A system and method for protection of an electrical grid. A respective one of the substations of the system including: a first directional protective relay to generate a signal operating on the electrical power line between the respective one of the substations and a remote one of the substations; a cyber health module to receive remote signals from two remote directional protective relays and output a reliability signal based on consistency of the remote signals and a status of the communication channels being operational; a circuit breaker to interrupt electrical power flow when directed; and a comparison circuit to receive signals and to direct the circuit breaker to interrupt electrical power flow when the reliability signal from the cyber health module indicates consistency, the first directional protective relay indicates fault, and at least one of the remote directional protective relays indicate fault.

A method for enabling communication over a cellular network between a first communication device of a first substation and a second communication device of a second substation. The substations are connected to a power transmission line. The method includes the steps of: receiving multicast communication from the first communication device, wherein the multicast communication including a plurality of multicast packets, and each multicast packet includes a phasor value associated with the first substation and a sequence number; receiving an acknowledgement from the second communication device, the acknowledgement including a plurality of sequence numbers of the most recently received multicast packets, that the second communication device has received from the first communication device; and determining a packet loss to the second communication device when there is a mismatch between the sequence numbers of the acknowledgment, when compared with the sequence numbers of the received multicast communication.

Apparatus and methods for recovering energy in a petroleum, petrochemical, or chemical plant as described. The invention relates to a recovered electric power measuring system comprising at least one processor; at least one memory storing computer-executable instructions; and at least one receiver configured to receive data from a sensor on an electrical powerline connected to a generator of a power-recovery turbine, the power-recovery turbine located in a petroleum, petrochemical, or chemical process zone wherein a portion of a first process stream flows through the power-recovery turbine and generates recovered electric power as direct current, the power-recovery turbine electrically connected to a single DC to AC inverter and the output of the DC to AC inverter electrically connected to a first substation.

An electrical power distribution system configured to automatically regulate one or more Voltage/VAR control devices for optimization of one or more user defined metrics in an alternating current (AC) electrical power distribution system that includes one or more power distribution lines configured to transmit AC electrical power between a substation and a plurality of loads, each power distribution line including one or more Voltage/VAR control devices configured to regulate voltage and reactive power of the AC electrical power on the power distribution line according to an operational setting for each of the one or more Voltage/VAR control devices and one or more sensors configured to sense a sensed quality of the AC electrical power on the one or more power distribution lines with at least one communication network communicating with the one or more Voltage/VAR control devices and the one or more sensors.

A system and method for protection of an electrical grid. A respective one of the substations of the system including: a first directional protective relay to generate a signal operating on the electrical power line between the respective one of the substations and a remote one of the substations; a cyber health module to receive remote signals from two remote directional protective relays and output a reliability signal based on consistency of the remote signals and a status of the communication channels being operational; a circuit breaker to interrupt electrical power flow when directed; and a comparison circuit to receive signals and to direct the circuit breaker to interrupt electrical power flow when the reliability signal from the cyber health module indicates consistency, the first directional protective relay indicates fault, and at least one of the remote directional protective relays indicate fault.

The present invention provides a system and computer program product for implementing a smart transformer, comprising a processor, and a balancing algorithm residing on the processor, wherein the balancing algorithm is stored on a non-transitory computer readable medium having computer executable program code embodied thereon, the computer executable program code configured to cause the system to monitor and control an electric customer load and generation in order to optimize the performance of a distribution transformer, wherein the processor receives a plurality of system inputs and uses the balancing algorithm to determine a rating of the transformer and an amount of customer load.

A computer system at a substation of an electrical grid examines on-grid communication channels and for very channel, the system compares and correlates a GLA signal provided by a downstream transmitter on that channel to a reference GLA signal. The channel that provided the signal with the best correlation is mostly likely the channel with the transmitter. Thus, the feeder and phase of the signal can be determined from the correlation of signals.

A system and a method for locally controlling delivery of electrical power along the distribution feeder by measuring certain electricity parameters of a distribution feeder line using a substation phasor measurement unit (PMU) electrically coupled to a substation distribution bus at a first node on the feeder line, and at least one customer site PMU electrically coupled to a low voltage end of a transformer at a customer site, wherein the transformer is coupled by a drop line to a second node on the distribution feeder line and the customer site is coupled by another drop line to the transformer, and by controlling at least one controllable reactive power resource and optionally a real power resource connected to the second node or at the customer site. Related apparatus, systems, articles, and techniques are also described.

A system, having a controller, with a 3-phase measurement sensor, wherein the 3-phase measurement sensor is connected at least for current measurement to a low-voltage feeder of a secondary unit substation, and wherein a distribution network with producers and/or consumers is connected to the low-voltage feeder. The controller and the 3-phase measurement sensor are arranged in the secondary unit substation. The controller has a data interface for detecting electrical measurement values of the connected 3-phase measurement sensor with associated timestamp. The controller has a communication interface for connection to a higher-level unit outside of the secondary unit substation. The controller has a first memory area in a local memory for storing the measurement values with associated timestamp.

A method and system for sending a repetitive permissive guard signal from an electrical power substation to a distributed generation site over existing medium voltage distribution lines to detect an islanding condition and apply transfer trip protection is disclosed. The permissive guard signal causes a receiver at the distributed generation site to control a recloser at the distributed generation site. Loss of the signal at the receiver device causes the tripping of the recloser at the distributed generation site in less than two seconds. The tripping of the recloser physically disconnects the distributed generation site from the electric power grid. The coupling to the medium voltage distribution lines can be implemented via a single phase-to-ground coupling or via a phase-to-phase differential coupling for multi-phase medium voltage distribution lines.