METHOD FOR OPERATING A WIND TURBINE AND WIND TURBINE

Abstract

This disclosure is directed to a method for operating a wind turbine which includes a speed-variable drive system. The system includes an electrical machine and a pulsewidth modulation-controlled converter. The speed-variable drive system is connected to an electrical grid. In the event of a transient grid fault, a frequency of the pulsewidth modulation is determined in response to a current in an electrical circuit connected to the converter.

Claims

1. A method for operating a wind turbine in association with an electrical grid wherein a transient grid fault can occur, the wind turbine including: a speed-variable drive system connectable to said electrical grid; said speed-variable drive system including an electric machine and a pulsewidth modulation-controlled converter; a first electrical circuit connecting said electrical machine to said pulsewidth modulation-controlled converter; and, a second electrical circuit connecting said pulsewidth modulation-controlled converter to said electrical grid; the method comprising the step of: in the event of the transient grid fault, determining a frequency of the pulsewidth modulation in response to a current increase in at least one of said first and second electrical circuits.

2. The method of claim 1, wherein said electrical machine is a double-fed induction generator having a rotor; said pulsewidth modulation-controlled converter includes a rotor-side inverter connected to said rotor; a grid-side inverter connected to the electrical grid; and, a DC link that connects said rotor-side inverter to said grid-side inverter; the method comprising the further step of: in the event of a transient grid fault, determining the frequency of said pulsewidth modulation of at least one of said rotor-side inverter and said grid-side inverter in response to said current.

3. The method of claim 2, wherein the current is at least one of a current in said first electrical circuit and a current in said second electrical circuit.

4. The method of claim 1, wherein, in the event of a transient grid fault, the frequency of the pulsewidth modulation is decreased in response to an increase of the current.

5. The method of claim 4, wherein the decrease of the frequency of the pulsewidth modulation with the increase of the current is monotonic or strictly monotonic, at least in some ranges.

6. The method of claim 4, wherein the frequency of the pulsewidth modulation decreases abruptly when the current exceeds a predetermined limit.

7. The method of claim 1, wherein the transient grid fault is detected when a voltage drop in the electrical grid is present.

8. The method of claim 1, wherein the transient grid fault is present for a time of between milliseconds and seconds.

9. The method of claim 1, wherein the transient grid fault is present for less than 10 seconds.

10. A wind turbine for operating in association with an electrical grid wherein a transient grid fault can occur, the wind turbine comprising: a speed-variable drive system connectable to said electrical grid; said speed-variable drive system including an electric machine and a pulsewidth modulation-controlled converter; a first electrical circuit connecting said electrical machine to said pulsewidth modulation-controlled converter; a second electrical circuit connecting said pulsewidth modulation-controlled converter to said electrical grid; said pulsewidth modulation-controlled converter including a controller; said controller being configured to detect the transient grid fault and to control said pulsewidth modulation-controlled converter via pulsewidth modulation; and, in the event of the transient grid fault, said controller being further configured to determine a frequency of said pulsewidth modulation in response to a current in at least one of said first and second electrical circuits.

11. The wind turbine of claim 10, wherein: said electric machine is a double-fed induction generator having a rotor; said pulsewidth modulation-controlled converter includes a rotor-side inverter connected to said rotor; a grid-side inverter connected to said electrical grid; and, a DC link that connects said rotor-side inverter to said grid-side inverter; and, said controller is further configured, in the event of the transient grid fault, to control the frequency of said pulsewidth modulation of at least one of said rotor-side inverter and said grid-side inverter in response to said current.

12. The wind turbine of claim 11, wherein said current is at least one of a current in one or more phases in said first circuit and a current in one or more phases of said second circuit.

13. The wind turbine of claim 10, wherein said controller is configured to, in the event of the transient grid fault, decrease the frequency of said pulsewidth modulation.

14. The wind turbine of claim 13, wherein said controller is configured to decrease the frequency of the pulsewidth modulation with the increase of the current in a monotonic or strictly monotonic way, at least in some ranges.

15. The wind turbine of claim 13, wherein the controller is configured to decrease the frequency of the pulsewidth modulation abruptly when the current exceeds a predetermined limit.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

[0020] The invention will now be described with reference to the drawings wherein:

[0021] FIG. 1 is a schematic of a wind turbine;

[0022] FIG. 2 is a simplified representation of a current-controlled pulsewidth modulation; and,

[0023] FIGS. 3A and 3B show two characteristic curves for the frequency of the pulsewidth modulation as a function of the current.

DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0024] FIG. 1 shows a schematic view of a wind turbine 10. The rotor 12 of the wind turbine 10 takes up a torque from the wind and transfers this torque via the drive train 14, which may comprise a gearbox, to the rotor 16 of the generator 15. The generator 15 of FIG. 1 is configured to convert the kinetic energy taken up by the rotor 12 into electrical energy and to feed this into a three-phase electrical grid 22. The stator 18 of the generator 15 is connected to the three-phase electrical grid 22 via a three-phase connection 20 and a transformer 21. The rotor 16 of the generator 15 is connected to the converter 26 via a three-phase connection 24. The grid side of the converter 26 is connected to the three-phase connection 20 and to the electrical grid 22 via a three-phase connection 28. For a better overview, only one line is shown for each three-phase electrical connection.

[0025] The converter 26 comprises a rotor-side inverter 30 and a grid-side inverter 32. Both are connected by a DC link 34. The converter 26 has a controller 27 configured to control the operation of the inverters 30, 32 depending on various input variables 58, 60, 62, 64, 70 present at the controller 27 and parameters and/or characteristic curves stored in the controller 27. The controller 27 is configured to control the converter 26 in accordance with the method of the present disclosure. For illustration, FIG. 1 shows a number of elements needed to implement the method of this disclosure. These elements may be implemented as software modules of a control software or as separate devices, which are configured to follow the steps of the method.

[0026] For better overview, a controller that controls the operation of the wind turbine is not shown. However, it is conceivable that parts of the method of this disclosure are implemented in such a controller and that, by way of example, a set point value for an electrical variable in dependence on the grid voltage is determined by such a controller. It is also conceivable to implement the method of this disclosure in whole or in part by analogue means.

[0027] The inverters 30, 32 are controlled by current controllers 40, 42 and pulsewidth modulators 36, 38. More specifically, the current controller 40 controls the pulsewidth modulator 36, which provides the pulsewidth modulation for the rotor-side inverter 30, and the current controller 42 controls the pulsewidth modulator 38, which provides the pulsewidth modulation for the grid-side inverter 32. Set point values 43, 46 and actual values 63, 65 for controlling the rotor-side inverter 30 and the grid-side inverter 32 are present at the current controllers 40, 42. The set point values 43, 46 are determined by a set point module 44. Measured values 62, 64 for the currents on the rotor side and on the grid side may also be present at the current controllers 40, 42, as shown in FIG. 1.

[0028] Measured voltages 58 and measured currents 60 from the three-phase connection 20 to the grid 22 are present at the controller 27. Furthermore, the measured currents 62 measured in the three-phase connection circuit 24 between the rotor 16 of the generator 15 and the rotor-side inverter 30 and the measured currents 64 measured in the three-phase connection circuit 28 of the grid-side inverter 32 are present as input quantities at the converter controller 27. The currents 62 measured in the three-phase connection 20 of the rotor-side inverter 30 to the rotor 16 may also be present at the current controller 40 that controls the pulsewidth modulator 36 and thus the rotor-side inverter 30. Accordingly, the currents 64 measured in the three-phase connection 28 of the grid-side inverter 32 may also be present at the current controller 42 that controls the pulsewidth modulator 38 and thus the grid-side inverter 32. This way it is possible to control the frequency of the pulsewidth modulation depending on the currents as it is explained below, referring to FIGS. 2, 3A, and 3B.

[0029] The plural used for the measured quantities 58, 60, 62, 64 is due to the fact that they are measured and processed in a multi-phase system. For example, in case of the measured voltage 58 there are voltage measurements for all three phases of the three-phase connection 20 present at the controller 27. Alternatively, for a three-phase system, without a neutral conductor, there may be only two measurements from two phases and the value of the third phase may be calculated.

[0030] The input quantities 58, 60, 62, 64 present at the converter controller 27 are measured by suitable sensors that capture the relevant quantities at the three-phase connections 20, 24, 28 and forward them to the controller 27 as input values. Dots represent these sensors in FIG. 1. The sensors may preferably be contactless. Apart from the measurements shown in FIG. 1, there may be other measurements that allow conclusions to be drawn about the input quantities. It is also conceivable that input quantities are obtained by estimation or other ways of observation. Other input quantities 70 may be present at the controller 27.

[0031] Usually the controller 27 has a transformation module 56, which is configured to transform the three-phase input quantities 58, 60, 62, 64 into a positive sequence system and a negative sequence system. The transformation module 56 therefore provides actual values 52, 54, 63, 65 for the voltages and currents in the positive and negative sequence systems to the set point module 44 and to the current controllers 40, 42. The set point module 44 is configured to provide set point values 43, 46 to the current controllers 40, 42. For example, the set point module 44 may have a characteristic curve 48, which it may use to determine a set point for a reactive current to be fed into the grid based on an actual voltage in the negative sequence system. The set point module 44 and/or the current controllers 40, 42 may further be configured to detect a grid fault based on the actual values of the grid voltage. For example, an asymmetric grid fault is detected from the voltage in the negative sequence system.

[0032] FIG. 2 shows a simplified presentation of a current-controlled pulsewidth modulation implemented in the current controller 40, 42 and the pulsewidth modulator 36, 38. An actual current 71 is present at the adaptation function 75. Using a characteristic curve as explained below with reference to FIGS. 3A and 3B a set point value for the frequency 72 of the pulse-with modulation is determined. This is applied to the carrier generator 76, which is configured to generate a carrier with the set frequency 73. The pulsewidth modulator 77 is configured to generate a control signal 74 that is applied to the respective inverter 30, 32 in order to actuate the electronic semiconductor switches. This sequence basically applies for both the rotor-side inverter 30 and the grid-side inverter 32; however, there may be differences in the actual implementation, such as different characteristic curves for the adaptation function 75.

[0033] FIGS. 3A and 3B show two examples for characteristic curves of how the set point value for the frequency 72 depends on the actual current 71. The characteristic curve of FIG. 3A has a discontinuous shape, comprising a constant range 80, a linear range 82 between a first threshold 78 and a second boundary 79 and a second constant range beyond the threshold 79. As the current 71 exceeds the first threshold 78 during a grid fault, the set point value for the frequency 72 of the pulsewidth modulation is decreased in order to avoid a thermal overload on the electronic semiconductor switches of the converter 26. Beyond the second threshold 79, the semiconductor switches operate at a constant, but much lower frequency 72 than in normal operation.

[0034] The characteristic curve of FIG. 3B has a continuous shape 83, such that the frequency 72 gradually decreases with an increasing current 71. The middle section of the curve has a steeper decrease, leading to a corresponding reduction of the load on the semiconductor switches mainly in this section.

[0035] It is understood that the foregoing description is that of the preferred embodiments of the invention and that various changes and modifications may be made thereto without departing from the spirit and scope of the invention as defined in the appended claims.

LIST OF REFERENCE NUMERALS

[0036] 10 Wind turbine

[0037] 12 Rotor

[0038] 14 Drive train

[0039] 15 Generator

[0040] 16 Generator rotor

[0041] 18 Generator stator

[0042] 20 Three-phase connection

[0043] 21 Transformer

[0044] 22 Electrical grid

[0045] 24 Three-phase connection

[0046] 26 Converter

[0047] 27 Controller

[0048] 28 Three-phase connection

[0049] 30 Rotor-side inverter

[0050] 32 Grid-side inverter

[0051] 34 DC link

[0052] 36 Pulsewidth modulator

[0053] 38 Pulsewidth modulator

[0054] 40 Current controller

[0055] 42 Current controller

[0056] 43 Set point value

[0057] 44 Set point module

[0058] 46 Set point value

[0059] 48 Characteristic curve

[0060] 52 Actual values (in the positive sequence system)

[0061] 54 Actual values (in the negative sequence system)

[0062] 56 Transformation module

[0063] 58 Measured voltage

[0064] 60 Measured current

[0065] 62 Measured value

[0066] 63 Actual values

[0067] 64 Measured value

[0068] 65 Actual values

[0069] 70 Input quantities

[0070] 71 Current

[0071] 72 Set point value for frequency

[0072] 73 Carrier with set frequency

[0073] 74 Control signal

[0074] 75 Adaptation function

[0075] 76 Carrier generator

[0076] 77 Pulsewidth modulator

[0077] 78 Threshold

[0078] 79 Threshold

[0079] 80 Constant range

[0080] 81 Constant range

[0081] 82 Linear range

[0082] 83 Continuous curve