Hydraulic Fracture Geometry Uncertainty Reduction
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Solution Overview
Problem
Hydraulic fracturing operations face uncertainty in estimating the geometry of hydraulic fractures due to high uncertainty in microseismic monitoring results, which affects production economics and completion costs.
Innovation Solution
A computing device manipulates the injection flow rate of fracturing fluid to increase the number of simultaneous microseismic events, reducing uncertainty in microseismic monitoring results by using additional microseismic events to update and calibrate the fracture model, specifically employing the Perkins-Kern-Nordgren model to predict hydraulic fracture geometry.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If microseismic monitoring is used to estimate hydraulic fracture geometry, then fracture geometry can be estimated, but high uncertainty in monitoring results reduces accuracy
Solution Approach 1:
The system uses real-time feedback from multiple microseismic events to continuously update and calibrate the fracture model. Each microseismic event provides feedback information about fracture propagation, which is used to adjust model parameters and reduce uncertainty in the predicted fracture geometry.
Solution Approach 2:
The patent combines multiple microseismic events into a unified fracture model update process. By merging information from multiple events rather than relying on single-event data, the system reduces uncertainty and improves the reliability of geometry estimation.
2Quantity of substance
If injection flow rate is increased to generate more microseismic events, then more data for model calibration is obtained, but operational complexity and costs increase
Solution Approach 1:
The system dynamically adjusts the injection flow rate based on real-time fracture model predictions and microseismic event detection. The flow rate is modified during the fracturing operation to optimize the generation of microseismic events for model calibration, rather than using a fixed or continuously high flow rate.
Solution Approach 2:
The patent changes the injection flow rate parameter strategically to induce microseismic events that provide valuable calibration data. By temporarily modifying this parameter and then returning to original conditions, the system obtains necessary monitoring data without permanently increasing operational complexity.
3Measurement precision
If fracture model is continuously updated with microseismic data, then predicted fracture geometry accuracy improves, but processing time and computational resources increase
Solution Approach 1:
The system performs partial model updates by selecting only the most significant microseismic events for calibration rather than processing every detected event. This approach maintains accuracy while reducing the computational burden and processing time required for continuous model updates.
Data Source
AI summary
Uncertainty of microseismic monitoring results can be reduced to improve hydraulic fracture modeling. A computing device can use a fracture model to determine a predicted geometry of a hydraulic fracture in a subterranean formation based on properties of a fracturing fluid that is introduced into the subterranean formation. An uncertainty index of the predicted geometry of the hydraulic fracture can be determined based on an uncertainty value of the predicted geometry and a trend of uncertainty values. When the injection flow rate of the fracturing fluid is less than a maximum flow rate, it can be increased from an initial injection flow rate to an increased injection flow rate in response to determining the uncertainty index exceeds a pre-set maximum.