233results about "Remote metering" patented technology

A system for providing communications with a plurality of power distribution equipment via a broadband over power line communication system that provides broadband internet access to a plurality of consumers is provided. In one embodiment, the system may include a computer system having executable program code executable to generate control messages for controlling the plurality of power distribution automation equipment and a plurality of interface devices, wherein each interface device is communicatively coupled to one or more of the plurality of power distribution equipment. The computer system may be configured to transmit control messages to the plurality of power distribution equipment via a communication path that includes the broadband over power line communication system and the plurality of interface devices.

An apparatus and method control transmission of messages over a fixed bandwidth link from fixed position communication devices to a central controller in a load management system. The messages include information relating to electric power consumption by power consuming devices located at service points that include the communication devices. In one embodiment, the central controller determines an identifier associated with each communication device, a reporting period during which the messages are to be transmitted by the communication devices, and transmission increments within the reporting period. The controller allocates each transmission increment to a respective group of communication devices. The controller then determines a transmission time for a message from a particular communication device based on the identifier for the particular device, a duration of a transmission increment allocated to a group of communication devices that includes the particular device, and a quantity of communication devices in the particular device's group.

A system that includes low voltage power line subnet coupler that provides bi-directional communications between multiple power line subnets while substantially preventing the flow of power is provided. The system may include a power line communications device coupled to a first LV power line subnet, and a low voltage power line subnet coupler providing a data communications path between the first low voltage power line subnet and a second low voltage power line subnet. Additionally, some embodiments include a low voltage repeater communicatively coupled to the second LV power line subnet.

An endpoint in a power distribution system includes a transmitter. The transmitter includes a transformer, a half-bridge driver, a first and second driver, and a resonant circuit. A primary winding from the transformer is coupled to a power distribution line, while the secondary winding is coupled to the transmitter. The half-bridge drive circuit selectively asserts drive signals. The resonant circuit has a natural resonant frequency in an audio frequency range. The half-bridge driver is arranged to selectively activate the first and second drivers such that the power-line is modulated with a square-wave signal at a frequency that is associated with encoded data. The half-bridge driver circuit can also be arranged to provide power to the transmitter, and to the endpoint.

An endpoint is configured for communication with a distribution substation. The endpoint includes a receiver conditioning block and a receiver processing block. The receiver conditioning block is positioned downstream from the distribution substation, and arranged to provide an analog signal that is responsive to the power signal from the distribution line. The receiver processing block is configured to extract encoded data from the power signal by under-sampling the analog signal, and processing the under-sampled analog signal such that fundamental and harmonic frequencies associated with the power signal are suppressed. Command signals from the distribution substation are extracted from the power-line. Each endpoint is addressable by an ID code, and is configurable via downstream command signals that are associated with the ID code. The endpoint collects data at demand based and schedule based intervals.

A method and apparatus for modifying a power distribution network in a building in order to provide data communication by using a Power Line Carrier (PLC) signal to an approximate electrical central location point of a power distribution system remote from the data entry point of the building. A passive coupler device is attached to a centrally located service panel. The passive coupler receives the Power Line Carrier (PLC) signal from the remote entry point in the building and conditions the signal for entry at the service panel onto each phase of the power distribution network.

A system and method that allows a consumer to monitor the electrical power usage in a residence is disclosed. The electrical use may be monitored at the service level, the circuit level, or at the group level. The electrical usage is communicated to a power monitoring system using a power line communications network (PLC). The monitored electrical usage can be accessed by both the utility supplying the electricity and by the consumer or owner of the residence.

There is disclosed a method of detecting the configuration of a network having a feeder line with a plurality of feeder meters and distribution transformer meters (DTMs) coupled thereto and with one or more customer meters and / or customer configuration modules coupled to the distribution transformers. The method includes the steps of having each of the feeder meters transmit a uniquely identifiable signal through the feeder line. The DTMs then identifying the phase of each of the uniquely identifiable signals and then transmitting the phase of each of the uniquely identifiable signals to a data collector along with a unique DTM identifier. The connectivity relationship between the feeder meters and distribution transformer meters is then extrapolated by comparing the phase information transmitted by the DTMs. The relationship of the customer meters relative to the DTMs can also be plotted by having each DTM transmit the DTM identifier to all of their respective customer meters, who then transmit this to the data collector along with their customer meter identifier. The method also permits the determination of which phase the DTM is connected to by analyzing the phase angle of a demodulated feeder meter signal.

An automatic local electric management system provides a comprehensive method and apparatus for consumers to more efficiently use energy. The system includes an intelligent service panel, numerous smart connectors, and system operation software. The intelligent service panel comprises microcontrollers, program controlled circuit breakers, sensors, and various interface and control circuits. By automatically monitoring power consumption and dynamically controlling the power connection to the grid and branch power lines, the intelligent service panel reduces unnecessary power consumption, eliminates the need for the subservices panel, the transfer switch, and additional wiring that is required for installing a local generator or renewable energy electric system. A smart connector can be used to monitor and control the power consumption of the appliance individually. The system operation software enables the intelligent service panel to communicate with smart appliances, smart connectors, local computer, remote servers, or the utility grid.

Meter nodes in a power line carrier (PLC) network may reliably communicate with an access point by alternate routes using additional media where available. A utility network may include one or more subnetworks. Each subnetwork may include one or more meter nodes and an access point configured to communicate with the meter nodes using PLC. Meter nodes operate as relays for other meter nodes to communicate with the access point. Some or all meter nodes may be configured to communicate using a power line carrier communications link and another communications link. The network may also include a node external to the subnetwork, e.g., a utility server. The access point may be configured to communicate with the node external to the subnetwork in addition to the meter nodes.

A system for detecting and reporting a defect in a telephone line includes a network of utility processors that communicate over a power line. Each utility processor monitors a telephone line connected to the processor. The utility processor includes a processing element, a line sensor, a telephone interface and a power line communication interface. Each utility processor reports a defect in the telephone line by sending message to a second utility processor via the power line. The second utility processor reports the defect to a central office via a telephone line.

Communications among multiple nodes via a shared power line medium are carried out by dividing the available frequency spectrum in the shared power line medium into plural non-overlapping channels. A first channel is assigned to a first group of nodes, and a second channel, different from the first channel, is assigned to a second group of nodes. Communications between the first group of nodes can occur simultaneously with communications between the second group of nodes via the shared power line medium. Time slots may be assigned for the communications between the first group of nodes that occurs simultaneously with the communications between the second group of nodes via the shared power line medium. The simultaneous communications between different groups of nodes via a shared power line medium may be implemented using a frequency-hopping spread spectrum technique.

A system and methods for optimizing the performance of communication network utilizing an electrical distribution grid are disclosed. Optimization methods may include archiving historical message data and metrics from transmissions by Remote Hubs received on one or more Substation-to-Edge channels. Trends in the archived metrics over time are later analyzed to determine which combination of transmission variables such as frequency band, modulation method, drive voltage, and transmission time produce the highest message success rates overall. The results of such analysis may be used to provide feedback to the Remote Hubs or reveal necessary repairs to the network. Optimization may also be carried out locally by an individual Remote Hub by estimating the impedance of the transmission medium and adjusting either drive voltage or transmission band.

A quick response system incorporated in a TWACS for mapping an outage in an electrical distribution system without having to continuously poll the electrical meters connected to the system. In a primary embodiment of the invention when a fault is sensed to have occurred, the amplitude of the fault is measured to determine if the fault is a medium voltage fault, or a low voltage fault. The pattern of the fault signature and change in load, both before and after the fault, are examined to determine what protective device was triggered by the fault. Using this information, and knowledge of the number and location of electrical meters connected in the distribution system, a population of meters to be polled is determined. By polling the identified population, a map of the extent of the outage is readily determined, and the time to respond to the fault and restore service is reduced.

There is disclosed a method of monitoring an electrical network of the type having a feeder line connected to a plurality of distribution transformers, each distribution transformer being in turn coupled to a load which may be provided with a customer meter. The method includes the steps of recording an accumulated in-phase current at each of the distribution transformers over a time period and recording for the same time period an accumulated in-phase current at the feeder line. The sum of the accumulated in-phase currents recorded at the distribution transformers are then compared to the accumulated in-phase current recorded at the feeder line. The method may also include the steps of recording accumulated in-phase currents at the customer meters and comparing their sum with the accumulated in-phase current measured at the distribution transformers coupled to the customer meters. The method may further include a method of automatically detecting the configuration of the network to determine on which phase the customer meters are connected to, and to which distribution transformer said customer meters are connected to, and further, where on the network, relative to a plurality of feeder meters, each of the distribution transformers are connected.

An automated meter reading power line communications system is provided, which may include measuring the utility usage of a first customer premises to provide first utility usage data, storing the first utility usage data in memory of a first device, wirelessly transmitting the first utility usage data from the first device, receiving the wirelessly transmitted first utility usage data at a second device coupled to a medium voltage power line, and transmitting the first utility usage data over the medium voltage power line.

A spread spectrum meter reading system enables the use of high power frequency hopping spread spectrum (HPSS) transmissions at both the encoder transmitter and repeater levels of the meter reading system. A plurality of end point encoder transmitter devices are each connected to a utility meter and transmit high power FHSS signals containing at least metering data for the corresponding utility meter. A plurality of intermediate transceiver units that are fewer in number than the number of end point encoder transmitter devices both receives and retransmits the high power FHSS signals. A base station includes a receiver that receives the high power FHSS signals. Preferably, the base station can receive the high power FHSS signals from both the encoder transmitter devices and the intermediate transceiver units and the intermediate transceiver units aggregates metering data from multiple encoder transmitter devices prior to block retransmission of the metering data to the base station. Preferably, the high power FHSS signals are transmitted at a maximum hopping rate of at least one minute per hop to reduce power consumption and increase battery life of the devices.

A system and method for inferring schematic and topological properties of an electrical distribution grid is provided. The system may include Remote Hubs, Subordinate Remotes, a Substation Receiver, and an associated Computing Platform and Concentrator. At least one intelligent edge transmitter, called a Remote Hub Edge Transmitter, may transmit messages on the electrical distribution grid by injecting a modulated current into a power main that supplies an electric meter. The Subordinate Remotes, Remote Hubs, the Substation Receiver, and the associated Computing Platform and Concentrator may contain processing units which execute stored instructions allowing each node in the network to implement methods for organizing the on-grid network and transmitting and receiving messages on the network. The Substation Receiver, Computing Platform and Concentrator may detect and infer schematic grid location attributes of the network and publish the detected and inferred attributes to other application systems including geospatial information systems maintaining the logical and physical network model.

A system and methods for managing a transformer area in an electrical distribution grid having at least one substation transformer and one service transformer are presented. At least one Remote Hub governed by a policy may be provided, which collects data about the transformer area. The Remote Hub may also execute a discovery procedure to inventory Remotes in the transformer area. The Remote Hub may use the collected data to detect events, such as exceptional conditions, configuration changes, or derived results, within the transformer area. Based on the collected data, the Remote Hub is able to transmit data about the transformer area via a Substation-to-Edge channel. A method and system for forming and establishing boundaries of Transformer Area Networks is also presented. Discovery procedures may be used to form Transformer Area Networks out of Remote Hubs and Remotes powered by the same phase of the service transformer.

An automated meter reading power line communications system is provided, which may include measuring the utility usage of a first customer premises to provide first utility usage data, storing the first utility usage data in memory of a first device, wirelessly transmitting the first utility usage data from the first device, receiving the wirelessly transmitted first utility usage data at a second device coupled to a medium voltage power line, and transmitting the first utility usage data over the medium voltage power line.

Certain embodiments are directed at methods and systems for transmitting utility usage data using a public switched telephone network (“PSTN”). The methods and systems may include collecting utility usage data pertaining to a customer premises with a utility meter at the customer premises. The utility usage data may be transmitted automatically from the utility meter to an access point of a public broadband network. The utility usage data may be received at the access point. A digital subscriber line (“DSL”) modem in communication with the access point may modulate the utility usage data at the access point. The utility usage data may be transmitted securely through the public switched telephone network to an Internet point of presence. The utility usage data may be received at the Internet point of presence. The utility usage data may be transmitted from the Internet point of presence to a utility provider via the Internet.

The disclosure relates to a meter for monitoring usage of power provided by a power transmission system to a site. The meter comprises: a meter module connected to a power feed associated with the power transmission system to provide readings relating to the power; a messaging module to provide messages to the power transmission system; a connection to an alternating current (AC) power supply; a rectifier circuit connected to the AC power supply to generate a direct current (DC) power signal; a capacitive circuit connected to an output of the rectifier circuit, the capacitive circuit including a capacitor for storing a voltage for temporarily providing replacement power for the rectifier circuit; and a switching regulator circuit connected to the output of the rectifier circuit and the capacitive circuit, the switching regulator converting the DC voltage signal to a stepped down voltage signal for the meter module.

In a power grid capable of electrical power delivery and power line communications, a distribution transformer and at least one smart meter is connected to the power grid. In one embodiment, the distribution transformer is configured to map the smart meters on the power grid to a virtual grid based upon measurements of signal metrics received from the various smart meters on the power grid, and the virtual grid is used to determine if a failure has occurred on the physical grid. A communications failure between nodes on the grid suggests a possible power failure, and the failure can be located using mapping information obtained from the virtual grid. A drop in power consumption on the power grid corroborates outages detected via the communications failure. In one embodiment, a cross phase delta value is computed to adjust the signal strength metrics measured between nodes having differing phases of electrical distribution.

The present invention is a meter for recording voltage and current on a transformer. The device has a housing with a body portion and a lever portion, the lever portion being movable between a closed position wherein the lever portion abuts the body portion and an open position wherein the lever portion is positioned away from the body portion. The device includes a pair of current sensors each current sensor being divided into two corresponding sensor fractions with one fraction of each sensor formed on the body portion of the housing and the other corresponding fraction formed on the lever portion of the housing. The fractions of each sensors are constructed such that each of the current sensors have a central opening dimensioned to receive one of the transformer terminals when the lever portion of the housing is in its first position. The current sensors are positioned on the housing such that the meter can be mounted to the terminals of the transformer. The device also includes two voltage leads which can be attached to the transformers terminals. An instrumentation module is contained in the housing and is coupled to the current sensors and the voltage leads, the instrumentation module being adapted and configured to record voltage and current measurements from the current sensors and voltage leads. The instrumentation module includes a signal processing module for processing the voltage and current signals to provide other information such as energy and accumulated in-phase current 90 data. Finally, the device includes a communications module coupled to the instrumentation module for communicating the voltage and current measurements and the derived data to a remote user.

A method and system for providing a secure communication network using an electrical distribution grid is disclosed. A device connected to the electrical distribution grid initiates a request for a secured key token by signaling an intelligent communicating device residing at or near an edge of the grid. The intelligent communicating device forwards the request to a receiver at a distribution substation on the electrical grid. This receiver enhances the properties of the request such that a grid location for the request can be inferred. The enhanced request is forwarded to a server at the distribution substation, which compares the request grid location to a Grid Map and Policies of known secure grid locations. Any inconsistencies between the grid location inferred from the enhanced request and the Grid Map and Policies locations are considered evidence of tampering, and the server rejects the request.

The transfer and usage of a modulated carrier signal within a power signal on a power line communication system is described. The modulated signal comprises metadata which is transmitted at a different frequency than the transmitted power. The metadata, including such elements as energy costs, providers, renewable source status and originating location, may be used by consumers to make subsequent purchasing decisions. Additionally, the energy costs of any given computer node commonly distributed in a grid architecture may be collected by a workload dispatcher in order to make more accurate cost and energy source based dispatch decisions. The consumer may be able to communicate directly back to the power provider. The use of computer-readable medium and product containing instructions that are implemented on a computer is also covered. Finally, the invention may be deployed on behalf of the consumer by a third party service provider.

The disclosure relates to a system and method for communicating with a meter at a remote premise through power transmission lines. The system comprises a head end for collecting and analyzing data from the meter; a power transmission network connected to the meter and to the head end; and a gateway. The network provides both power to the remote location and data communications; the network includes a first network providing a first voltage and a second network connected to the first network and the remote location. The gateway is a bridge between the first and second networks; the gateway provides an interface communication point. The communications are carried over the network following Internet protocol (IP) communication standards.

Methods, systems, computer-readable media, and apparatuses for using a smart meter as a reliable crowd-sourcing agent are presented. In some embodiments, a smart meter installed at a location may observe one or more wireless signals at the location. Subsequently, the smart meter may provide, to at least one signal almanac server, information that identifies the location and describes one or more detected properties of the one or more observed wireless signals. In at least one arrangement, the information provided to the at least one signal almanac server may be configured to be used by the at least one signal almanac server in providing position assistance information to one or more mobile devices located in a vicinity of the location.

Systems and devices are disclosed for enabling communication by and between meters and networks are disclosed. In one embodiment, a device includes: a network interface controller configured to be directly coupled to a meter socket and provide a communication path between a utility meter and at least one network, the network interface controller including: a computing device; and at least one communications interface coupled to the computing device, the at least one communications interface configured to be physically located within a meter socket housing.