Methods, systems, and computer readable mediums for protecting and controlling a microgrid with a dynamic boundary are disclosed. One method includes detecting a fault in a microgrid that includes a dynamic point-of-common-coupling (PCC), in response to determining that the microgrid is operating in a grid-connected mode, isolating the fault by tripping a microgrid side smart switch and a grid side smart switch that are located immediately adjacent to the fault, initiating the reclosing of the grid side smart switch, and initiating the reclosing for the microgrid side smart switch via resynchronization if the grid side smart switch is successfully reclosed, and in response to determining that the microgrid is operating in an islanded mode, isolating the fault by tripping a microgrid side smart switch that is located immediately adjacent to the fault, and initiating the reclosing of the microgrid side smart switch.

This regional energy management device calculates the power interchange between consumers, on the basis of: storage battery level distribution indicating the relationship between storage battery levels and the position of storage batteries in a region at each time; excess or shortages of power for each consumer at each time, if a consumer has implemented a power supply equipment operation plan for fulfilling a consumer target index for that consumer; and an overall regional target index.

Aspects of the present invention relate to a method of controlling a renewable power plant comprising a plurality of renewable power generators electrically connected by a local network and configured to supply active power to a main network. The method comprises: in response to receiving a signal requesting substantially zero active power supply to the main network: categorizing a generator as power-supplying, and the remaining generators as power-consuming; operating the power-consuming generators to generate no active power and to have their auxiliary systems draw power from the local network; and operating the power-supplying generator to supply active power to the local network such that the plant supplies substantially zero active power to the main network.

A method for operating an electric power converter and an electric power converter configured to convert DC power into AC power supplied to a three-phase AC network, conclude, during the converting, that a single-phase tripping has started in the three-phase AC network connected to the three-phase output of the converter, and after the concluding that the single-phase tripping has started in the three-phase AC network, control an active current in the three-phase output of the converter such that a negative sequence voltage in the three-phase output of the converter remains at or below a predetermined level, wherein the converter is configured to perform the controlling until concluding that the single-phase tripping has ended in the three-phase AC network.

A method for controlling an electrical transmission network including a plurality of DC high-voltage lines and at least three AC/DC converters identified by a respective index i. For each of the converters having index i, the method includes recovering the setpoint active power value Pdci applied thereto, and recovering instantaneous voltage value Vi and voltage angle value θi of the buses having index i and modifying the setpoint active power Pdci of each of the converters having index i by a value including a term ΔPdcsi as a function of a sum of deviations of voltage angles multiplied by contribution adjustment parameters.

A method for controlling an electrical transmission network including a plurality of DC high-voltage lines and at least three AC/DC converters identified by a respective index i. For each of the converters having index i, the method includes recovering the setpoint active power value Pdci applied thereto, and recovering instantaneous voltage value Vi and voltage angle value θi of the buses having index i and modifying the setpoint active power Pdci of each of the converters having index i by a value including a term ΔPdcsi as a function of a sum of deviations of voltage angles multiplied by contribution adjustment parameters.

Disclosed is an optimal power flow acquiring method for regional distribution network of small hydropower groups based on deep learning, which specifically includes the following steps: generating required data sets by adopting continuous power flow and power flow equation calculation methods; the data set is randomly divided into training data (80 percent) and test data (20 percent); training the built convolutional neural network model with training data to learn the mapping relationship between load and generator output power; inputting test data, and directly obtaining P.sub.G and Q.sub.G from the trained convolutional neural network; and solving residual variables V.sub.i and θ.sub.i with traditional power flow solver. The application can accelerate the solving speed of the optimal power flow problem with higher prediction accuracy.

A method may include obtaining irradiance data at a first time and a second time from sensors, determining whether one or more solar modules of a plurality of networked power plants will be covered by a shadow or shade at a third time based on the irradiance data, and generating, based on the determination, a power output prediction for each power plant of the networked power plants at the third time. The method may further include receiving power delivery profiles for first and second loads, adjusting a power output of one or more power plants of the networked power plants based at least in part on the power output prediction and the power delivery profiles for the first and second loads, and allocating a combined power output of the power plants to the first and second loads based on first and second load reliability thresholds.

The present disclosure provides an electrical system that includes an energy control system, a photovoltaic (PV) power generation system electrically coupled to the energy control system, an energy storage system electrically coupled to the energy control system, and a smart load panel electrically coupled to the energy control system and to a plurality of backup loads. The energy control system operates in an on-grid mode electrically connecting the PV power generation system to a utility grid and a backup mode electrically disconnecting the PV power generation system from the utility grid. The smart load panel selectively disconnects one or more of the plurality of backup loads from the energy control system when the energy control system is in the on-grid mode and when the energy control system is in the backup mode.

A method for controlling an inverter-based resource (IBR) having a power converter connected to an electrical grid includes receiving a first power limit signal for the IBR from an external controller, receiving a second power limit signal for the IBR, and determining a constrained power limit signal based on the first and second power limit signals. The method also includes applying a first frequency droop function to the constrained power limit signal and determining at least one of a power reference signal or a pitch reference signal for the IBR as a function of an output of the first frequency droop function and the constrained power limit signal. Further, the method includes determining one or more control commands for the IBR based on at least one of the power reference signal or the pitch reference signal and controlling the IBR based on the control command(s) so as to support a grid frequency of the electrical grid within power available at the IBR.