Our team can provide the proper sample restoration and relative permeability protocol to provide accurate data for reservoir simulators inputs.
Co-injection of two (or more) immiscible fluids at various fractional flows until steady state equilibrium is achieved. Saturations are determined using in-situ saturation monitoring (ISSM) and effective permeabilities for each phase at a given saturation are determined using Darcy’s Law.
Displacement of the mobile saturation phase with a single immiscible fluid at a constant rate. This method defines breakthrough recovery and uses post break-through volumetric and endpoint recovery data for calculation of the relative permeability.
Displacement of the mobile saturation phase with a single immiscible fluid using a single speed centrifuge. This method provides data at lower saturations and defines the relative permeability of the displaced phase only.
This is the preferred approach for determining relative permeability in low permeability reservoirs, especially when traditional methods may not yield accurate results. This method effectively simulates reservoir fluid states by allowing one fluid phase to flow while keeping the other phase stationary or immobile.
Relative Permeability Database and Toolkit
In cases when measured data is unable to be acquired or is needed for fast-track reservoir simulations, our Relative Permeability database provides analog data gathered from thousands of tests that can be utilized to estimate residual oil, relative permeability, water cut, and recovery factors.Explore the RelK Database