Fracture Network Model Using Fluid Temperature Predictions
Find Innovative SolutionsGenerate Solutions
Solution Overview
Problem
Current hydraulic fracture monitoring methods and systems are complex and time-consuming, particularly in unconventional reservoirs like shales, due to the complexity of hydraulic fracture networks, which hinders efficient hydrocarbon production and requires extensive computational resources for accurate simulations.
Innovation Solution
A method and system that characterizes hydraulic fracturing in subterranean formations using sensor-measured field data in conjunction with a hydraulic fracture network model, reducing complexity and processing time by constraining geometric properties, allowing for real-time adjustments to the fracturing process, such as optimizing wellbore placement, fluid flow rates, and proppant placement.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional hydraulic fracture monitoring methods are used to accurately simulate fracture networks in unconventional reservoirs, then measurement precision and reliability are improved, but device complexity and computational resources increase significantly
Solution Approach 1:
The patent extracts and separates the geometric properties of the fracture network from the full computational model. By identifying and isolating key geometric parameters that can be directly constrained by field data, the method removes the need for complex simulations while maintaining characterization accuracy.
Solution Approach 2:
The patent applies preliminary constraints to the geometric properties of the fracture network before performing full simulations. By pre-constraining geometric parameters using field data, the method reduces the computational search space and eliminates the need for extensive iterative simulations.
2Measurement precision
If conventional hydraulic fracture monitoring methods are used with extensive simulations, then measurement precision is improved, but loss of time increases due to computational processing time
Solution Approach 1:
The patent extracts only the essential geometric properties needed for characterization, avoiding full computational simulations. This extraction approach maintains measurement precision while eliminating time-consuming computational processing.
Solution Approach 2:
The patent performs preliminary constraint application using field data before any simulation work. This preliminary action establishes the fracture network geometry upfront, eliminating the need for iterative computational processing and reducing time loss.
3Productivity
If real-time optimization of fracturing process is implemented, then productivity is improved, but device complexity increases due to additional monitoring and control systems
Solution Approach 1:
The patent enables the fracturing process to self-optimize by using field data to directly constrain geometric properties. The system uses the data itself to guide the optimization without requiring complex external monitoring and control systems, achieving productivity improvement through self-service.
Solution Approach 2:
The patent makes the field data collection system multi-functional by using it for both fracture network characterization and real-time process optimization. This universal approach eliminates the need for separate dedicated monitoring and control systems, reducing device complexity while maintaining productivity benefits.
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 real-time optimization of the hydraulic fracturing process, improving hydrocarbon production efficiency by reducing computational complexity and enabling faster design and analysis of stimulation jobs, thereby enhancing production rates and fracture geometry alignment with desired results.
Implementation Method 1
a hydraulic fracture network model, the model comprising a heat transfer model for predicting a temperature of the fracturing fluid in the wellbore
Data Source
AI summary
A method of performing an oilfield operation about a wellbore penetrating a subterranean formation. The method involves performing a fracture operation comprising injecting fluid into the formation and generating fractures about the wellbore. The fractures form a fracture network about the wellbore. The method further involves collecting during the performing data comprising injection temperature and pressure, generating a fluid distribution through the fracture network by performing real time simulations of the fracture network based on the collected data (the fluid distribution comprising temperature distribution), and performing a production operation comprising generating production based on the temperature distribution.