Schweitzer Engineering Laboratories, Inc.

Schweitzer Engineering Labs, Inc.

Jeffrey B Roberts

Edmund O Schweitzer, Iii

Armando Guzman-Casillas

Gabriel Benmouyal

Daqing Hou

David E Whitehead

Hector J Altuve-Ferrer

Demetrios A Tziouvaras

Ralph W Folkers

Tony J Lee

Luther S Anderson

Joseph B Mooney

Demetrios Tziouvaras

William D Hawbaker

Daging Hou

Provided is a compensated inverse-time undervoltage load shedding system and method for use in an electrical power system. The compensated inverse-time undervoltage load shedding system includes a compensation element for determining a compensated value and an inverse-time undervoltage element operatively coupled to the compensation element and enabled based on the compensated value. When enabled, the inverse-time undervoltage element calculates a load shedding time delay value based on the compensated value, and determines a load shedding signal based on the load shedding time delay value. An associated load of the electrical power system is shed based on the load shedding signal. The compensation element may determine the compensated value using a voltage magnitude, a rate-of-change of power system voltage over time, a weighted rate-of-change of power system voltage over time, a current magnitude, a weighted current magnitude, and an impedance phasor value, to name a few.

Compensated inverse-time undervoltage load shedding systems

A power system bus total overcurrent system is used with a part of a power system which includes two buses and first and second power line portions which extend between them. A protective relay system includes protective relays for each of the first and second power line portions, located near the two buses, wherein the relays determine the total current into and out of each bus. The bus total overcurrent system includes first and second communication lines between each pair of relays and another communication line which extends between the first and second communication lines. In a current balance arrangement, the relays measure difference current using the same communication line arrangement between the two pairs of relays to determine a fault condition. Fault determinations are made in each case by the protection algorithms from total and difference currents.

Bus total overcurrent system for a protective relay

The fault detection system includes at least one valid zero sequence voltage source, either from a local relay or a remote relay on a protected line. Zero sequence current is selected between total (vector sum from both ends of the protected line) measured zero sequence current or calculated zero sequence current. A zero sequence impedance-based calculation is then made and the result is compared against a threshold value to produce a trip decision. The trip decision is then applied through a normal tripping circuit or a slow tripping circuit, depending upon selected circuit conditions, involving the local and remote ends of the line.

Ground fault detection system for ungrounded power systems

The directional element, following enablement under selected input current conditions, calculates a zero sequence impedance, in response to values of zero sequence voltage and zero sequence current. The current value is selected between two possible values, one being the value from an associated current transformer, the other being the sum of the currents I &plus;I &plus;I . The calculated zero sequence impedance is then compared against sensitive selected threshold values, established particularly for ungrounded systems. A forward fault indication is provided when the calculated zero sequence impedance is above a first established sensitive threshold value, and a reverse fault indication is provided when the calculated zero sequence impedance is below a second established sensitive threshold value.

Directional element to determine faults on ungrounded power systems

The system includes a plurality of protection application elements to accomplish various power system protection functions, including for example line protection, line fault location, current direction determination, breaker protection and synchronism check, among others. The system includes local sources of current and voltage information for the protective functions as well as a receiving section for receiving such current and voltage values from a remote source, such as another protection device, as well as other necessary input information for the protective functions. A selection logic section is responsive to the output of the protective function elements, as well as the local and remote data to determine whether the primary or local sources are to be used. The outputs of the protective function elements are used by an output section to control circuit breakers and the like and are also transmitted, with the local and remote source quantities, to other protective devices.

Voltage and current source selection system for use in the protection, automation and control of an electric power system

In a three terminal power line current differential protection system, all three phase current values (I , I and I ) are obtained from all three terminals. The current values for each phase are processed in three successive processing operations, using in turn the current values from each terminal as local current values and the combination of the other two terminal current values in each case as the remote current values. The resulting local and remote current values are then processed against preselected values which establish a restrain region in the current ratio (alpha) plane. Current values for each set of local and combined remote currents which result in the ratio being within the restrain region result in a blocking signal while current values which result in a ratio outside of the region result in a tripping signal. If the outputs of the three processing operations agree, then that signal is the system output. If there is disagreement, the output produced when the terminal having the largest current (Imax) value is the local current is the system output.

Line differential protection system for a power transmission line

A system for detecting ground faults in a compensated electric power distribution network includes the determination of zero sequence voltage (V ) and zero sequence current (I ) on a power line and calculating the zero sequence conductance (G ) therefrom. The operation of the conductance calculation circuit occurs only under selected power line conditions involving minimum values of zero sequence voltage, zero sequence current and positive sequence voltage, to ensure the accuracy of a fault direction determination. The conductance values are processed on an adaptive basis in which the difference between the most recent conductance value and a conductance value from a selected previous point in time is determined and then compared against threshold values to make forward and reverse fault declarations.

Sensitive ground fault detection system for use in compensated electric power distribution networks

The system includes a plurality of voltage transformers in a protective relay for A, B and C-phase power system voltages, responsive to the secondary windings of corresponding voltage transformers for the power system, the secondary windings of the voltage system power transformers being connected in a broken delta arrangement. The primary windings of the relay voltage transformers are arranged in a broken delta configuration and connected to the secondary windings of the power system voltage transformers so that A-phase, B-phase and C-phase voltage are provided at the secondary windings of the relay voltage transformers. The three-phase voltages may then be summed to produce a residual voltage value.

System for obtaining phase-ground voltages from a broken delta VT voltage connection system

The fault identification system includes a first logic circuit which is responsive to conventional protective elements which recognize the presence of low resistance single line-to-ground faults for the A, B and C phases on a power transmission line. The first logic circuit includes a portion thereof for recognizing and providing an output indication of single line-to-ground faults, faults involving two phases and three-phase faults, in response to the occurrence of different combinations of outputs from the protective elements. A calculation circuit, when enabled, is used to determine the angular difference between the total zero sequence current and the total negative sequence current for high resistance faults when the protective elements themselves cannot identify fault conditions. The angular difference is in one of three pre-selected angular sectors. An angular difference in the first sector indicates an A phase-to-ground fault or a BC phase-to-phase to ground fault; an angular difference in the second sector indicates a B phase-to-ground fault or a C phase-to-phase to ground fault; and a signal in the third sector indicates a C phase-to-ground fault or an AB phase-to-phase to ground fault. A processor is used to determine which of the two possible for each angle determination is the actual fault type. An output indication of the actual fault type is then provided.

Fault type selection system for identifying faults in an electric power system

In a power line current differential protection system, all three phase current values (I , I and I ) are obtained from both the local end and the remote end of a power transmission line. The magnitude of the ratio of the remote current values to the local current values are calculated. Also, the angle difference between the local and the remote current values for each phase are calculated. Comparison elements then compare the ratio and angle values against preselected values which establish a restrain region in the current ratio plane. Current values which result in the ratio being within the region do not result in a tripping signal for the circuit breaker on the power transmission line, while current values which result in a ratio outside of the region result in a tripping of the circuit breaker. Similar circuitry is used for negative sequence current quantities, with the negative sequence preselected values being set substantially lower to produce a more sensitive response to possible faults in the line.

A delta filter for use in a protective relay which includes an input circuit for receiving phasor signals representative of electrical signal quantities on the power line. A difference value, if any, is determined between the phasor signals at a present time and the phasor signals at a past point in time (delayed), the delay typically being one cycle. A first incremental output value is produced if there is a difference. When a power line disturbance is first noted by the recognition of a first incremental output value, the phasor signal value at the beginning of the disturbance is stored and then used as a reference value for comparison with subsequent present time phasor signals to determine continuing change in power system condition.

Delta filter with an adaptive time window for protective relays

In a fault location system, selected information concerning the power signal is obtained at each terminal location on a multi-ended power line. Typically, protective relays are positioned at the terminal locations. The selected information includes the magnitude value of the negative sequence current and the magnitude and angle of the negative sequence impedance of the power signal, at approximately mid-fault in time. An automatic calculation circuit is provided for calculating from the negative sequence values a fractional value m of the total line length representing the point on the line where the fault has occurred, and a system for calculating the distance to the fault from the fault location calculation terminal using the value m and the total distance between the two terminals.

Multi-ended fault location system

The system first identifies the existence of a fault involving ground using the phase angle difference between negative sequence and zero sequence current on the power line. Phase angle differences within three specific ranges provide an indication of the presence of particular faults. Once a particular fault has been identified, such as a BC-to-ground fault, the fault condition is monitored to determine if the fault evolves, such as to a C-to-ground fault from the BC-to-ground fault. If an evolution is recognized, the protective relay is reset so as to coordinate its operation with downstream protective elements for the evolved fault.

System for improving protective relay coordination with other protective

A DC monitoring system is provided in each protective relay in an electric power substation to detect DC grounds on the DC supply system. The DC monitoring system includes a first portion which indicates the presence of a DC ground. In a second portion of the system, the voltages at the contact inputs of the relay are recognized and compared against a standard voltage value range. An indication is provided when the recognized voltage is within said range. The combination of the indications from the first and second portions is useful in determining the location of DC grounds in the substation DC supply system.

Protective relay-based monitoring system of DC power within an electric

The system impedance ratio (SIR) is determined for the original zone 1 distance element reach of a protective relay. The reduction in the original zone 1 reach is then determined, using the SIR value and a known table of reduced values. When a fault is recognized the minimum reach to just detect the fault is determined. A trip signal is provided without any delay if the minimum reach is less than or equal to the reduced reach. The trip is delayed for a selected time if the minimum reach is greater than the reduced reach but not greater than the original reach.

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Viola, ID, United States of America

Jeffrey B Roberts