Abstract: A system and method to determine battery lifetime of a remote meter transmission unit. Disclosed methods may comprise sampling a meter transmission unit's voltage and temperature while the unit is not transmitting any data; selecting a temperature curve based on the sampled temperature of the unit from a plurality of predetermined temperature curves, wherein each predetermined temperature curve representing the battery lifetime based on the unit's sampled voltage at the unit's sampled temperature; locating a position from the selected curve based on the voltage sampled of the unit; determining the battery's electrical power consumed and remained based on the position of the curve; and determining the battery's lifetime based on the power consumed and remained. The disclosed method may be used to estimate the battery's remaining lifetime. Disclosed products may utilize the disclosed method.

Abstract: An electric utility distribution system in which power is supplied by a distribution transformer through an electric utility meter including an apparatus for detecting the presence of a back-feed voltage source connected to the load. The apparatus includes a virtual neutral established in the electric utility meter at ground potential and a remote switch that is opened to interrupt electric power flow from the distribution transformer to the load. The apparatus further includes a balanced voltage divider circuit including a connection point established between a pair of series connected resistive elements. In addition, the apparatus includes a detection circuit configured to monitor a voltage signal at the connection point to detect a back-feed voltage source connected between a neutral conductor of the electric utility distribution system and one of a first or second power line at the load.

Abstract: An energy harvesting device (CTH) installed in an electrical distribution system (EDS) for powering ancillary electrical devices (AD) used in the distribution system. The device includes a first voltage regulator circuit (CC) configured to produce a voltage matched to a power curve of a current transformer (CT) to which the device is electrically coupled. The device also includes a second and separate voltage regulator circuit (SVR) which continuously operates to maximize the amount of electrical energy recovered from the current transformer.

Abstract: Improvements to IEC 61968-9:2013 meter reading schemas. These include significantly compressing messages into a single integer number which, when transmitted over a utility's communication system, is used to configure meters at utility user locations, obtain meter data, command and control operations at a utility location, and expand messaging capabilities. A method is disclosed for simplifying the IEC 61968-9:2013 schema for communications between a HeadEnd utility communications facility and the meter at an EndPoint so to enable use of the schema for operations it could not previously perform. While providing this enhanced capability, the IEC 61968-9:2013 schema's ability to function for its intended purpose; i.e., meter reading and control, is not compromised or impeded.

Abstract: Disclosed herein are devices, designs, and methods of attaching an antenna to a utility meter faceplate. The faceplate is capable having an antenna adhesively attached to a side surface of the faceplate in a manner that minimizes noise from meter components.

Abstract: The present disclosure pertains to novel systems and methods that incorporate advanced inference algorithms can be developed to detect floating neutrals using phasor measurements. In one aspect, the present disclosure relates to the use of phasor measurements to detect and localize floating neutrals in a distributed power network.

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: Systems and methods for detecting faults in a power distribution network are described. In an aspect, the systems and methods determine a probability that each node of the network is powered and a probability that each distribution line in the network is faulted. In another aspect, the systems and methods determine the probabilities by transmitting a signal over a power distribution network with an active sounding system. In an additional aspect, the systems and methods determine the probabilities by utilizing collected data coupled to the power distribution network.

Abstract: Disclosed herein are devices, designs, and methods of attaching an antenna to a utility meter faceplate. The faceplate is capable having an antenna adhesively attached to a side surface of the faceplate in a manner that minimizes noise from meter components.

Abstract: Systems and methods for synchronized phasor measurement in a power distribution network are described. In an aspect, the systems and methods quantify the phase angle between voltages or currents at any two points in the distribution network. In another aspect, the systems and methods establish a common time reference between points on a power distribution network by transmitting a synchronization pulse throughout the distribution network. In an additional aspect, the systems and methods extract phasors from a power line waveform by utilizing a phase-locked loop (PLL) and regression of the zero-crossings of the PLL output waveform.

Abstract: An antenna system for a meter and/or other communication device, including a capacitive electric field source and an external antenna element. The capacitive electric field source is positioned within a dielectric cover and is electrically connected to an output port of a transceiver for forming an electric field indicative of the output signal. The external antenna element is separated from the capacitive electric field source by the dielectric cover and is configured for capacitively coupling to the capacitive electric field source and radiating electromagnetic radiation indicative of the output signal. The external antenna element then efficiently radiates and receives electromagnetic waves for wireless communications.

Abstract: A circuit (100) for coupling an amplifier (1) in an electrical power distribution system with the amplifier electrically and physically isolated from a power line of the system. The amplifier generates arbitrary signal waveforms injected into the power line. A transformer (T1) has a primary and a secondary side with the amplifier located on the primary side and the secondary side connected to the power line. A resistor (R1) series connected with the primary side of the transformer is sized to accommodate a minimum load impedance of the amplifier and minimize power dissipation. A resonant circuit interposed between the secondary side of the transformer and the power line has values for a capacitor (C1) and an inductor (L3) forming the resonant circuit chosen to peak the amplitude of the arbitrary signal waveform at the frequency of a waveform propagated through the power line.

Abstract: A trident antenna arrangement (300) is described. The antenna arrangement includes a driving element (302), a first parasitic element (304), a second parasitic element (306), a feed point (308), and a ground plate (309) disposed on a substrate (310). The parasitic elements have different lengths which causes a dual resonance. Operation of the driving element and parasitic elements over the substrate and the ground plate allows the antenna system to be minimally impacted by the conductive material underneath. The antenna arrangement is used to transmit water meter (110) readings from a remote location to a utility.

Abstract: A sensor unit coupled to a first wire of a power line for measuring power-related parameters of the power line. The sensor unit contains a first capacitor and makes voltage measurements relative to another wire, to which the sensor unit is coupled by a second capacitor. The captors form a voltage divider such that the sensor unit may measure a voltage in a range much lower than the voltage on the power line. Additionally, the capacitive voltage divider yields a voltage that can be used to power the sensor unit, including by charging an energy storage device. The sensor unit may also supply power to other nearby devices, such as other devices that form a mesh sensor network.

Abstract: The present disclosure pertains to novel systems and methods that incorporate advanced inference algorithms can be developed to detect floating neutrals using phasor measurements. In one aspect, the present disclosure relates to the use of phasor measurements to detect and localize floating neutrals in a distributed power network.

Abstract: An apparatus, network system, and method for detecting network phenomena of a power distribution network. A signal injection device adapted to be connected to the power distribution network injects a signal having signal parameters onto the power distribution network. A signal receiving device adapted to be connected to the power distribution network receives the injected signal on the power distribution network. The signal receiving device is adapted to determine the signal parameters of the received signal and is adapted to evaluate the signal parameters of the injected signal with respect to the determined signal parameters of the received signal. An output device connected to the signal receiving device provides an indication of the determined evaluation.

Abstract: Techniques comprising obtaining, using a sensor unit coupled to a power line in a power distribution system, at least one measurement of at least one inertial property of the power line; and detecting at least one condition of the power line at least in part by analyzing the at least one measurement. A sensor unit configured to be coupled to a power line in a power distribution system, the sensor unit comprising an inertial sensor configured to collect at least one measurement of at least one inertial property of the power line.

Abstract: An energy management system (EMS) is connected to a distribution grid upstream of substation transformers and provides a demand response (DR) program signal to the distribution grid. The program signal specifies a target load adjustment. A plurality of DR RCE (Demand Response Remote Communication Equipment) are connected to phases of the distribution grid downstream of a corresponding substation transformer. Each DR RCE controls an operation of a plurality of endpoint devices. A plurality of FANG devices, each connected to phases of the distribution grid downstream of a corresponding substation transformer, receives the DR program signal via the grid. Each FANG device selectively controls power to its endpoint devices in response to a received DR program signal. As a result, the FANG device reduces the total power applied to its endpoint devices in response to the DR program signal.

Abstract: An optical voltage sensor for measuring voltage on an underground power line or for use in other scenarios in which access to a conductor is available through a blind hole. The optical voltage sensor includes a light modulating member, such as a Pockel's crystal. A reflective, conductive member is positioned at one end of the light modulating member and another conductive member is positioned at an opposed end. A voltage capacitively coupled to the reflective conductive member induces a voltage across the light modulating member, thereby impacting the amount of modulation. A beam of light is directed through the crystal and reflected back out of the crystal, where the amount of modulating can be measured. The amount of modulation indicates a measured voltage, and can be transmitted to a monitoring station where processing can determine the status of the power grid or generate other results based on the measured voltage.