Aclara Technologies, LLC

Other

Distribution Control Systems, Inc.

David Haynes

Todd Ellis

Roger Astbury Smith

Rebecca Webb Ross

Christopher K Fleck

Glenn A Emelko

Timothy Dierking

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.

Meter reading schema to enhance system functionality

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.

Phasor identification via synchronous messaging

A method of adaptably allowing an upgrade to firmware or a configuration of target endpoint hardware to be at least one of replaced or modified by way of instructions generated by a patch generator and executed by target endpoint hardware to generate an upgrade file, install the upgrade file, and audit the installation of the upgrade file is disclosed.

Robust firmware and configuration update over network

An electrical grid system including a phase conductor, a neutral conductor, and a neutral-to-ground conductor configured to conduct current flow between the neutral conductor and a ground. The electrical grid system further includes a fault detection sensor including a current sensor configured to sense current flowing along the neutral-to-ground conductor. The fault detection sensor further includes a controller having an electronic processor that is configured to receive signals indicative of the current flowing through the neutral-to-ground conductor from the current sensor, monitor the received signals for an occurrence of an event associated with the current flowing along the neutral-to-ground conductor; and output an occurrence of a fault in the electrical grid system based on detecting occurrence of the event.

High impedance fault detector

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.

IEC 61968-9:2013 schemas for a utility system's communications

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.

Demand response system with field area network gateway

A method of generating random and pseudo-random material which is incorporated in devices located at each end of a communications network for secure communications through a channel of the network. The material is used to generate time based one-time pads, one-time keys, and the keys themselves. The one-time pads, one-time keys, and the keys support a key-based or pad based cryptographic technique employed to produce secure communications of messages transmitted through the channel with a one-time pad, one-time key, or a key generated at one interval of time being different and unique from a one-time pad, one-time key, or a key generated at any other interval of time.

Method for generating cryptographic 'one-time pads' and keys for secure network communications

An advanced metering infrastructure (AMI) system includes a meter data management system, an AMI network, a network communication module and metering devices. The AMI network connects to a reference time clock and the meter data management system. The network communication module connects to the AMI network and is in communication with the reference time clock via the AMI network. Each metering device is connected to the network communication module and has a metrology device and a communication module device. The communication module device provides clock adjustments to the metrology clock and/or its own clock. The metrology device provides clock adjustments to the communications module clock and/or its own clock. Methods for use in an advanced metering infrastructure (AMI) system provide clock adjustments.

Metrology timekeeping systems and methods

A method of Demand Response (DR) utilizing a Load Control Transponder (LCT) installed at the location of an electricity consumer. A DR program, in conjunction with the LCT, allows a consumer to determine, in advance, when they will reduce their demand on an electricity supply system. The consumer is informed of price points at which the cost of energy increases due to overall demand. The consumer then determines if, and when, they will reduce their demand on the system when a price point is reached. In addition, when an unplanned, critical event occurs, the method enables the utility to bypass any intermediate consumer established settings and immediately and directly drop the level of energy consumption to the consumer's lowest selected level for continuing service thereby to shed sufficient load on the system to maintain an adequate level of electricity supply. Once the event has been resolved, the method enables the utility to restore the consumer's previous level of usage.

Achieving energy demand response using price signals and a load control transponder

Apparatus () comprising a power plant or air motor utilizing compressed air or liquid air for energy storage. The apparatus includes an electrical plant (), a mechanical plant (), and a pneumatic plant (). When operating as a compressor, the plant receives electrical and/or direct mechanical power as an input to drive the plant, compress air, and store its output in the form of compressed or liquefied air. When operating as an engine, the plant consumes the compressed or liquid air to drive a mechanism of the engine and deliver mechanical power and/or electrical power as an output.

Power plant using compressed or liquefied air for energy storage

A method of providing a graphic display (SD) of an electrical distribution network (N) to provide network personnel insight as to network operation comprising. A segment of the network is monitored to obtain information about predetermined types of incidents which occur. The information is then processed to ascertain where the incidents occurred and the number of incidents which occur over a predetermined period of time. The results are presented in a graphical display which includes the number of incidents occurring at each location within the network segment, and the number of incidents which occurred at each location during previous period of time at the respective locations.

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St. Peters, MO, United States of America

David Haynes