Porous Medium Permeability Prediction via Superficial Effective Diameter
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Solution Overview
Problem
Existing methods for predicting permeability in porous media, particularly in shale gas and tight oil formations, are inaccurate due to rapid and uncertain geometric changes, leading to unreliable estimates and limitations in applying these methods to actual oil and gas fields.
Innovation Solution
A method is proposed that predicts permeability based on geometrical changes in a porous medium using the superficial effective diameter, which involves calculating porosity and permeability at multiple points, establishing correlations between porosity, superficial effective diameter, and permeability, and then using these correlations to predict permeability changes.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Ease of manufacture
If power-law equations are used to predict permeability based on porosity, then the prediction method is simple to apply, but the accuracy is greatly reduced in reservoir rocks with low porosity and complex pore structures
Solution Approach 1:
The patent transforms the permeability prediction approach by changing the fundamental parameter from porosity-based power-law equations to superficial effective diameter-based linear equations. This parameter transformation enables accurate prediction in low porosity ranges while maintaining simplicity of application through straightforward linear correlations.
Solution Approach 2:
The patent segments the permeability prediction problem into distinct porosity ranges (high, medium, low) and develops specific linear equations for each range. This segmentation allows the method to capture the different flow characteristics in each porosity regime, particularly improving accuracy in the previously problematic low porosity range.
2Ease of manufacture
If conventional permeability prediction methods are applied to shale gas and tight oil formations, then the methodology can be implemented, but the reliability is greatly reduced due to rapid and uncertain geometric changes in the first 2-3 years of production
Solution Approach 1:
The patent introduces a dynamic permeability prediction model that explicitly accounts for time-dependent geometric changes in porous media. The linear equations incorporate porosity changes over time, enabling the model to adapt to the rapid and uncertain geometric changes characteristic of shale gas and tight oil formations during the first 2-3 years of production.
Solution Approach 2:
The patent establishes a feedback mechanism where permeability predictions are continuously updated based on measured porosity changes at different time points. This allows the model to capture and respond to the rapid geometric changes in the formation, improving reliability by incorporating actual field data feedback into the prediction process.
3Adaptability or versatility
If power-law equations with steep change slopes are used for low porosity ranges, then the equations can be applied to various reservoirs, but the reliability and accuracy are greatly reduced
Solution Approach 1:
The patent fundamentally changes the parameter basis from porosity to superficial effective diameter, which linearizes the relationship and eliminates the steep change slope problem in low porosity ranges. This parameter transformation maintains broad applicability across different reservoir types while dramatically improving prediction accuracy where it was previously compromised.
Data Source
AI summary
Provided a method for predicting permeability according to the geometrical change in a porous medium on the basis of a superficial effective diameter, wherein the permeability according to geometrical changes in the porous medium is precisely predicted. The method for predicting permeability according to geometric change in the porous medium comprises: providing a porous medium; obtaining first porosity and first permeability at a plurality of points of the porous medium, respectively; calculating a first superficial effective diameter using the first porosity and the first permeability; establishing a first correlation between the first porosity and the first superficial effective diameter, a second correlation between the first permeability and the first superficial effective diameter, and a third correlation between the first porosity and the first permeability; and using the correlations to predict a second permeability for a second porosity changed by a geometrical change in the porous medium.