A method, apparatus, and system for identifying electrical phases connected to electricity meters are disclosed. Voltage time series data of electricity meters are collected over a preselected collection time period, and three initial kernels representing three line-to-neutral phases are generated based on voltage correlations of meter-to-meter combinations. Three new kernels are then generated based on correlation values calculated for each of the three initial kernels with each electricity meter, and electricity meters are clustered into three groups based on average correlation values associated with each electricity meter. Six new kernels representing six phases are then formed based on the average correlation value associated with each electricity meter, and a predicted phase is assigned to each electricity meter based on correlation values of the electricity meter with each of the six new kernels based on the voltage time series data.

Methods are described for monitoring a power grid at an output of a power converter. Operational parameters of the power converter may be determined as a result of data collected during monitoring. A grid code for the power grid to which the power converter is to be connected may be received subsequent to the collecting. An operational mode of the power converter may be established, based, at least on part, on the operational parameters and the grid code. In the event the grid code and the operational parameters match, the power converter may be activated for electrical power production based on the operational mode. When the grid code and the operational parameters do not match, an error condition may be raised.

A current measurement system comprising a multi-phase open loop current transducer for measuring phase currents (I.sub.1, I.sub.2, I.sub.3) flowing in a plurality n of primary conductors of a multi-phase electrical system. The transducer comprises a housing, a magnetic core including first and second core parts and a plurality n+1 of magnetic field detectors mounted in the housing between the first and second core parts in which portions of the primary conductors traversing the current transducer housing are positioned. The system further comprises a non-volatile memory in which information on at least one coupling matrix (K), pre-defined in a calibration procedure, is stored.

An energy storage system can include a battery, a power converter comprising a first plurality of switching devices coupled to the battery and a second plurality of switching devices coupled between the first plurality of switching devices and an AC power system, and control circuitry that determines whether the AC power system is a single/split phase system or a three phase system and operates the first and second pluralities of switching devices accordingly. The control circuitry can include a microcontroller and a plurality of voltage sensors each configured to monitor a magnitude and a phase of a voltage to allow the control circuitry to determine whether the AC power system is a single/split phase system or a three phase system and whether the AC power system is connected with a line to line or line to neutral fault condition

A method for monitoring power consumption of an appliance within a space is provided. The method includes obtaining a first set of data indicative of power consumption of the appliance during an interval of time and determining a profile indicative of power consumption of the appliance based, at least in part, on the first set of data. The method includes obtaining a second set of data indicative of power consumption of the appliance subsequent to obtaining the first set of data. The method includes determining whether power consumption of the appliance deviates from the profile based, at least in part, on the second set of data. Furthermore, in response to determining power consumption of the appliance deviates from the profile, the method includes providing a notification indicative of power consumption of the appliance deviating from the profile.

A state estimation apparatus is configured to extract a time interval to be analyzed from a time series of a first signal based on a second signal acquired in conjunction with the first signal relating to the operation of the facility, and estimate a change in a state of the facility based on waveform data of the time interval of the first signal.

A system and method for fault location and isolation in an electrical power distribution network, where the network includes a plurality of switching devices provided along a feeder. The method includes detecting an overcurrent event in the network from the fault and interrupting the overcurrent event by opening and then immediately locking out or subsequently reclosing and testing the fault. A count value is increased in each switching device that detected the overcurrent event. A count and current (C&I) message is sent from each of the switching devices that detected the overcurrent event and then detected the loss of voltage upstream to an upstream neighbor switching device. Current measurements in the C&I messages, measured current by the devices and the counts values in the devices determine what devices are opened to isolate the fault.

The present invention disclosed a method for calculating an oscillation damping ratio of a power grid, and relates to the field of power system operation and control. When a power system oscillates, an oscillation period, two oscillation extreme points, and an oscillation direct current component start to be detected. Then an oscillation decay time constant is calculated according to the two oscillation extreme points and the oscillation direct current component. The oscillation damping ratio is calculated through the oscillation decay time constant and the oscillation period. Compared with a conventional fitting method, the conventional fitting method cannot calculate and analyze the oscillation damping ratio in a cast that a complete oscillation waveform is not obtained. The method proposed by the present inventive patent may complete the calculation of the oscillation damping ratio in a case of obtaining 2 pieces of data, so as to accelerate the speed of calculation.

Disclosed are an online analysis system and method for a line loss of a transmission line. The system includes: a terminal extension and a terminal host, where time information synchronization between the terminal extension and the terminal host and between terminal extensions is performed by a clock synchronization module, and communication between the terminal extension and the terminal host and between the terminal extensions is performed by a communications module; and a line loss management platform, configured to receive measurement data of the terminal extension and the terminal host, match time information in the measurement data, and if time information in the measurement data of the terminal extension and the terminal host is matched, and time information in measurement data of the terminal extensions is matched, determine corresponding line loss information based on corresponding measurement information.

A transformer area identification method includes: performing data acquisition on all sub-meters and a master meter in an identification domain to obtain a steady-state load, and generating a steady-state load jump curve; and performing load jump feature matching between steady-state load jump curves of all the sub-meters and a steady-state load jump curve of the master meter, and obtaining attribution of the sub-meters with a load jump according to matching results. A method for constructing transformer area line topology is further provided. A load jump identification technique is utilized to acquire a load value of each node in a transformer area power supply network, so as to form a load jump curve for each node. By performing load jump feature matching between load jump curves of all sub-meters and a load jump curve of a master meter, a mounting relationship of a corresponding electric meter is determined.