3D Fracture Network Simulation Using Geostatistical Conditioning
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Solution Overview
Problem
Current reservoir modeling techniques face challenges in accurately simulating the 3D geometry of natural fracture networks, which are crucial for understanding flow characteristics and fracture-matrix interaction in petroleum reservoirs, due to complexities in spatial distribution, aperture, length, height, conductivity, and connectivity of fractures.
Innovation Solution
A geostatistical method for conditional simulation of 3D fracture networks is developed, involving algorithms to determine simulated and actual fracture parameters from data analysis and image logs, with probabilistic selection of seed points and triangulation processes to model fracture geometry, using kriging methods and probability distributions to ensure accurate representation.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If traditional reservoir modeling techniques are used to model fracture networks, then the modeling process is simpler, but the accuracy of fracture geometry simulation is insufficient
Solution Approach 1:
The patent segments the fracture network modeling into distinct components: fracture initiation zones around wellbores, fracture propagation paths, and fracture termination points. Each segment is modeled with appropriate geometric parameters and statistical distributions, allowing accurate representation of complex fracture geometries while managing computational complexity through modular processing
Solution Approach 2:
The patent transitions from 2D fracture cross-sections to 3D fracture network geometry by incorporating vertical fracture height, dip angles, and spatial distribution in three-dimensional space. This dimensional expansion enables accurate simulation of fracture connectivity and fluid flow paths while using point process theory and conditional simulation to manage the increased complexity
2Reliability
If detailed fracture parameters are incorporated into the model, then the representation of fracture properties improves, but the data processing complexity increases
Solution Approach 1:
The patent transforms detailed fracture parameters (length, aperture, orientation, connectivity) into statistical distributions and spatial point patterns. By characterizing fracture networks through probability density functions and conditional spatial processes rather than deterministic individual fracture modeling, the system achieves reliable representation of fracture properties while reducing data processing complexity through statistical aggregation
Solution Approach 2:
The patent uses conditional simulation to generate multiple realistic fracture network realizations that replicate the statistical properties and spatial patterns observed in field data. Instead of processing every individual fracture measurement, the system creates representative synthetic fracture networks that preserve key geometric and topological characteristics, reducing processing complexity while maintaining reliability
3Measurement precision
If conditional simulation methods are used to model fracture networks, then the spatial distribution accuracy improves, but the computational time increases
Solution Approach 1:
The patent performs preliminary conditioning by incorporating observed fracture locations, wellbore data, and geological constraints before running the full conditional simulation. By pre-establishing boundary conditions, spatial correlation structures, and constraint zones around observed fractures, the system achieves accurate spatial distribution while reducing computational time through pre-processing of conditioning data and constraint definition
Data Source
AI summary
The disclosed embodiments include a method, apparatus, and computer program product for providing a geostatistical procedure for simulation of the 3D geometry of a natural fracture network conditioned by well bore observations.