CO2 Reservoir Fracture Network Evaluation for Permeability Gain
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Solution Overview
Problem
Existing methods for characterizing fracture networks and evaluating permeability-increasing effects in carbon dioxide storage target reservoirs are inadequate, failing to provide multi-dimensional quantitative assessment and optimization.
Innovation Solution
A method involving geological data exploration, supercritical carbon dioxide injection through multi-branch horizontal and vertical well structures, microseismic monitoring, and seismic source mechanism inversion to determine fracture connectivity, density, and permeability, enabling real-time assessment and optimization of fracture network modifications.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Reliability
If conventional storage geological bodies (porous rock mass reservoirs, oil reservoirs, coal seams, deep saline aquifers) are used for CO2 injection, then storage capability is achieved, but storage costs are high, re-leakage risks are high, and engineering disaster risks increase
Solution Approach 1:
The patent changes the physical and chemical parameters of the storage medium by using supercritical CO2 instead of conventional gaseous CO2, and by modifying the rock mass parameters through fracture network construction. This enables mineralization storage which provides more stable CO2 underground storage with lower costs and reduced re-leakage risks
Solution Approach 2:
The patent creates a composite system combining supercritical CO2, modified fracture networks, and carbon-based mineral rock mass. This composite approach enables mineralization storage that achieves stable storage while reducing costs and risks compared to conventional methods
2Productivity
If fracture network modification is performed to increase rock mass permeation capability, then CO2 injection efficiency is improved, but existing characterization methods fail to provide multi-dimensional quantitative assessment
Solution Approach 1:
The patent transitions from traditional one-dimensional or two-dimensional fracture characterization to a multi-dimensional quantitative assessment system. It characterizes fractures in terms of spatial distribution, connectivity, orientation, and permeability effects, providing comprehensive evaluation of fracture network modification effects
Solution Approach 2:
The patent replaces traditional mechanical measurement methods with a integrated system combining microseismic monitoring, seismic source mechanism inversion, and quantitative characterization models. This enables precise measurement of fracture parameters and permeability changes without direct physical intervention in the fracture network
3Productivity
If multi-branch horizontal and vertical well structures are used for CO2 injection, then fracture network modification is enhanced, but device complexity increases
Solution Approach 1:
The patent divides the injection well system into multiple independent horizontal well sections and vertical well sections arranged in an extended configuration. This segmentation allows each well section to target specific fracture zones, enhancing the overall fracture network modification effect while maintaining manageable complexity through modular design
Solution Approach 2:
The patent implements a dynamic injection system where CO2 is injected through multiple well sections that can operate independently and be controlled differently. This dynamic approach allows optimization of injection parameters for each well section based on real-time monitoring data, maximizing fracture network modification while managing system complexity
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
Enables accurate, real-time characterization and optimization of fracture networks for enhanced permeability, maximizing storage potential and minimizing re-leakage risks in carbon dioxide mineralization storage.
Implementation Method 1
transporting supercritical carbon dioxide to the storage target reservoir through the injection well structure to fracture a rock mass
Implementation Method 2
constructing monitoring wells to perform microseismic monitoring, analyzing a microseismic waveform signal for performing fracture source locating
Implementation Method 3
obtaining spatial scale parameters of a fracture volume, a fracture surface normal direction and a fracture displacement movement direction through seismic source mechanism inversion
Implementation Method 4
CO2 mineralization storage is capable of achieving more stable CO2 underground storage, moreover mineralization storage carbon-based mineral storage rock strata are widely distributed
Data Source
AI summary
The present invention discloses a carbon dioxide storage target reservoir modified fracture characterization and permeability-increasing effect evaluation method. The evaluation method includes the following steps: enlarging a storage target reservoir fracture network structure, utilizing microseismic monitoring to obtain fracture development waveform data, obtaining a fracture connectivity from three dimensions of a fracture source spacing, a fracture size and a fracture orientation, determining a fracture density by utilizing three-dimensional volume number density of locating points, characterizing a rock mass permeation capability based on a maximum eigenvalue and a corresponding eigenvector of a fracture damage tensor, quantitatively characterizing a storage target reservoir rock mass fracturing and permeability-increasing modified fracture network from three dimensions of connectivity, density and permeability of a target reservoir rock mass, and instantly assessing a permeability-increasing effect of the fracture network structure to achieve storage target reservoir fracture network modification effect maximization.