplines.
This is taught in a classroom setting, using a combination of fundamental theory and practical exercises. We can facilitate a trial license to a commercial software application to implement these learnings on an open-source dataset, or walk you through how to manually implement this approach in your software of choice. Alternatively, the course can be structured to incorporate your own field data – providing you with both training and expert consultation.
understanding the controls of immiscible fluid saturations in reservoir rocks.
a 101 on the Buckingham π theorem to understand the power of dimensionless analysis.
a deep dive how fluid contacts are measured, providing all participants with a consistent understanding of the confidence (and retained uncertainty) in this essential field data point/assumption.
learn how conversion of laboratory & field physical measurements to derived rock properties (facies, porosity, permeability, saturation) interacts with our understanding of 3D fluid saturation.
the correct (and incorrect) ways to upscale derived logs.
populate saturation in 3D, honouring well data, geology and reservoir engineering.
Duration is 2-3 days.
MEng
30+ years – petrophysics and geomechanics
Joe develops and runs courses in the Reservoir, E&P Overview and Master Class Series. He has a career background at Schlumberger, RWE-DEA AG, PDO, TRACS. He is an expert in his field and as Project lead digital core analysis for PDO/SHELL, Design and introduction of GDP and ATP program, GDP Coach for the GG&GM community.
Energy transition and renewables
Early development
E&P overview
Reservoir
Wells
Business
Open air
Uncertainty and Risk
e-Products
