Permeability Modeling in Layered Rock Formations
Find Innovative SolutionsGenerate Solutions
Solution Overview
Problem
Current methods fail to accurately model permeability in layered rock formations, which affects the prediction of fluid flow and hydrocarbon production across multiple wells, as they either localize enhanced permeability to hydraulic fracturing areas or require high densities of naturally occurring fractures that are uncommon.
Innovation Solution
A method is developed to simulate fluid movement by defining a lab-scale rock fabric model at a single well location, converting it to a field-scale model, correlating with log data, and interpolating it across the formation volume to predict fluid flow and production, considering rock fabric properties like computed tomography density and permeability.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If microcrack theory is used to explain field-observed permeability, then permeability enhancement is explained, but the explanation fails to account for fluid communication beyond localized hydraulic fracturing areas
Solution Approach 1:
The patent transitions from considering only horizontal microcracks at the wellbore scale to incorporating vertical layering and interfaces at the formation scale. This dimensional expansion allows the model to explain fluid communication across offset wells and parent-child well relationships that extend beyond the localized hydraulic fracturing zone.
2Measurement precision
If naturally-occurring fractures are used to explain high field permeability, then fluid communication is provided, but high fracture density across the entire field is required which is uncommon
Solution Approach 1:
The patent applies local quality by assigning different permeability characteristics to different rock layers and interfaces based on their specific properties. Instead of requiring uniform high fracture density throughout the formation, the model identifies specific layers with higher permeability and interfaces that preferentially conduct fluid, allowing high effective permeability in localized zones without requiring pervasive fracturing across the entire field.
Solution Approach 2:
The patent changes the governing parameters from fracture density to layer thickness, layer permeability, and interface properties. This parameter transformation allows the model to reproduce high field-observed permeability values through the combined effect of multiple thin permeable layers and conductive interfaces, rather than requiring high fracture density.
3Measurement precision
If lab-scale permeability measurements are used directly, then accurate rock fabric properties are obtained, but the measurements do not represent field-scale permeability behavior
Solution Approach 1:
The patent introduces an intermediary scaling model that bridges lab-scale and field-scale measurements. The model uses measured properties from core samples at lab-scale resolution to define a rock fabric model, then applies statistical methods and rock physics relationships to upscale these properties to field-scale resolution, allowing accurate representation of formation-wide permeability behavior.
Solution Approach 2:
The patent changes the scale parameter from lab-scale (core sample level) to field-scale (formation level) through systematic upscaling. By measuring properties at lab-scale resolution and applying statistical upscaling techniques, the model transforms localized measurements into formation-wide permeability distributions that capture field-scale fluid flow behavior.
Data Source
AI summary
Methods for simulating the movement of fluid through a formation volume comprises defining a lab-scale model representing rock fabric and associated permeability along a single well location within a formation volume and converting the lab-scale model to a field-scale model representing rock fabric and associated permeability at the single well location. The field-scale model representing rock fabric and associated permeability is correlated with field-scale log data and interpolated between multiple well locations so as to create a field-scale model representing rock fabric and associated permeability across the formation volume so that the movement of fluid through the formation volume can be simulated.