Extendable Fracture Imaging Module for Microseismic Detection
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Solution Overview
Problem
Conventional microseismic event detection systems in the oil and gas industry face challenges such as limited observation distance, high noise interference, and costly deployment and retrieval processes, particularly when attempting to image fractures within a wellbore during fracturing operations.
Innovation Solution
A fracture imaging module (FIM) with axially spaced 3-component sensors that can be extended and collapsed, allowing for increased measurement windows within the wellbore, reducing noise interference, and enabling accurate microseismic event detection without the need for remote wellbores or surface arrays, by being integrated into a bottomhole assembly (BHA) for real-time monitoring.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If sensors are positioned at surface in a surface array, then deployment and retrieval costs are reduced, but observation distance is limited to kilometers and only larger magnitude events can be detected
Solution Approach 1:
The patent transitions sensor deployment from surface level to subsurface wellbores, changing the spatial dimension of observation. By positioning sensors within the formation at depths of several hundred meters to kilometers, the system achieves both close proximity to microseismic events for high detection precision and extended observation distance through the vertical dimension of wellbore access.
2Measurement precision
If sensors are deployed in an adjacent vertical observation well, then smaller magnitude events can be detected, but the system requires the existence of an adjacent well and is only optimally located for a small number of frac ports
Solution Approach 1:
The patent integrates microseismic sensors directly into the fracturing toolstring, enabling the same equipment to perform both fracturing operations and microseismic monitoring. This multi-functional approach eliminates the need for separate observation wells and allows comprehensive coverage of multiple frac ports along the horizontal wellbore, as the sensors move with the fracturing operation to each treatment location.
3Adaptability or versatility
If sensors are deployed in an adjacent horizontal well, then coverage of frac ports is improved, but complicated equipment such as wireline tractor or pump assembly is required
Solution Approach 1:
The patent combines microseismic sensors with the fracturing toolstring, merging two previously separate operations (fracturing and monitoring) into a single integrated system. This eliminates the need for additional complex deployment equipment such as wireline tractors or pump assemblies, as the sensors are already positioned at the treatment location through the normal fracturing operation.
4Measurement precision
If the measurement window is increased to reduce positioning errors, then 3D positioning accuracy improves, but the device length increases making deployment and retrieval more difficult
Solution Approach 1:
The patent employs an extendable measurement window that can be dynamically adjusted between a retracted configuration for compact deployment and an extended configuration for enhanced measurement capability. This dynamic structure allows the sensor array to achieve the necessary baseline length for accurate 3D positioning while maintaining a compact form factor that facilitates easy deployment and retrieval through the wellbore.
Data Source
AI summary
Fracture imaging modules having one or more 3-component sensors, are incorporated into a tool comprising two or more of the modules for detecting microseismic events in a formation from the same wellbore as is being stimulated. The modules are locked together in a compact mode to permit injection into the wellbore through a conventional lubricator which has a fixed length. Once injected into the wellbore, the modules are spaced from one another in an extended mode to form an axially spaced sensor array which increases the measurement window in the wellbore compared to sensor arrays conventionally injected through a fixed length lubricator. Following the operation, the modules are actuated to return to the compact mode for pulling out of the hole through the lubricator.