Pore Network Model for Waterflooding Reservoir Parameter Prediction
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Solution Overview
Problem
Current techniques can only measure the changing principle of reservoir permeability over time but fail to simultaneously measure the changing principle of oil-water two-phase relative permeability curves, which is crucial for accurate oil reservoir development and optimization.
Innovation Solution
A method and system that convert T2 spectra into pore size distributions, build pore network models, and perform oil-water two-phase flow simulations to obtain time-varying oil-water two-phase relative permeability curves, allowing for simultaneous measurement of permeability and relative permeability changes.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional measurement techniques are used, then reservoir permeability changing principle can be obtained, but oil-water two-phase relative permeability curve changing principle cannot be obtained
Solution Approach 1:
The patent applies a pore network model that can simultaneously simulate and predict both single-phase permeability and two-phase relative permeability curves. The model integrates pore structure parameters (obtained from NMR T2 spectra) with flow simulation capabilities, enabling one system to perform multiple measurement functions that previously required separate techniques.
Solution Approach 2:
The patent introduces a pore network model as an intermediary between the measured pore size distribution (from T2 spectra) and the desired permeability parameters. This model acts as a bridge that translates pore structure characteristics into both absolute permeability and relative permeability curve predictions, enabling simultaneous acquisition of both parameters.
2Measurement precision
If separate measurement methods are used for permeability and relative permeability, then individual parameters can be measured, but simultaneous measurement of both is difficult
Solution Approach 1:
The patent merges the measurement of absolute permeability and relative permeability into a single integrated system. By combining pore structure characterization (via NMR T2 spectra) with pore network modeling and flow simulation, the system simultaneously predicts both permeability parameters from one set of measurements, eliminating the need for separate experimental setups.
Solution Approach 2:
The patent creates a virtual copy of the reservoir pore structure through the pore network model. This digital replica allows for simulated flow experiments that can extract both permeability parameters without requiring physical core plug experiments for each measurement type, thereby simplifying the overall measurement system.
Applied Scientific Principles
This section explains which scientific principles are used to turn an abstract innovation direction into a practical engineering solution.
Function Achieved in This Case
Accurately predicts the time-varying principle of waterflooding oil reservoir formation parameters, addressing the limitations of existing methods by providing a comprehensive understanding of permeability and relative permeability changes.
Implementation Method 1
acquiring a measured pore size distribution curve and a measured T2 spectrum of a rock sample of a waterflooding oil reservoir
Data Source
AI summary
The present disclosure relates to a method and system for predicting a time-varying principle of waterflooding oil reservoir formation parameters. Firstly, a T2 spectrum-pore size relation model is built according to a measured pore size distribution curve and a measured T2 spectrum. A T2 spectrum of a rock sample at different water injection amounts during a waterflooding physical simulation experiment is acquired. The acquired T2 spectrum at different water injection amounts is then converted into a pore size distribution at different water injection amounts, and a pore network model at different water injection amounts is built with the pore size distribution. Oil-water two-phase flow simulation is performed, and a corresponding oil-water two-phase relative permeability curve of the rock sample at different pore volume (PV) multiples is obtained eventually. The oil-water two-phase relative permeability curve is the formation parameters in the waterflooding oil reservoir.