Methods for determining a line fault of a power system. The methods include obtaining sampled values of voltages and currents of phases of a power line in the power system, determining a phase compensation voltage of a first phase and an interphase compensation voltage of an interphase loop between a second phase and a third phase, and detecting the line fault in the first phase and/or the interphase loop by comparing the phase compensation voltage and the interphase compensation voltage.

Systems and methods performed by a fault detection apparatus for fault detection and localization in distribution feeders having branches and nodes. The method including receive feeder raw data in a feeder of a power system. Process the feeder raw data with given operational electrical characteristics of the feeder to generate a branch attribute dataset for each branch separated by a pair of nodes for all branches. Generate a node attribute dataset for each node for all the nodes in the feeder. Input the branch and node attribute datasets into a trained neural network to determine whether a branch has a fault and a fault location within the branch, to output a classification of the fault and the fault location. Generate an alert signal based upon determining the classified fault and fault location in response to the alert signal to an outage response system.

The invention relates to a self-adaptive positive-sequence current quick-break protection method for a petal-shaped power distribution network trunk line. The method comprises the following steps: step 1, calculating a positive-sequence voltage phasor and a positive-sequence current amplitude at a protection installation position when a fault occurs, acquiring and storing a positive sequence impedance value of a protected line; judging a fault type, and judging a fault direction; step 2, when a fault direction element judges that a fault occurs in the forward direction, selecting a self-adaptive current quick-break protection setting formula according to the fault type, and when positive sequence current measured by protection is larger than a protection setting value, judging that the protected line has a short-circuit fault, and making a circuit breaker trip quickly. Compared with the prior art, the method provided by the invention has enough sensitivity and does not change along with the change of the line length and the system operation mode.

A method can be used for fault detection of a transmission. The method includes obtaining instantaneous measurements of local voltages and local currents of the transmission line, obtaining filtered measurements of the local voltages and local currents by subjecting the measurements of the local voltages and local currents to low pass filtering, obtaining a compensated voltage calculated by subjecting the filtered measurements to a differential equation based algorithm, and performing fault detection by forming a ratio between the compensated voltage and the a reference voltage. An internal fault is determined when the ratio is below a threshold and an external fault is determined when ratio is larger than above the threshold.

Systems and methods performed by a fault detection apparatus for fault detection and localization in distribution feeders having branches and nodes. The method including receive feeder raw data in a feeder of a power system. Process the feeder raw data with given operational electrical characteristics of the feeder to generate a branch attribute dataset for each branch separated by a pair of nodes for all branches. Generate a node attribute dataset for each node for all the nodes in the feeder. Input the branch and node attribute datasets into a trained neural network to determine whether a branch has a fault and a fault location within the branch, to output a classification of the fault and the fault location. Generate an alert signal based upon determining the classified fault and fault location in response to the alert signal to an outage response system.

A method can be used for fault detection of a transmission. The method includes obtaining instantaneous measurements of local voltages and local currents of the transmission line, obtaining filtered measurements of the local voltages and local currents by subjecting the measurements of the local voltages and local currents to low pass filtering, obtaining a compensated voltage calculated by subjecting the filtered measurements to a differential equation based algorithm, and performing fault detection by forming a ratio between the compensated voltage and the a reference voltage. An internal fault is determined when the ratio is below a threshold and an external fault is determined when ratio is larger than above the threshold.

An apparatus for determining a fault location distance or distance protection in a multi-phase power transmission medium, configured to; determine a set of line fault parameters based on a measurement of voltage and current at a point of said power transmission medium and a fault type, the line fault parameters determined at a plurality of sample times determine a derivative with respect to time of a line fault parameters representative of an inductive part of measured faulty phase current; determine a set of phasors using a Fourier transformation of the derivative and of the remaining line fault parameters at the plurality of sample times and use said set of phasors to determine a fault location distance or distance projection distance along the power transmission medium; wherein, the determination of the fault location distance or the distance protection distance is based on the line equation; ${\stackrel{.}{U}}_P={\stackrel{.}{U}}_F+\left[R_1{\stackrel{.}{I}}_{\mathrm{PR}}+\frac{X_1}{{}_0}{\stackrel{.}{I}}_{\mathrm{PX}}\right]D_F.$

Systems and methods for identifying faulted segment(s) in a multiphase power network may include receiving a current measurement that was measured during a fault, obtaining a set of equivalent sequence impedances for the segments, building a set of sequence bus impedance matrices, selecting a segment, calculating coefficients for the segment based on the set of equivalent sequence impedances for the segment and the sequence bus impedance matrices, calculating an estimated per unit fault distance for the segment based at least partially on the current measurement and the coefficients, identifying the segment as a potentially faulted segment if the estimated fault distance for the segment is between about zero and about one, and repeating for each of the segments the calculating coefficients, calculating an estimated per unit fault distance, and identifying as a potentially faulted segment if the estimated fault distance for the segment is between about zero and about one.

The present invention provides a method for current for fault identification in a transmission line and an apparatus thereof. The method comprises the following steps: measuring the real-time values of the currents and the voltages of the other unbroken healthy phase conductors when a single-phase fault occurs; calculating the inductive voltage and the capacitive coupling voltage according to the measured currents and voltages respectively; comparing the capacitive coupling voltage with the inductive voltage multiplied by a factor, in which the multiplication result is used as a self-adjusted threshold based on the real time load condition of the transmission line; and identifying the fault type based on the maximum of the capacitive coupling voltage and the multiplication.

Determination of information relating to a location of an electrical fault in an electrical energy distribution system based on phasor information is disclosed. A component can receive phasor information and electrical energy distribution system information. The system can determine a distance factor based on the phasor information. The distance factor can be employed to determine fault location information. A set of fault location information can be generated. Fault location information can be corrected for fault characteristics. Equivalent circuit models can be employed in determining the distance factor. Fault locations can be validated to facilitate generating subset of fault location information. Access to fault location information can be facilitated.