Calibrating Hydraulic Fracture Geometry to Microseismic Events
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Solution Overview
Problem
Current hydraulic fracture monitoring methods struggle to accurately model and optimize complex fracture networks in subterranean formations, particularly in simulating the interaction of hydraulic fractures with pre-existing natural fractures and accounting for stress shadow effects, which affects fracture propagation and proppant placement.
Innovation Solution
The development of an unconventional fracture model (UFM) that incorporates an enhanced 2D Displacement Discontinuity Method (DDM) with 3D corrections to compute stress shadows, allowing for the simulation of complex fracture networks with intersecting fractures and the interaction between hydraulic and natural fractures, and the use of microseismic data for calibration.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional hydraulic fracture monitoring methods are used to map fracture locations, then basic fracture extent can be determined, but accurate simulation of complex fracture networks and stress shadow effects cannot be achieved
Solution Approach 1:
The patent transitions from conventional 2D fracture mapping to a 3D fracture network model that incorporates spatial coordinates (x, y, z) and temporal evolution. The system models fractures as three-dimensional geometries with length, height, and width parameters, enabling accurate representation of complex fracture networks including intersections with natural fractures and stress shadow effects in volumetric space.
Solution Approach 2:
The patent integrates multiple modeling components into a composite simulation system: geometric fracture models, stress shadow calculations, microseismic event correlations, and proppant transport modeling. This composite approach combines conventional monitoring data with advanced mechanical earth models to achieve comprehensive fracture network characterization that exceeds the capability of individual methods.
2Adaptability or versatility
If hydraulic fractures are extended into fracture networks with natural fractures, then complex fracture networks are formed, but stress interference and crossing behavior become difficult to predict
Solution Approach 1:
The patent implements an iterative feedback mechanism where the fracture model is repeatedly updated by comparing simulated microseismic event locations with actual observed events. The system adjusts fracture geometry parameters (length, height, width, orientation) and stress shadow calculations until the model accurately reproduces the observed microseismic pattern, thereby validating stress interference predictions.
Solution Approach 2:
The patent dynamically adjusts multiple fracture parameters including geometry (length, height, width), orientation (azimuth, dip), and stress state (minimum and maximum horizontal stresses) to match observed microseismic data. The system modifies these parameters iteratively to account for stress shadow effects and natural fracture interactions, improving prediction reliability for complex fracture networks.
3Manufacturing precision
If fracture geometry is calibrated to microseismic events, then accurate fracture dimensions are obtained, but computational complexity increases
Solution Approach 1:
The patent performs preliminary fracture geometry modeling using initial estimates of fracture parameters before detailed calibration. The system pre-calculates stress shadow effects and generates initial fracture networks based on injection parameters and geological data, providing a starting model that reduces the computational burden and time required for subsequent microseismic event calibration.
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
This approach enables more accurate simulation of hydraulic fracture propagation and stress interference, improving fracture network geometry and proppant placement, leading to enhanced hydrocarbon recovery by optimizing fracture spacing and propagation patterns.
Implementation Method 1
incorporates an enhanced 2D Displacement Discontinuity Method (DDM) with 3D corrections to compute stress shadows
Implementation Method 2
2D Displacement Discontinuity Method (DDM)
Implementation Method 3
use of microseismic data for calibration
Data Source
AI summary
A method of performing a fracture operation at a wellsite about a subterranean formation having a fracture network with natural fractures is provided. The wellsite is stimulated by injection of fluid into the fracture network. The method involves generating wellsite data including natural fracture parameters and obtaining measurements of microseismic events, modeling hydraulic fractures of the fracture network based on the wellsite data and defining a hydraulic fracture geometry of the hydraulic fractures, generating a stress field of the hydraulic fractures using a geomechanical model, determining shear failure parameters comprising a failure envelope and a stress state about the fracture network, determining a location of shear failure of the fracture network from the failure envelope and the stress state, and calibrating the hydraulic fracture geometry by comparing the modeled hydraulic fractures and the locations of shear failure against the measured microseismic events.