Reservoir Geometry Determination via Permeability-Based Flow Path Simulation
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Solution Overview
Problem
Current methods for determining the geometry of an oil reservoir are limited by insufficient data from exploration wells and seismic data, which struggles to interpret structural traps and accurately model the soil's mineralogical composition and permeability.
Innovation Solution
A computer-implemented method using a geological model with simulated wells to determine a preferred flowing path based on permeability values, updating the path until it matches the investigated area's volume and permeability, employing a fast-marching algorithm and stochastic particle movement to simulate changes in mineralogical composition and permeability.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Quantity of substance
If seismic data is used to identify and characterize rock layers and reservoir geometry, then the amount of available data is increased, but the ability to interpret structural traps and seal integrity remains insufficient
Solution Approach 1:
The patent introduces an intermediary simulation process that models particle flow through the reservoir to generate synthetic well test data. This simulated data acts as a mediator between the seismic data and the final reservoir geometry interpretation, enabling validation of structural traps and seal integrity that cannot be directly observed from seismic data alone.
Solution Approach 2:
The method implements a feedback loop where simulated well test results are compared with actual well test data, and the geological model is iteratively adjusted to minimize discrepancies. This feedback mechanism enhances the precision of reservoir geometry determination by continuously refining the model based on observed versus predicted behavior.
2Manufacturing precision
If particle flow simulation is used to model soil mineralogical composition and reservoir geometry, then the detail of the model is improved, but the difficulty of determining when the model corresponds to reality increases
Solution Approach 1:
The patent uses feedback by comparing simulated well test results with actual field measurements. This comparison provides a quantitative criterion for determining when the detailed particle flow simulation adequately represents reality, allowing the modeler to stop the simulation when convergence is achieved without needing to evaluate every detail of the complex mineralogical evolution.
Solution Approach 2:
The method replaces the complex mechanical judgment of model accuracy with a computational comparison of well test parameters. Instead of manually assessing whether the simulated mineralogical composition and geometry match reality, the system automatically compares predicted versus observed pressure and flow data, substituting subjective evaluation with objective mathematical comparison.
3Measurement precision
If exploration wells are drilled to gather reservoir data, then direct measurement of permeability and volume is possible, but the coverage and knowledge about the entire reservoir remains limited
Solution Approach 1:
The patent creates a computational copy of the reservoir through particle flow simulation that replicates the geological structures and fluid flow behavior. This virtual model allows exploration of the entire reservoir volume and geometry without requiring additional physical wells, extending the limited direct measurements from a few wells to comprehensive reservoir-scale understanding.
Solution Approach 2:
The method transitions from point-based measurements at well locations to a three-dimensional continuous model of the entire reservoir. By simulating particle flow paths throughout the volume, the system extrapolates local well data into a comprehensive spatial understanding of reservoir geometry, permeability distribution, and trap structures across the full reservoir extent.
Data Source
Figure 1a~1d
Figure 2
Figure 3a~3b
AI summary
The application discloses a method for determining a geometry of an investigated area of a reservoir, wherein a volume of the investigated area is known, the method comprising: receiving a geological model of the soil in which said area is located, the geological model comprising a plurality of adjacent cells each having respective spatial coordinates and respective permeability values, and two wells being simulated in said geological model, determining a preferred flowing path between the two wells, the preferred flowing path being formed by a series of adjacent cells of the model, and determined based on the respective permeability values of the cells, evaluating a volume of the preferred flowing path and, if the volume of the preferred flowing path is lower than the volume of the investigated area, updating the preferred flowing path until its volume is superior or equal to the volume of the investigated area.