DAS and DTS Wellbore Monitoring for Hydraulic Fracturing Screen-Out Detection
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Solution Overview
Problem
Hydraulic fracturing processes face inefficiencies due to screen-outs, where perforations fill with proppant before others, leading to non-uniform fractures and reduced productivity, making it difficult to predict and address screen-outs in real-time.
Innovation Solution
A system combining distributed acoustic sensing (DAS) and distributed temperature sensing (DTS) to detect screen-outs in real-time by analyzing acoustic signals and temperature changes, allowing for accurate fluid allocation modeling and fracture characterization.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If hydraulic fracturing is performed with traditional monitoring methods, then the process can proceed with standard equipment, but screen-outs cannot be detected in real-time leading to non-uniform fractures
Solution Approach 1:
The patent replaces traditional mechanical pressure monitoring with optical sensing systems (DAS and DTS) that use light propagation through optical fibers to detect acoustic signals and temperature changes. This substitution enables real-time detection of screen-outs by monitoring acoustic waveforms and temperature variations along the wellbore, providing both high measurement precision and immediate response capability without the limitations of mechanical sensors.
Solution Approach 2:
The patent introduces optical fibers as intermediary sensing elements that are deployed along the wellbore to detect screen-outs. These optical fibers act as mediators between the fracturing process and the surface monitoring system, transmitting acoustic and thermal information from deep within the wellbore to surface equipment for real-time analysis and response.
2Reliability
If multiple sensing systems are combined to detect screen-outs in real-time, then detection accuracy improves, but system complexity increases
Solution Approach 1:
The patent merges two complementary sensing systems - Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS) - into a unified monitoring platform. Both systems use optical fiber technology as their sensing medium, allowing them to be integrated along the same wellbore trajectory. The combination provides redundant detection capabilities and cross-validation, improving reliability while leveraging shared infrastructure to manage complexity.
Solution Approach 2:
The patent employs optical fibers that serve multiple functions simultaneously - acting as both acoustic sensors (DAS) and temperature sensors (DTS) along the same physical medium. This multi-functionality reduces the need for separate sensor deployments and simplifies the overall system architecture while maintaining high detection reliability through multiple measurement modalities.
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 real-time detection of screen-outs and improved fluid allocation modeling, enhancing the effectiveness of hydraulic fracturing by optimizing fracture formation and reducing the risk of premature process termination.
Implementation Method 1
A DAS can measure data about acoustic signals generated by the treatment fluid moving through the perforations
Implementation Method 2
A DTS can measure warm-back data (e.g., data indicating an increase in temperature toward a geothermal temperature) based on the temperature at the perforation as the perforation warms in response to the screen-out
Data Source
AI summary
Fluid allocation in a well can be determined with a distributed temperature sensing system using data from a distributed acoustic sensing system. Flow data indicating a flow rate of a fluid through a perforation in a well based on an acoustic signal generated during a hydraulic fracturing operation in the well can be received. Warm-back data indicating an increase in temperature at the perforation can be received. A fluid allocation model can be generated based on the flow data and the warm-back data. The fluid allocation model can represent positions of the fluid in fractures formed in a subterranean formation of the well.