Abstract: A plurality of edge of network grid volt ampere reactive (VAR) sources are provided in a power system in order to effectuate control at a customer level, which in turn effectuates control at a feeder level, which in turn effectuates control of an entire power system or wide area electric grid network. By optimally selecting voltage setpoints and applying such voltage setpoints to the plurality of edge of network grid VAR sources, the power system can be configured to self-balance, power factor compensation can be determined without the need for measuring load power factor. Moreover, traditionally volatile voltages at the feeder can be flattened, and VAR control can be realized.

Abstract: By virtue of the ability to vary local load via inverter (e.g., solar PV inverter) volt-ampere reactive power (VAR) injection, local demand and energy consumption can be controlled at a system level. Utilities that provide solar PV systems to consumers can leverage this ability to reduce the purchase of high cost energy. Moreover, revenue for such utilities can be maximized. For example, such localized voltage and VAR control allow for precise control to achieve, e.g., plus or minus about two percent of kW and kWHr of power consumed at a node.

Abstract: Systems and methods for controlling grid voltage include a distribution power network and one or more smart inverters at or near the edge of the distribution power network, each smart inverter configured to absorb or insert VARs to control the voltage based on a reference Q value, wherein the reference Q value is calculated by a reference Q calculator. A reference Q calculator includes a processor and a non-transitory computer readable memory with software embedded thereon, the software configured to cause the processor to receive a voltage measurement taken at or near the edge of a power distribution grid, a voltage band value, and a voltage set point value, determine a difference, ev, between the voltage measurement and the voltage set point, generate a new reference Q value if an absolute value of ev is greater than the voltage band value, and cause the smart inverter to either absorb or insert VARs depending on the sign of ev.

Abstract: Systems and methods for controlling grid voltage include a distribution power network and one or more smart inverters at or near the edge of the distribution power network, each smart inverter configured to absorb or insert VARs to control the voltage based on a reference Q value, wherein the reference Q value is calculated by a reference Q calculator. A reference Q calculator includes a processor and a non-transitory computer readable memory with software embedded thereon, the software configured to cause the processor to receive a voltage measurement taken at or near the edge of a power distribution grid, a voltage band value, and a voltage set point value, determine a difference, ev, between the voltage measurement and the voltage set point, generate a new reference Q value if an absolute value of ev is greater than the voltage band value, and cause the smart inverter to either absorb or insert VARs depending on the sign of ev.

Abstract: By virtue of the ability to vary local load via inverter (e.g., solar PV inverter) volt-ampere reactive power (VAR) injection, local demand and energy consumption can be controlled at a system level. Utilities that provide solar PV systems to consumers can leverage this ability to reduce the purchase of high cost energy. Moreover, revenue for such utilities can be maximized. For example, such localized voltage and VAR control allow for precise control to achieve, e.g., plus or minus about two percent of kW and kWHr of power consumed at a node.

Abstract: A plurality of edge of network grid volt ampere reactive (VAR) sources are provided in a power system in order to effectuate control at a customer level, which in turn effectuates control at a feeder level, which in turn effectuates control of an entire power system or wide area electric grid network. By optimally selecting voltage setpoints and applying such voltage setpoints to the plurality of edge of network grid VAR sources, the power system can be configured to self-balance, power factor compensation can be determined without the need for measuring load power factor. Moreover, traditionally volatile voltages at the feeder can be flattened, and VAR control can be realized.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage to a load, and detecting a sag in the power voltage during steady-state operation of the load. The method includes the steps of adding an impedance to the load upon detection of the sag in the power voltage, and removing the impedance from the load when the power voltage has reached a predefined point in the power voltage cycle after the power voltage has returned to a nominal voltage.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage to a load, and detecting a sag in the power voltage during steady-state operation of the load. The method includes the steps of adding an impedance to the load upon detection of the sag in the power voltage, and removing the impedance from the load when the power voltage has reached a predefined point in the power voltage cycle after the power voltage has returned to a nominal voltage.

Abstract: Systems and methods for an edge of network voltage control of a power grid are described. In some embodiments, a system comprises a distribution power network, a plurality of loads, and a plurality of shunt-connected, switch-controlled VAR sources. The loads may be at or near an edge of the distribution power network. Each of the loads may receive power from the distribution power network. The plurality of shunt-connected, switch-controlled VAR sources may be located at the edge or near the edge of the distribution power network where they may each detect a proximate voltage. Further, each of the VAR sources may comprise a processor and a VAR compensation component. The processor may be configured to enable the VAR source to determine whether to enable the VAR compensation component based on the proximate voltage and to adjust network volt-ampere reactive by controlling a switch to enable the VAR compensation component.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage to a load, and detecting a sag in the power voltage during steady-state operation of the load. The method includes the steps of adding an impedance to the load upon detection of the sag in the power voltage, and removing the impedance from the load when the power voltage has reached a predefined point in the power voltage cycle after the power voltage has returned to a nominal voltage.

Abstract: Systems and methods for an edge of network voltage control of a power grid are described. In some embodiments, a system comprises a distribution power network, a plurality of loads, and a plurality of shunt-connected, switch-controlled VAR sources. The loads may be at or near an edge of the distribution power network. Each of the loads may receive power from the distribution power network. The plurality of shunt-connected, switch-controlled VAR sources may be located at the edge or near the edge of the distribution power network where they may each detect a proximate voltage. Further, each of the VAR sources may comprise a processor and a VAR compensation component. The processor may be configured to enable the VAR source to determine whether to enable the VAR compensation component based on the proximate voltage and to adjust network volt-ampere reactive by controlling a switch to enable the VAR compensation component.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage to a load, and detecting a sag in the power voltage during steady-state operation of the load. The method includes the steps of adding an impedance to the load upon detection of the sag in the power voltage, and removing the impedance from the load when the power voltage has reached a predefined point in the power voltage cycle after the power voltage has returned to a nominal voltage.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage to a load, and detecting a sag in the power voltage during steady-state operation of the load. The method includes the steps of adding an impedance to the load upon detection of the sag in the power voltage, and removing the impedance from the load when the power voltage has reached a predefined point in the power voltage cycle after the power voltage has returned to a nominal voltage.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage to a load, and detecting a sag in the power voltage during steady-state operation of the load. The method includes the steps of adding an impedance to the load upon detection of the sag in the power voltage, and removing the impedance from the load when the power voltage has reached a predefined point in the power voltage cycle after the power voltage has returned to a nominal voltage.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage to a load, and detecting a sag in the power voltage during steady-state operation of the load. The method includes the steps of adding an impedance to the load upon detection of the sag in the power voltage, and removing the impedance from the load when the power voltage has reached a predefined point in the power voltage cycle after the power voltage has returned to a nominal voltage.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage (100) to a load (246), and detecting a sag in the power voltage (106) during steady-state operation of the load. The method includes the steps of adding an impedance (RT) to the load upon detection of the sag in the power voltage, and removing the impedance when the power voltage has reached a predetermined point in the power voltage cycle after the voltage has returned to normal.

Abstract: Various systems and methods are provided for minimizing an inrush current to a load after a voltage sag in a power voltage. In one embodiment, a method is provided comprising the steps of applying a power voltage (100) to a load (246), and detecting a sag in the power voltage (106) during steady-state operation of the load. The method includes the steps of adding an impedance (RT) to the load upon detection of the sag in the power voltage, and removing the impedance when the power voltage has reached a predetermined poin in the power voltage cycle after the voltage has returned to normal.

Abstract: A system and method for determining non-linear load harmonics impact on the voltage distortion at the point of common coupling is disclosed. Briefly described, one embodiment is a method comprising metering voltage on an electric power system; metering current on the electric power system; determining a predicted voltage based upon the metered current; comparing the predicted voltage with the metered voltage; and determining a harmonic voltage component using a plurality of weights determined when the predicted voltage converges with the metered voltage.

Abstract: Floating electrically isolated active impedance modules are formed to attach to power transmission lines without breaking the lines such that the power line forms a secondary of the main transformer of the module. Each module includes an electrical energy storage device and a switching circuit, such as a single phase inverter, connected to the storage device and to the main transformer primary winding. The inverter can be controlled to couple a selected voltage to the transmission line through the main transformer primary winding which can provide effective positive impedance, negative impedance, or a voltage at or near phase quadrature with the line current. Many active impedance modules may be distributed over a power system grid to allow control of the impedance of the power lines in the grid and to steer power through the grid, with each module electrically isolated from ground and from other phase lines of the transmission system.