Phase Connectivity Detection via Zero-Crossing Disturbances
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Solution Overview
Problem
In power distribution systems, determining the service phase of customer endpoints is challenging due to outdated or missing information about the grid topology, leading to inaccurate calculations of power losses and revenue loss for utilities, especially as customer density increases.
Innovation Solution
A method using an ad-hoc wireless network with nodes at meter locations and substations to induce temporary power interruptions and detect zero-crossings, allowing for the determination of service phases by measuring relative phase differences and calculating phase shifts, thereby creating a phase connectivity model for the entire grid.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If traditional power distribution monitoring methods are used without real-time phase detection, then the system operation is simple and cost-effective, but the accuracy of power loss calculation and revenue management deteriorates significantly
Solution Approach 1:
The patent replaces physical inspection and manual phase identification methods with electromagnetic field-based detection. Current sensors and voltage sensors detect electrical parameters wirelessly through the existing power infrastructure, eliminating the need for physical grid mapping and manual phase identification while achieving precise phase detection accuracy.
Solution Approach 2:
The patent introduces wireless communication modules and control servers as intermediaries between the power distribution network and monitoring systems. These intermediaries enable real-time data exchange between sensors, meters, and utility systems without requiring direct physical connections or complex wired infrastructure, thus improving measurement precision while maintaining system simplicity.
2Reliability
If real-time phase detection and mapping systems are implemented, then the accuracy of power loss calculation and revenue management is improved, but the device complexity and implementation cost increase
Solution Approach 1:
The patent implements feedback mechanisms where sensors continuously monitor phase information and feed this data back to control servers. The servers automatically update grid topology maps and adjust power distribution calculations in real-time, ensuring high reliability of power loss calculations without requiring complex manual tracking systems.
Solution Approach 2:
The system enables self-service automation where the control server automatically performs phase mapping, topology updates, and power loss calculations based on sensor data. This eliminates the need for utility personnel to manually track grid changes, reducing implementation complexity while maintaining high reliability through automated real-time updates.
3Measurement precision
If comprehensive phase mapping of all customer endpoints is performed, then the accuracy of aggregated usage comparison and theft detection is improved, but the measurement and detection difficulty increases
Solution Approach 1:
The patent segments the large-scale grid mapping problem into smaller, manageable units by implementing hierarchical phase detection. Instead of mapping the entire grid simultaneously, the system divides it into feeder-level segments and customer endpoint segments, detecting phase information at each level independently and aggregating results, thereby improving measurement precision while reducing detection difficulty through modular processing.
Solution Approach 2:
The patent creates universal phase detection capabilities that can be applied across all customer endpoints using standardized sensors and communication protocols. The same detection mechanisms used for phase identification are also utilized for usage measurement, topology mapping, and anomaly detection, improving aggregated usage measurement accuracy without proportionally increasing detection difficulty through multi-functional reuse of the same infrastructure.
Data Source
AI summary
The service phase of the electrical connection to a customer endpoint device located within a power distribution system is determined by various techniques. At the feeder level, the system may be programmed to induce disturbances, thereby causing missed zero crossings at the customer endpoint devices. The pattern of these disturbances is a controlled one, designed specifically to avoid causing noticeable disruption even to sensitive devices, but to be unusual enough that it is statistically unlikely to be naturally occurring. The monitoring of the zero crossing information is used to determine the phase of the service line to the customer endpoint devices.