Systems, methods, and frameworks for distribution grid optimal power flow (D-OPF) are provided, to find the optimal droop and mode settings of smart inverters (SIs). The droop and mode settings of SIs can be found as per the Institute of Electrical and Electronics Engineers (IEEE)-1547 in coordination with the operations of legacy voltage control devices for optimal Volt-VAR control performance. The D-OPF framework can utilize two timescale coordination of control of legacy grid voltage control devices, modes and droop settings of SIs, and active/reactive power dispatch of SIs.

Systems, methods, and frameworks for distribution grid optimal power flow (D-OPF) are provided, to find the optimal droop and mode settings of smart inverters (SIs). The droop and mode settings of SIs can be found as per the Institute of Electrical and Electronics Engineers (IEEE)-1547 in coordination with the operations of legacy voltage control devices for optimal Volt-VAR control performance. The D-OPF framework can utilize two timescale coordination of control of legacy grid voltage control devices, modes and droop settings of SIs, and active/reactive power dispatch of SIs.

A method for attenuating low-frequency oscillations in an electrical power supply grid by means of a feed device which feeds into the electrical power supply grid, in particular a wind power installation, wherein the electrical power supply grid has a grid voltage and a grid frequency, comprising the following steps: picking up a grid signal having the low-frequency oscillations, splitting a total frequency range of the grid signal in which oscillations to be attenuated are to be expected into a plurality of partial frequency ranges, each having a lower and an upper range frequency, performing in each case one frequency analysis of the grid signal for each partial frequency range in order to identify in each case one or more oscillations having an oscillation frequency in the partial frequency range, if present, identifying a low-frequency oscillation to be attenuated as target oscillation depending on the frequency analyses of all of the partial frequency ranges, detecting the target oscillation at least according to frequency and amplitude and optionally according to phase, determining a setpoint attenuation signal depending on the target oscillation detected according to frequency and amplitude and possibly phase for attenuating the detected target oscillation, generating a setpoint feed signal depending on the setpoint attenuation signal and a basic setpoint signal, and generating and feeding in a feed signal depending on the setpoint feed signal (QE).

Harmonics of a power output of a power plant at a point of common coupling between the power plant and a utility grid, wherein the power plant comprises a plurality of energy production units. The method comprises determining an electrical characteristic at the point of common coupling; determining the electrical characteristic at an output terminal of each of the energy production units and dispatching a control signal to at least one of the energy production units to control the electrical characteristic at an output terminal of the respective energy production units. The control signal is based on the measurement of the electrical characteristic at the point of common coupling and arranged for damping the harmonic of the power output of the power plant at the point of common coupling, wherein the control signal is determined on the basis of a predetermined prioritizing sequence of said electrical characteristic.

A control system and method for an inverter-based resource device provided in a synchronous power grid. The control system includes at least one inverter based resource device connected to an electrical power system, and a controller module. The inverter based resource device includes a reference power Pref, a combination module and a transfer function. The inverter based resource device injects modulated power into the power system. The power system (which is represented by a transfer function in the control system) receives an undesirable forced oscillation, which is connected to a measuring device. A controller module processes the measured output and provides a control signal to the inverter based resource device. The controller is arranged to suppress a forced oscillation detected in the power system.

The present invention discloses a unit commitment method considering security region of wind turbine generators with frequency response control, and the main steps are: 1) determining security region of wind turbine generators when provides frequency response; 2) based on the security region of the wind turbine generators when provides frequency response, establishing a unit commitment model considering security region of wind turbine generators; and 3) calculating the unit commitment model considering the security region of the wind turbine generators by using mixed-integer linear programming method, and obtaining the operation result of the unit commitment considering the security region of the wind turbine generators with frequency response control. The present invention can be widely used in the setting of frequency response parameters of wind turbine generators dispatched in the prior art and the start-stop and output plans of synchronous generator.

The system and method described herein provide grid-forming control of a power generating asset having a double-fed generator connected to a power grid. Accordingly, a stator-frequency error is determined for the generator. The components of the stator frequency error are identified as a torsional component corresponding to a drivetrain torsional vibration frequency and a stator component. Based on the stator component, a power output requirement for the generator is determined. This power output requirement is combined with the damping power command to develop a consolidated power requirement for the generator. Based on the consolidated power requirement, at least one control command for the generator is determined and an operating state of the generator is altered.

The system and method described herein provide grid-forming control of a power generating asset having a double-fed generator connected to a power grid. Accordingly, a stator-frequency error is determined for the generator. The components of the stator frequency error are identified as a torsional component corresponding to a drivetrain torsional vibration frequency and a stator component. Based on the stator component, a power output requirement for the generator is determined. This power output requirement is combined with the damping power command to develop a consolidated power requirement for the generator. Based on the consolidated power requirement, at least one control command for the generator is determined and an operating state of the generator is altered.

A power control device for controlling an electrical load. The system includes decision logic to implement a local response responsive to events currently occurring in a power grid. The power control device includes a user interface allowing programming the response to the grid imbalance to adapt that response to the particular application in which the load operates.

An energy offloading system is in direct electric communication with an energy generating system and dynamically receives energy from the energy generating system. The energy offloading system uses energy for high-load computations. The energy offloading system includes computers performing the high-load computations as well as servers, cooling units, and communication devices. When the energy from the energy generating system is terminated, the energy offloading system may power down these and other devices, or may switch these devices to an alternative power source. The energy offloading system may be portable.