Abstract: An improvement to a utility (U) meter's (M) meter reading schema. The improvement includes a device (D) responsive to a native language with which a meter is programmed to convert communications to and from the meter from that native language into a neutral language. The neutral language is convertible by other meters programmed with different native languages into the native language of a particular meter for meters programmed with different native languages can communicate with each other. This allows facilities within a localized area of a utility's power grid (G) to form into a micro-grid (MG) in which meters programmed with the same or different native languages can communicate with each other without having communications between them routed through a central location of the utility.

Abstract: A switched capacitor bank system including a switched capacitor bank assembly having a switch between a capacitor and a phase line, a first voltage sensor to sense a phase line voltage, and a second voltage sensor to sense a capacitor voltage. The switched capacitor bank system includes a wireless current sensor to sense a current of the phase line and an electronic controller configured to receive a first voltage signal from the first voltage sensor, a second voltage signal from the second voltage sensor, a current signal from the wireless current sensor, determine a phase shift calculation for the voltage of the phase line based on the current signal, determine when the voltage of the phase line is at zero by comparing the first voltage signal, the second voltage signal, and the phase shift calculation, and close the switch when the voltage of the phase line is at zero.

Abstract: A system for determining a linear state estimation of a power distribution network. The system includes a plurality of metering devices, a plurality of power sources, each of the plurality of power sources coupled to a respective metering device, and a plurality of collection devices, each of the plurality of collection devices in electronic communication with a respective metering device. The plurality of collection devices measure an Advanced Metering Infrastructure (AMI) dataset and calculate a phase angle of the power source coupled to the metering device. The system includes a host device in electronic communication with the plurality of collection devices. An electronic processor of the host device receives the AMI dataset and the phase angle of the plurality of metering devices, determines the linear state estimation of the power distribution network based on the phase angle and the AMI dataset, and identifies information associated with the power distribution network.

Abstract: A switched capacitor bank assembly may include a first capacitor. The switched capacitor bank assembly may include a first switch selectively connected between the first capacitor and a first phase line. The switched capacitor bank assembly may include a first voltage sensor integrated within a housing of the first switch and used to sense a. The switched capacitor bank assembly may include voltage of the first phase line, a controller including an electronic processor, the controller operably coupled to the first voltage sensor and the first switch; and a frame arranged to physically support the first capacitor, the first switch, the first voltage sensor, and the controller; and a communication module configured to wirelessly communicate with an external device, wherein the communication module is contained within a second housing that is physically supported by the frame.

Abstract: Systems and methods for coordinating monitoring devices associated with a medium voltage distribution system. The systems include a data aggregation device, a first monitoring device associated with a first phase of the medium voltage distribution system, and a second monitoring device associated with a second phase of the medium voltage distribution system. The first monitoring device is configured to sense one or more parameters of the first phase, store the one or more stored parameters, and determine whether an event has occurred based on the sensed parameters. The first monitoring device is further configured to transmit a coordination signal to a second monitoring device in response to determining the event has occurred and a first event message to a data aggregator device in response to determining the event has occurred, wherein the event message includes one or more sensed parameters associated with the determined event.

Abstract: A metering system including a utility meter having a processing circuit and a communication module interface. The metering system also includes a communication module electronically coupled to the utility meter via the communication module interface. The communication module interface is configured to transmit information to, and receive information from, the utility meter. The processing circuit of the utility meter includes one or more electronic processors that are configured to receive a first message from the communication, read a header frame of the first message, and determine a message type of the first message based on the header frame. The electronic processors are also configured to verify the first message based on the determined message type, and process the first message based on the determined message type.

Abstract: A telemetry device is configured to receive data from one or more sensing devices associated with a component of a utility system. The telemetry device processes the received data by determining a range associated with a value of the received data, and in response to determining the value of the received data is in a first range, generate a first data package having a second number of received data values and transmit the first data package at a first transmission interval. In response to determining that the value of the received data is in a second range, the telemetry device is configured to generate a second data package having a second number of received data values and transmit the second data package at a second transmission interval.

Abstract: A utility sensor module includes one or more sensors, a communication link, and an electronic processor. The electronic processor is configured to broadcast an advertisement signal associated with a communication protocol for a first transmission time. The advertisement signal is configured to cause an external device to transmit a response message. The electronic processor is further configured to determine whether the response message is received within a predetermined time period, and in response to determining that the response message was not received within the predetermined time period, operating in a modified sleep mode. Operating in the modified sleep mode includes modifying the operation of the communication interface to broadcast the advertisement signal at a periodic interval, such that the advertisement signal is only broadcast at the periodic interval for a second transmission time.

Abstract: A system includes a number of sensor units and a local controls station. The sensor units include one or more conductor sensors configured to monitor one or more parameters of a conductor in a power distribution system. The local control station includes a communication interface for communicating with the sensor units and a controller. The controller is configured to receive data from the sensing units, determine whether an event associated with one or more components of a power distribution network occurred based on the received data, and then determine whether the event requires protective action in response to determining that the event occurred. The controller determines whether the event occurred downstream of the local control station, and, in response to determining that the event requires protective action and occurred downstream of the local control station, control the one or more protective devices to perform a protective action.

Abstract: A contaminant detector is capable of sending a signal or alert when a contaminant is detected within a housing of a utility meter, a meter transmission unit (MTU), or other associated equipment. Circuitry enclosed within the housing is capable of detecting utility usage, transmitting information between one or more utility meters and a utility provider, and/or otherwise monitoring or tracking utility usage. The contaminant detector includes a resistive voltage divider network having a resistance that varies when in contact with a contaminant such as a form of water or metal. The variable resistor has a serpentine structure comprising a plurality of detective fingers that are formed from conductive material and separated by a non-conductive substance.

Abstract: A system for determining a phase of a power supply coupled to a metering device. The system includes a collection device in electronic communication with a metering device connected to a power distribution network and having a memory and one or more electronic processors. The electronic processors are configured to receive a first beacon signal and measure a phasor in response to receiving the first beacon signal. The phasor is stored in the memory along with an identification value associated with the device that transmitted the first beacon signal and a first time. The electronic processors receive a second beacon signal, and extract data from the request message. The electronic processors determine whether the extracted time matches the first time and based on determining that the extracted time matches the first time stored in the memory, calculate a phase by comparing the reference phasor data to the stored phasor.

Abstract: An electric utility meter includes a housing, an input configured on the housing that receives input electricity from an electricity source, and a controller having an electronic processor and a memory. The electronic processor is configured to measure a first characteristic and a second characteristic of the input electricity, determine a fault parameter value, calculate a confidence score corresponding to the fault parameter value, compare the confidence score to a threshold value, and determine that a fault is occurring based on the confidence score exceeding the threshold value.

Abstract: Techniques for determining conditions of power lines in a power distribution system based on data collected by a plurality of sensor units deployed in the power distribution system. The techniques include obtaining data associated with measurements collected by at least two sensor units in the plurality of sensor units, and determining, by using at least one processor, at least one condition of at least one power line in the power distribution system by using the data obtained by the at least two sensor units.

Abstract: A faulty meter socket detection system configured to detect faulty sockets as evidenced by series arcs in an input current waveform or an increased temperature of the meter is disclosed. The system includes a metering circuit configured to receive an input current waveform, and a controller including a power monitoring module. The meter may also include a temperature sensor. The power monitoring module is configured detect series arc currents input current waveform data by filtering the input current waveform data to produce filtered data, performing feature recognition on the filtered data, classifying the features of the filtered data, performing temporal processing on the filtered data, (optionally) scaling the temporal processing of the filtered data, and, scoring the input current waveform based on the temporal processing of the filtered data. The temperature sensor may detect an increased temperature of the meter, which may indicate a faulty socket.

Abstract: An optimized, energy-sensitive system and method for fulfilling various data needs of gas utilities. In particular, the disclosure relates to optimized methods for discovering and reacting to an alarm. In one aspect, when an alarm is triggered a telemetry unit automatically alters its operating mode to begin transmitting live pressure reads every minute instead of every hour, as typically performed. This variance in operation eliminates the need for a user to monitor a pipeline system for an incoming alarm and manually request data by initiating a live communication session.

Abstract: An improvement to a utility (U) meter's (M) meter reading schema. The improvement includes a device (D) responsive to a native language with which a meter is programmed to convert communications to and from the meter from that native language into a neutral language. The neutral language is convertible by other meters programmed with different native languages into the native language of a particular meter for meters programmed with different native languages can communicate with each other. This allows facilities within a localized area of a utility's power grid (G) to form into a micro-grid (MG) in which meters programmed with the same or different native languages can communicate with each other without having communications between them routed through a central location of the utility.

Abstract: An electrical meter including a housing including a socket interface operable to connect to a facility. The meter further including a sensor configured to sense a characteristic of the electrical meter. The meter further including a controller having an electronic processor and a memory. The electronic processor is configured to receive, from the sensor, a signal indicative of the electrical characteristic, determine, based on the signal, presence of a hot socket, and output an alert based on determining presence of the hot socket.

Abstract: A node in a power distribution system is described. The node includes an electrical connection to a single-phase power signal from an AC mains power source, a wireless communication interface configured to receive a first phase synchronization message, and a controller. The controller is configured to determine whether the first phase synchronization message is acceptable and detect a zero-crossing event on the single phase power signal subsequent to the receipt of the first phase synchronization message in response to determining that the first phase synchronization message is acceptable. The controller is further configured to calculate a time difference between the receipt of the first phase synchronization signal and the detected zero-crossing event, determine a local phase angle based on the time difference, and establish an identity of the single phase power signal based on the local phase angle.

Abstract: Improved power line management is provided by the systems and methods disclosed herein that accurately measures voltage in a power distribution system. In various embodiments, the system may include one or more sensor units, each coupled to the power lines using a capacitive or resistive voltage divider to yield a voltage at a sensor unit that is within a measurable range. In one aspect, this voltage may also be used to power the sensor unit and/or other devices coupled to it.