FVM-FEM Coupling via Inverse Distance Weighting
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Solution Overview
Problem
Current reservoir modeling techniques face challenges in accurately coupling fluid flow and geomechanical data between finite volume method (FVM) and finite element method (FEM) models due to different grid geometries, often failing to converge on a realistic solution, which is essential for efficient hydrocarbon field production management.
Innovation Solution
A method that maps fluid characteristics from FVM cells to FEM elements using inverse distance weighting, projecting pore pressure and temperature as weighted averages, and segmenting FEM elements into sub-volumes to improve data transfer between models.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Reliability
If iterative mapping approaches are used to couple FVM and FEM models, then convergence on an acceptable solution may be achieved, but computational cost increases and convergence reliability decreases due to different grid geometries
Solution Approach 1:
The patent introduces an intermediary mapping system that uses geometric relationships and transfer matrices to bridge FVM cells and FEM elements. This intermediary approach avoids direct iterative coupling by establishing predetermined mapping relationships based on spatial coordinates and geometric transformations, thereby improving convergence reliability while reducing coupling complexity
Solution Approach 2:
The patent performs preliminary geometric analysis and establishes mapping relationships between FVM cells and FEM elements before the actual simulation coupling. By pre-calculating transfer matrices and establishing spatial relationships in advance, the system eliminates the need for complex iterative adjustments during runtime, reducing both computational cost and coupling complexity
2Measurement precision
If detailed reservoir modeling is performed for both fluid flow and geomechanical behavior, then production accuracy improves, but computational cost increases
Solution Approach 1:
The patent segments the reservoir modeling into distinct FVM cells for fluid flow and FEM elements for geomechanical behavior, allowing each to be modeled at appropriate detail levels independently. This segmentation enables selective refinement where needed while maintaining coarser representations elsewhere, improving production analysis accuracy without proportionally increasing computational cost across the entire model
Solution Approach 2:
The patent dynamically adjusts modeling parameters and mesh densities based on local reservoir characteristics and production requirements. By changing parameters such as element size, polynomial order, and coupling intensity in different spatial regions, the system achieves high accuracy in critical areas while reducing computational cost in less critical regions
Data Source
Figure 1A~1B
Figure 2
Figure 3A~3B
AI summary
A method and computer program product for managing hydrocarbon field production, e.g., petro-chemical reservoir production. The hydrocarbon field is modeled using the finite volume method (FVM) model and the finite element method (FEM). Centroids are located in each FVM cell and each FEM element and overlapping cells are identified. After determining the distance between centroids for overlapping cells, fluid characteristics are mapped to the FEM element centroids, weighted inversely for distance between the respective centroids. A permeability/conductivity weighted average is determined for pore pressure and temperature of sub-volumes clustered around each FEM element node. Field production may be adjusted in response to FEM element node characteristics.