This document describes systems and techniques for evaluating and improving distribution-grid data transportability. These systems and techniques allow engineers to quantify the data transportability of a communication system within or connected to a distribution grid, which represents an ability to transport in real-time telemetry from source locations (e.g., sensors in the distribution grid) to control mechanisms. Distribution engineers can use the sensor readings to perform grid analytics, control operating parameters, and operate protection systems. Distribution engineers can also use the transportability of the communication system to evaluate the observability of the distribution grid, which represents an ability to combine actual measurements and various types of computations (e.g., analytics, estimators, forecasters) from a system model. Distribution engineers can then generate a sensor allocation plan that indicates the number and location of sensors to maximize observability for a fixed sensor cost and/or minimize sensor cost for predetermined observability.

Distance protection for electric power delivery systems that include an unconventional source is disclosed herein using apparent impedance independent of memory and cross-phase polarizing. The apparent impedance may be compared with an offset distance operating characteristic. Fault direction is determined by using zero-sequence ground directional logic for phase-to-ground faults. For phase-to-phase faults, fault direction is determined using weak-infeed directional logic. Fault direction may further use incremental quantity directional principles. The distance protection may further determine a faulted loop using voltage logic. The distance protection may select between traditional distance protection and the methods described herein based on the current feeding the fault.

Various embodiments may provide systems and methods for determining a distance to a short in a two-conductor wire. Various embodiments may include determining a distance to a short in a two-conductor wire based at least in part on a phase difference between a phase of an injected tone and a phase of a reflected tone. Various embodiments may include determining a distance to a short in a two-conductor wire based at least in part on both a phase difference and an amplitude difference between an injected tone and a reflected tone. Various embodiments may include determining a distance to a short in a two-conductor wire based at least in part on a measured peak voltage of a combined pulse.

Examples of operating an Intelligent Electronic Device (IED) during power swings, are described. In an example, voltage measurements for a phase is received and sampled. Root mean square (RMS) values of the voltage samples is calculated based on the voltage measurements. Delta quantities for each phase are calculated based on the RMS values. Each of the RMS values and delta quantities are associated with respective sampling instants. In response to a delta quantity being greater than a predefined threshold, a peak delta quantity is detected. A time interval between a sampling instant associated with the peak delta quantity and a sampling instant associated with a first delta quantity is determined. Based on a comparison of the time interval with a threshold time, a disturbance condition may be detected as a power swing and consequently, fault detection at the IED may be blocked.

Described herein are methods and systems for estimating an originating location of a power quality event in an electrical grid. Each of a plurality of sensor devices connected to the electrical grid detects an input signal generated by electrical activity on the electrical grid, generates an output signal based upon the detected input signal, and transmits power quality data to a computing device via a communications network, where the power quality data is based upon the output signal. The computing device is configured to analyze the power quality data from at least a subset of the sensor devices to determine a power quality event occurring in the electrical grid, estimate an originating location of the power quality event based upon the power quality data, and transmit a notification to one or more remote computing devices based upon the estimated originating location of the power quality event.

A method which allows for the quick and accurate detection of faulty operating conditions and bad interconnections between and within devices in an electrical system. The method allows for the detection of arcing in wiring and components, high resistance connections, loose components, and the like. Voltage or current at each end of a conductor, or on each side of a system component, or the current through a component, may be detected and analyzed. A fault or abnormal condition is indicated when the voltage or current exceeds an expected level. Alternatively, resistance may be detected and analyzed, and a fault condition indicated when the resistance exceeds an expected level. Existing detection or computation equipment already associated with the system may be used for the detection and analysis.

A method determines a fault position on a line of a power supply network. Transient profiles of current and voltage values are measured at the line ends of the line and, by using the transient profiles, after the occurrence of a fault, a fault position is determined. To carry out fault location with high accuracy even in the case of a line having more than two line ends, transient profiles of a node current and a node voltage at a node point are determined by using the current and voltage values of a line end and a traveling wave model for the respective line section, and, for each line section, a two-sided fault position determination is carried out using the transient profile of the current and voltage values measured at its line end and, the node current and the node voltage and the traveling wave model for this line section.

A system and method for determining the optimal time to perform a pulse test to determine the presence of a fault after a switch opens to clear the fault to prevent generator instability. The method includes detecting the fault, opening a switch to clear the fault, determining an optimal time for performing the pulse test for determining the continued presence of the fault based on predetermined system data and parameters after the switch is opened so as to prevent the pulse test from occurring too early that could cause generator instability, and performing the pulse test at the optimal time to determine if the fault is still present. Determining the optimal time can use available system data and information, such as a priori knowledge or real-time behaviour. If the fault is not present, then the method determines a desired time to perform a reclose operation.

A method, a system and a tangible product and non-transitory computer program are provided to automatically identify electrical installations in an electrical distribution system that are likely to exhibit an electrical non-conformity (ENC). The method requires only electrical profiles collected from meters and IT tools, without the need for any other sub-metering equipment. The method includes the steps of recovering electrical profiles generated by the meters; applying algorithmic processing associated with indicators of an ENC on the profiles; and identifying electrical installations likely to exhibit an ENC, according to the indicators that have met their target conditions. The method may include the recovery of local meteorological data and nominal data related to the electrical installations to confirm or deny that the identified electrical installations are likely to be non-conforming.

Techniques for controlling a power distribution network are provided. An electronic processor receives, a fault indication associated with a fault from a first isolation device of a plurality of isolation devices. The processor identifies a first subset of a plurality of phases associated with the fault indication and a second subset of the plurality of phases not associated with the fault indication. The processor identifies a downstream isolation device downstream of the fault. The processor sends send a first open command to the downstream isolation device for each phase in the first subset. The processor sends a close command to a tie-in isolation device for each of the plurality of phases. The processor sends a second open command to the downstream isolation device for each phase in the second subset. Responsive to identifying a potential loop configuration, the processor sends the second open command prior to the close command.