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WO2019229638A1 - Localisation de défaut pour lignes de transmission parallèles avec des courants de séquence zéro estimés à partir de mesures de ligne défectueuse - Google Patents

Localisation de défaut pour lignes de transmission parallèles avec des courants de séquence zéro estimés à partir de mesures de ligne défectueuse Download PDF

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Publication number
WO2019229638A1
WO2019229638A1 PCT/IB2019/054393 IB2019054393W WO2019229638A1 WO 2019229638 A1 WO2019229638 A1 WO 2019229638A1 IB 2019054393 W IB2019054393 W IB 2019054393W WO 2019229638 A1 WO2019229638 A1 WO 2019229638A1
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WO
WIPO (PCT)
Prior art keywords
fault
line
measurements
transmission line
zero sequence
Prior art date
Application number
PCT/IB2019/054393
Other languages
English (en)
Inventor
Neethu GEORGE
Obbalareddi DEMUDU NAIDU
Swaroop GAJARE
Sachin Srivastava
A.v.s.s.r. SAI
Original Assignee
Abb Schweiz Ag
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Abb Schweiz Ag filed Critical Abb Schweiz Ag
Publication of WO2019229638A1 publication Critical patent/WO2019229638A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R31/00—Arrangements for testing electric properties; Arrangements for locating electric faults; Arrangements for electrical testing characterised by what is being tested not provided for elsewhere
    • G01R31/08—Locating faults in cables, transmission lines, or networks
    • G01R31/081—Locating faults in cables, transmission lines, or networks according to type of conductors
    • G01R31/085—Locating faults in cables, transmission lines, or networks according to type of conductors in power transmission or distribution lines, e.g. overhead
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R27/00—Arrangements for measuring resistance, reactance, impedance, or electric characteristics derived therefrom
    • G01R27/02—Measuring real or complex resistance, reactance, impedance, or other two-pole characteristics derived therefrom, e.g. time constant
    • G01R27/16—Measuring impedance of element or network through which a current is passing from another source, e.g. cable, power line
    • G01R27/18—Measuring resistance to earth, i.e. line to ground
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R31/00—Arrangements for testing electric properties; Arrangements for locating electric faults; Arrangements for electrical testing characterised by what is being tested not provided for elsewhere
    • G01R31/08—Locating faults in cables, transmission lines, or networks
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R31/00—Arrangements for testing electric properties; Arrangements for locating electric faults; Arrangements for electrical testing characterised by what is being tested not provided for elsewhere
    • G01R31/50—Testing of electric apparatus, lines, cables or components for short-circuits, continuity, leakage current or incorrect line connections
    • G01R31/52—Testing for short-circuits, leakage current or ground faults
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02H—EMERGENCY PROTECTIVE CIRCUIT ARRANGEMENTS
    • H02H3/00—Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition with or without subsequent reconnection ; integrated protection
    • H02H3/02—Details
    • H02H3/04—Details with warning or supervision in addition to disconnection, e.g. for indicating that protective apparatus has functioned
    • H02H3/042—Details with warning or supervision in addition to disconnection, e.g. for indicating that protective apparatus has functioned combined with means for locating the fault
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02H—EMERGENCY PROTECTIVE CIRCUIT ARRANGEMENTS
    • H02H3/00—Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition with or without subsequent reconnection ; integrated protection
    • H02H3/26—Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition with or without subsequent reconnection ; integrated protection responsive to difference between voltages or between currents; responsive to phase angle between voltages or between currents
    • H02H3/32—Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition with or without subsequent reconnection ; integrated protection responsive to difference between voltages or between currents; responsive to phase angle between voltages or between currents involving comparison of the voltage or current values at corresponding points in different conductors of a single system, e.g. of currents in go and return conductors
    • H02H3/34—Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition with or without subsequent reconnection ; integrated protection responsive to difference between voltages or between currents; responsive to phase angle between voltages or between currents involving comparison of the voltage or current values at corresponding points in different conductors of a single system, e.g. of currents in go and return conductors of a three-phase system
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02H—EMERGENCY PROTECTIVE CIRCUIT ARRANGEMENTS
    • H02H3/00—Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition with or without subsequent reconnection ; integrated protection
    • H02H3/38—Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition with or without subsequent reconnection ; integrated protection responsive to both voltage and current; responsive to phase angle between voltage and current
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02H—EMERGENCY PROTECTIVE CIRCUIT ARRANGEMENTS
    • H02H7/00—Emergency protective circuit arrangements specially adapted for specific types of electric machines or apparatus or for sectionalised protection of cable or line systems, and effecting automatic switching in the event of an undesired change from normal working conditions
    • H02H7/26—Sectionalised protection of cable or line systems, e.g. for disconnecting a section on which a short-circuit, earth fault, or arc discharge has occured

Definitions

  • the present invention relates to fault location in power transmission systems. More specifically, the present invention relates to fault location in power transmission systems with parallel transmission lines.
  • Transmission lines are often subjected to electrical faults due to bad weather conditions, or failure of power system components. For example, there could be electrical faults due to storms, lightning, snow, freezing rain, insulation breakdown, short circuits because of birds, tree contact with a transmission line and other external objects and so forth. In many fault events, mechanical damages to line equipment need to be repaired before restoring the line into service. Service continuity is one of the most important concerns for utilities. Fast restoration of lines is very important to the utilities. Thus, accurate fault location in transmission lines is very important for maintenance crew to reach the fault point and undertake repair at earliest. Quick identification of fault location can assist in improving reliability, availability of supply and reducing revenue loss for the utilities.
  • Fault location for parallel transmission lines may be influenced considerably by mutual coupling effect between the two lines (or circuits) especially for unbalanced faults.
  • the fault location may be underestimated or overestimated, based on operation status of the healthy line (i.e. open / connected).
  • fault location may be overestimated, because the fault current (i.e. current in faulted line) and residual current (i.e. current in healthy line) may flow in same direction.
  • the fault location may be underestimated, because the fault current and residual current may flow in opposite direction.
  • compensation for the mutual coupling effect has to be done.
  • Zero sequence current quantities from the healthy line is also required to achieve this mutual compensation. This can be a challenge, especially in cases where the healthy line is open and grounded, where healthy line current measurements are not available. For these cases the unavailable/unknown healthy line zero sequence current has to be estimated.
  • the existing solutions for fault location in parallel transmission lines, which estimate zero sequence currents for the healthy line use source impedances. Such settings may not be available, and even if available, such values may not be accurate. Even in case the healthy line is connected, there is difficulty in accurately estimating the effect of mutual compensation because of the residual current. As the currents are not uniformly distributed over the line, there is difficulty in accurately obtaining the direction of the faulted current flow, which may not always be in the opposite direction of the healthy line current.
  • the power transmission system may be a two terminal system having two terminals, i.e. a first terminal and a second terminal.
  • the two terminals are connected with parallel transmission lines (also referred as double circuit lines).
  • the parallel transmission lines comprise at least a first transmission line and a second transmission line.
  • the first transmission line has the fault.
  • the first transmission line is the line having the fault
  • the second transmission line is healthy (also referred as healthy circuit).
  • the invention is applicable for fault in any of the parallel lines, and not limited to fault in the first line.
  • the method for fault location is performed with a device associated with the power transmission system.
  • the method comprises obtaining measurements of post- fault voltages and currents carried out at the first terminal of the first transmission line, and measurements of post-fault currents carried out at the second terminal of the first transmission line.
  • positive, negative and zero sequence quantities are obtained for the measurements.
  • positive sequence voltages / currents, negative sequence voltages / currents and zero sequence voltages / currents are obtained for one end of the faulted line (i.e. first line in accordance with the embodiment), and positive, negative and zero sequence currents for the other end of the faulted line.
  • the method further comprises calculating voltage and current phasors for a plurality of fault location values based on the measurements.
  • the voltage and current phasors for a fault location value comprise positive, negative and zero sequence voltage and current phasors calculated for the fault location value.
  • the positive sequence voltage and current phasors for a fault location value are calculated from the positive sequence quantities of the measurements and line impedance parameters associated with the first transmission line (faulted line).
  • the negative sequence voltage and current phasors for a fault location value are calculated from the negative sequence quantities of the measurements.
  • the zero sequence voltage and current phasors for a fault location value are calculated from the zero sequence quantities of the measurements, and zero sequence currents estimated for the second transmission line.
  • the zero sequence currents for the second transmission line are estimated for each end of the second transmission line, based on the zero sequence quantities of the measurements from first transmission line.
  • the zero sequence currents for the second transmission line are estimated with the measurements of the zero sequence voltages and currents at the first terminal, the measurements of the zero sequence currents at the second terminal and line impedance parameters associated with the first and second transmission lines.
  • self-impedances of each of the two lines, and mutual- impedance between the two lines are considered.
  • the line impedance parameters associated with the first transmission line comprises self-impedance of the first transmission line, and mutual-impedance between the first and second transmission lines. Similarly, for the second line, the self-impedance of the second line, and mutual- impedances between the lines is considered.
  • the calculation of the positive, negative and zero sequence phasors for the fault location values includes compensation for charging currents.
  • the compensation is performed by considering line impedance parameters associated with charging currents.
  • the compensation can be provided by considering capacitance per unit length for a transmission line.
  • the voltage and current phasors calculated for the plurality of fault location values are used to estimate the fault location.
  • the location of the fault (fault location) is estimated based on phase differences between the voltage and current phasors calculated for the plurality of fault location values.
  • a phase difference between the voltage and current phasors for a fault location value can be estimated from angles of the voltage and current phasors. In one embodiment, the phase difference is the difference between the angles of the voltage and current phasors.
  • the fault location value for which the phase difference is zero is estimated as the location of the fault.
  • the method is implemented with a device associated with the power transmission system.
  • the device can be an Intelligent Electronic Device (IED) associated with a terminal, or a point of the line.
  • IED Intelligent Electronic Device
  • the device is a server connected with various power system devices associated with the parallel transmission lines. In such a case, the server can receive the measurements carried out at terminals of the first transmission line. Further, the IEDs may send measurements / processed information to the server for the purposes of fault location.
  • the device is an IED associated with one of the two terminals.
  • the IED can be associated with the first terminal, or second terminal of the first transmission line (i.e. the faulted line).
  • the IED obtains one or more signals from one or more measurement equipment connected to the line.
  • the measurement equipment can include a current transformer, a potential transformer, a sensor-based measurement equipment (e.g. Rogowski coils, non-conventional instrument transformers etc.) and the like, which provides a signal corresponding to current, voltage or other information as sensed from the line.
  • a current transformer provides single/multiple phase current signal and a potential transformer can provide single/multiple phase voltage signal to the IED.
  • the device is associated with one of the first terminal and the second terminal and receives data from other devices (that are associated with the other terminals).
  • the IED at the first terminal communicates with the IED at the second terminal of the first transmission line.
  • the IED at one terminal obtains the post-fault voltages and currents for the corresponding terminal (or bus), and receives post-fault currents measured at a remote terminal from another IED at the remote terminal.
  • the device has one or more modules for performing the fault location and other functions of the device. Such modules may be implemented with a processor(s) of the corresponding device.
  • the device has an interface, a phasor calculator and a fault locator.
  • the device can also have a memory with the line impedance parameters of the parallel transmission lines.
  • the line impedance parameters are associated with self and mutual-impedances of the lines.
  • the line impedance parameters can include parameters for compensating for charging currents (e.g. capacitance).
  • the interface obtains the measurements of the post-fault voltages and currents of the first terminal, and the measurements of the post-fault currents of the second terminal. That is the measurements of the post-fault voltages and currents at one end of the faulted line, and the measurements of the post-fault currents at the other end of the faulted line are obtained.
  • the local end measurements include the post-fault voltages and currents, while the remote end measurements include the post- fault currents.
  • the device is the server
  • the measurements for the two terminals are communicated with the server. It is assumed that the various devices that are involved in the fault location are synchronized with each other. In other words, all the measurements required for the fault location estimation are synchronized.
  • the phasor calculator obtains positive, negative and zero sequence quantities from the measurements.
  • the calculator can calculate the values from the measurements, or receive the values obtained by another device (i.e. via communication). These quantities and the line impedance parameters associated with the parallel transmission lines are used to calculate the voltage and current phasors for the plurality of fault location values.
  • the phasor calculator calculates the positive sequence voltage and current phasors for the fault location values from the positive sequence quantities of the measurements at the first line, and the line impedance parameters associated with the first line (i.e. associated with self-impedances). Similarly, the phasor calculator calculates the negative sequence voltage and current phasors for the fault location values from the negative sequence quantities and the line impedance parameters.
  • the phasor calculator estimates zero sequence currents for the second line (healthy line) from the zero sequence quantities obtained from the measurements of the first line, the self-impedances of each of the two lines, and the mutual impedance of the two lines.
  • the phasor calculator calculates the zero sequence voltage and current phasors for the fault location values with the zero sequence quantities obtained for the faulted line, the zero sequence currents estimated for the healthy line, and the line impedance parameters of the two lines.
  • the line impedance parameters are associated with the self-impedances of the lines, and the mutual impedances between the lines.
  • the fault locator estimates the location of the fault in the first transmission line.
  • the fault location is estimated based on phase differences between the fault point voltage and current phasors for the plurality of fault location values.
  • the phase differences may be estimated by the phasor estimator or the fault locator.
  • Fig. 1 shows a configuration of a power transmission system with parallel transmission lines, in which both lines are in operation;
  • Fig. 2 shows another configuration of the power transmission system with parallel transmission lines, in which one of the two lines is open and grounded;
  • Fig. 3 shows an Intelligent Electronic Device (IED) connected with one or more measurement equipment associated with the power transmission system;
  • IED Intelligent Electronic Device
  • Fig. 4 is a block diagram of a device for fault location in the power transmission system
  • Fig. 5 is a flowchart of a method for fault location in the power transmission system
  • Fig. 6 shows equivalent positive sequence circuit diagrams for the two configurations of the power transmission system shown in Figs. 1 and 2;
  • Fig. 7 shows approximate pi model of zero sequence circuit when both lines of the power transmission system are in operation.
  • Fig. 8 shows equivalent zero sequence circuit diagram when one of the parallel lines of the power transmission system is open and grounded.
  • the power transmission system can be a two terminal system as shown in Fig. 1.
  • Bus A first terminal, or terminal A
  • Bus B second terminal, or terminal B
  • the electrical bus A is connected to a source as shown, where the source can be a substation (or generating station).
  • the electrical bus B is connected to a source as shown.
  • the two terminals are connected by parallel transmission lines as shown.
  • the transmission system comprises two parallel lines, with a first transmission line (A1B1), and a second transmission line (A2B2).
  • Each of the parallel lines may comprise circuit breakers (not shown) to break the circuit when needed.
  • each of the two transmission lines may carry a three-phase current.
  • the two transmission lines may be referred as double circuit lines, wherein one line or circuit is fault (faulted / faulty line or faulted / faulty circuit)), while the other is healthy (healthy line / healthy circuit).
  • the fault location is estimated in response to the electrical fault (or disturbance) in the system (i.e. in one of the lines).
  • the fault location is performed by a device associated with the power transmission system.
  • the method is performed with one or more processors associated with the device.
  • the device may be an Intelligent Electronic Device (IED) associated with a terminal of the faulted line.
  • the device may be a server or another device of the power system that receives voltage / current measurements at the ends (or terminals of the faulted line).
  • the method is implemented by an JED associated with a terminal of the faulted line (e.g. terminal A of first transmission line).
  • a terminal of the faulted line e.g. terminal A of first transmission line.
  • An example is illustrated in Fig. 3, wherein the JED (302) is associated with Bus A.
  • the JED (302) receives one or more signals from one or more measurement equipment connected to the line.
  • a current transformer (CT) provides single/multiple phase current signal
  • PT potential transformer
  • the IED receives a signal(s) from the measurement equipment and obtain measurements therefrom.
  • the measurement equipment publishes the measurements over a communication bus (e.g. process bus) or in a communication channel or through suitable interface (e.g., input/output modules), and the JED (e.g. subscribed to receive data from such bus/communication channel) receives the measurements over the communication bus.
  • the IED also communicates with IEDs associated with other electrical buses (i.e. Bus B).
  • the IED at bus A may receive measurements, or phasors obtained at other IEDs.
  • the IED at bus B would receive information from IED at bus A.
  • the device has a plurality of modules.
  • the plurality of modules may be implemented using one or more processors.
  • the one or more processors may be a processor of an IED (e.g. IED 302).
  • the method may also be implemented with communication between a device associated with the line, and a server.
  • some of the modules may be implemented with one or more processors of the server (e.g. calculations or use of models using measurements from various measurement equipment at various terminals of the line), while the others are performed with one or more processors of the device (e.g. interface for voltage / current measurements, phasor estimator etc.).
  • the method may be implemented at the server, and the fault location communicated to the IED.
  • the server has also information about the line that has the fault (e.g. communicated to the server from IED or other fault line detector), and line parameters of the two lines (including self and mutual impedances, parameters for charging currents etc.).
  • Fig. 4 is a simplified block diagram of the device (400).
  • the plurality of modules includes an interface (402), a memory (404), a phasor calculator (406), and a fault locator (408).
  • the interface (402) obtains measurements of voltages and currents, that are measured at the two ends (or terminals) of the line with the fault.
  • the measurements are synchronized measurements.
  • the post-fault voltages and currents at one end (e.g. bus A) of the faulted line, along with post-fault currents at another end (e.g. bus B) of the faulted line are used for the purposes of fault location.
  • the device (400) is the IED (302) at bus A.
  • the IED receives the measurements obtained from the measurement equipment at Bus A.
  • the interface (402) can receive a signal(s) from the measurement equipment and obtain measurements therefrom.
  • the interface also acts as a communication interface for receiving information from other devices (e.g. other IEDs or server). For instance, the measurements may be published over the process bus, and the IED subscribes to the same.
  • the IED at bus A can receive information from IED at buses B or other modules (e.g. a phasor calculator (406)) of other devices (e.g. on the server or other power system devices).
  • the memory (404) (of the device or on server) can be any suitable storage for storing different information such as, but not limited to, disturbance records, line parameters etc.
  • the self and mutual impedances for the lines is available with the device.
  • information such as surge impedance of the first and / or second transmission lines, propagation constant of the first and / or second transmission lines, mutual impedances between the lines etc. can be stored.
  • Such parameter information can be stored in the device beforehand (e.g. by an operating personnel). This may also be stored in the server or other power system device for fault location purposes.
  • the phasor calculator (406) obtains positive, negative and zero sequence quantities from the measurements. These may be calculated by the phasor calculator or received (communicated) from another device (e.g. IED at other end).
  • the phasor calculator calculates voltage and current phasors for a plurality of fault location values from the positive, negative and zero sequence measurements. For example, voltage and current phasors can be estimated for different values of fault distances (e.g.‘O’,‘L’, ‘L/2’etc. where‘L’ is the line length of the two lines). There could be an optimization with regards to selection of the fault location values for which the phasors are calculated.
  • the phasor calculator calculates positive, negative and zero sequence phasors for the fault location values to estimate the voltage and current phasors for the fault location values.
  • the device can calculate the different voltage and current phasors (e.g. using suitable phasor calculation such as Fourier calculations etc.), from the voltage / current measurements carried out at the associated terminals of the faulted line.
  • Positive, negative and zero sequence quantities can be derived by using methods such as symmetrical component analysis etc.
  • the calculation of the positive and negative sequence voltage and current phasors for the fault location values is performed using the positive and negative sequence quantities/ measurements from the faulted circuit alone. Further, in accordance with the embodiments, the calculation of the zero sequence voltage and current phasors for the fault location values is performed using the zero sequence quantities/ measurements from the faulted circuit (line), and estimate of zero sequence currents for the healthy circuit (line). The zero sequence currents for the healthy line are estimated for each end (i.e. bus A, or bus B) of the line.
  • the estimation of the zero sequence current is based on the voltages and currents measured at the same (or local) end for the faulted line, the currents measured at the other (or remote) end of the faulted line, and self and mutual impedances of the two lines (described in further details below).
  • the fault locator (408) estimates the location of the fault (fault location) based on phase differences between the fault point voltage and current phasors.
  • the phase differences may be estimated by the phasor estimator or the fault locator.
  • a phase difference between the voltage and current phasors for a fault location value can be estimated from the angles of the voltage and current phasors.
  • the phase difference is the difference between the angles of the voltage and current phasors calculated for the fault location value.
  • the fault location value for which the phase difference is zero is estimated as the fault location.
  • Fig. 1 shows the case where both the lines (first line A1B1, and second line A2B2) are connected.
  • Fig. 2 shows the case where one line (faulted line) is connected and the other (healthy line) is open and grounded.
  • Terminal A and B are the two terminals (or electrical buses) of the system.
  • Line connecting Al to Bl is the first line (referred A1B1 above) and the line connecting A2 to B2 is the second line (referred A2B2 above).
  • both the lines are of length L km.
  • Both the circuits (lines) are mutually coupled.
  • VAI 1 , VA2 1 , VBI 1 and VB2 1 are the voltages measured at the terminals Al, A2, Bl and B2 respectively.
  • the superscript‘i’ can be equal to 0, 1 or 2, denoting zero, positive and negative sequence quantities respectively.
  • IAI 1 , , IBI 1 and are the currents measured at the terminals Al, A2, Bl and B2 respectively.
  • the superscript‘i’ can be equal to 0, 1 or 2, denoting zero, positive and negative sequence quantities respectively.
  • ABCD 1 parameters are used to represent the impedance parameters of the line.
  • the superscript‘i’ can be equal to 0, 1 or 2, denoting zero, positive and negative sequence quantities respectively.
  • the subscript ‘m’ wherever used denotes the mutual quantities between the two lines.
  • the fault is assumed to be located on line 1, connecting terminals Al and Bl, at a fractional distance, d, from the terminal Al .
  • d fractional distance
  • positive, negative and zero sequence voltage and current phasors for fault location values are required.
  • the various phasors may be calculated at the device (i.e. IED or server). Such calculation may be performed by the phasor calculator (406).
  • the phasor calculator can obtain the positive, negative and zero sequence quantities from the measurements to arrive at the voltage and current phasors for the fault location (or point) values.
  • the calculation of positive sequence voltage and current phasors is performed for fault location value(s) (i.e. taking values for fault distance (d)). Since the positive sequence networks of both the circuits of the double circuit line are not mutually coupled, the positive sequence voltage and current phasors for the fault location can be calculated using positive sequence quantities/ measurements from the faulted circuit alone.
  • the fault point voltage, V F 1 can be calculated using equation (1). Further, the fault current contribution from terminal Al, I FA 1 can be calculated using equation (2).
  • a d 1 , B d 1 , C d 1 and D d 1 are ABCD parameters of the first line (A1B1) defined upto the fault location (i.e.‘d’).
  • r 1 , l 1 and c 1 are positive sequence resistance, inductance and capacitance per unit length of the line.
  • AH 1 , Bi- d 1 , Ci- d 1 and Di- d 1 are ABCD parameters of the line defined from fault location to remote terminal.
  • Bl_ d — Z sinh(y 1 (l— d)L ) ;
  • r 1 , l 1 and c 1 are positive sequence resistance, inductance and capacitance per unit length.
  • the total fault current can be calculated as, l IF 1 —— l IF 1 A 4 + - ' IF 1 B (7)
  • the calculation of negative sequence voltage and current phasors for the fault location value(s) is performed.
  • the negative sequence network is similar to positive sequence network and hence negative sequence fault point voltage and fault current can be calculated in the same way as explained in the previous step, just by replacing all positive sequence quantities by negative sequence quantities.
  • the estimation of zero sequence currents in the healthy circuit in terms of the fault location value(s) is performed. This is required to calculate the zero sequence voltage and current phasors for the fault location value(s). Such estimation of the zero sequence currents for the healthy line is performed with the device (e.g. phasor calculator).
  • the zero sequence currents are estimated using the zero sequence voltage and current quantities / measurements from local terminal of the faulted line, and the zero sequence current quantities / measurements from the remote terminal of the faulted line.
  • subscript‘dl’ denotes self-impedance of line 1 till the fault location
  • subscript‘d2’ denotes self-impedance of line 2 till the fault location
  • subscript‘dm’ denotes mutual-impedance between both the circuits till the fault location.
  • subscript‘(l-d)l’ denotes self-impedance of line 1 from fault location to terminal B
  • subscript‘(l-d)2’ denotes self-impedance of line 2 from fault location to terminal B
  • subscript‘(l-d)m’ denotes mutual-impedance between both the circuits from fault location to terminal B.
  • VBI° VBI°
  • IA2° IB2°
  • VB2° 0.
  • Relation 2 Calculation of voltage at terminal B2 from terminal A2.
  • Voltage at terminal B2 can be calculated using voltage current from terminal A2. This can be written from the second row of equation (14)
  • the calculation of zero sequence fault point voltage and fault current for the fault location value (zero sequence voltage and current phasors for the fault location value(s)) is performed.
  • the fault point voltage is obtained using A-end data is calculated as,
  • Fault current can be written as, r° -— ro 7° (25)
  • the voltage and current phasors for the fault location value(s) are calculated.
  • the fault point voltage can be calculated as
  • fault current can be calculated as
  • the estimation of the fault location is performed. This estimation is performed by the device (e.g. with the fault locator). In order to estimate the fault location, calculation of phase differences between fault point voltage and fault current is required. The phase differences may be calculated by the phasor estimator or fault locator. In accordance with an embodiment, the phase difference between fault point voltage and fault current, is calculated by
  • K is essentially zero (assumption: fault resistance is purely resistive in nature) when calculated for the correct fault location. That is, the angle of fault point voltage and fault current will be ideally equal (i.e. V and I are in phase), at the fault location. However for any other value of d, K is non-zero.
  • the method of the invention estimates unknown/unavailable zero- sequence currents of the healthy line using known/available limited measurements from the faulted line.
  • the known/available limited measurements from the faulted line include voltage and current measurements from the local terminal, and current measurements from remote terminal. These are used to determine the unknown / unavailable zero sequence currents, which are used for zero sequence mutual compensation.
  • the invention considers and accounts for capacitive charging on the transmission line which makes it more accurate. This is performed with consideration of line impedance parameters such as capacitance per unit length, thereby accounting for distribution of current in the line.

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  • Physics & Mathematics (AREA)
  • General Physics & Mathematics (AREA)
  • Locating Faults (AREA)

Abstract

La présente invention concerne un procédé de localisation de défaut dans un système de transmission de puissance, avec deux bornes connectées par des lignes de transmission parallèles. Le défaut est situé dans une première ligne de transmission. Le procédé comprend une étape consistant à obtenir des mesures de tensions et de courants post-défaut au niveau d'une borne, et des mesures de courants post-défaut au niveau d'une autre borne de la première ligne de transmission. Les mesures post-défaut sont utilisées pour calculer des phaseurs de tension et de courant pour diverses valeurs de localisation de défaut. Pour estimer les phaseurs pour une valeur de localisation de défaut, des phaseurs de tension et de courant de séquence positive, négative et zéro sont calculés pour la valeur de localisation de défaut. Les phaseurs de séquence zéro sont calculés à partir des premières mesures de ligne, et des courants de séquence zéro estimés pour la seconde ligne de transmission. Les courants de séquence zéro pour la seconde ligne sont estimés avec les quantités de séquence zéro des premières mesures de ligne et des paramètres d'impédance de ligne associés aux deux lignes.
PCT/IB2019/054393 2018-05-31 2019-05-28 Localisation de défaut pour lignes de transmission parallèles avec des courants de séquence zéro estimés à partir de mesures de ligne défectueuse WO2019229638A1 (fr)

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CN111624510A (zh) * 2020-06-11 2020-09-04 国网四川省电力公司电力科学研究院 基于复合模量网络的接地极线路短路阻抗获取方法及装置
CN111736107A (zh) * 2020-05-27 2020-10-02 湖南省湘电试验研究院有限公司 一种基于序电流比相的ct断线检测方法、系统及介质
CN112255461A (zh) * 2020-11-24 2021-01-22 云南电网有限责任公司 一种模块化多电平换流器多域宽频带阻抗测量方法
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EP3993204A1 (fr) * 2020-10-28 2022-05-04 Katholieke Universiteit Leuven Détermination de la localisation d'un défaut sur une ligne électrique
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EP3993204A1 (fr) * 2020-10-28 2022-05-04 Katholieke Universiteit Leuven Détermination de la localisation d'un défaut sur une ligne électrique
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US12272943B2 (en) 2021-03-30 2025-04-08 Hitachi Energy Ltd Device, system, and method for double-circuit transmission systems
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US12362556B2 (en) 2023-03-07 2025-07-15 Schweitzer Engineering Laboratories, Inc. Single-ended broken conductor detection logic using incremental quantities
WO2024196565A1 (fr) * 2023-03-22 2024-09-26 General Electric Technology Gmbh Systèmes et procédés pour la détermination d'une distance à un défaut dans des systèmes de lignes hybrides
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