Pore-Scale Multiphase Flow Visualization via Occupation Time
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Solution Overview
Problem
Current methods for simulating and visualizing multiphase flow in porous rock, particularly oil and water displacement during water flooding, lack detailed understanding of displacement mechanisms and relative permeability, which hinders optimized oil production and residual oil minimization.
Innovation Solution
A method involving 3D imaging of porous rock, digital representation of pore space, and numerical multiphase flow simulation using the lattice-Boltzmann method, with visualization techniques that color fluid phases based on occupation time to capture capillary events and fluid dynamics at the pore scale, enabling detailed analysis of displacement processes.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If numerical multiphase flow simulation is performed to accurately predict relative permeability, then measurement precision is improved, but device complexity increases
Solution Approach 1:
The patent creates a digital copy of the porous rock structure through 3D imaging to form a digital rock model. This virtual replica allows numerical simulations to be performed on the copied structure, enabling accurate relative permeability prediction without requiring complex physical experimental setups. The digital copy preserves the geometric and topological features of the original rock while allowing controlled virtual experiments.
2Measurement precision
If 3D imaging of porous rock is performed to obtain digital representation, then measurement precision is improved, but loss of time increases
Solution Approach 1:
The patent performs 3D imaging and creates the digital rock model in advance, before the actual flow simulation experiments are needed. This preliminary action captures the complete pore space geometry and structure upfront, so that subsequent numerical simulations can proceed efficiently without repeated imaging or data acquisition delays. The digital model serves as a reusable foundation for multiple simulation scenarios.
3Loss of information
If detailed visualization of fluid interface movement is implemented, then loss of information is reduced, but device complexity increases
Solution Approach 1:
The patent employs color-based visualization techniques to represent different fluid phases and their interfaces within the porous structure. By assigning distinct colors to different fluid phases (e.g., water, oil, gas) and using color transitions to indicate interfaces and saturation levels, the system captures detailed displacement mechanism information in an intuitive visual format without requiring complex additional measurement devices.
Applied Scientific Principles
This section explains which scientific principles are used to turn an abstract innovation direction into a practical engineering solution.
Function Achieved in This Case
This approach provides high-fidelity simulations that accurately predict relative permeability and fluid displacement mechanisms, offering insights for optimizing oil production by visualizing fluid interface movement and understanding pore-scale dynamics.
Implementation Method 1
numerical multiphase flow simulation using the lattice-Boltzmann method
Implementation Method 2
capture capillary events and fluid dynamics at the pore scale
Data Source
AI summary
Systems, methods, and computer program products can be used for visualizing the behavior of flow of two or more fluid phases, wherein a fluid phase behavior is represented in a visualization. One of the methods includes determining an occupation time, which is the amount of elapsed time from when a fluid phase first occupies a particular location until a second time. The method includes generating data for a visualization, with a location in the visualization corresponding to the particular location, and with the generated data for that location in the visualization indicating the occupation time.