CN113410862A - Commutation failure prevention control method considering multi-feed-in direct current coupling effect - Google Patents

Commutation failure prevention control method considering multi-feed-in direct current coupling effect Download PDF

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CN113410862A
CN113410862A CN202110671591.5A CN202110671591A CN113410862A CN 113410862 A CN113410862 A CN 113410862A CN 202110671591 A CN202110671591 A CN 202110671591A CN 113410862 A CN113410862 A CN 113410862A
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direct current
station
target
voltage
adjacent
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CN113410862B (en
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韩伟
肖超
欧阳金鑫
刘超
王默
刘磊
刘尧
宋闯
段文岩
叶俊君
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Chongqing University
Electric Power Research Institute of State Grid Henan Electric Power Co Ltd
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Electric Power Research Institute of State Grid Henan Electric Power Co Ltd
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    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/36—Arrangements for transfer of electric power between ac networks via a high-tension dc link
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
    • H02J2203/10—Power transmission or distribution systems management focussing at grid-level, e.g. load flow analysis, node profile computation, meshed network optimisation, active network management or spinning reserve management
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
    • H02J2203/20—Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/60—Arrangements for transfer of electric power between AC networks or generators via a high voltage DC link [HVCD]

Abstract

The invention discloses a commutation failure prevention control method considering multi-feed-in direct current coupling effect, which comprises the following steps: calculating a phase change failure critical voltage of a target direct current inverter station, and calculating a phase change failure critical voltage of an adjacent direct current inverter station which is reduced to the target direct current inverter station; and different trigger angle regulating quantities are adopted in the inverter controller to implement control by comparing the measured value of the converter bus voltage of the target direct-current inverter station with the critical voltage of phase change failure. Compared with a conventional commutation failure prevention control method, the method considers the coupling relation of multi-feed-in direct current and the influence of a controller, provides a trigger angle regulating quantity calculation method for avoiding adjacent direct current inverter stations from commutation failure caused by commutation failure of a target direct current inverter station, can perform coordination control on commutation failure of a multi-feed-in direct current system, and reduces the risk of simultaneous or secondary commutation failure of the multi-feed-in direct current system.

Description

Commutation failure prevention control method considering multi-feed-in direct current coupling effect
Technical Field
The invention relates to the field of protection and control of power systems, in particular to a commutation failure prevention control method considering multi-feed-in direct current coupling effect.
Background
With the implementation of energy strategies of 'west-east power transmission' and 'national networking', high-voltage direct-current transmission (LCC-HVDC) of a power grid commutation converter is widely applied to the field of long-distance high-power transmission, and a typical multi-direct-current feed-in power grid pattern is formed by east China power grids and south China power grids. The commutation failure is a common fault in the running process of a direct current transmission system, and in the single-circuit LCC-HVDC commutation failure and the recovery process thereof, the falling of the turn-off angle and the alternating current bus voltage triggers the starting of control systems such as a low-voltage current limiting control (VDCOL) and a fixed turn-off angle controller of the LCC-HVDC to promote the commutation recovery. The subsequent start-up of the LCC-HVDC control system will further exacerbate the variation of the electrical quantity. Therefore, LCC-HVDC with commutation failure affects adjacent normally-operated LCC-HVDC by electromagnetic coupling, which causes secondary response of normally-operated LCC-HVDC and short-time large transient drop of direct current transmission power, and affects stable operation of the system. It can be seen that the electrical coupling between the converter stations is an important factor in influencing whether multiple direct currents will cause phase commutation failures simultaneously or successively. The existing research mainly focuses on optimizing controller parameters to improve the sensitivity and rapidity of the controller, reduce the probability of phase commutation failure of a direct current system in the recovery process, and do not fully consider the influence of the coupling effect between multi-feed-in direct current systems. Therefore, the problem to be solved by the present invention is how to effectively suppress the phase commutation failure of a target dc and adjacent dc in a multi-fed dc system, i.e. to avoid the phase commutation failure of multiple dc loops occurring simultaneously or sequentially.
Disclosure of Invention
To solve the deficiencies of the prior art, an object of the present invention is to provide a commutation failure prevention control method considering multi-feed dc coupling.
The invention adopts the following technical scheme:
a commutation failure prevention control method considering multi-feed direct current coupling effect comprises the following steps:
step S1: collecting converter bus voltage U of target DC inversion station in real timeLiAnd calculating voltage data;
step S2: collecting the voltage U of the converter bus of the target direct current inverter station according to the step S1LiCalculating a first critical trigger advance angle beta required for avoiding the phase change failure of the target direct current inverter station caused by the voltage drop of a current conversion bus of the target direct current inverter station1；
Step S3: collecting the voltage U of the converter bus of the target direct current inverter station according to the step S1LiCalculating a second critical trigger lead angle beta required for avoiding the phase change failure of the target DC inverter station from causing the phase change failure of the adjacent DC inverter stations2；
Step S4: converting bus voltage U of target DC inverter stationLiAnd the voltage U of a current conversion bus of the adjacent direct current inversion stationLjRespectively exchange phase failure critical voltage U with target DC inverter stationthiAnd the adjacent direct current inverter station commutation failure critical voltage U which is reduced to the target direct current inverter stationthjComparing; if U isLi＞UthiAnd U isLj＞UthjThen the method is ended; if U isLi≤UthiAnd U isLj≥UthjStep S5 is performed; if U isLi＜UthiAnd U isLj＜UthjStep S6 is performed;
step S5: comparing the first critical trigger advance angle beta1And a second critical trigger advance angle beta2Size, if beta1＞β2Step S6 is performed, otherwise step S7 is performed;
step S6: using a first threshold trigger advance angle beta1Calculating the firing angle adjustment Delta alpha1And will be alpha0-Δα1Setting a first trigger angle control reference value of a target direct current inverter station;
step S7: using a second threshold trigger advance angle beta2Calculating the firing angle adjustment Delta alpha2And will be alpha0-Δα2And setting a second trigger angle control reference value of the target direct current inverter station.
In step S1, the calculated voltage data includes a target dc inverter station commutation failure threshold voltage UthiAnd the adjacent direct current inverter station commutation failure critical voltage U which is reduced to the target direct current inverter stationthjAdjacent DC inversion station current conversion bus voltage ULj。
Phase-change failure critical voltage U of target direct-current inverter stationthiSatisfies the following relation:
Figure BDA0003118973080000021
in the formula (I), the compound is shown in the specification,
Uithe effective value of the converter bus voltage under the steady-state operation of the target direct-current inverter station is obtained,
γiis the turn-off angle of the target direct current inversion station,
γminthe critical turn-off angle of the direct current inversion station is generally 7 degrees,
βithe trigger advance angle of the target direct current inversion station is shown.
Reckoning to eyesAdjacent direct current inversion station conversion bus voltage U of standard direct current inversion stationLjSatisfies the following relation:
Figure BDA0003118973080000031
in the formula (I), the compound is shown in the specification,
ULNithe rated value of the voltage of the converter bus of the target direct current inverter station,
ULNjfor the rated value of the voltage of the converter bus of the adjacent direct current inversion station,
ULithe collected voltage of the current conversion bus of the target direct current inverter station is obtained.
MIIFijFor the multi-feed interaction factor, the calculation method is shown by the following relation:
Figure BDA0003118973080000032
in the formula (I), the compound is shown in the specification,
ΔUithe voltage variation when the alternating current fault occurs at the converter bus of the target direct current inverter station is shown,
ΔUjthe variation of the voltage of the current conversion bus of the adjacent direct current inversion station when the alternating current fault occurs at the current conversion bus of the target direct current inversion station is shown,
Zijis the mutual impedance between a target DC inversion station and an adjacent DC inversion station in the node impedance matrix,
Zjjthe self-impedance of the adjacent direct current inversion station in the node impedance matrix.
Phase change failure critical voltage U of adjacent direct current inversion stationsthjSatisfies the following relation:
Figure BDA0003118973080000033
in the formula (I), the compound is shown in the specification,
Ujthe effective value of the converter bus voltage under the steady state operation of the adjacent direct current inversion station,
γjis the turn-off angle of the adjacent direct current inversion station,
βjthe trigger advance angle of the adjacent direct current inversion station is obtained.
In step S2, the first threshold trigger advance angle β1Satisfies the following relation:
Figure BDA0003118973080000034
in the formula (I), the compound is shown in the specification,
ULfifor the voltage U of the converter bus of the target DC inverter stationLiAfter falling, the effective value of the voltage of the valve side line of the target direct current inversion station,
α0the trigger angle of the target DC inversion station before the voltage of the converter bus drops,
γ0the current conversion bus voltage is the turn-off angle of the target direct current inversion station before the voltage of the current conversion bus drops.
Step S3 includes the following:
step S301: calculating the variation delta U of the voltage of the adjacent direct current conversion bus after the phase conversion failure of the target direct current inversion station according to the following relational expressionLjcComprises the following steps:
Figure BDA0003118973080000041
in the formula (I), the compound is shown in the specification,
ULfjfor adjacent DC inversion station change of current busbar voltage ULjAfter falling, the effective value of the voltage of the valve side line of the adjacent direct current inversion station,
γ′jand the turn-off angle value of the adjacent direct current inversion station after the alternating current fault occurs.
Step S302: the variation delta U of the adjacent direct current conversion bus voltage obtained in the step S301LjcThe total amount of reactive power Δ Q supplied by adjacent direct currents is calculated in the following relationexj；
Figure BDA0003118973080000042
In the formula (I), the compound is shown in the specification,
Sacjand feeding short-circuit capacity of the receiving end alternating current system into adjacent direct current inversion stations.
Step S303: according to the reactive power consumption Q of the target DC inverter stationIi-thThe maximum advance trigger angle allowed by the target direct-current transmission line under the condition of avoiding the phase change failure of the target direct-current inverter station to cause the phase change failure of the adjacent direct-current inverter station is calculated and used as a second critical trigger advance angle beta2；
Reactive power consumption Q of target direct current inverter stationIi-thThe constraint relationship satisfies the following relation:
Figure BDA0003118973080000043
in the formula (I), the compound is shown in the specification,
Bfithe equivalent susceptance of the filter of the target DC inversion station is obtained,
Sacithe short-circuit capacity of the receiving end alternating current system is fed into the target direct current inverter station,
Qacithe reactive exchange quantity of the target direct current inversion station and the alternating current system is obtained.
In step S303, under the condition of avoiding the phase change failure of the adjacent dc inverter station caused by the phase change failure of the target dc inverter station, the maximum advance trigger angle allowed by the target dc transmission line, that is, the second critical trigger advance angle β, is calculated2Second critical trigger advance angle β2Satisfies the following relation:
Figure BDA0003118973080000051
in the formula (I), the compound is shown in the specification,
Pdfor the active power of the target dc transmission,
mu is the commutation angle of the target DC inversion station.
In step S6, a first firing angle adjustmentQuantity Δ α1Calculated from the following formula:
Δα1＝α0-(π-β1)
in the formula, beta1Is the first critical trigger advance angle.
In step S7, the second firing angle adjustment amount Δ α2The calculation method of (2) is as follows:
Δα2＝α0-(π-β2)
in the formula, beta2Is the second critical trigger advance angle.
Compared with the prior art, the invention has the following beneficial effects:
1. compared with the method for judging the commutation failure in the prior art, the method takes the coupling effect among different direct currents in the multi-feed-in direct current transmission system into consideration, calculates the commutation bus voltage of adjacent direct current inverter stations based on the multi-feed-in interaction factors, and can accurately judge whether the target direct current inverter station and the adjacent direct current inverter stations have commutation failure.
2. Different from a commutation failure suppression strategy in the prior art, the method considers the influence of fixed turn-off angle control and low-voltage current-limiting control on adjacent direct-current lines in the multi-feed-in direct-current power transmission system, provides a trigger angle regulating quantity calculation method for avoiding the commutation failure of adjacent direct-current inverter stations caused by the commutation failure of a target direct-current inverter station, and can provide a basis and a reference for the commutation failure suppression strategy of the multi-feed-in direct-current power transmission system.
3. Compared with the prior art that a single control strategy is adopted by a multi-feed-in direct-current power transmission system, the method provided by the invention considers the difference among different direct-current systems, adopts different trigger angle regulating quantities to implement control, fills the blank of suppressing multi-circuit direct-current commutation failure in the multi-feed-in direct-current power transmission system, and can be used for avoiding the problem of large-area safe and stable operation of an alternating-current and direct-current system caused by commutation failure.
Drawings
Fig. 1 is a flowchart of a commutation failure prevention control method for a multi-feed dc power transmission system according to the present invention;
fig. 2 is a wiring diagram of a multi-feed dc system in accordance with the present invention, which considers the phase commutation failure prevention control method of the multi-feed dc power transmission system;
fig. 3 is a diagram illustrating the comparison effect of the reactive power exchange amount in the commutation failure prevention control method of the multi-feed dc power transmission system according to the present invention;
fig. 4 is a diagram illustrating the comparison effect of the turn-off angles of adjacent dc inversion stations in the method for preventing and controlling the commutation failure of the multi-feed-in dc power transmission system according to the present invention.
Detailed Description
The present application is further described below with reference to the accompanying drawings. The following examples are only for illustrating the technical solutions of the present invention more clearly, and the protection scope of the present application is not limited thereby.
The invention discloses a commutation failure prevention control method considering multi-feed-in direct current coupling effect, which comprises the following steps:
step S1: collecting converter bus voltage U of target DC inversion station in real timeLiAnd calculating voltage data;
the calculated voltage data comprises a target direct current inversion station commutation failure critical voltage UthiAnd the adjacent direct current inverter station commutation failure critical voltage U which is reduced to the target direct current inverter stationthjAdjacent DC inversion station current conversion bus voltage ULj。
Phase-change failure critical voltage U of target direct-current inverter stationthiThe calculation method comprises the following steps:
Figure BDA0003118973080000061
in the formula (I), the compound is shown in the specification,
Uithe effective value of the converter bus voltage under the steady-state operation of the target direct-current inverter station is obtained,
γiis the turn-off angle of the target direct current inversion station,
γminthe critical turn-off angle of the direct current inversion station is generally 7 degrees,
βithe trigger advance angle of the target direct current inversion station is shown.
Reduce to the targetAdjacent direct current inversion station conversion bus voltage U of current inversion stationLjSatisfies the following relation:
Figure BDA0003118973080000071
in the formula (I), the compound is shown in the specification,
ULNithe rated value of the voltage of the converter bus of the target direct current inverter station,
ULNjfor the rated value of the voltage of the converter bus of the adjacent direct current inversion station,
ULicollecting the voltage of a converter bus of a target direct current inverter station;
MIIFijfor the multi-feed interaction factor, the calculation method is shown by the following relation:
Figure BDA0003118973080000072
in the formula (I), the compound is shown in the specification,
ΔUithe voltage variation when the alternating current fault occurs at the converter bus of the target direct current inverter station is shown,
ΔUjthe variation of the voltage of the current conversion bus of the adjacent direct current inversion station when the alternating current fault occurs at the current conversion bus of the target direct current inversion station is shown,
Zijis the mutual impedance between a target DC inversion station and an adjacent DC inversion station in the node impedance matrix,
Zjjthe self-impedance of the adjacent direct current inversion station in the node impedance matrix.
Phase change failure critical voltage U of adjacent direct current inversion stationsthjSatisfies the following relation:
Figure BDA0003118973080000073
in the formula (I), the compound is shown in the specification,
Ujthe effective value of the converter bus voltage under the steady state operation of the adjacent direct current inversion station,
γjis the turn-off angle of the adjacent direct current inversion station,
βjthe trigger advance angle of the adjacent direct current inversion station is obtained.
Step S2: collecting the voltage U of the converter bus of the target direct current inverter station according to the step S1LiCalculating a first critical trigger advance angle beta required for avoiding the phase change failure of the target direct current inverter station caused by the voltage drop of a current conversion bus of the target direct current inverter station1；
First critical trigger advance angle beta1Satisfies the following relation:
Figure BDA0003118973080000081
in the formula (I), the compound is shown in the specification,
ULfifor the voltage U of the converter bus of the target DC inverter stationLiAfter falling, the effective value of the voltage of the valve side line of the target direct current inversion station,
α0the trigger angle of the target DC inversion station before the voltage of the converter bus drops,
γ0the current conversion bus voltage is the turn-off angle of the target direct current inversion station before the voltage of the current conversion bus drops.
Step S3 includes: according to the converter bus voltage U of the target direct current inverter station collected in the step S1LiCalculating a second critical trigger lead angle beta required for avoiding the phase change failure of the target DC inverter station from causing the phase change failure of the adjacent DC inverter stations2。
Step S301: calculating the variation delta U of the voltage of the adjacent direct current conversion bus after the phase conversion failure of the target direct current inversion station according to the following relational expressionLjcComprises the following steps:
Figure BDA0003118973080000082
in the formula (I), the compound is shown in the specification,
ULfjfor adjacent DC inversion station change of current busbar voltage ULjEffective value of voltage of valve side line of adjacent direct current inversion station after falling，γ′jAnd the turn-off angle value of the adjacent direct current inversion station after the alternating current fault occurs.
Step S302: the variation delta U of the adjacent direct current conversion bus voltage obtained in the step S301LjcThe total amount of reactive power Δ Q supplied by adjacent direct currents is calculated in the following relationexj；
Figure BDA0003118973080000083
In the formula (I), the compound is shown in the specification,
Sacjand feeding short-circuit capacity of the receiving end alternating current system into adjacent direct current inversion stations.
Step S303: according to the reactive power consumption Q of the target DC inverter stationIi-thThe maximum advance trigger angle allowed by the target direct-current transmission line under the condition of avoiding the phase change failure of the target direct-current inverter station to cause the phase change failure of the adjacent direct-current inverter station is calculated and used as a second critical trigger advance angle beta2；
Reactive power consumption Q of target direct current inverter stationIi-thThe constraint relationship satisfies the following relation:
Figure BDA0003118973080000091
in the formula (I), the compound is shown in the specification,
Bfiequivalent susceptance, S, of a filter of a target DC inverter stationaciThe short-circuit capacity of the receiving end alternating current system is fed into the target direct current inverter station,
Qacithe reactive exchange quantity of the target direct current inversion station and the alternating current system is obtained.
Under the condition of avoiding the phase change failure of the target direct current inversion station to cause the phase change failure of the adjacent direct current inversion station, calculating the maximum advance trigger angle allowed by the target direct current transmission line, namely a second critical trigger advance angle beta2，β2The following relation is satisfied:
Figure BDA0003118973080000092
in the formula (I), the compound is shown in the specification,
Pdfor the active power of the target dc transmission,
mu is the commutation angle of the target DC inversion station.
Step S4: converting bus voltage U of target DC inversion stationLiAnd the voltage U of a current conversion bus of the adjacent direct current inversion stationLjRespectively associated with its phase change failure threshold voltage UthiAnd UthjMaking a comparison if ULi＞UthiAnd U isLj＞UthjThen the method is ended; if U isLi≤UthiAnd U isLj≥UthjStep S5 is performed; if U isLi＜UthiAnd U isLj＜UthjStep S6 is performed.
Step S5: comparing the first critical trigger advance angle beta1And a second critical trigger advance angle beta2If β is1＞β2Step S6 is performed, otherwise step S7 is performed;
step S6: using a first threshold trigger advance angle beta1Calculating the firing angle adjustment Delta alpha1And will be alpha0-Δα1Setting a first trigger angle control reference value of a target direct current inverter station so as to implement control;
if U isLi＜UthiAnd U isLj＜UthjAnd beta is1＞β2Using a critical trigger advance angle beta required to avoid commutation failure of the target DC inverter station1Calculating the firing angle adjustment Delta alpha1And will be alpha0-Δα1And setting the trigger angle control reference value of the target direct current inverter station so as to implement control.
First firing Angle adjustment Δ α1Calculated from the following formula:
Δα1＝α0-(π-β1)
in the formula, beta1Is the first critical trigger advance angle.
Step S7: using a second threshold trigger advance angle beta2ComputingFiring angle adjustment Δ α2And will be alpha0-Δα2And setting the trigger angle control reference value of the target direct current inverter station so as to implement control.
Firing angle adjustment Δ α2The calculation method of (2) is as follows:
Δα2＝α0-(π-β2)
in the formula, beta2Is the second critical trigger advance angle.
Table 1 shows all the parameters in the present invention and their corresponding meanings.
Table 1: the very corresponding meaning of a parameter
Figure BDA0003118973080000101
Figure BDA0003118973080000111
Figure BDA0003118973080000121
According to the invention, through comparison of the effective value of the alternating-current bus voltage of the target direct-current inverter station and the phase-change failure critical voltage, different trigger angle regulating quantities are output according to different voltage drop values, so that control is implemented. The invention considers the coupling relation of multi-feed-in direct current and the influence of a controller, provides a calculation method aiming at different trigger angle regulating quantities of target and adjacent direct current commutation failures, and has important significance for inhibiting commutation failures of a multi-feed-in direct current power transmission system.
To verify the effectiveness of the method of the present invention, the multi-feed dc system wiring diagram shown in fig. 2 is taken as an example for analysis and calculation. LCC-HVDC in fig. 2 represents the grid commutated converter high voltage direct current transmission. And each loop of direct current transmission system adopts a CIGRE high-voltage direct current standard test model, the rated direct current voltage is 500kV, and the rated capacity is 1000 MW. Taking the three-phase short-circuit fault at the alternating current bus M of the inverter station as an example, the effectiveness of the phase change failure prevention control method of the multi-feed direct current transmission system is verified.
Fig. 3 and fig. 4 are a comparison effect graph of the commutation failure prevention control reactive power exchange amount of the multi-feed-in dc power transmission system and a comparison effect graph of the turn-off angle of the adjacent dc inversion station after the method provided by the present invention is adopted. And 1s, setting a three-phase short-circuit fault at a target direct current system current conversion bus M, wherein the fault duration is 0.5 s. In both figures, the dashed line indicates the use of the conventional control method and the solid line indicates the use of the control method herein. The calculation example shows that the method can reduce the reactive power exchange amount between different direct currents in the multi-feed direct current system, avoid the phase commutation failure of adjacent direct current inverter stations caused by the phase commutation failure of a target direct current inverter station, provide reference basis for a phase commutation failure suppression strategy of the multi-feed direct current transmission system, and improve the safety of the system.
The present applicant has described and illustrated embodiments of the present invention in detail with reference to the accompanying drawings, but it should be understood by those skilled in the art that the above embodiments are merely preferred embodiments of the present invention, and the detailed description is only for the purpose of helping the reader to better understand the spirit of the present invention, and not for limiting the scope of the present invention, and on the contrary, any improvement or modification made based on the spirit of the present invention should fall within the scope of the present invention.

Claims (10)

1. A commutation failure prevention control method considering multi-feed direct current coupling effect is characterized by comprising the following steps:
step S1: collecting converter bus voltage U of target DC inversion station in real timeLiAnd calculating voltage data;
step S2: collecting the voltage U of the converter bus of the target direct current inverter station according to the step S1LiCalculating a first critical trigger advance angle beta required for avoiding the phase change failure of the target direct current inverter station caused by the voltage drop of a current conversion bus of the target direct current inverter station1；
Step S3: collecting the voltage U of the converter bus of the target direct current inverter station according to the step S1LiCalculating a second critical trigger lead angle beta required for avoiding the phase change failure of the target DC inverter station from causing the phase change failure of the adjacent DC inverter stations2；
Step S4: converting bus voltage U of target DC inverter stationLiAnd the voltage U of a current conversion bus of the adjacent direct current inversion stationLjRespectively exchange phase failure critical voltage U with target DC inverter stationthiAnd the adjacent direct current inverter station commutation failure critical voltage U which is reduced to the target direct current inverter stationthjComparing; if U isLi＞UthiAnd U isLj＞UthjThen the method is ended; if U isLi≤UthiAnd U isLj≥UthjStep S5 is performed; if U isLi＜UthiAnd U isLj＜UthjStep S6 is performed;
step S5: comparing the first critical trigger advance angle beta1And a second critical trigger advance angle beta2Size, if beta1＞β2Step S6 is performed, otherwise step S7 is performed;
step S6: using a first threshold trigger advance angle beta1Calculating the firing angle adjustment Delta alpha1And will be alpha0-Δα1Setting a first trigger angle control reference value of a target direct current inverter station;
step S7: using a second threshold trigger advance angle beta2Calculating the firing angle adjustment Delta alpha2And will be alpha0-Δα2And setting a second trigger angle control reference value of the target direct current inverter station.
2. The commutation failure prevention and control method according to claim 1, wherein:
in the step S1, the calculated voltage data includes a target dc inverter station commutation failure critical voltage UthiAnd the adjacent direct current inverter station commutation failure critical voltage U which is reduced to the target direct current inverter stationthjAdjacent DC inversion station current conversion bus voltage ULj。
3. The commutation failure prevention and control method according to claim 2, wherein:
the target DC inverter station commutation failure critical voltage UthiSatisfies the following relation:
Figure FDA0003118973070000021
in the formula (I), the compound is shown in the specification,
Uithe effective value of the converter bus voltage under the steady-state operation of the target direct-current inverter station is obtained,
γiis the turn-off angle of the target direct current inversion station,
γminthe critical turn-off angle of the direct current inversion station is generally 7 degrees,
βithe trigger advance angle of the target direct current inversion station is shown.
4. The commutation failure prevention control method according to claim 3, wherein:
converting bus voltage U of adjacent direct current inverter station converted to target direct current inverter stationLjSatisfies the following relation:
Figure FDA0003118973070000022
in the formula (I), the compound is shown in the specification,
ULNithe rated value of the voltage of the converter bus of the target direct current inverter station,
ULNjfor the rated value of the voltage of the converter bus of the adjacent direct current inversion station,
ULifor collecting the voltage of the converter bus of the target direct current inversion station,
MIIFijfor the multi-feed interaction factor, the calculation method is shown by the following relation:
Figure FDA0003118973070000023
in the formula (I), the compound is shown in the specification,
ΔUithe voltage variation when the alternating current fault occurs at the converter bus of the target direct current inverter station is shown,
ΔUjthe variation of the voltage of the current conversion bus of the adjacent direct current inversion station when the alternating current fault occurs at the current conversion bus of the target direct current inversion station is shown,
Zijis the mutual impedance between a target DC inversion station and an adjacent DC inversion station in the node impedance matrix,
Zjjis the self-impedance of the adjacent DC inversion station in the node impedance matrix,
the phase change failure critical voltage U of the adjacent DC inversion stationthjSatisfies the following relation:
Figure FDA0003118973070000031
in the formula (I), the compound is shown in the specification,
Ujthe effective value of the converter bus voltage under the steady state operation of the adjacent direct current inversion station,
γjis the turn-off angle of the adjacent direct current inversion station,
βjthe trigger advance angle of the adjacent direct current inversion station is obtained.
5. The commutation failure prevention and control method according to claim 4, wherein:
in said step S2, the first threshold trigger advance angle β1Satisfies the following relation:
Figure FDA0003118973070000032
in the formula (I), the compound is shown in the specification,
ULfifor the voltage U of the converter bus of the target DC inverter stationLiAfter falling, the voltage of the valve side line of the target direct current inversion stationThe effective value of (a) of (b),
α0the trigger angle of the target DC inversion station before the voltage of the converter bus drops,
γ0the current conversion bus voltage is the turn-off angle of the target direct current inversion station before the voltage of the current conversion bus drops.
6. The commutation failure prevention and control method according to claim 5, wherein:
the step S3 includes the following:
step S301: calculating the variation delta U of the voltage of the adjacent direct current conversion bus after the phase conversion failure of the target direct current inversion station according to the following relational expressionLjcComprises the following steps:
Figure FDA0003118973070000033
in the formula (I), the compound is shown in the specification,
ULfjfor adjacent DC inversion station change of current busbar voltage ULjAfter falling, the effective value of the voltage of the valve side line of the adjacent direct current inversion station,
γ′jthe turn-off angle value of the adjacent direct current inversion station after the alternating current fault occurs,
step S302: the variation delta U of the adjacent direct current conversion bus voltage obtained in the step S301LjcThe total amount of reactive power Δ Q supplied by adjacent direct currents is calculated in the following relationexj；
Figure FDA0003118973070000041
In the formula (I), the compound is shown in the specification,
Sacjthe short-circuit capacity of the alternating current system at the receiving end is fed into the adjacent direct current inversion station,
step S303: according to the reactive power consumption Q of the target DC inverter stationIi-thThe constraint relation of the target direct current transmission line is calculated under the condition that the phase commutation failure of the target direct current inversion station causes the phase commutation failure of the adjacent direct current inversion stationAllowable maximum advance trigger angle as the second critical trigger advance angle beta2；
7. The commutation failure prevention and control method according to claim 6, wherein:
the reactive power consumption Q of the target direct current inverter stationIi-thThe constraint relationship satisfies the following relation:
Figure FDA0003118973070000042
in the formula (I), the compound is shown in the specification,
Bfithe equivalent susceptance of the filter of the target DC inversion station is obtained,
Sacithe short-circuit capacity of the receiving end alternating current system is fed into the target direct current inverter station,
Qacithe reactive exchange quantity of the target direct current inversion station and the alternating current system is obtained.
8. The commutation failure prevention and control method according to claim 7, wherein:
in step S303, under the condition that the phase change failure of the target dc inverter station causes the phase change failure of the adjacent dc inverter station, the maximum advance trigger angle allowed by the target dc transmission line, that is, the second critical trigger advance angle β, is calculated2Said second critical trigger advance angle β2Satisfies the following relation:
Figure FDA0003118973070000043
in the formula (I), the compound is shown in the specification,
Pdfor the active power of the target dc transmission,
mu is the commutation angle of the target DC inversion station.
9. The commutation failure prevention and control method according to claim 8, wherein:
in step S6, the first trigger angle adjustment amount Δ α1Calculated from the following formula:
Δα1＝α0-(π-β1)
in the formula, beta1Is the first critical trigger advance angle.
10. The commutation failure prevention and control method according to claim 9, wherein:
in step S7, the second trigger angle adjustment amount Δ α2The calculation method of (2) is as follows:
Δα2＝α0-(π-β2)
in the formula, beta2Is the second critical trigger advance angle.
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