A measuring system comprises a measuring device for measuring data with respect to a measurement setup comprising circuits with the aid of a probe, and at least one mobile device wirelessly connected to the measuring device, wherein the at least one mobile device displays a live view of the measurement setup superimposed on at least one measurement result of the measuring device.

A data processing device includes: a data obtaining section obtaining time series data on a total value of current consumed by a plurality of electric apparatuses; and a parameter estimating section obtaining a model parameter when states of operation of the plurality of electric apparatuses are modeled by a factorial HMM on a basis of the obtained time series data.

A system of sensors associated with a branched conductor of an AC power line using the conductor as the communication medium between different sensors. The communication is carried out at frequencies higher than the powerline frequency. At least one sensor is provided in every branch in the vicinity of every branching point of the conductor. Synchronous measurements are carried out of the root mean square current passing through every branch of the conductor and the direction of energy flow in the branch. Results of the measurements are regularly reported throughout the system. An arrangement is provided for analyzing the results of the measurements to determine the graph topology of the branched conductor and ascertain the distribution of the root mean square current passing through every branch of the graph.

A computer-implemented method includes linking a plurality of load distribution points in a power distribution unit to a plurality of electrical loads in response to user input, receiving data indicative of one or more electrical parameters associated with the plurality of load distribution points, selecting a visual indicator from a group of indicators based on the one or more electrical parameters associated with the load distribution point for each of the plurality of load distribution points, and displaying the selected visual indicators for the plurality of load distribution points on a visual display for viewing by a user. Each of the electrical loads are electrically coupled to one or more of the plurality of load distribution points. Example computer systems and non-transitory computer readable medium including computer executable instructions for performing one or more computer-implemented methods are also disclosed.

An energy monitoring system for retrofitting a miniature circuit breaker load center 100, comprises energy monitoring module 120, data bus 140, and main controller 110. The energy monitoring module attaches onto miniature circuit breaker 130, forming a combined shape that fits into a branch circuit space of the load center. An attachment connector 320 electrically and mechanically connects the energy monitoring module to load terminal 318 of the circuit breaker. An energy sensing circuit 314 in the energy monitoring module senses energy passing through the circuit breaker and transmits data signals over the data bus to the main controller. The main controller has a shape that fits into another branch circuit space of the load center. The main controller wirelessly transmits to a network, information based on the data signals received on the data bus. The main controller provides operating power via the data bus, to the energy monitoring module.

Embodiments of the present invention may provide a device for monitoring electric power at the distribution level. The device may include an analog-to-digital converter (ADC) to convert an input signal into digital samples at time intervals, a receiver to generate a pulse-per-second (PPS) signal, an oscillator to generate an oscillator signal, and a data processor coupled to the ADC, the receiver, and the oscillator. The data processor may include a counter to measure an oscillator frequency of the oscillator signal at each pulse of the PPS signal, an adjuster to adjust a timer period register value, and a timer to adjust the time intervals based on the adjusted timer period register value. Based on the digital samples, the data processor may generate a plurality of metrics, which may include one or more measurements of frequency, magnitude, phase, harmonic level, signal-to-noise ratio, sag, and swell of the input signal.

Disclosed herein are systems and methods for anomaly detection. A distributed physical state estimation system determines low-level state estimates covering respective sections of a cyber-physical system based on raw, high-performance measurement data. Low-level state estimates may be determined for a plurality of sections (substations) concurrently. An upper-level state estimate may be derived from the low-level state estimates. Anomalies pertaining to the system may be detected through analysis of the low-level and upper-level state estimates. The anomalies may be analyzed to determined whether the system is exhibiting behavior indicative of a fault, cyber-attack, and/or compromise.