Impedance Shift Analysis for Power Network Failure Prediction
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Solution Overview
Problem
The existing electrical power distribution networks lack accurate methods for predicting failures in overhead splices, which can lead to thermal runaway and dangerous line breaks, due to the lack of precise information on the number and placement of these splices, and existing methods do not effectively detect impending failures before they result in power outages.
Innovation Solution
The method involves impedance shift analysis, where a sequence of electrical measurements is collected over time, processed to identify trends, and a slope is computed to determine if the impedance increase exceeds a threshold, triggering a notification for physical inspection via a computer communications network, using upstream and downstream electrical meters connected through a mesh network.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Reliability
If traditional power distribution monitoring methods are used, then the system structure remains simple, but failure prediction capability is insufficient and cannot detect impending thermal runaway
Solution Approach 1:
The system performs preliminary impedance measurements and trend analysis to detect thermal runaway conditions before they cause failures. By continuously monitoring impedance shifts and computing slopes of trend lines, the system identifies impending failures in advance, allowing preventive action before actual outages occur.
Solution Approach 2:
The system establishes a feedback loop where impedance measurements are continuously taken, processed through trend analysis, and used to generate alerts when threshold steepness is exceeded. This closed-loop monitoring enables real-time detection and response to developing thermal runaway conditions throughout the power distribution network.
2Loss of time
If impedance shift analysis with trend line slope computation is implemented, then early failure detection is achieved, but data processing complexity increases
Solution Approach 1:
The system uses the existing electrical measurement infrastructure (meters already present in the power distribution network) to collect impedance data. This self-service approach leverages available resources rather than requiring entirely new measurement equipment, reducing overall system complexity while enabling advanced failure detection.
Solution Approach 2:
The system replaces physical inspection methods with automated computational analysis. Instead of manual monitoring and physical checks, the system uses computer-based trend line computation and automated alert generation, substituting mechanical/manual processes with electronic data processing to reduce time to detection.
3Measurement precision
If continuous impedance monitoring is performed, then failure prediction accuracy is improved, but energy consumption increases
Solution Approach 1:
The system performs impedance measurements at periodic intervals rather than continuously, collecting data at scheduled times and processing trends between measurements. This periodic monitoring approach maintains measurement precision for failure detection while significantly reducing energy consumption compared to continuous real-time monitoring.
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 allows for early prediction of failures, reducing the time to locate and address issues, thereby preventing power outages and dangerous conditions by accurately identifying impending thermal runaway in electrical power distribution networks.
Implementation Method 1
receiving a sequence of electrical measurements indicative of an impedance measured for a segment of an electrical power distribution network over a period of time
Data Source
AI summary
Embodiments of the present invention provide for impedance shift analysis for failure prediction in an electrical power distribution network. In an embodiment of the invention, the method includes receiving a sequence of electrical measurements indicative of an impedance measured for a segment of an electrical power distribution network over a period of time. Then, a set of impedance measurements is computed for the period of time and the set of impedance measurements is organized into a distribution correlating each one of the impedance measurement with a corresponding computed current measurement. A trend line for the distribution is identified and a slope computed of the trend line. Finally, on condition that the slope exceeds a threshold steepness, an impending failure in the segment is determined and a notification transmitted over a computer communications network to an end user requesting physical inspection of the segment.