Abstract: A method includes performing by a processor: receiving a plurality of power system phase angle measurements over a time interval from a plurality of phasor measurement units (PMUs) in a power system, generating a phase angle curve over the time interval based on the plurality of power system phase angle measurements, and detecting a sustained oscillation event in a power signal generated by the power system based on an envelope of the phase angle curve.

Abstract: 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.

Abstract: Systems and methods for simulating and controlling a power system in real time, using a controller, are provided. The controller includes a simulation layer to simulate an operation of the power system, a disturbance generation layer to provide data to the simulation layer to disturb the simulated operation of the power system, an application layer to display the simulated operation of the power system and generate a control signal to control, based on the simulated operation of the power system, at least one element of the power system, and a distributed data streaming server (D2S2) to allow interoperability among the simulation layer, the disturbance layer, and the application layer.

Abstract: Embodiments of the present invention may provide a device for monitoring electric power at the distribution level. The device may include an analog-to-digital converter (ADC) to convert an input signal into digital samples at time intervals, a receiver to generate a pulse-per-second (PPS) signal, an oscillator to generate an oscillator signal, and a data processor coupled to the ADC, the receiver, and the oscillator. The data processor may include a counter to measure an oscillator frequency of the oscillator signal at each pulse of the PPS signal, an adjuster to adjust a timer period register value, and a timer to adjust the time intervals based on the adjusted timer period register value. Based on the digital samples, the data processor may generate a plurality of metrics, which may include one or more measurements of frequency, magnitude, phase, harmonic level, signal-to-noise ratio, sag, and swell of the input signal.

Abstract: A method includes performing by a processor: receiving a first plurality of power system frequency measurements from a plurality of phasor measurement units (PMUs) in the power system over a first time interval, generating a first plurality of multi-dimensional ellipsoids based on the first plurality of power system frequency measurements, extracting a plurality of first graphic parameter values from the first plurality of multi-dimensional ellipsoids, respectively, performing a regression analysis on the plurality of first graphic parameter values to generate a predictive relationship between the plurality of first graphic parameter values and inertia values of the power system, receiving a second plurality of power system frequency measurements from the plurality of PMUs over a second time interval, generating a second plurality of multi-dimensional ellipsoids based on the second plurality of power system frequency measurements, extracting a plurality of second graphic parameter values from the second plura

Abstract: A pulsar based timing synchronization method and system are disclosed. In one example, a method includes receiving, by a pulsar signal receiver device, a pulse signal emitted from one or more celestial objects and processing, by the pulsar signal receiver device, the pulse signal to discipline a local clock to determine an accurate time output. The method also includes generating, by the pulsar signal receiver device, a timing synchronization signal based on the determined accurate time output. The method further includes providing, by the pulsar signal receiver device, the timing synchronization signal to at least one of a local power system device and a timing distribution network server.

Abstract: An energy system includes a microgrid including a network of at least one distributed energy resource and a plurality of loads, the at least one distributed energy resource being configured to supply power to the plurality of loads. The microgrid is configurable to connect to one of a plurality of feeder circuits of a main power grid at one of a plurality of coupling interface locations, respectively. The microgrid is also configurable to expand or shrink its power supply area according to the available power generation capabilities.

Abstract: A method for determining a location of a disturbance in a power system is provided. The method includes receiving data from a plurality of sensors distributed across the power system; performing a recurrence quantification analysis on the received data to identify a predetermined number of sensors, from the plurality of sensors, that are closest to the disturbance; constructing a plurality of minimum-volume-enclosing ellipsoids based on and enclosing the data received from the identified sensors; extracting one or more parameters from the plurality of minimum-volume-enclosing ellipsoids; inputting the one or more parameters into a multivariate-random-forest regression algorithm to determine the location of the disturbance and a power mismatch corresponding to the disturbance; and presenting, on one or more display units, the determined location of the disturbance and the determined power mismatch.

Abstract: A method for determining a location of a disturbance in a power system is provided. The method includes receiving data from a plurality of sensors distributed across the power system; determining, with one or more processors, for each sensor, an extremum of the data corresponding to the sensor; interpolating, with the one or more processors, the extrema; and presenting, on one or more display units, a location corresponding to a global maximum of the interpolated extrema as the location of the disturbance. The method may further include, if a difference between the largest extremum and each of remaining extremum is greater than a predetermined threshold, skipping the interpolating step and the presenting step, and presenting a location of the sensor corresponding to the largest extremum as the location of the disturbance.

Abstract: An energy system includes a microgrid including a network of at least one distributed energy resource and a plurality of loads, the at least one distributed energy resource being configured to supply power to the plurality of loads. The microgrid is configurable to connect to one of a plurality of feeder circuits of a main power grid at one of a plurality of coupling interface locations, respectively. The microgrid is also configurable to expand or shrink its power supply area according to the available power generation capabilities.

Abstract: A synchrophasor measurement method for a device configured to take synchronized measurements in a power system is provided. The synchrophasor measurement method includes receiving global positioning system (GPS)-synchronized samples of a signal sensed by the device from the power system; determining a level of distortion of the signal; selecting, based on the level of distortion, a computation method, the computation method being one of an improved zero-crossing (IZC) method and an enhanced phase-lock-loop (EPLL) method; performing the selected computation method to determine at least one parameter of the signal at a reporting frequency, which is at least twice a line frequency of the power system; and outputting, at the reporting frequency, the at least one parameter to an operator of the power system to allow the operator to perform at least one of a monitoring and a controlling of at least one element of the power system.

Abstract: A synchrophasor measurement method for a device configured to take synchronized measurements in a power system is provided. The synchrophasor measurement method includes receiving global positioning system (GPS)-synchronized samples of a signal sensed by the device from the power system; determining a level of distortion of the signal; selecting, based on the level of distortion, a computation method, the computation method being one of an improved zero-crossing (IZC) method and an enhanced phase-lock-loop (EPLL) method; performing the selected computation method to determine at least one parameter of the signal at a reporting frequency, which is at least twice a line frequency of the power system; and outputting, at the reporting frequency, the at least one parameter to an operator of the power system to allow the operator to perform at least one of a monitoring and a controlling of at least one element of the power system.

Abstract: A method for determining a location of a disturbance in a power system is provided. The method includes receiving data from a plurality of sensors distributed across the power system; performing a recurrence quantification analysis on the received data to identify a predetermined number of sensors, from the plurality of sensors, that are closest to the disturbance; constructing a plurality of minimum-volume-enclosing ellipsoids based on and enclosing the data received from the identified sensors; extracting one or more parameters from the plurality of minimum-volume-enclosing ellipsoids; inputting the one or more parameters into a multivariate-random-forest regression algorithm to determine the location of the disturbance and a power mismatch corresponding to the disturbance; and presenting, on one or more display units, the determined location of the disturbance and the determined power mismatch.

Abstract: Systems and methods for simulating and controlling a power system in real time, using a controller, are provided. The controller includes a simulation layer to simulate an operation of the power system, a disturbance generation layer to provide data to the simulation layer to disturb the simulated operation of the power system, an application layer to display the simulated operation of the power system and generate a control signal to control, based on the simulated operation of the power system, at least one element of the power system, and a distributed data streaming server (D2S2) to allow interoperability among the simulation layer, the disturbance layer, and the application layer.

Abstract: A system may include an electric field sensor, an analog to digital converter, and an estimator. The electric field sensor may measure electric fields of electric power grid. The analog to digital converter may generate digital output based upon measurements from the electric field sensor. The estimator may estimate phasor data of the electric power grid based upon the digital output.

Abstract: A method for determining a location of a disturbance in a power system is provided. The method includes receiving data from a plurality of sensors distributed across the power system; determining, with one or more processors, for each sensor, an extremum of the data corresponding to the sensor; interpolating, with the one or more processors, the extrema; and presenting, on one or more display units, a location corresponding to a global maximum of the interpolated extrema as the location of the disturbance. The method may further include, if a difference between the largest extremum and each of remaining extremum is greater than a predetermined threshold, skipping the interpolating step and the presenting step, and presenting a location of the sensor corresponding to the largest extremum as the location of the disturbance.

Abstract: A system and methods for monitoring an impact of geomagnetic disturbances (GMDs) or an E3 component of electromagnetic pulses (EMP-E3), involving a transducer generating a transduced signal in response to a magnetic field of a current carrying element of a transmission line. The transduced signal reflects harmonic characteristics of the current carrying element, and is amplified and filtered, then digitally converted. Excessive impact is detected when a threshold condition is met with respect to a total harmonic distortion (THD) and/or a change in THD. The THD can be calculated from amplitudes of harmonic components of interest. The amplitudes can be calculated in various ways, including Fourier transforming the digital signal to locate peaks in the resulting spectral lines, or using a phase sensitive detection algorithm in which the digital signal is multiplied by a phase swept reference signal and then integrated.

Abstract: Systems and methods for detecting a tampering and identifying a location of a digital recording are provided. A frequency sequence and a phase angle sequence may be extracted from the digital recording. A portion of the frequency sequence may be matched to one of a plurality of reference frequency sequences, and a portion of the phase angle sequence may be matched to one of a plurality of reference phase angle sequences. Tampering of the digital recording may be detected when the frequency and phase sequences differ from the matched reference sequences. Moreover, a noise sequence may be extracted from the extracted frequency sequence. A location of the digital recording may be identified by matching the noise sequence to one of a plurality of noise sequences of the plurality of reference frequency sequences.

Abstract: Embodiments of the present invention may provide a device for monitoring electric power at the distribution level. The device may include an analog-to-digital converter (ADC) to convert an input signal into digital samples at time intervals, a receiver to generate a pulse-per-second (PPS) signal, an oscillator to generate an oscillator signal, and a data processor coupled to the ADC, the receiver, and the oscillator. The data processor may include a counter to measure an oscillator frequency of the oscillator signal at each pulse of the PPS signal, an adjuster to adjust a timer period register value, and a timer to adjust the time intervals based on the adjusted timer period register value. Based on the digital samples, the data processor may generate a plurality of metrics, which may include one or more measurements of frequency, magnitude, phase, harmonic level, signal-to-noise ratio, sag, and swell of the input signal.

Abstract: A system may include an electric field sensor, an analog to digital converter, and an estimator. The electric field sensor may measure electric fields of electric power grid. The analog to digital converter may generate digital output based upon measurements from the electric field sensor. The estimator may estimate phasor data of the electric power grid based upon the digital output.