DTS-DAS Wellbore Inflow Detection via Segmented Sensing
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Solution Overview
Problem
Determining fluid inflow locations and rates in a wellbore is challenging, especially when multiple production zones are present, as existing methods struggle to accurately identify where fluid is inflowing and quantify the inflow rates.
Innovation Solution
A method and system using distributed temperature sensing (DTS) and distributed acoustic sensing (DAS) to derive temperature and frequency domain features, which are then used in identification and prediction models to determine fluid inflow locations and rates along the wellbore.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If distributed temperature sensing (DTS) and distributed acoustic sensing (DAS) are used to determine fluid inflow locations, then measurement precision is improved, but device complexity increases
Solution Approach 1:
The patent segments the wellbore into multiple discrete locations along its length, with sensing elements distributed at specific intervals. This segmentation allows precise localization of fluid inflow at different depths while managing system complexity through structured spatial distribution of sensors rather than continuous sensing throughout the entire wellbore.
Solution Approach 2:
The patent employs a multi-functional sensing system where the same distributed sensing infrastructure (optical fibers) performs both temperature measurement (DTS) and acoustic detection (DAS). This universal approach improves measurement precision for fluid inflow identification without proportionally increasing device complexity, as a single sensing platform accomplishes multiple detection functions simultaneously.
2Productivity
If multiple production zones are monitored simultaneously, then productivity is improved, but difficulty of detecting and measuring increases
Solution Approach 1:
The patent adds the spatial dimension (depth along the wellbore) to the monitoring system, transforming single-point measurements into distributed spatial measurements. This dimensional expansion enables simultaneous monitoring of multiple production zones at different depths by analyzing temperature and acoustic variations along the wellbore length, thereby improving productivity while managing detection complexity through spatial resolution.
Solution Approach 2:
The patent establishes baseline temperature and acoustic profiles before fluid inflow events occur. These preliminary measurements serve as reference data that simplify subsequent detection of fluid inflow at multiple production zones, reducing the complexity of real-time monitoring by comparing current measurements against pre-established baselines to identify deviations indicating fluid entry.
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 accurate identification and quantification of fluid inflow locations and rates, improving the management of fluid production by providing near-real-time data and enhancing the understanding of fluid flow dynamics within the wellbore.
Implementation Method 1
determining a plurality of temperature features from a distributed temperature sensing signal originating in a wellbore
Implementation Method 2
distributed acoustic sensing (DAS) to derive temperature and frequency domain features
Data Source
AI summary
A method of determining fluid inflow locations comprises determining a plurality of temperature features from a distributed temperature sensing signal originating in a wellbore, using the plurality of temperature features in a fluid inflow identification model, and determining the presence of fluid inflow at one or more locations along the wellbore based on an output from the fluid inflow identification model.