Methods and devices for a condition classification of a power network asset of a power network asset are disclosed. The methods and devices may combine an automatic classification procedure with a missing data replacement procedure.

Systems and methods are disclosed for automated power plant unit trip prediction and control. Power plant controls may have limited time to manage the plant loads when one of the units trips unexpectedly. To mitigate any consequences on a power grid associated with a trip event, these systems and methods may allow for prediction of such trip events. The predictions may allow a signal to be provided to a controller in sufficient time for the controller to automatically take any necessary action to mitigate any impacts of the future trip event.

A local electric power system (EPS) field tester is provided for field testing of a local EPS. The local EPS has distributed energy resources (DERs) and is capable of operating in conjunction with, or independently from, an external power system while supplying load(s). The local EPS field tester comprises local EPS testing equipment deployed in and/or on mobile deployment equipment. The local EPS testing equipment includes a gateway (for relaying signaling between the local EPS field tester and a local EPS controller of the local EPS), a power distribution busbar, and various switchgear including local EPS connection switchgear, DER connection switchgear, and load connection switchgear. The local EPS testing equipment further includes load controller equipment configured to emulate or simulate a load controller of the local EPS, according to signaling from the local EPS controller or an emulated or simulated SCADA/DMS system as relayed by the gateway.

An information processing device includes: an acquisition unit that acquires state data indicating a state of a monitoring target device from a communication device of the monitoring target device, which is an energy storage device or a power supply related device, or from a communication device of a system including a plurality of the monitoring target devices by communication; a storage processing unit that stores the acquired state data in a storage medium in association with identification data of the monitoring target device or the system; and a transmission processing unit that transmits, in response to a request from an outside or as an event, display information collectively displaying the state data stored in the storage medium and a communication state with the communication device while the state data and the communication state are distinguished from each other for each monitoring target device or system.

Fault detection is provided. A system for fault detection includes an earthing transformer structured to be coupled with an alternating current (AC) output of an inverter and an earthing device. The system includes a controller. The controller is configured to receive a voltage for multiple phases of an output, or the input voltages with respect to ground of the inverter. The controller is configured to determine a difference between a first voltage of the voltages and a second voltage of the voltages. The controller is configured to compare the determined difference to a predefined threshold. The controller is configured to classify, based on the comparison, a first fault state of a circuit comprising the inverter.

Examples described herein provide a system for controlling power flow in an energy distribution network. The system includes a plurality of inverters, each having an inverter controller associated therewith. The system further includes a utility controller associated with a utility and configured to communicate with at least a subset of the plurality of inverters. The system further includes a customer controller associated with a customer of the utility and configured to communicate with at least the utility controller. The system further includes a direct current (DC) breaker associated with a battery of the customer. The system further includes a DC meter of the customer, the DC meter and the DC breaker each configured to communicate with the utility controller and the customer controller. The utility controller is configured to determine a current operational scenario of the energy distribution network and to control power routing within the energy distribution network.

An automated control system includes at least one memory storing instructions. The automated control system includes at least one processor being configured to execute the instructions to perform operations. The operations include automatically determining the following in a steady-state current injection model: current withdrawal phase angles, power factor constraints, demand bus voltage magnitude constraints, generator voltage magnitude constraints, network flow constraints, generator capacity constraints, thermal line flow constraints, minimum and maximum demand bus voltage phase angle differences, minimum and maximum generator voltage phase angle differences, nodal voltage phase angle vectors, voltage stability constraints, a reference voltage constraint, linear marginal cost curves, linear marginal revenue curves, and retail rates. The operations include automatically minimizing a profit objective function through employment of a Lagrangian function, KKT conditions, and a Newton-Raphson algorithm. The operations include automatically determining setpoints for a plurality of electric power system resources.

A modular remote current monitoring device plugs into a single-pole mounting location on a power distribution panel of a direct-current (DC) power system, e.g., where a circuit breaker, fuse, shorting device, or other target device would ordinarily be installed. The target device plugs into the modular device (e.g., via bullet-type connectors) such that an individual (e.g., single-pole) current is conveyed between the power distribution panel and the target device via the modular device. The modular device senses an amperage of the individual current and reports the sensed amperage to a remotely located end user or controller. The end user or controller similarly may interrupt (disable) or reset (enable) the current from a remote location via the modular device.

An AI-based platform for enabling intelligent orchestration and management of at least one operating process is provided herein. The AI-based platform includes an artificial intelligence system that is configured to generate a prediction of an energy pattern associated with the at least one operating process. The AI-based platform is also configured to manage the at least one operating process based on the prediction of the energy pattern.

An information communication system includes a communication network configured to exchange uninterruptable power supply, UPS, information; a UPS connected to the communication network and configured to exchange UPS information to the communication network; an information collector configured to collect and process the UPS information; wherein the information collector has no direct access to the UPS information; wherein the information communication system comprises an information aggregator connected to the communication network and configured to poll the UPS information from the UPS; generate collector information using the polled UPS information; and send the collector information to the information collector.