Embedded Fracture Model Visualization for Reservoir Simulation Accuracy
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Solution Overview
Problem
Reservoir simulations face challenges in accurately modeling fluid flow through fracture networks, which are crucial for maximizing oil and gas recovery. Existing technologies often neglect fluid transfer between fracture networks and surrounding matrix rock due to computational expenses.
Innovation Solution
The method involves generating a computer-implemented visualization of reservoir simulations using an Embedded Fracture Model (EFM), which accounts for the interactions between fracture networks and the surrounding matrix rock by creating a grid of 3D reservoir cells and 2D fracture cells, and updating the model based on fluid flow parameters.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If fluid transfer between fracture networks and surrounding matrix rock is accounted for in the simulation model, then the accuracy of reservoir performance prediction is improved, but the computational expense increases significantly
Solution Approach 1:
The simulation model is segmented into distinct fracture network components and matrix rock components, allowing fluid transfer interactions to be modeled through defined interfaces between these segments. This segmentation enables accurate representation of fluid exchange while managing computational complexity by treating different regions with appropriate level of detail.
Solution Approach 2:
An intermediary computational framework is introduced that facilitates fluid transfer calculations between fracture networks and matrix rock without requiring full coupling of all simulation parameters. This intermediary approach allows accurate prediction of reservoir performance by capturing essential fluid exchange mechanisms while reducing the overall computational burden through selective modeling of interaction terms.
2Productivity
If detailed fracture network modeling is implemented to maximize oil and gas recovery, then the recovery efficiency is improved, but the model complexity increases
Solution Approach 1:
The model applies local quality by assigning different properties and modeling approaches to different regions: fracture networks are modeled with high permeability and specific flow characteristics, while matrix rock regions use appropriate porosity and permeability parameters. This allows detailed fracture network modeling that maximizes recovery efficiency without uniformly increasing complexity throughout the entire model.
Solution Approach 2:
The fracture networks are represented as two-dimensional surfaces embedded within the three-dimensional matrix rock grid. This dimensional approach allows detailed fracture geometry and flow paths to be captured in 2D while maintaining compatibility with the 3D reservoir model, thereby improving recovery predictions without proportionally increasing overall model complexity.
Data Source
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AI summary
Systems and methods are described for generating visualizations of reservoir simulations with embedded fracture networks by using data representing a subterranean formation to obtain a matrix grid with an embedded fracture network. The matrix grid can be separated into matrix grid control volumes, and the fracture network can be separated into fracture network control volumes. Locations of fracture-fracture intersections between the fracture network control volumes and locations of matrix-fracture intersections between the matrix grid control volumes and the fracture network control volumes can be identified. Based on the identified intersections, shapes of the fracture network control volumes can be determined and a visualization of the matrix grid with the embedded fracture network can be generated with a grid representing the matrix grid and an embedded plane within the gird, where the embedded plane is based on the shapes of each fracture network control volume.