WO2011070520A2 - Système et procédé de protection contre le glissement des pôles pour machines synchrones - Google Patents

Système et procédé de protection contre le glissement des pôles pour machines synchrones Download PDF

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Publication number
WO2011070520A2
WO2011070520A2 PCT/IB2010/055663 IB2010055663W WO2011070520A2 WO 2011070520 A2 WO2011070520 A2 WO 2011070520A2 IB 2010055663 W IB2010055663 W IB 2010055663W WO 2011070520 A2 WO2011070520 A2 WO 2011070520A2
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WIPO (PCT)
Prior art keywords
fault
machine
machine arrangement
generator
synchronous
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PCT/IB2010/055663
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English (en)
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WO2011070520A3 (fr
Inventor
Jan Abraham De Kock
Lafras Lamont
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North-West University
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Publication date
Application filed by North-West University filed Critical North-West University
Priority to CA2783878A priority Critical patent/CA2783878C/fr
Priority to AU2010329540A priority patent/AU2010329540A1/en
Priority to EP10807736.3A priority patent/EP2510611B1/fr
Priority to US13/514,905 priority patent/US9093839B2/en
Publication of WO2011070520A2 publication Critical patent/WO2011070520A2/fr
Publication of WO2011070520A3 publication Critical patent/WO2011070520A3/fr
Priority to ZA2012/04203A priority patent/ZA201204203B/en

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Classifications

    • 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
    • H02H3/48—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 loss of synchronism
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02P—CONTROL OR REGULATION OF ELECTRIC MOTORS, ELECTRIC GENERATORS OR DYNAMO-ELECTRIC CONVERTERS; CONTROLLING TRANSFORMERS, REACTORS OR CHOKE COILS
    • H02P25/00—Arrangements or methods for the control of AC motors characterised by the kind of AC motor or by structural details
    • H02P25/02—Arrangements or methods for the control of AC motors characterised by the kind of AC motor or by structural details characterised by the kind of motor
    • H02P25/022—Synchronous motors
    • H02P25/03—Synchronous motors with brushless excitation
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02P—CONTROL OR REGULATION OF ELECTRIC MOTORS, ELECTRIC GENERATORS OR DYNAMO-ELECTRIC CONVERTERS; CONTROLLING TRANSFORMERS, REACTORS OR CHOKE COILS
    • H02P29/00—Arrangements for regulating or controlling electric motors, appropriate for both AC and DC motors
    • H02P29/02—Providing protection against overload without automatic interruption of supply
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02P—CONTROL OR REGULATION OF ELECTRIC MOTORS, ELECTRIC GENERATORS OR DYNAMO-ELECTRIC CONVERTERS; CONTROLLING TRANSFORMERS, REACTORS OR CHOKE COILS
    • H02P9/00—Arrangements for controlling electric generators for the purpose of obtaining a desired output
    • H02P9/009—Circuit arrangements for detecting rotor position
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02P—CONTROL OR REGULATION OF ELECTRIC MOTORS, ELECTRIC GENERATORS OR DYNAMO-ELECTRIC CONVERTERS; CONTROLLING TRANSFORMERS, REACTORS OR CHOKE COILS
    • H02P9/00—Arrangements for controlling electric generators for the purpose of obtaining a desired output
    • H02P9/10—Control effected upon generator excitation circuit to reduce harmful effects of overloads or transients, e.g. sudden application of load, sudden removal of load, sudden change of load
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02P—CONTROL OR REGULATION OF ELECTRIC MOTORS, ELECTRIC GENERATORS OR DYNAMO-ELECTRIC CONVERTERS; CONTROLLING TRANSFORMERS, REACTORS OR CHOKE COILS
    • H02P9/00—Arrangements for controlling electric generators for the purpose of obtaining a desired output
    • H02P9/14—Arrangements for controlling electric generators for the purpose of obtaining a desired output by variation of field
    • H02P9/26—Arrangements for controlling electric generators for the purpose of obtaining a desired output by variation of field using discharge tubes or semiconductor devices
    • H02P9/30—Arrangements for controlling electric generators for the purpose of obtaining a desired output by variation of field using discharge tubes or semiconductor devices using semiconductor devices
    • H02P9/302—Brushless excitation
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02H—EMERGENCY PROTECTIVE CIRCUIT ARRANGEMENTS
    • H02H1/00—Details of emergency protective circuit arrangements
    • H02H1/04—Arrangements for preventing response to transient abnormal conditions, e.g. to lightning or to short duration over voltage or oscillations; Damping the influence of dc component by short circuits in ac networks
    • 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
    • H02H7/08—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 for dynamo-electric motors
    • H02H7/0805—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 for dynamo-electric motors for synchronous motors

Definitions

  • This invention relates to protection systems and methods for synchronous machines and more particularly to a method of protecting a synchronous machine arrangement connected to an electricity network against pole-slip and a pole-slip protection relay.
  • Pole-slipping in synchronous machines occurs when there is insufficient electromagnetic torque to hold the rotor in synchronism with the stator magnetic flux. Typically, pole-slipping occurs under severe fault conditions that cause a transient torque which exceeds the ability of the rotor magnetic field to keep the rotor synchronized with the stator rotating magnetic field.
  • Synchronous generators may pole-slip due to faults in the network, power swings and loss-of- excitation.
  • Synchronous motors may pole-slip during under-voltage conditions, loss of excitation and during sudden mechanical failure.
  • pole-slip protection apparatus and methods make use of an impedance scheme pole-slip protection algorithm to detect pole-slip. These apparatus and methods are reactive in nature in that they first trip a machine after it has pole-slipped one or more times. Severe mechanical damage could be caused by just one pole-slip. To the best of the applicant's knowledge, there is not currently available a pole-slip protection apparatus and method that operate preventatively.
  • a method of protecting a synchronous machine arrangement connected to an electricity network against pole-slip comprising the steps of:
  • the machine arrangement is disconnected from the network before the machine arrangement becomes unstable.
  • the machine arrangement may be disconnected from the network, before or after the fault is cleared.
  • the first parameter may be a power transfer angle between an electromotive force (EMF) of the machine arrangement and the reference value in the form of a reference voltage (Vref)
  • the second parameter may be power transfer relating to the machine arrangement
  • the third parameter may be at least one of an actual voltage and current measured on a terminal of the machine arrangement
  • the fourth parameter may be at least one of a voltage and a current on the terminal of the machine arrangement.
  • the reference voltage may be chosen at an infinite bus in the electricity network.
  • the method may comprise the step of utilizing the representation and the stability criterion to compute a critical value of the first parameter at which the fault must be cleared for the machine arrangement to regain stability and if the first parameter reaches the critical value, the machine arrangement is caused to be disconnected from the network.
  • the stability criterion may be the equal area stability criterion.
  • the synchronous machine arrangement may comprise a synchronous rotating machine comprising one of a synchronous motor and a synchronous generator.
  • the machine may be a salient pole or a round rotor machine.
  • the synchronous machine arrangement may comprise a transformer associated with the synchronous rotating machine and connected in series between the electricity network and the synchronous rotating machine and the synchronous machine arrangement may be disconnected from the network at a first circuit breaker between the synchronous rotating machine and the transformer or at a second circuit breaker between the transformer and the electricity network.
  • the synchronous rotating machine may be a synchronous power generator at a first power station connected to the electricity network and the reference may be a voltage chosen at another spaced power station connected to the electricity network.
  • the other spaced power station may be a power station physically or geographically closest to the first power station.
  • a pole-slip protection rely for an electrical synchronous machine arrangement connected to an electricity network comprising a controller comprising a processing machine configured to execute a program comprising a pole-slip detection and instability prediction algorithm and which controller is configured, in response to a prediction of instability, to cause a protection action, such as a circuit breaker to be operated.
  • the processing machine may comprise a digital processor and the program may comprise a computer program code.
  • a computer program having a program code for performing the method as herein defined, when the computer program runs on a processor.
  • a computer readable medium with a computer program having a program code for performing the method as herein defined, when the computer program runs on a processor.
  • the processor may form part of any suitable processing machine, such as an embedded processor, including a programmable logic controller, a computer, whether a personal computer, lap-top or any other computer.
  • figure 1 is a high level diagram of a synchronous power generator connected to an electrical network
  • figure 2 is a high level diagram of the generator and more detail of the network
  • figure 3 is a diagram against time of events prior to and following a fault that may cause pole-slip of the generator, until after the fault has been cleared;
  • figure 4 representation of power output against a power transfer angle of the generator
  • figure 5 is a graph against time of generator speed deviation due to a
  • FIGS. 6(a) and (b) illustrate a block diagram of a pole-slip protection algorithm embodied in a pole-slip protection application computer program
  • figure 7 is a vector diagram for computing a power transfer angle over the transmission line
  • figure 8 is a block diagram of a power system layout indicating measurement of the real and reactive power of the transmission line feeders
  • figure 9 is a phasor diagram of a overexcited generator
  • figure 1 0 is a block diagram model of a salient pole machine
  • figure 1 1 is a block diagram model of a round rotor machine
  • figure 1 2 is a graph of rotor speed increase against power transfer angle during faulted and post-fault periods;
  • figure 1 3 are representations of power transfer during a fault and post- fault against power transfer angle;
  • figure 1 4 is a circuit diagram of an example electricity network
  • figure 1 5 is a first Thevenin equivalent circuit of the circuit in figure
  • figure 1 6 is a second Thevenin equivalent circuit of the circuit in figure 1 4;
  • figure 1 7 is a third Thevenin equivalent circuit of the circuit in figure 1 4;
  • figure 1 8 is a fourth Thevenin equivalent circuit of the circuit in figure 1 4;
  • figure 1 9 is an iteration convergence curve for the accuracy of 5 gen and ;
  • figure 20 are graphs from a PSCAD simulation illustrating the equal area criterion
  • figure 21 are power curves of a generator with the effect of saliency
  • figure 22 is a graph illustrating the determination of 1 on the power curve with saliency included.
  • FIG. 1 there is shown a synchronous rotating machine in the form of a power generator 10 connected to an electricity network 1 2.
  • the machine 1 0 forms part of a machine arrangement 1 4 also comprising an associated transformer 1 6.
  • a computerized protection relay 1 8 comprises a controller comprising a processor and an associated memory arrangement.
  • the processor is configured to execute a pole-slip detection and protection application program comprising a program code for performing a method of protecting the synchronous machine arrangement against pole-slip as will hereinafter be described.
  • the method comprises the steps of the relay 1 8 continuously computing and monitoring a first variable parameter relating to the machine arrangement with reference to a reference value.
  • the first parameter is a power transfer angle ( ⁇ ) between an electromotive force (EMF) 20 of the machine 1 0 and a reference voltage (Vref) 22 .
  • the relay 1 8 derives a representation 28 (shown in figure 4) of a second parameter relating to the machine arrangement, in this example embodiment power transfer P, against the first parameter power transfer angle ( ⁇ ) utilizing data relating to a value of a third parameter relating to the machine, in this example embodiment actual voltages (Va, Vb and Vc) and currents (la, lb and lc) measured on terminals 26 of the machine 1 0 before the fault has occurred and computed data relating to a fourth parameter, in this example embodiment expected voltages and currents at the terminals of the machine after the fault has occurred.
  • the processor and program utilizes data relating to the representation and a stability criterion to compute a critical value for the transfer angle ⁇ at which the fault 24 must be cleared (for example by opening relay 30 to isolate the fault) for the machine to regain stability.
  • the relay 1 8 is configured to disconnect the machine 10 from the network at any one or both of machine circuit breaker 32 or at the high voltage circuit breaker 34, if the fault 24 is not cleared when the transfer angle reaches the critical value.
  • the invention provides a new pole-slip protection function that determines when a machine, such as the generator 1 0 will become unstable after a network fault. If instability is predicted, the generator will be tripped, even before the fault is cleared, to avoid damaging post-fault torque effects.
  • the reference voltage Vref is a voltage at an infinite bus in the network 1 2.
  • the infinite bus can be chosen as the physically or geographically closest other power station 40 to the generator 10 under consideration. This means that only the transmission line impedance Ziinei between the generator 10 under consideration and the closest other power station 40 needs to be known. For this assumption to be valid, it was tested that the line impedance between said closest other power station and the rest of the network must be less than 5% of the line impedance Ziinei between generator 1 0 and the closest other power station 40. This assumption has been found to be valid for at least some practical power systems.
  • the well known equal area criterion is used in a pole-slip algorithm embodied in the pole-slip protection application program to predict generator stability.
  • the algorithm is divided into steady state calculations and transient calculations.
  • the steady state calculations involve the calculation of the pre-fault transfer angle between the EMF of generator 10 and the infinite bus.
  • the effect of shunt or local loads 42 and generators in parallel to generator 1 0 is included in the transfer angle calculation.
  • EMF Eq' of generator 1 0 is also calculated during steady state conditions.
  • Eq' is used in the transient calculations with the assumption that is will not change during a fault duration of up to 300ms due to the large field winding time constant Tdo' .
  • the slight increase in Eq' after the fault is cleared, will cause the generator 1 0 to be more stable.
  • This effect is compensated for in a rotor overshoot factor calculation.
  • the rotor overshoot factor is defined as the time that the rotor remains above synchronous speed after the fault is
  • the generator 1 0 active electrical power output reduces, although the prime mover, such as a turbine (not shown) mechanical power remains approximately constant for the fault duration. This causes the generator rotation speed to increase during the fault as shown in figure 5. After the fault is cleared, the generator electrical active power is restored. The electrical active power is greater than the mechanical turbine power after the fault is cleared, and hence the generator 1 0 will decelerate again to steady state conditions, if stability is maintained.
  • the prime mover such as a turbine (not shown) mechanical power
  • the generator and transformer transient power angles must also be determined during the fault for use in the equal area criterion.
  • An iterative solution was developed to calculate the transient power angles.
  • a rotor overshoot factor of 50% of the calculated value is used to compensate for the assumption of a fixed EMF Eq' and to ensure the pole-slip protection relay 1 8 will not cause spurious trips.
  • Figures 6(a) and (b) illustrate a high level block diagram of the new pole-slip protection algorithm embodied in a pole-slip detection and protection application program.
  • the following equation calculates the pre-fault power transfer angle.
  • Trfr is the transformer steady-state power transfer angle
  • Tline is the transmission line steady-state power transfer angle
  • the steady-state generator power transfer angle 5 Gen is calculated for underexcited and overexcited conditions as is shown in Table 1 .
  • the transformer power transfer angle ⁇ ? is calculated as follows:
  • XTrfr is the transformer reactance
  • Vpri and Vsec are the transformer primary and secondary voltages respectively
  • Figure 7 explains how the network transfer angle is determined by the impedance principle.
  • the following impedances are drawn in the R-X complex impedance plane:
  • Step-up transformer reactance X trfr .
  • V an is the generator terminal voltage (line to neutral) / is the generator line current
  • the measured impedance angle ⁇ is also the power factor angle:
  • Za corrected IS calculated as follows:
  • the power angle over the transmission line is calculated from figure 7 as follows:
  • FIG 8. A practical implementation to measure the real- and reactive power of the transmission line feeders is shown in figure 8. It can be seen from figure 8 that the active- and reactive powers are measured on the transmission line feeders only (no shunt load measurements are taken).
  • a device like a summation CT, may be installed to summate the active powers of all the transmission line feeders.
  • Figure 9 shows the phasor diagram of an overexcited synchronous generator. Since the EMF is located on the q-axis, the sum of the q- axis components alone can determine the EMF. Sum of q-axis components : (1.13) Figure 1 0 and figure 1 1 show the block diagram model of a salient pole and round rotor machine respectively.
  • V d V gen sin(3 ⁇ 4 event)
  • Igen is the generator line current
  • Vgen is the generator line voltage
  • 6gen is the generator power transfer angle
  • ⁇ is the generator power factor It has been found that the generator power factor is close to unity after the fault is cleared. This is so due to the fact that the generator has to supply maximum active power in order to decelerate. Almost no reactive power is supplied in the post-fault period. It can therefore be assumed that the power factor angle ⁇ is close to zero degrees in the post-fault period.
  • X q _eff is required to determine the post-fault magnitudes of Igen and V gen . Equation (1 .1 5) is therefore not practical to use to determine X q eft. However, it can be seen that l q will approach 0 as gen approaches 90° (since ⁇ is assumed to be 0 in the post-fault period).
  • a generator will be more stable with a larger X q _ e .
  • the approximation in (1 .1 7) proved to be sufficiently accurate for at least some applications.
  • Figure 1 2 shows a typical rotor speed increase during a fault, with the periods “Faulted” and “Post-fault” depicted as such.
  • the rotor is still above synchronous speed due to inertia. This causes the power transfer angle to increase during the "post- fault” period. With a larger power transfer angle, larger current will flow, which will cause a greater voltage drop on the terminals of the generator 10 and the transformer 1 6.
  • the post-fault voltages (after the fault is cleared) are important to predict, since these voltages are used in the equal area criterion to determine generator stability.
  • the rotor kinetic energy increase during the fault must equal the kinetic energy decrease after the fault is cleared.
  • the rotor angle increase during the post-fault period can be determined by using the calculated "Area 1 " in figure 1 3. This area is the same as the area designated "Area 2" in figure 1 3.
  • the region depicted "Area 2" may be assumed to be a rectangle. This rectangle has a vertical side with length p elec (5 c ) , i-e. the value of active power at the instant that the fault is cleared.
  • the horizontal side of this rectangle will represent the power transfer angle increase, after the fault is cleared, or ⁇ y max . Due to the assumption of a rectangular area, will be smaller than the true s ⁇ This will make the protection function more conservative, since a value of 5 C where instability may become possible would be around 90° (the point where maximum power transfer occurs) . With a "long" vertical side of the rectangle, the horizontal side will be smaller for the same area, and therefore a smaller s will be calculated.
  • the maximum power transfer angle s m3x after the fault is cleared can be determined as follows:
  • Pmech is the pre-fault mechanical prime mover power
  • the voltage on the generator terminals 26 and the terminals of the step-up transformer 1 6 greatly influences the stability of the generator 1 0 after the fault is cleared.
  • the expected post-fault current needs to be calculated, before the fault is cleared, to predict the post-fault voltages on the different busses.
  • Figure 14 shows a circuit diagram of an example complete electricity network comprising generator 1 0 with associated step-up transformer 1 6, a second generator 46 and associated transformer in parallel, a shunt load 42 and the transmission line 48.
  • the aim is to determine the post-fault voltages on the terminals 26 of generator 1 0 and on the secondary terminals 44 of transformer 1 6. These voltages are to be used in the equal area criterion for generator 1 0 and transformer 1 6 respectively, to determine stability after the fault is cleared .
  • FIG 1 5 there is shown the Thevenin equivalent circuit resulting from the generator 46 in parallel and with the transmission line 48 and shunt loads 42 connected .
  • the only equipment that is disconnected from this Thevenin circuit is generator 1 0.
  • the first step is to determine the current of generator 46 ( i Th ze ) as if only the shunt loads 42 were connected to generator 46. This current is then used to determine the Thevenin voltage ⁇ ⁇ - ° ⁇ . l' Q *3 ⁇ 4 _
  • ⁇ 2_postfauit 'ls used to calculate the expected post-fault voltage magnitudes that are used in the equal area stability calculation.
  • ⁇ n ze represents only the currents of the generators that are parallel to generator 1 0.
  • ( ⁇ ' is the current of generator 46 with the shunt loads 42 included.
  • the voltage v n z . 6 n as calculated in ( 1 .20) is used in a second Thevenin equivalent circuit as shown in figure 1 6 to determine the current ⁇ ⁇ ⁇
  • V Th ZS Th V Th ZS Th -l Th Z0-(R Th + jX Th )
  • the voltage ⁇ ⁇ ⁇ ⁇ as calculated in (1.20) is used as shown in the third Thevenin equivalent circuit as shown in figure 17, to determine the current of generator 10, namely' ⁇ .
  • Thevenin impedance 2TM In order to calculate the Thevenin impedance 2TM must be determined as follows:
  • the generator terminal 26 voltage ge ⁇ _posttauit gem anc j transformer secondary 44 voltage ⁇ . ⁇ ⁇ ** are calculated as follows:
  • the voltage angles in (1.26) and (1.27) may not be accurate enough for stability study purposes.
  • the bus voltage magnitudes calculated in (1.26) and (1.27) are therefore used in the equal area criterion.
  • An iterative algorithm as hereinafter described is used to determine the generator power angle and the voltage angle over the transformer, which is also used in the equal area criterion.
  • the during-fault voltages and currents may be considered to be the voltages and currents at the instant when the fault is cleared. These voltages on the terminals 26, 44 of the generator 1 0 and step-up transformer 1 6 may be calculated at the instant the fault is cleared. These voltage magnitudes are used to determine the transient power transfer angles of the generator and transformer during the fault. These power transfer angles are used in the equal area criterion.
  • the generator 1 0 power transfer angle s gen and the voltage angle over the transformer S tx are required to determine where instability will occur by using two different equal area criteria calculations.
  • the first equal area criterion calculation determines generator stability by including generator saliency effects, while the other equal area criterion calculation determines the stability of the step-up transformer 1 6.
  • the initial estimate for A gen and 5 fY is determined as follows:
  • 3 ⁇ 4(0) ⁇ 3 ⁇ 4,, - 3 ⁇ 4 ( 1 .31 )
  • S Th is the power transfer angle on the Thevenin bus (i.e.
  • S c is the power transfer angle between the EMF and the infinite bus at the instant that the fault is cleared, as is calculated in (1 .37)
  • V gen is the generator terminal voltage (p.u)
  • E q is the generator internal EMF Since there exists no explicit solution to the following equations, an iterative solution may be followed in order to determine 5 gen and 5 tx .
  • the generator power (Pgen) and transformer power (Ptx) are determined in terms of the iteration index (i):
  • Ki 7/Vgen.
  • the choice for Ki is valid when the angles are in degrees and the active power P in per unit.
  • Figure 19 presents a typical convergence curve for the accuracy in ⁇ and ⁇ .
  • the iterative algorithm reaches a solution that is typically 99.5 % of the true value within 5 iterations.
  • the equal area criterion states that the accelerating area under the active power curve (Area 1 ) must be less than the decelerating area (Area 2) for stability to be maintained.
  • the mechanical prime-mover power is denoted as Po in figure 4.
  • Figure 20 shows the active power curve in the steady-state, in the faulted and post-fault conditions.
  • the equal area criteria for the pole- slip function will be performed for the generator 1 0 (with saliency effects included in the power curve) and for the step-up transformer. If instability is predicted to occur in the generator 1 0 or the step-up transformer 16, the generator 10 must be disconnected from the network 12, or tripped, before the fault 24 is cleared.
  • the increase in rotor angle AS mtor must be added to the pre-fault transfer angle ⁇ 0 to obtain the post-fault power transfer angle between the generator EMF and the network infinite bus.
  • the post- fault power transfer angle is calculated as:
  • Area 1 is calculated by integrating from the pre-fault transfer angle (s 0 ) to the post-fault transfer angle s c as determined by equation (1.37).
  • the accelerating area (Area 1) for the generator 10 and step-up transformer 16 respectively, may be calculated as follows:
  • the decelerating area (Area 2) for the generator 10 is calculated as follows: J_
  • the decelerating area (Area 2) for the transformer 16 is calculated as follows:
  • the angle £ L indicated in figure 4 is the maximum allowable transfer angle for stability to be maintained and can be determined as follows:
  • + ne(ivoA is the network impedance from the generator terminals up to the infinite bus
  • X is the generator transient direct-axis reactance.
  • 5 L is the generator transient direct-axis reactance.
  • the saliency curves are shown in figure 21 .
  • a trigonometric solution for 5 L is obtained in figure 21 by using the prime-mover power as 1 pu in this illustration.
  • a vertical line may be drawn from the point where Papprox (without saliency) intersects with the prime-mover power (point B) to point A where this vertical line intersects with Pgen salient.
  • a line can be drawn from 1 80° (point D) to point A.
  • the intersection with the prime-mover power (point E) can be regarded as 5 L .
  • the gradient m of line AD in figure 22 is determined as follows:
  • the equal area states that the machine shall be tripped if the following condition is met for either the generator 10 or the transformer 16:

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  • Engineering & Computer Science (AREA)
  • Power Engineering (AREA)
  • Control Of Eletrric Generators (AREA)
  • Protection Of Generators And Motors (AREA)
  • Emergency Protection Circuit Devices (AREA)

Abstract

L'invention porte sur un procédé de protection d'une machine synchrone (10) connectée à un réseau électrique (12) contre le glissement des pôles. Ce procédé consiste à surveiller en continu un angle de transfert de puissance (δ) entre une force électromotrice (EMF) de la machine et une tension de référence Vref. Dans le cas d'un défaut (24) du réseau électrique, qui peut entraîner un glissement des pôles de la machine (10), on déduit une représentation du transfert de puissance (P) relatif à la machine par rapport à l'angle de transfert de puissance (δ) en utilisant des données relatives à la valeur d'un courant ou d'une tension mesurée sur une borne (26) de la machine avant que le défaut n'ait eu lieu et des données calculées relatives à une future valeur attendue d'un courant ou d'une tension sur la borne (26) après que le défaut a eu lieu. Le procédé utilise ensuite la représentation et un critère de stabilité pour prédire si la machine (10) peut devenir instable et, si l'instabilité est prédite, et amène la machine (10) à être déconnectée du réseau électrique (12) en 32 ou 34.
PCT/IB2010/055663 2009-12-10 2010-12-08 Système et procédé de protection contre le glissement des pôles pour machines synchrones WO2011070520A2 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
CA2783878A CA2783878C (fr) 2009-12-10 2010-12-08 Systeme et procede de protection contre le glissement des poles pour machines synchrones
AU2010329540A AU2010329540A1 (en) 2009-12-10 2010-12-08 Pole-slip protection system and method for synchronous machines
EP10807736.3A EP2510611B1 (fr) 2009-12-10 2010-12-08 Système et procédé de protection contre le glissement des pôles pour machines synchrones
US13/514,905 US9093839B2 (en) 2009-12-10 2010-12-08 Pole-slip protection system and method for synchronous machines
ZA2012/04203A ZA201204203B (en) 2009-12-10 2012-06-08 Pole-slip protection system and method for synchronous machines

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
ZA2009/08800 2009-12-10
ZA200908800 2009-12-10

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WO2011070520A2 true WO2011070520A2 (fr) 2011-06-16
WO2011070520A3 WO2011070520A3 (fr) 2011-12-29

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WO2013102849A3 (fr) * 2012-01-03 2014-03-13 ComAp a.s. Procédé et appareil de détection de glissement de pôle dans des générateurs synchrones
GB2501687A (en) * 2012-04-30 2013-11-06 Isentropic Ltd Electrical machine having regulated power angle
GB2501687B (en) * 2012-04-30 2014-12-10 Isentropic Ltd Improvements relating to the transmission of energy
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WO2014056144A1 (fr) * 2012-10-09 2014-04-17 Abb Research Ltd. Procédés, systèmes et support lisible par ordinateur pour la protection adaptative en cas de déphasage de groupes électrogènes à capacité de re-synchronisation de charge
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US10770997B2 (en) 2018-05-30 2020-09-08 Rolls-Royce Plc Power system
US10931217B2 (en) 2018-05-30 2021-02-23 Rolls-Royce Plc Power system
US11079255B2 (en) 2018-05-30 2021-08-03 Rolls-Royce Plc Angle determination for a generator

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EP2510611A2 (fr) 2012-10-17
EP2510611B1 (fr) 2018-03-21
ZA201204203B (en) 2013-02-27
US9093839B2 (en) 2015-07-28
CA2783878A1 (fr) 2011-06-16
CA2783878C (fr) 2017-01-10
WO2011070520A3 (fr) 2011-12-29
AU2010329540A1 (en) 2012-07-05

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