CN107959303B - Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation - Google Patents

Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation Download PDF

Info

Publication number
CN107959303B
CN107959303B CN201711236861.XA CN201711236861A CN107959303B CN 107959303 B CN107959303 B CN 107959303B CN 201711236861 A CN201711236861 A CN 201711236861A CN 107959303 B CN107959303 B CN 107959303B
Authority
CN
China
Prior art keywords
converter station
voltage
transformer substation
entering
control
Prior art date
Legal status (The legal status 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 status listed.)
Expired - Fee Related
Application number
CN201711236861.XA
Other languages
Chinese (zh)
Other versions
CN107959303A (en
Inventor
赵伟
罗亚洲
汤磊
贾琳
李小江
高洵
李柱华
谭贝斯
王鹏
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
State Grid Corp of China SGCC
North China Grid Co Ltd
Beijing King Star Hi Tech System Control Co Ltd
Original Assignee
State Grid Corp of China SGCC
North China Grid Co Ltd
Beijing King Star Hi Tech System Control Co Ltd
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 State Grid Corp of China SGCC, North China Grid Co Ltd, Beijing King Star Hi Tech System Control Co Ltd filed Critical State Grid Corp of China SGCC
Priority to CN201711236861.XA priority Critical patent/CN107959303B/en
Publication of CN107959303A publication Critical patent/CN107959303A/en
Application granted granted Critical
Publication of CN107959303B publication Critical patent/CN107959303B/en
Expired - Fee Related legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • 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
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
    • H02J3/46—Controlling of the sharing of output between the generators, converters, or transformers
    • H02J3/50—Controlling the sharing of the out-of-phase component
    • 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]

Landscapes

  • Engineering & Computer Science (AREA)
  • Power Engineering (AREA)
  • Supply And Distribution Of Alternating Current (AREA)
  • Control Of Electrical Variables (AREA)

Abstract

The invention provides a reactive voltage coordination control method for an extra-high voltage direct current converter station and a near-field transformer substation, and belongs to the technical field of automatic voltage control of power systems. The method checks whether the dc converter station is in a fault condition after monopolar or bipolar blocking at the arrival of each automatic voltage control cycle: if the converter station is in a fault state, carrying out emergency control on a nearby transformer substation; and if the converter station is in a normal operation state, judging the operation trend of the converter station, and generating a corresponding control strategy for the nearby transformer substation aiming at different time periods where the active power transmission power of the converter station is located. The method realizes the coordinated control of the ultrahigh voltage and the ultrahigh voltage near-region transformer substation, avoids the repeated switching of reactive equipment in the near-region transformer substation in the process of adjusting the direct current active transmission capacity of the converter station and the frequent switching of the reactive equipment of the converter station, and improves the voltage stability and the voltage quality of a power grid.

Description

Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation
Technical Field
The invention relates to a reactive voltage coordination control method for an extra-high voltage direct current converter station and a near-field transformer substation, and belongs to the technical field of automatic voltage control of power systems.
Background
An Automatic Voltage Control (AVC) system is an important means for realizing safe (Voltage stability margin improvement), economic (network loss reduction) and high-quality (Voltage yield improvement) operation of a power transmission network. The AVC system is constructed on a power grid Energy Management System (EMS), can utilize real-time operation data of a power transmission network, scientifically decides an optimal reactive voltage regulation scheme from the perspective of global optimization of the power transmission network, and automatically issues the optimal reactive voltage regulation scheme to a power plant, a transformer substation and a subordinate power grid dispatching mechanism for execution. The architecture of automatic voltage control of a large power grid is described in "global voltage optimization control system design based on soft partitioning" (power system automation, 2003, volume 27, paragraph 8, pages 16-20) by grand son, zhenberging and guo celebration.
The main station part of the AVC system is realized in a power system control center based on software, and the voltage control strategies of the AVC system on a power transmission network mainly comprise a reactive power control strategy for each generator of a power plant and a reactive power equipment control strategy for a transformer substation, which are 2 types. The reactive power control strategy of each generator in the power plant adopts the following main modes at present: and after receiving the reactive adjustment quantity of the generator, the AVC substation of the power plant adjusts the reactive power sent by the generator in a stepping mode according to the current running state of each generator in the power plant until the adjustment quantity sent by the AVC main station is reached. The control strategy of the reactive equipment of the transformer substation is a switching instruction of the reactive compensation equipment, the reactive equipment mainly comprises a capacitor and a reactor, and when the capacitor is put into the reactive equipment or the reactor is cut off, the bus voltage is increased; when the capacitor is cut off or the reactor is put in, the bus voltage decreases. And the AVC master station issues an instruction for putting in or cutting off the reactive equipment, and an automatic monitoring system in the transformer substation finds the circuit breaker connected with the reactive equipment and switches on or off the circuit breaker according to the received instruction so as to complete the putting in or cutting off of the reactive equipment.
With the construction of ultra-high voltage (1000kV) transmission projects of power grids in China, large power grids are increasingly subjected to long-distance transmission through ultra-high voltage direct current. In recent years, a plurality of pieces of +/-800 kV direct current transmission projects are put into operation, and the active capacity of a single-circuit direct current line capable of being transmitted for a long distance exceeds 6 GW. In the extra-high voltage direct current transmission project, the operation of a converter is always accompanied with the consumption of reactive power. Under the stable operation mode, the reactive power absorbed by the rectifier station is generally 30% -50% of the direct current output power, and the reactive power absorbed by the inverter station is 40% -60% of the direct current input power. Therefore, when the converter station operates, a large amount of reactive compensation is needed to ensure normal operation. A conventional reactive compensation measure of a converter station is to provide a parallel capacitor and an ac filter. Generally, a plurality of filters and capacitors are arranged in a converter station, the reactive capacity of each filter and capacitor is 100-200 MVAR, the total configured capacity meets the requirements of the minimum and maximum direct current transmission capacity of the converter station, and the reactive exchange between the converter station and an external alternating current system is 0 as an operation target. The direct current transmission capacity of the converter station is different in different time periods of a day, the converter station operates according to a preset plan, and the reactive compensation capacity required by the converter station is different under different active transmission capacities, so that a reactive compensation automatic control system (RPC) needs to be configured in the converter station, and a filter and a capacitor are automatically switched according to the direct current transmission capacity.
The bang and the bang provide a control strategy of a relatively typical converter station RPC system in research on reactive power control and filter switching strategies of +/-660 kV converter stations (Ningxia electric power, No. 4 in 2015, page 22-25), mainly considers control strategies such as absolute minimum filter capacity limit control, reactive power switching control, maximum voltage limit, maximum reactive power limit and the like, mainly takes reactive power switching control as a main strategy under normal conditions, and the main strategy is as follows: if the reactive power exchange value of the direct current system and the alternating current system of the converter station exceeds a preset limit value, the RPC sends a command to put in or cut off a capacitor or a filter bank. Because the filter bank can not be switched frequently, a hysteresis characteristic is required to be adopted, and the reactive upper and lower limit amplitude of a hysteresis window is larger than 1/2 maximum capacitor/filter bank capacity. After the RPC system is configured, when the direct current transmission of the converter station is increased, the RPC system can automatically and sequentially put into the capacitor/filter bank, and when the direct current transmission of the converter station is decreased, the RPC system sequentially exits from the capacitor/filter bank. The control method only performs the switching of the capacitor/filter according to the transmission capacity and is not included in the automatic voltage control optimization.
With the wide application of automatic voltage control systems (AVC) in power grid dispatching centers in recent years, a large number of substations in power grids have been put into AVC automatic control, including substations in near-area power grids connected with extra-high voltage direct current converter stations (a near-area substation refers to a substation with a sensitivity greater than 0.2 to an extra-high voltage station 500kV bus). The reactive equipment in the converter station and the reactive equipment in the nearby power grid are uncoordinated in operation due to the fact that the reactive equipment in the converter station and the reactive equipment in the peripheral transformer substations are controlled by the converter station RPC system and the AVC system respectively, and the method is mainly embodied in the following three aspects. Firstly, during the active power transmission capacity adjustment of the converter station, the RPC system gradually switches the filter bank and the capacitor according to the increase and decrease of the power transmitted by the converter station, because the reactive power capacity of the filter is large, each switching can cause the large fluctuation of the voltage in the area, and meanwhile, the transformer substation can follow the control target of voltage optimization under the AVC control, so that the voltage is low before the filter (capacitor) of the converter station is put into the transformer substation, which causes the capacitor (or the reactor) to be put into the transformer substation, and the voltage is high after the filter (capacitor) of the converter station is put into the transformer substation, which causes the capacitor (or the reactor) to be put into the transformer substation, so that the phenomenon that reactive power equipment in the near area is repeatedly switched back and forth in the process of adjusting the direct current active transmission capacity of the converter station occurs, and the voltage fluctuation. Secondly, after the active power transmission capacity of the converter station is adjusted and the converter station enters stable operation, voltage change of the converter station is caused by switching capacitors, reactors and the like of a near-region transformer substation under AVC control, reactive power exchange between the converter station and an external alternating current system is out of limit and triggers RPC to switch filters (capacitors) in the converter station, and therefore the phenomenon that the filters (capacitors) in the converter station are frequently switched due to AVC control occurs, and safe and stable operation of the converter station is affected. Thirdly, when an extra-high voltage converter station has abnormal faults such as direct current converter pole single-stage locking or bipolar locking, the active power transmission capacity of the converter station is changed greatly in the fault process, the regulating capacity of a filter (capacitor) in the station is used up possibly in the fault process, the voltage in the region possibly exceeds the limit greatly after the fault occurs, a control instruction for switching reactive equipment is issued to a transformer substation close to the converter station in a fixed period (such as 5 minutes) in the traditional AVC, and the bus voltage in the region cannot be corrected within the shortest time.
In summary, with the rapid construction of the extra-high voltage direct current transmission project and the wide application of the automatic voltage control system of the power grid, the problem of the reactive voltage coordination control of the extra-high voltage direct current converter station and the nearby transformer substation needs to be solved urgently to ensure the stable and reliable operation of the extra-high voltage direct current transmission.
In a near-area power grid of an extra-high voltage converter station, a 500kV transformer substation is mainly automatically controlled by an AVC (automatic voltage control) scheduling center, and a transformer of the transformer is provided with multiple taps for no-load voltage regulation and cannot regulate the tap gears during operation, so that AVC control objects are reactive devices such as capacitors, reactors and the like on the low-voltage side of a main transformer in the transformer substation. An AVC system of a provincial power grid dispatching center mainly adopts a multi-target-oriented substation control strategy to realize automatic control of reactive equipment in a 500kV substation. The main points of this control strategy are: the control targets of the substation include: 1) the bus voltage of each level is qualified; 2) and optimizing the main network bus voltage. Wherein 1) when any bus of the high side, the middle side and the low side of the transformer substation has voltage overlimit, reactive equipment such as a capacitor and an electric reactor needs to be switched to eliminate the overlimit; when the control target of 1) is met, namely the voltages of the buses in the transformer substation are all qualified, the voltage optimization target of the high-voltage side bus is considered, namely when the voltages of the high-voltage side bus are lower than or higher than the optimization target value, reactive equipment is switched to enable the voltages of the high-voltage side bus to reach the vicinity of the optimization target value. Because the reactive equipment in the transformer substation cannot be switched frequently, when the voltage of the high-voltage side bus is checked to be lower than or higher than the optimized target value, dead zone parameters of optimized control need to be considered, namely, the criterion for judging that the voltage of the bus is lower than the optimized target value is as follows:
Vi real<Vi opt-Vi dead
the criterion for judging that the bus voltage is higher than the optimization target value is as follows:
Vi real>Vi opt+Vi dead
wherein, Vi realAs a voltage measurement of the bus i, Vi optOptimizing the target value, V, for the voltage of the bus ii deadThe voltage of a transformer substation bus i which is set manually is optimized to control the parameters of the dead zone, generally for a 500kV transformer substation, Vi dead＝2kV。
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provides a reactive voltage coordination control method for an extra-high voltage direct current converter station and a nearby transformer substation. The method realizes the coordinated control of the ultrahigh voltage and the ultrahigh voltage near-region transformer substation, avoids the repeated switching of reactive equipment in the near-region transformer substation in the process of adjusting the direct current active transmission capacity of the converter station and the frequent switching of the reactive equipment of the converter station, and improves the voltage stability and the voltage quality of a power grid.
The invention provides a reactive voltage coordination control method for an extra-high voltage direct current converter station and a near-field substation, which is characterized by comprising the following steps of:
1) setting an automatic voltage control period to Tc；
2) When each automatic voltage control cycle comes, the coming time is recorded as t0Reading the telecommand values of the single-stage blocking signal and the bipolar blocking signal of the extra-high voltage direct current converter station and the corresponding change time thereof from a dispatching monitoring system of a power grid dispatching center, and if any signal telecommand value is at the nearest T0If the change occurs in the time period, carrying out emergency control on the near-zone transformer substation of the converter station, and entering the step 7); otherwise, entering step 3);
3) with the current t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking time as a reference1Active transmission power history value of time period, and future T2And (3) judging the operation trend of the extra-high voltage direct current converter station by the active power transmission power plan value in the time period: if the active transmission power of the converter station is determined to be in the adjusting time period, entering the step 4); if the active transmission power of the converter station is judged to be in the time period just completed by adjustment, the step 5) is carried out; otherwise, judging that the active transmission power of the converter station is in a stable time interval, and entering the step 6);
4) when the active transmission power of the converter station is in the adjusting time period, the reactive equipment control method of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, locking bus voltage optimization control, and then entering step 7);
5) when the active power transmission power of the converter station is in the period of just completing the adjustment, the reactive power equipment control method of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, automatically reducing parameters of bus voltage optimization dead zones of the transformer substation to increase the switching control of the transformer substation on reactive equipment, and then entering step 7);
6) when the active power transmission power of the converter station is in a stable period, the control method of the reactive power equipment of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, reading the constraint condition of the converter station on the external reactive power exchange limit value in the bus voltage optimization control, and then entering step 7);
7) and when the next control period comes, returning to the step 2) again, and starting a new round of control calculation.
The method has the characteristics and beneficial effects that:
the invention provides a reactive voltage coordination control method of an extra-high voltage direct current converter station and a nearby transformer substation, which is characterized in that when each automatic voltage control period comes, whether the direct current converter station is in a fault state after monopolar locking or bipolar locking is firstly checked, if the converter station is in the fault state, emergency control is carried out on the nearby transformer substation, and reactive equipment in the transformer substation is quickly switched to eliminate possible voltage out-of-limit; if the converter station is in a normal operation state, checking the change trend of the direct current active transmission of the current converter station, and generating corresponding near-area substation control strategies aiming at different time periods when the active transmission power is being adjusted or just adjusted; and if the converter station is in a normal operation state and the active power transmission flow is stable, reading the limit value constraint of the reactive power exchange between the direct current converter station and the outside, generating a reasonable substation control strategy, and avoiding the AVC control of the substation from triggering the switching of a filter or a capacitor in the converter station. The method solves the defects that the frequent action of equipment and unstable voltage are easily caused by the mutual influence of reactive equipment action between the extra-high voltage direct current converter station and the nearby substation in the prior method and are not considered; the method for coordinately controlling the extra-high voltage direct current converter station and the nearby transformer substation is adopted, and the equipment unqualified actions and voltage fluctuation are reduced. By adopting the method, the coordination control of the AVC of the power grid and a reactive power control system in the extra-high voltage direct current converter station can be realized, and the safe and stable operation of extra-high voltage direct current transmission can be effectively ensured.
Drawings
FIG. 1 is a diagram of the connection relationship between the extra-high voltage direct current converter station and the power grid of the near-field substation of the extra-high voltage direct current converter station in the power grid model related by the method.
FIG. 2 is an overall flow diagram of the method of the present invention.
Detailed Description
The reactive voltage coordination control method for the extra-high voltage direct current converter station and the near-region transformer substation provided by the invention is further described in detail below by combining the attached drawings and specific embodiments.
In a power grid model related to the method, the connection relation between an extra-high voltage direct current converter station and a near-region substation of the extra-high voltage direct current converter station is shown in figure 1, the current conversion side of the extra-high voltage direct current converter station A in the power grid model is in electrical connection with a substation B, namely the substation B is a near-region substation of the extra-high voltage direct current converter station.
The invention provides a reactive voltage coordination control method for an extra-high voltage direct current converter station and a near-field substation, the whole flow is shown in figure 2, and the method comprises the following steps:
1) setting an automatic voltage control period to TcThe value T is taken in this embodimentc300 seconds (T)cThe range of the available value is 30-3000 seconds, and is usually set as 300 seconds);
2) when each automatic voltage control cycle comes, the coming time is recorded as t0In this embodiment, t is set01511253600, reading the telecommand values of the single-stage blocking signal and the double-stage blocking signal of the extra-high voltage direct current converter station (hereinafter referred to as the converter station) and the corresponding change time thereof from the dispatching monitoring system of the power grid dispatching center, and if any signal telecommand value is at the nearest T0(in this embodiment, T is set0300 seconds, the available value range is 30-3000 seconds), and then performing emergency control on the near-zone substation of the converter station, and entering step 7); otherwise, entering step 3);
3) with the current t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking time as a reference1The active transmission power historical value in a time period (the range of the available value is 30-86400 seconds and is usually set as 900 seconds), and the future T2And (3) judging the operation trend of the extra-high voltage direct current converter station by the active power transmission power plan value in a time period (the range of the available value is 30-86400 seconds, and is usually set as 900 seconds): if the active transmission power of the converter station is determined to be in the adjusting time period, entering the step 4); if the active transmission power of the converter station is judged to be in the time period just completed by adjustment, the step 5) is carried out; otherwise, judging that the active transmission power of the converter station is in a stable time interval, and entering the step 6);
4) when the active transmission power of the converter station is in the adjusting time period, the reactive equipment control method of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, locking bus voltage optimization control, and then entering step 7);
5) when the active power transmission power of the converter station is in the period of just completing the adjustment, the reactive power equipment control method of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, automatically reducing parameters of bus voltage optimization dead zones of the transformer substation to increase the switching control of the transformer substation on reactive equipment, and then entering step 7);
6) when the active power transmission power of the converter station is in a stable period, the control method of the reactive power equipment of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, reading the constraint condition (the value range is-3000' 3000, usually-200) of the converter station on the external reactive power exchange limit value in the bus voltage optimization control, and then entering step 7);
7) and when the next control period comes, returning to the step 2) again, and starting a new round of control calculation.
The step 2) comprises the following specific steps:
2-1) at t0Reading a remote signaling value S of a single-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system at any moment1And the most recent time of change C of the signal1；
2-2) at t0At any moment, reading a remote signaling value S of a two-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system2And the most recent time of change C of the signal2；
2-3) determining whether the following holds:
(S1＝1)∨(t0-C1<T0)∨(S2＝1)∨(t0-C2<T0) (1)
if the formula (1) is established, entering the step 2-4) to carry out emergency control on the near-zone transformer substation of the converter station; if the formula (1) is not satisfied, the converter station is in a normal operation state, emergency control on a nearby transformer substation is not needed, and the step 2-5 is carried out;
2-4) checking the bus voltage of each level in the near-zone transformer substation of the converter station: if the lower limit of the bus voltage is higher, a capacitor or a cut-off reactor is put into the reactor (the two are selected alternatively); if the bus voltage is higher than the upper limit, cutting off the capacitor or putting in the reactor (one of the two is selected); then the automatic voltage control period TcModified as Tc′，Tc' is an automatic voltage control period under emergency control, Tc′<TcEntering step 7);
2-5) restoring the automatic voltage control period of the AVC system to TcProceed to step 3).
The step 3) comprises the following specific steps:
3-1) with current t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking time as a reference1The active power transmission history value of the time interval is recorded as
Figure BDA0001489148360000061
Where ti represents the instant of an integer of the past n control cycles,
Figure BDA0001489148360000062
and determines the past T1The time interval direct current transmission power variation trend comprises the following specific steps:
3-1-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA0001489148360000063
DC transport trend reduction counter
Figure BDA0001489148360000064
3-1-2) if satisfied
Figure BDA0001489148360000071
Then set up
Figure BDA0001489148360000072
Go to step 3-1-3), wherein
Figure BDA0001489148360000073
Determining a power threshold (typically set to 100) for a predetermined trend, in the sense of the amount of change in dc transmission capacity per control period; if it is satisfied with
Figure BDA0001489148360000074
Then set up
Figure BDA0001489148360000075
Entering the step 3-1-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-1-3) is carried out;
3-1-3) setting i ═ i +1, and deciding: if i < n is satisfied, returning to the step 3-1-2), otherwise, entering the step 3-1-4);
3-1-4) determining the value of the counter: if it is satisfied with
Figure BDA0001489148360000076
Or
Figure BDA0001489148360000077
It is determined that the dc transmission capacity is T in the past1The time interval changes, and the change state of the historical DC transmission capacity is marked
Figure BDA0001489148360000078
Otherwise marking
Figure BDA0001489148360000079
Wherein
Figure BDA00014891483600000710
A counter threshold value (typically set to 100) for the dc trend determination;
3-2) with current t0Scheduling from a power grid scheduling center by taking time as referenceReading future T of extra-high voltage direct current converter station in monitoring system2The planned value of active transmission power in the time interval is recorded as
Figure BDA00014891483600000711
Wherein f isiRepresenting the instant of an integer of m control cycles in the future,
Figure BDA00014891483600000712
and determines the future T2Whether the change trend of the direct current transmission power changes or not in a time period comprises the following specific steps:
3-2-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA00014891483600000713
DC transport trend reduction counter
Figure BDA00014891483600000714
3-2-2) if satisfied
Figure BDA00014891483600000715
Then set up
Figure BDA00014891483600000716
Entering the step 3-2-3); if it is satisfied with
Figure BDA00014891483600000717
Then set up
Figure BDA00014891483600000718
Entering the step 3-2-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-2-3) is carried out;
3-2-3) setting i ═ i +1, and deciding: if the i < m is satisfied, returning to the step 3-2-2), otherwise, entering the step 3-2-4);
3-2-4) determining the value of the counter: if it is satisfied with
Figure BDA00014891483600000719
Or
Figure BDA00014891483600000720
Determining the DC transport capacity in the future T2The time interval changes, and marks the change state of the future DC transmission capacity
Figure BDA00014891483600000721
Otherwise marking
Figure BDA00014891483600000722
3-3) judging the active power transmission state of the current converter station, specifically as follows:
if it is satisfied with
Figure BDA00014891483600000723
Judging that the active transmission power of the current converter station is in the adjusting time period, and entering the step 4);
if it is satisfied with
Figure BDA00014891483600000724
Judging that the active transmission power of the current converter station is in the time period just adjusted, and entering step 5);
if it is satisfied with
Figure BDA00014891483600000725
It is determined that the current converter station has active power transmission in the stationary period and step 6) is entered.
The step 4) comprises the following specific steps:
4-1) checking the bus voltage and out-of-limit conditions of each level in the converter station near-field substation: if the lower limit of the bus voltage is lower, a capacitor or a cut-off reactor is put into the reactor (the two are selected alternatively), and the step 7 is carried out; if the bus voltage is higher than the upper limit, cutting off the capacitor or putting in the reactor (the two are selected alternatively), and entering the step 7); if the out-of-limit condition does not exist, entering the step 4-2);
4-2) locking the bus voltage optimization control calculation of the near-zone transformer substation of the converter station, and entering the step 7).
The step 5) comprises the following specific steps:
5-1) checking the bus voltage and out-of-limit conditions of each level in the converter station near-field substation: if the lower limit of the bus voltage is lower, a capacitor or a cut-off reactor is put into the reactor (the two are selected alternatively), and the step 7 is carried out; if the bus voltage is higher than the upper limit, generating a cut capacitor or an input reactor (either one of the two is selected), and entering the step 7); if the out-of-limit condition does not exist, entering the step 5-2);
5-2) adjusting the bus i voltage optimization control dead zone parameters of the near-zone transformer substation of the converter station as follows: vi dead′＝Vi dead/2，Vi deadThe method comprises the steps of (1) optimizing and controlling a dead zone parameter for the voltage of a transformer substation bus i set manually;
5-3) checking the bus voltage of the substation: if V is satisfiedi real<Vi opt-Vi dead' then put into the capacitor or cut off the reactor; if V is satisfiedi real<Vi opt+Vi dead′Cutting off the capacitor or putting in the reactor; wherein, Vi realAs a voltage measurement of the bus i, Vi optOptimizing a target value for the voltage of the bus i; proceed to step 7).
The step 6) comprises the following specific steps:
6-1) checking the bus voltage and out-of-limit conditions of each level in the converter station near-field substation: if the lower limit of the bus voltage is lower, a capacitor or a cut-off reactor is put into the reactor (the two are selected alternatively), and the step 7 is carried out; if the bus voltage is higher than the upper limit, cutting off the capacitor or putting in the reactor (the two are selected alternatively), and entering the step 7); if the out-of-limit condition does not exist, entering the step 6-2);
6-2) adjusting the bus i voltage optimization control dead zone parameters of the near-zone transformer substation of the converter station as follows: vi dead′＝Vi dead，Vi deadThe method comprises the steps of (1) optimizing and controlling a dead zone parameter for a manually set transformer substation bus i voltage;
6-3) reading exchange of the extra-high voltage direct current converter station and the external alternating current system from the dispatching center monitoring systemReactive capacity of
Figure BDA0001489148360000081
And calculating constraint conditions for optimal control of the bus voltage of the transformer substation according to the comparison result between the calculated constraint conditions and a preset external reactive power exchange limit value, wherein the constraint conditions are as follows:
6-3-1) setting I voltage optimization control reactive power increasing blocking mark of transformer substation bus
Figure BDA0001489148360000082
I voltage optimal control reactive power reduction locking mark for transformer substation bus
Figure BDA0001489148360000083
6-3-2) is provided with
Figure BDA0001489148360000084
For a preset upper limit value of reactive capacity exchanged by the converter station and the external ac system,
Figure BDA0001489148360000085
for a preset lower limit value of reactive capacity exchanged by the converter station with the external ac system,
Figure BDA0001489148360000086
determining a dead zone for reactive power; if so:
Figure BDA0001489148360000087
then the increased reactive power blocking flag is set:
Figure BDA0001489148360000088
otherwise if:
Figure BDA0001489148360000089
then the reactive power reduction blocking flag is set:
Figure BDA00014891483600000810
6-3-4) if satisfied
Figure BDA0001489148360000091
Then the capacitor is put in or the reactor is cut off; if it is satisfied with
Figure BDA0001489148360000092
Cutting off the capacitor or putting the reactor into the reactor; otherwise, not carrying out optimization control; proceed to step 7).
The reactive voltage coordination control method for the extra-high voltage direct current converter station and the near-region transformer substation provided by the invention is further described in detail below by combining the embodiment.
Case 1: emergency control is carried out on a near-area transformer substation;
the invention provides a reactive voltage coordination control method for an extra-high voltage direct current converter station and a near-field transformer substation, which comprises the following steps:
1) setting an automatic voltage control period to Tc300 seconds;
2) when each automatic voltage control cycle comes, the coming time is recorded as t0In this embodiment, t is set01511253600, reading the telecommand values of the single-stage blocking signal and the double-stage blocking signal of the extra-high voltage direct current converter station (hereinafter referred to as the converter station) and the corresponding change time thereof from the dispatching monitoring system of the power grid dispatching center, and if any signal telecommand value is at the nearest T0(in this embodiment, T is set0300 seconds), performing emergency control on the near-zone substation of the converter station, and entering step 7); otherwise, entering step 3); the method comprises the following specific steps:
2-1) at t0Reading a remote signaling value S of a single-stage blocking signal of the extra-high voltage direct current converter station A from a power grid dispatching center dispatching monitoring system at any moment11 and the latest change time of the signal C1＝1511253400；
2-2) at t0At any moment, reading a remote signaling value S of a two-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system20 and the latest change time of signal C2＝0；
2-3) determining whether the following holds:
(S1＝1)∨(t0-C1<T0)∨(S2＝1)∨(t0-C2<T0) (1)
if the formula (1) is established, entering the step 2-4) to carry out emergency control on the near-zone transformer substation of the converter station; if the formula (1) is not satisfied, emergency control is not needed to be carried out on the transformer substation in the near area, and the step 2-5 is carried out;
in this example, S11 and t0-C1When the two conditions satisfy equation (1) 200, equation (1) is satisfied, the AVC system is triggered to perform emergency control of the converter station a in the near-field substation, and the process proceeds to step 2-4.
2-2-4) checking the bus voltage of each level in the near-zone transformer substation of the converter station: if the lower limit of the bus voltage is higher, a capacitor or a cut-off reactor is put into the reactor (the two are selected alternatively); if the bus voltage is higher than the upper limit, cutting off the capacitor or putting in the reactor (one of the two is selected); then the automatic voltage control period TcModified as Tc′，Tc' is an automatic voltage control period under emergency control, Tc′<TcEntering step 7);
in the embodiment, the AVC system checks the bus voltages and the out-of-limit conditions of all levels of a near-field substation B of a converter station A, and statistics are shown in the following table 1;
TABLE 1 statistical table of bus voltage conditions of each level of substation B
500kV bus voltage (kV) 220kV bus voltage (kV) 35kV voltage (kV)
Upper limit ofValue of 523.0 232.0 38.0
Lower limit value 515.0 223.0 33.0
Measured value 523.96 227.13 34.93
Whether or not to exceed the limit Is that Whether or not Whether or not
As shown in table 1, the AVC system cuts off a capacitor (reactor input) in substation B as bus voltage 523.96 of substation B500kV goes up to 523.
Modifying an automatic voltage control period of an AVC system to Tc′,Tc′＝100，Tc′<TcEntering step 7);
7) and when the next control period comes, returning to the step 2) again, and starting a new round of control calculation.
Case 2: the extra-high voltage converter station is in a normal operation state, and active power transmission power is in a time interval being adjusted:
2) when each automatic voltage control cycle comes, the coming time is recorded as t0In this embodiment, t is set01511253900, reading the telecommand values of the single-stage blocking signal and the double-stage blocking signal of the extra-high voltage direct current converter station (hereinafter referred to as a converter station) from the dispatching monitoring system of the power grid dispatching center and corresponding telecommand valuesIf any signal is far signaled value is in the nearest T0(in this embodiment, T is set0300 seconds), performing emergency control on the near-zone substation of the converter station, and entering step 7); otherwise, entering step 3); the method comprises the following specific steps:
2-1) at t0Reading a remote signaling value S of a single-stage blocking signal of the extra-high voltage direct current converter station A from a power grid dispatching center dispatching monitoring system at any moment10 and the latest change time of signal C1＝1511253400；
2-2) at t0At any moment, reading a remote signaling value S of a two-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system20 and the latest change time of signal C2＝0；
2-3) determining whether the following holds:
(S1＝1)∨(t0-C1<T0)∨(S2＝1)∨(t0-C2<T0) (1)
if the formula (1) is established, entering the step 2-4) to carry out emergency control on the near-zone transformer substation of the converter station; if the formula (1) is not satisfied, emergency control is not needed to be carried out on the transformer substation in the near area, and the step 2-5 is carried out;
in this embodiment, if the formula (1) does not hold, the process proceeds to step 2-5);
2-5) restoring the automatic voltage control period of the AVC system to Tc，TcGo to step 3) for 300 seconds.
3) With the current t0Time t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking 1511253900 as a reference1Time interval (set T)1900 seconds) and the future T, and2time interval (set T)2900 seconds), determining the operation trend of the extra-high voltage direct current converter station: if the active transmission power of the converter station is determined to be in the adjusting time period, entering the step 4); if the active transmission power of the converter station is judged to be in the time period just completed by adjustment, the step 5) is carried out; otherwise, judgeDetermining that the active transmission power of the converter station is in a stable time period, and entering step 6); the method comprises the following specific steps:
3-1) with current t0Time being a reference (t)01511253900), reading the past T of the extra-high voltage direct current converter station A from the dispatching monitoring system of the power grid dispatching center1Time period (T)1900 seconds) of active power delivery history, noted
Figure BDA0001489148360000111
Where ti represents the instant of an integer of the past n control cycles,
Figure BDA0001489148360000112
then
Figure BDA0001489148360000113
And determines the past T1The time interval direct current transmission power variation trend comprises the following specific steps:
3-1-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA0001489148360000114
DC transport trend reduction counter
Figure BDA0001489148360000115
3-1-2) if satisfied
Figure BDA0001489148360000116
Then set up
Figure BDA0001489148360000117
Go to step 3-1-3), wherein
Figure BDA0001489148360000118
Determining a power threshold for a predetermined trend (100 in this embodiment); if it is satisfied with
Figure BDA0001489148360000119
Then set up
Figure BDA00014891483600001110
Entering the step 3-1-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-1-3) is carried out;
3-1-3) setting i ═ i +1, and deciding: if i < n is satisfied, returning to the step 3-1-2), otherwise, entering the step 3-1-4);
3-1-4) determining the value of the counter: if it is satisfied with
Figure BDA00014891483600001111
Or
Figure BDA00014891483600001112
It is determined that the dc transmission capacity is T in the past1The time interval changes, marks
Figure BDA00014891483600001113
Otherwise marking
Figure BDA00014891483600001114
Wherein
Figure BDA00014891483600001115
A counter threshold value (typically set to 100) for the dc trend determination;
in this embodiment, the initialization i is 1, and a dc transfer tendency increase counter is provided
Figure BDA00014891483600001116
Decrementing counters
Figure BDA00014891483600001117
Wherein
Figure BDA00014891483600001118
Satisfy the requirement of
Figure BDA00014891483600001119
Then
Figure BDA00014891483600001120
Not meet the requirements of
Figure BDA00014891483600001121
Satisfy the requirement of
Figure BDA00014891483600001122
Then
Figure BDA00014891483600001123
Does not satisfy:
Figure BDA00014891483600001124
then
Figure BDA00014891483600001125
Setting the threshold value of the counter for the DC trend determination
Figure BDA00014891483600001126
Due to the fact that
Figure BDA00014891483600001127
Wherein
Figure BDA00014891483600001128
Satisfy the requirement of
Figure BDA00014891483600001129
It is determined that the dc transmission capacity is T in the past1The time interval changes, marks
Figure BDA00014891483600001130
3-2) with current t0Time (t)01511253900) as a reference, reading future T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system2The planned value of active transmission power in the time interval is recorded as
Figure BDA00014891483600001131
Wherein f isiRepresenting the instant of an integer of m control cycles in the future,
Figure BDA0001489148360000121
then
Figure BDA0001489148360000122
And determines the future T2Whether the change trend of the direct current transmission power changes or not in a time period comprises the following specific steps:
3-2-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA0001489148360000123
DC transport trend reduction counter
Figure BDA0001489148360000124
3-2-2) if satisfied
Figure BDA0001489148360000125
Then set up
Figure BDA0001489148360000126
Entering the step 3-2-3); if it is satisfied with
Figure BDA0001489148360000127
Then set up
Figure BDA0001489148360000128
Entering the step 3-2-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-2-3) is carried out;
3-2-3) setting i ═ i +1, and deciding: if the i < m is satisfied, returning to the step 3-2-2), otherwise, entering the step 3-2-4);
3-2-4) determining the value of the counter: if it is satisfied with
Figure BDA0001489148360000129
Or
Figure BDA00014891483600001210
Determining the DC transport capacity in the future T2The time interval will change, mark
Figure BDA00014891483600001211
Otherwise marking
Figure BDA00014891483600001212
In this embodiment, the initialization i is 1, and a dc transfer tendency increase counter is provided
Figure BDA00014891483600001213
Decrementing counters
Figure BDA00014891483600001214
Wherein
Figure BDA00014891483600001215
Satisfy the requirement of
Figure BDA00014891483600001216
Then
Figure BDA00014891483600001217
Does not satisfy:
Figure BDA00014891483600001218
then set up
Figure BDA00014891483600001219
Satisfy the requirement of
Figure BDA00014891483600001220
Then
Figure BDA00014891483600001221
Does not satisfy:
Figure BDA00014891483600001222
then
Figure BDA00014891483600001223
Due to the fact that
Figure BDA00014891483600001224
Wherein
Figure BDA00014891483600001225
Satisfy the requirement of
Figure BDA00014891483600001226
It is determined that the DC transport capacity is in the future T2The time interval will change, mark
Figure BDA00014891483600001227
3-3) judging the active power transmission state of the current converter station, specifically as follows:
if it is satisfied with
Figure BDA00014891483600001228
Judging that the active transmission power of the current converter station is in the adjusting time period, and entering the step 4);
if it is satisfied with
Figure BDA00014891483600001229
Judging that the active transmission power of the current converter station is in the time period just adjusted, and entering step 5);
if it is satisfied with
Figure BDA00014891483600001230
It is determined that the current converter station has active power transmission in the stationary period and step 6) is entered.
The present embodiment satisfies
Figure BDA00014891483600001231
Judging that the active transmission power of the current converter station A is in the adjusting time period, and entering the step 4);
4) when the active transmission power of the converter station is in the adjusting time period, the reactive equipment control method of the near-region transformer substation comprises the following steps: calculating the voltage elimination out-of-limit in the transformer substation, locking the bus voltage for optimal control, and then entering the step 7);
in this embodiment, the specific steps are as follows:
4-1) checking the bus voltages and out-of-limit conditions of all levels of a near-zone transformer substation B of the converter station A, and counting as shown in the following table 2;
table 2 statistics table for bus voltage condition of each stage of substation B
500kV bus voltage (kV) 220kV bus voltage (kV) 35kV voltage (kV)
Upper limit value 523.0 232.0 38.0
Lower limit value 515.0 223.0 33.0
Measured value 518.3 227.5 35.93
Whether or not to exceed the limit Whether or not Whether or not Whether or not
As shown in the above table 2, if all the buses of each level of the substation B are out of limit, the AVC system does not generate a policy for eliminating out of limit of the substation B, and the step 4-2) is performed;
4-2) locking the bus voltage optimization control calculation of the near-zone transformer substation B of the converter station A, and entering the step 7);
7) and when the next control period comes, returning to the step 2) again, and starting a new round of control calculation.
Case 3: the extra-high voltage converter station is in a normal operation state, and the active power transmission capacity of the extra-high voltage converter station is in a time period of just completing adjustment:
2) when each automatic voltage control cycle comes, the coming time is recorded as t0In this embodiment, t is set01511264800, reading the telecommand values of the single-stage blocking signal and the double-stage blocking signal of the extra-high voltage direct current converter station (hereinafter referred to as the converter station) and the corresponding change time thereof from the dispatching monitoring system of the power grid dispatching center, and if any signal telecommand value is at the nearest T0(in this embodiment, T is set0300 seconds), performing emergency control on the near-zone substation of the converter station, and entering step 7); otherwise, entering step 3); the method comprises the following specific steps:
2-1) at t0Reading a remote signaling value S of a single-stage blocking signal of the extra-high voltage direct current converter station A from a power grid dispatching center dispatching monitoring system at any moment10 and the latest change time of signal C1＝1511253400；
2-2) at t0At any moment, reading a remote signaling value S of a two-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system20 and the latest change time of signal C2＝0；
2-3) determining whether the following holds:
(S1＝1)∨(t0-C1<T0)∨(S2＝1)∨(t0-C2<T0) (1)
if the formula (1) is established, entering the step 2-4) to carry out emergency control on the near-zone transformer substation of the converter station; if the formula (1) is not satisfied, emergency control is not needed to be carried out on the transformer substation in the near area, and the step 2-5 is carried out;
in this embodiment, if the formula (1) does not hold, the process proceeds to step 2-5);
2-5) restoring the automatic voltage control period of the AVC system to Tc，TcGo to step 3) for 300 seconds.
3) With the current t0Time t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking 1511264800 as a reference1Time interval (set T)1900 seconds) and the future T, and2time interval (set T)2900 seconds), determining the operation trend of the extra-high voltage direct current converter station: if the active transmission power of the converter station is determined to be in the adjusting time period, entering the step 4); if the active transmission power of the converter station is judged to be in the time period just completed by adjustment, the step 5) is carried out; otherwise, judging that the active transmission power of the converter station is in a stable time interval, and entering the step 6); the method comprises the following specific steps:
3-1) with current t0Time being a reference (t)01511264800), reading the past T of the extra-high voltage direct current converter station A from the dispatching monitoring system of the power grid dispatching center1Time period (T)1900 seconds) of active power delivery history, noted
Figure BDA0001489148360000141
Where ti represents the instant of an integer of the past n control cycles,
Figure BDA0001489148360000142
then
Figure BDA0001489148360000143
And determines the past T1The time interval direct current transmission power variation trend comprises the following specific steps:
3-1-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA0001489148360000144
DC transport trend reduction counter
Figure BDA0001489148360000145
3-1-2) if satisfied
Figure BDA0001489148360000146
Then set up
Figure BDA0001489148360000147
Go to step 3-1-3), wherein
Figure BDA0001489148360000148
Determining a power threshold for a predetermined trend (100 in this embodiment); if it is satisfied with
Figure BDA0001489148360000149
Then set up
Figure BDA00014891483600001410
Entering the step 3-1-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-1-3) is carried out;
3-1-3) setting i ═ i +1, and deciding: if i < n is satisfied, returning to the step 3-1-2), otherwise, entering the step 3-1-4);
3-1-4) determining the value of the counter: if it is satisfied with
Figure BDA00014891483600001411
Or
Figure BDA00014891483600001412
It is determined that the dc transmission capacity is T in the past1The time interval changes, marks
Figure BDA00014891483600001413
Otherwise marking
Figure BDA00014891483600001414
Wherein
Figure BDA00014891483600001415
A counter threshold value (typically set to 100) for the dc trend determination;
in this embodiment, the initialization i is 1, and a dc transfer tendency increase counter is provided
Figure BDA00014891483600001416
Decrementing counters
Figure BDA00014891483600001417
Wherein
Figure BDA00014891483600001418
Not meet the requirements of
Figure BDA00014891483600001419
Then
Figure BDA00014891483600001420
Satisfy the requirement of
Figure BDA00014891483600001421
Then
Figure BDA00014891483600001422
Not meet the requirements of
Figure BDA00014891483600001423
Then
Figure BDA00014891483600001424
Satisfies the following conditions:
Figure BDA00014891483600001425
then
Figure BDA00014891483600001426
Setting the threshold value of the counter for the DC trend determination
Figure BDA00014891483600001427
Due to the fact that
Figure BDA00014891483600001428
Wherein
Figure BDA00014891483600001429
Satisfy the requirement of
Figure BDA00014891483600001430
It is determined that the dc transmission capacity is T in the past1The time interval changes, marks
Figure BDA00014891483600001431
3-2) with current t0Time (t)0＝t01511264800) as a reference, reading future T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system2The planned value of active transmission power in the time interval is recorded as
Figure BDA00014891483600001432
Wherein f isiRepresenting the instant of an integer of m control cycles in the future,
Figure BDA0001489148360000151
then
Figure BDA0001489148360000152
And determines the future T2Whether the change trend of the direct current transmission power changes or not in a time period comprises the following specific steps:
3-2-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA0001489148360000153
DC transport trend reduction counter
Figure BDA0001489148360000154
3-2-2) if satisfied
Figure BDA0001489148360000155
Then set up
Figure BDA0001489148360000156
Entering the step 3-2-3); if it is satisfied with
Figure BDA0001489148360000157
Then set up
Figure BDA0001489148360000158
Entering the step 3-2-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-2-3) is carried out;
3-2-3) setting i ═ i +1, and deciding: if the i < m is satisfied, returning to the step 3-2-2), otherwise, entering the step 3-2-4);
3-2-4) determining the value of the counter: if it is satisfied with
Figure BDA0001489148360000159
Or
Figure BDA00014891483600001510
Determining the DC transport capacity in the future T2The time interval will change, mark
Figure BDA00014891483600001511
Otherwise marking
Figure BDA00014891483600001512
In this embodiment, the initialization i is 1, and a dc transfer tendency increase counter is provided
Figure BDA00014891483600001513
Decrementing counters
Figure BDA00014891483600001514
Wherein
Figure BDA00014891483600001515
Not meet the requirements of
Figure BDA00014891483600001516
Then
Figure BDA00014891483600001517
Does not satisfy:
Figure BDA00014891483600001518
then set up
Figure BDA00014891483600001519
Not meet the requirements of
Figure BDA00014891483600001520
Then
Figure BDA00014891483600001521
Does not satisfy:
Figure BDA00014891483600001522
then
Figure BDA00014891483600001523
Due to the fact that
Figure BDA00014891483600001524
Not meet the requirements of
Figure BDA00014891483600001525
Or
Figure BDA00014891483600001526
It is determined that the DC transport capacity is in the future T2The time interval will not change, and mark
Figure BDA00014891483600001527
3-3) judging the active power transmission state of the current converter station, specifically as follows:
if it is satisfied with
Figure BDA00014891483600001528
Judging that the active transmission power of the current converter station is in the adjusting time period, and entering the step 4);
if it is satisfied with
Figure BDA00014891483600001529
Then it is decidedEntering step 5) when the active transmission power of the current converter station is in the time period of just completing the adjustment;
if it is satisfied with
Figure BDA00014891483600001530
It is determined that the current converter station has active power transmission in the stationary period and step 6) is entered.
In the present embodiment, the following conditions are satisfied
Figure BDA00014891483600001531
Judging that the active transmission power of the current converter station is in the time period just adjusted, and entering step 5);
5) when the active power transmission power of the converter station is in the period of just completing the adjustment, the reactive power equipment control method of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, automatically reducing parameters of bus voltage optimization dead zones of the transformer substation to increase the switching control of the transformer substation on reactive equipment, and then entering step 7); the specific steps of the embodiment are as follows:
5-1) checking the bus voltages and out-of-limit conditions of all levels of a near-field substation B of a converter station A, and counting the bus voltages and the out-of-limit conditions as shown in the following table;
table 3 statistics table for bus voltage condition of each stage of substation B
500kV bus voltage (kV) 220kV bus voltage (kV) 35kV voltage (kV)
Upper limit value 523.0 232.0 38.0
Lower limit value 515.0 223.0 33.0
Measured value 519.8 227.9 35.16
Whether or not to exceed the limit Whether or not Whether or not Whether or not
As shown in table 3, if all buses of each level of the substation B are out of limit, the AVC system does not generate a policy for eliminating out of limit of the substation B, and the step 5-2) is performed; 5-2) Vi deadSetting a transformer substation bus i voltage optimization control dead zone parameter for manual setting, and setting Vi dead2 kV. Adjusting the parameters of the bus voltage optimization control dead zone of the near-zone transformer substation B of the converter station A as follows: vi dead′＝Vi dead1kV,/2; 5-3) checking the bus voltage of the transformer substation, and setting a 500kV bus Vi opt521 then Vi opt-Vi dead′＝520,Vi real519.8 satisfies Vi real<Vi opt-Vi dead′The AVC system generates a strategy to throw in the capacitors (cut-out reactors).
7) And when the next control period comes, returning to the step 2) again, and starting a new round of control calculation.
Case 4 the active transmission capacity of the extra-high voltage converter station is in the time period:
2) when each automatic voltage control cycle comes, the coming time is recorded as t0In this embodiment, t is set01511275800, reading the telecommand values of the single-stage blocking signal and the double-stage blocking signal of the extra-high voltage direct current converter station (hereinafter referred to as the converter station) and the corresponding change time thereof from the dispatching monitoring system of the power grid dispatching center, and if any signal telecommand value is at the nearest T0(in this embodiment, T is set0300 seconds), performing emergency control on the near-zone substation of the converter station, and entering step 7); otherwise, entering step 3); the method comprises the following specific steps:
2-1) at t0Reading a remote signaling value S of a single-stage blocking signal of the extra-high voltage direct current converter station A from a power grid dispatching center dispatching monitoring system at any moment10 and the latest change time of signal C1＝1511253400；
2-2) at t0At any moment, reading a remote signaling value S of a two-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system20 and the latest change time of signal C2＝0；
2-3) determining whether the following holds:
(S1＝1)∨(t0-C1<T0)∨(S2＝1)∨(t0-C2<T0) (1)
if the formula (1) is established, entering the step 2-4) to carry out emergency control on the near-zone transformer substation of the converter station; if the formula (1) is not satisfied, emergency control is not needed to be carried out on the transformer substation in the near area, and the step 2-5 is carried out;
in this embodiment, if the formula (1) does not hold, the process proceeds to step 2-5);
2-5) restoring the automatic voltage control period of the AVC system to Tc，TcGo to step 3) for 300 seconds.
3) With the current t0Time t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking 1511275800 as a reference1Time interval (set T)1900 seconds) and the future T, and2time interval (set T)2900 seconds), determining the operation trend of the extra-high voltage direct current converter station: if the active transmission power of the converter station is determined to be in the adjusting time period, entering the step 4); if the active transmission power of the converter station is judged to be in the time period just completed by adjustment, the step 5) is carried out; otherwise, judging that the active transmission power of the converter station is in a stable time interval, and entering the step 6); the method comprises the following specific steps:
3-1) with current t0Time being a reference (t)01511275800), reading the past T of the extra-high voltage direct current converter station A from the dispatching monitoring system of the power grid dispatching center1Time period (T)1900 seconds) of active power delivery history, noted
Figure BDA0001489148360000171
Where ti represents the instant of an integer of the past n control cycles,
Figure BDA0001489148360000172
then
Figure BDA0001489148360000173
And determines the past T1The time interval direct current transmission power variation trend comprises the following specific steps:
3-1-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA0001489148360000174
DC transport trend reduction counter
Figure BDA0001489148360000175
3-1-2) if satisfied
Figure BDA0001489148360000176
Then set up
Figure BDA0001489148360000177
Entering step 3-1-3),wherein
Figure BDA0001489148360000178
Determining a power threshold for a predetermined trend (100 in this embodiment); if it is satisfied with
Figure BDA0001489148360000179
Then set up
Figure BDA00014891483600001710
Entering the step 3-1-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-1-3) is carried out;
3-1-3) setting i ═ i +1, and deciding: if i < n is satisfied, returning to the step 3-1-2), otherwise, entering the step 3-1-4);
3-1-4) determining the value of the counter: if it is satisfied with
Figure BDA00014891483600001711
Or
Figure BDA00014891483600001712
It is determined that the dc transmission capacity is T in the past1The time interval changes, marks
Figure BDA00014891483600001713
Otherwise marking
Figure BDA00014891483600001714
Wherein
Figure BDA00014891483600001715
A counter threshold value (typically set to 100) for the dc trend determination;
in this embodiment, the initialization i is 1, and a dc transfer tendency increase counter is provided
Figure BDA00014891483600001716
Decrementing counters
Figure BDA00014891483600001717
Wherein
Figure BDA00014891483600001718
Not meet the requirements of
Figure BDA00014891483600001719
Then
Figure BDA00014891483600001720
Not meet the requirements of
Figure BDA00014891483600001721
Then
Figure BDA00014891483600001722
Not meet the requirements of
Figure BDA00014891483600001723
Then
Figure BDA00014891483600001724
Does not satisfy:
Figure BDA00014891483600001725
then
Figure BDA00014891483600001726
Is provided with
Figure BDA00014891483600001727
Due to the fact that
Figure BDA00014891483600001728
Not meet the requirements of
Figure BDA00014891483600001729
Or
Figure BDA00014891483600001730
It is determined that the dc transmission capacity is T in the past1The time interval is not changed, and is marked
Figure BDA00014891483600001731
3-2) with current t0Time (t)0＝t01511275800) as a reference, reading future T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system2The planned value of active transmission power in the time interval is recorded as
Figure BDA00014891483600001732
Wherein f isiRepresenting the instant of an integer of m control cycles in the future,
Figure BDA0001489148360000181
then
Figure BDA0001489148360000182
And determines the future T2Whether the change trend of the direct current transmission power changes or not in a time period comprises the following specific steps:
3-2-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure BDA0001489148360000183
DC transport trend reduction counter
Figure BDA0001489148360000184
3-2-2) if satisfied
Figure BDA0001489148360000185
Then set up
Figure BDA0001489148360000186
Entering the step 3-2-3); if it is satisfied with
Figure BDA0001489148360000187
Then set up
Figure BDA0001489148360000188
Entering the step 3-2-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-2-3) is carried out;
3-2-3) setting i ═ i +1, and deciding: if the i < m is satisfied, returning to the step 3-2-2), otherwise, entering the step 3-2-4);
3-2-4) determining the value of the counter: if it is satisfied with
Figure BDA0001489148360000189
Or
Figure BDA00014891483600001810
Determining the DC transport capacity in the future T2The time interval will change, mark
Figure BDA00014891483600001811
Otherwise marking
Figure BDA00014891483600001812
In this embodiment, the initialization i is 1, and a dc transfer tendency increase counter is provided
Figure BDA00014891483600001813
Decrementing counters
Figure BDA00014891483600001814
Wherein
Figure BDA00014891483600001815
Not meet the requirements of
Figure BDA00014891483600001816
Then
Figure BDA00014891483600001817
Does not satisfy:
Figure BDA00014891483600001818
then set up
Figure BDA00014891483600001819
Not meet the requirements of
Figure BDA00014891483600001820
Then
Figure BDA00014891483600001821
Does not satisfy:
Figure BDA00014891483600001822
then
Figure BDA00014891483600001823
Due to the fact that
Figure BDA00014891483600001824
Not meet the requirements of
Figure BDA00014891483600001825
Or
Figure BDA00014891483600001826
It is determined that the DC transport capacity is in the future T2The time interval will not change, and mark
Figure BDA00014891483600001827
3-3) judging the active power transmission state of the current converter station, specifically as follows:
if it is satisfied with
Figure BDA00014891483600001828
Judging that the active transmission power of the current converter station is in the adjusting time period, and entering the step 4);
if it is satisfied with
Figure BDA00014891483600001829
Judging that the active transmission power of the current converter station is in the time period just adjusted, and entering step 5);
if it is satisfied with
Figure BDA00014891483600001830
It is determined that the current converter station has active power transmission in the stationary period and step 6) is entered.
In the present embodiment, the following conditions are satisfied
Figure BDA00014891483600001831
Judging that the active transmission power of the current converter station is in a stable time period, and entering step 6);
6) when the active power transmission power of the converter station is in a stable period, the control method of the reactive power equipment of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, reading the constraint condition (the value range is-3000, usually-200) of the converter station to the external reactive power exchange limit value in the bus voltage optimization control, and then entering step 7); the specific steps of the embodiment are as follows:
6-1) checking the bus voltages and out-of-limit conditions of all levels of a near-field substation B of a converter station A, and counting the bus voltages and the out-of-limit conditions as shown in the following table;
table 4 statistics table for bus voltage condition of each stage of substation B
500kV bus voltage (kV) 220kV bus voltage (kV) 35kV voltage (kV)
Upper limit value 523.0 232.0 38.0
Lower limit value 515.0 223.0 33.0
Measured value 518.3 228.1 35.67
Whether or not to exceed the limit Whether or not Whether or not Whether or not
As shown in the table 4, if all the buses of each level of the substation B are out of limit, the AVC system does not generate a strategy for eliminating out-of-limit of the substation B, and the step 6-2) is carried out;
6-2) adjusting the bus i voltage optimization control dead zone parameter of the near-zone transformer substation of the converter station to be Vi dead′＝Vi dead，Vi deadThe method comprises the steps of (1) optimizing and controlling a dead zone parameter for a manually set transformer substation bus i voltage; in this embodiment, let Vi deadAdjusting the bus voltage optimization control dead zone parameters of a converter station A near-zone transformer substation B as 2 kV: vi dead′＝Vi dead＝2kV；
6-3) reading the reactive capacity exchanged between the extra-high voltage direct current converter station A and the external alternating current system from the dispatching center monitoring system
Figure BDA0001489148360000191
And calculating the constraint on the optimized control of the voltage of the B bus of the transformer substation according to the comparison result between the calculated constraint and the preset reactive power exchange fixed value, wherein the constraint is as follows:
6-3-1) setting of optimized control of bus voltage of transformer substation to increase reactive power blocking mark
Figure BDA0001489148360000192
Reactive power reduction blocking mark
Figure BDA0001489148360000193
6-3-2)
Figure BDA0001489148360000194
For a preset upper limit value of reactive capacity exchanged by the converter station a with the external ac system,
Figure BDA0001489148360000195
for a preset lower limit value of reactive capacity exchanged by the converter station a with the external ac system,
Figure BDA0001489148360000196
and determining a dead zone for idle work. Is provided with
Figure BDA0001489148360000197
6-3-3)
Figure BDA0001489148360000198
Then satisfy
Figure BDA0001489148360000199
Then the increased reactive power blocking flag is set:
Figure BDA00014891483600001910
(at this point AVC considers that reactive power cannot be added any more, so the optimization strategy is not implemented).
6-3-4)
Figure BDA00014891483600001911
Let Vi opt521 then Vi opt-Vi dead′＝519，Vi real518.3, satisfies Vi real<Vi opt-Vi deadBut do not satisfy
Figure BDA00014891483600001912
And the transformer substation B does not generate a 500kV bus optimization strategy.
7) And when the next control period comes, returning to the step 2) again, and starting a new round of control calculation.

Claims (4)

1. A reactive voltage coordination control method for an extra-high voltage direct current converter station and a near-field transformer substation is characterized by comprising the following steps:
1) setting an automatic voltage control period to Tc；
2) When each automatic voltage control cycle comes, the coming time is recorded as t0Reading the telecommand values of the single-stage blocking signal and the bipolar blocking signal of the extra-high voltage direct current converter station and the corresponding change time thereof from a dispatching monitoring system of a power grid dispatching center, and if any signal telecommand value is at the nearest T0If the change occurs in the time period, carrying out emergency control on the near-zone transformer substation of the converter station, and entering the step 7); otherwise, entering step 3); the method comprises the following specific steps:
2-1) at t0Reading a remote signaling value S of a single-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system at any moment1And the most recent time of change C of the signal1；
2-2) at t0At any moment, reading a remote signaling value S of a two-stage blocking signal of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system2And the most recent time of change C of the signal2；
2-3) determining whether the following holds:
(S1＝1)∨(t0-C1＜T0)∨(S2＝1)∨(t0-C2＜T0) (1)
if the formula (1) is established, entering the step 2-4) to carry out emergency control on the near-zone transformer substation of the converter station; if the formula (1) does not hold, entering the step 2-5);
2-4) checking the bus voltage of each level in the near-zone transformer substation of the converter station: if the lower limit of the bus voltage is higher, a capacitor or a cut-off reactor is put in; if the bus voltage is higher than the upper limit, cutting off the capacitor or putting in the reactor; then the automatic voltage control period TcModified as Tc′，Tc' is an automatic voltage control period under emergency control, Tc′＜TcEntering step 7);
2-5) restoring the automatic voltage control period to TcEntering step 3);
3) with the current t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking time as a reference1Active transmission power history value of time period, and future T2And (3) judging the operation trend of the extra-high voltage direct current converter station by the active power transmission power plan value in the time period: if the active transmission power of the converter station is determined to be in the adjusting time period, entering the step 4); if the active transmission power of the converter station is judged to be in the time period just completed by adjustment, the step 5) is carried out; otherwise, judging that the active transmission power of the converter station is in a stable time interval, and entering the step 6); the method comprises the following specific steps:
3-1) with current t0Reading past T of the extra-high voltage direct current converter station from a power grid dispatching center dispatching monitoring system by taking time as a reference1The active power transmission history value of the time interval is recorded as
Figure FDA0002425761150000011
Where ti represents the instant of an integer of the past n control cycles,
Figure FDA0002425761150000012
and determines the past T1The time interval direct current transmission power variation trend comprises the following specific steps:
3-1-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure FDA0002425761150000013
DC transport trend reduction counter
Figure FDA0002425761150000021
3-1-2) if satisfied
Figure FDA0002425761150000022
Then set up
Figure FDA0002425761150000023
Go to step 3-1-3), wherein
Figure FDA0002425761150000024
Determining a power threshold for a predetermined trend; if it is satisfied with
Figure FDA0002425761150000025
Then set up
Figure FDA0002425761150000026
Entering the step 3-1-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-1-3) is carried out;
3-1-3) setting i ═ i +1, and deciding: if i is less than n, returning to the step 3-1-2), otherwise, entering the step 3-1-4);
3-1-4) determining the value of the counter: if it is satisfied with
Figure FDA0002425761150000027
Or
Figure FDA0002425761150000028
It is determined that the dc transmission capacity is T in the past1The time interval changes, and the change state of the historical DC transmission capacity is marked
Figure FDA0002425761150000029
Otherwise marking
Figure FDA00024257611500000210
Wherein
Figure FDA00024257611500000211
A counter threshold value for the dc trend determination;
3-2) with current t0Reading the extra-high voltage direct current conversion from a power grid dispatching center dispatching monitoring system by taking the time as a referenceStation future T2The planned value of active transmission power in the time interval is recorded as
Figure FDA00024257611500000212
Wherein f isiRepresenting the instant of an integer of m control cycles in the future,
Figure FDA00024257611500000213
and determines the future T2Whether the change trend of the direct current transmission power changes or not in a time period comprises the following specific steps:
3-2-1) initializing i ═ 1, setting a direct current delivery trend increasing counter
Figure FDA00024257611500000214
DC transport trend reduction counter
Figure FDA00024257611500000215
3-2-2) if satisfied
Figure FDA00024257611500000216
Then set up
Figure FDA00024257611500000217
Entering the step 3-2-3); if it is satisfied with
Figure FDA00024257611500000218
Then set up
Figure FDA00024257611500000219
Entering the step 3-2-3); if the two conditions are not met, the numerical values of the two counters are kept unchanged, and the step 3-2-3) is carried out;
3-2-3) setting i ═ i +1, and deciding: if i is less than m, returning to the step 3-2-2), otherwise, entering the step 3-2-4);
3-2-4) determining the value of the counter: if it is satisfied with
Figure FDA00024257611500000220
Or
Figure FDA00024257611500000221
Determining the DC transport capacity in the future T2The time interval changes, and marks the change state of the future DC transmission capacity
Figure FDA00024257611500000222
Otherwise marking
Figure FDA00024257611500000223
3-3) judging the active power transmission state of the current converter station, specifically as follows:
if it is satisfied with
Figure FDA00024257611500000224
Judging that the active transmission power of the current converter station is in the adjusting time period, and entering the step 4);
if it is satisfied with
Figure FDA00024257611500000225
Judging that the active transmission power of the current converter station is in the time period just adjusted, and entering step 5);
if it is satisfied with
Figure FDA00024257611500000226
Judging that the active transmission power of the current converter station is in a stable time period, and entering step 6); 4) when the active transmission power of the converter station is in the adjusting time period, the reactive equipment control method of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, locking bus voltage optimization control, and then entering step 7);
5) when the active power transmission power of the converter station is in the period of just completing the adjustment, the reactive power equipment control method of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, automatically reducing parameters of bus voltage optimization dead zones of the transformer substation to increase the switching control of the transformer substation on reactive equipment, and then entering step 7);
6) when the active power transmission power of the converter station is in a stable period, the control method of the reactive power equipment of the near-region transformer substation comprises the following steps: checking the bus voltage and out-of-limit conditions of each level in a near-zone transformer substation of the converter station, eliminating voltage out-of-limit, performing bus voltage optimization control, reading the constraint condition of the converter station on the external reactive power exchange limit value in the bus voltage optimization control, and then entering step 7);
7) and when the next control period comes, returning to the step 2) again, and starting a new round of control calculation.
2. The method as claimed in claim 1, wherein the step 4) comprises the following specific steps:
4-1) checking the bus voltage and out-of-limit conditions of each level in the converter station near-field substation: if the lower limit of the bus voltage is lower, a capacitor is put in or the reactor is cut off, and the step 7) is carried out; if the bus voltage is higher than the upper limit, cutting off the capacitor or putting in the reactor, and entering step 7); if the out-of-limit condition does not exist, entering the step 4-2);
4-2) locking the bus voltage optimization control calculation of the near-zone transformer substation of the converter station, and entering the step 7).
3. The method as claimed in claim 1, wherein the step 5) comprises the following specific steps:
5-1) checking the bus voltage and out-of-limit conditions of each level in the converter station near-field substation: if the lower limit of the bus voltage is lower, a capacitor is put in or the reactor is cut off, and the step 7) is carried out; if the bus voltage is higher than the upper limit, generating a cut capacitor or an input reactor, and entering the step 7); if the out-of-limit condition does not exist, entering the step 5-2);
5-2) adjusting the bus i voltage optimization control dead zone parameters of the near-zone transformer substation of the converter station as follows: vi dead′＝Vi dead/2，Vi deadThe method comprises the steps of (1) optimizing and controlling a dead zone parameter for the voltage of a transformer substation bus i set manually;
5-3) checking the bus voltage of the substation: if V is satisfiedi real＜Vi opt-Vi dead′Then putting a capacitor or cutting off the reactor; if V is satisfiedi real＜Vi opt+Vi dead′Cutting off the capacitor or putting in the reactor; wherein, Vi realAs a voltage measurement of the bus i, Vi optOptimizing a target value for the voltage of the bus i; proceed to step 7).
4. The method as claimed in claim 1, wherein the step 6) comprises the following specific steps:
6-1) checking the bus voltage and out-of-limit conditions of each level in the converter station near-field substation: if the lower limit of the bus voltage is lower, a capacitor is put in or the reactor is cut off, and the step 7) is carried out; if the bus voltage is higher than the upper limit, cutting off the capacitor or putting in the reactor, and entering step 7); if the out-of-limit condition does not exist, entering the step 6-2);
6-2) adjusting the bus i voltage optimization control dead zone parameters of the near-zone transformer substation of the converter station as follows: vi dead′＝Vi dead，Vi deadThe method comprises the steps of (1) optimizing and controlling a dead zone parameter for a manually set transformer substation bus i voltage;
6-3) reading the reactive capacity exchanged between the extra-high voltage direct current converter station and the external alternating current system from the dispatching center monitoring system
Figure FDA0002425761150000041
And calculating constraint conditions for optimal control of the bus voltage of the transformer substation according to the comparison result between the calculated constraint conditions and a preset external reactive power exchange limit value, wherein the constraint conditions are as follows:
6-3-1) setting I voltage optimization control reactive power increasing blocking mark of transformer substation bus
Figure FDA0002425761150000042
I voltage optimal control reactive power reduction locking mark for transformer substation bus
Figure FDA0002425761150000043
6-3-2) is provided with
Figure FDA0002425761150000044
For a preset upper limit value of reactive capacity exchanged by the converter station and the external ac system,
Figure FDA0002425761150000045
for a preset lower limit value of reactive capacity exchanged by the converter station with the external ac system,
Figure FDA0002425761150000046
determining a dead zone for reactive power; if so:
Figure FDA0002425761150000047
then set up
Figure FDA0002425761150000048
Otherwise if:
Figure FDA0002425761150000049
then set up
Figure FDA00024257611500000410
6-3-4) if satisfied
Figure FDA00024257611500000411
Then the capacitor is put in or the reactor is cut off; if it is satisfied with
Figure FDA00024257611500000412
Cutting off the capacitor or putting the reactor into the reactor; otherwise, not carrying out optimization control; entering step 7); wherein, Vi realAs a voltage measurement of the bus i, Vi optThe target value is optimized for the voltage of bus i.
CN201711236861.XA 2017-11-30 2017-11-30 Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation Expired - Fee Related CN107959303B (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN201711236861.XA CN107959303B (en) 2017-11-30 2017-11-30 Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
CN201711236861.XA CN107959303B (en) 2017-11-30 2017-11-30 Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation

Publications (2)

Publication Number Publication Date
CN107959303A CN107959303A (en) 2018-04-24
CN107959303B true CN107959303B (en) 2020-06-26

Family

ID=61962700

Family Applications (1)

Application Number Title Priority Date Filing Date
CN201711236861.XA Expired - Fee Related CN107959303B (en) 2017-11-30 2017-11-30 Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation

Country Status (1)

Country Link
CN (1) CN107959303B (en)

Families Citing this family (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN109193736B (en) * 2018-09-26 2021-08-20 云南电网有限责任公司电力科学研究院 STATCOM self-adaptive voltage control method applied to direct current converter station
CN110011320B (en) * 2019-03-29 2022-08-19 国电南瑞科技股份有限公司 Reactive voltage optimization control method and system for extra-high voltage alternating current transformer substation
CN110676857B (en) * 2019-10-28 2021-05-14 南方电网科学研究院有限责任公司 Reactive compensation method, device and equipment
CN110808583A (en) * 2019-11-06 2020-02-18 国网北京市电力公司 Multi-objective-oriented substation optimization control method
CN110994624B (en) * 2019-11-14 2023-02-24 国网新疆电力有限公司 Voltage control method for avoiding voltage out-of-limit caused by extra-high voltage direct current converter station fault
CN110932287B (en) * 2019-11-14 2023-03-24 国网新疆电力有限公司 Power grid voltage control method for reducing near-zone voltage fluctuation of extra-high voltage direct current converter station
CN110994626B (en) * 2019-12-31 2023-03-24 云南电网有限责任公司昆明供电局 500-220kV regional power grid automatic voltage control method based on voltage trend prediction
CN111799811B (en) * 2020-07-13 2023-04-14 国家电网公司西北分部 Reactive replacement method for phase modulator of extra-high voltage converter station and near-region power plant in power grid
CN113595098A (en) * 2021-08-23 2021-11-02 南方电网科学研究院有限责任公司 Tap joint control method, device and equipment for converter transformer
CN114374211B (en) * 2021-12-10 2024-01-30 国网重庆市电力公司市区供电分公司 Automatic voltage control method and device considering energy storage active plan

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
自动电压控制中厂站时序协调控制方法的研究;杨银国等;《陕西电力》;20150520;第43卷(第5期);第71-75页 *

Also Published As

Publication number Publication date
CN107959303A (en) 2018-04-24

Similar Documents

Publication Publication Date Title
CN107959303B (en) Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field transformer substation
CN107834567B (en) Reactive voltage coordination control method for extra-high voltage direct current converter station and near-field power plant
CN108493950B (en) Ultra-high voltage direct current near-region multi-stage power grid coordinated automatic voltage control method and system
CN110932287B (en) Power grid voltage control method for reducing near-zone voltage fluctuation of extra-high voltage direct current converter station
CN103812112B (en) A kind of area power grid AVC control method
CN104201693A (en) Power distribution line reactive power optimization control method based on dynamic adjustment of power factor interval
CN103595135A (en) Intelligent reactive power optimization and coordinated control system of middle-and-low-voltage regional power grid
CN110854870B (en) Bus voltage automatic correction control method considering static synchronous compensator
CN107863777B (en) It is a kind of to consider powerless control method when low anti-sending end converter station high power fluctuates
CN107910877B (en) Switching control method for parallel capacitor in high-power fluctuation of sending end converter station
CN206850446U (en) A kind of intelligent load-balancing regulator
WO2023108384A1 (en) Comprehensive identification index-based energy storage multi-scenario application switching control method
CN113659582B (en) Comprehensive regulation and control method and system for transformer area voltage based on intelligent transformer area fusion terminal
CN110994624B (en) Voltage control method for avoiding voltage out-of-limit caused by extra-high voltage direct current converter station fault
CN103972897A (en) Method for determining control range of operation voltage of 500kV bus of extra-high voltage alternating-current transformer substation
CN102290818A (en) Automatic control system for reactive power of regional power grid
CN113555878A (en) Platform district electric energy quality synthesizes compensation system
CN103166236B (en) A kind of AVC joint debugging method based on stillness wattless occurrence apparatus
CN106356866A (en) Automatic voltage control substation device of intelligent substation and control method thereof
CN106487022A (en) A kind of rural area low-voltage administering method
CN202190125U (en) Automatic voltage and reactive power control device for regional power grid
CN109659950A (en) Become the powerless control system and method for the voltage source converter of lower voltage limit
CN107492932A (en) A kind of charge protection method and system of DC charging unit
CN108075477B (en) Electric power system voltage regulating method based on electric heat storage device
Azzouz Voltage Regulation in Smart Grids

Legal Events

Date Code Title Description
PB01 Publication
PB01 Publication
SE01 Entry into force of request for substantive examination
SE01 Entry into force of request for substantive examination
GR01 Patent grant
GR01 Patent grant
CF01 Termination of patent right due to non-payment of annual fee

Granted publication date: 20200626

Termination date: 20201130

CF01 Termination of patent right due to non-payment of annual fee