A distribution network reactive power compensation control method, device, equipment and storage medium

Abstract

The present invention discloses a reactive power compensation control method, device, equipment and storage medium for distribution network. The first current and voltage data and the first historical active load data acquired are updated in real time through the change of the number of distribution transformers in the line, and the predicted active power and the predicted reactive power of each distribution transformer at the system scoring moment are calculated according to the updated first historical active load data and the first current and voltage data; the predicted active power and the predicted reactive power are calculated to obtain the predicted reactive power control scheme at the system scoring moment, so that the distribution network is subjected to reactive power compensation control according to the predicted reactive power compensation control scheme. Compared with the prior art, the present invention utilizes ultra-short-term load forecasting to realize the pre-determination of the reactive power compensation control scheme, effectively alleviates the situation where the timeliness between reactive power demand and reactive power compensation is poor, and improves the effectiveness of reactive power compensation.

Description

Technical Field

[0001] The present invention relates to the technical field of reactive power compensation for distribution networks, and in particular to a reactive power compensation control method, device, equipment and storage medium for distribution networks. Background Art

[0002] With the rapid development of the economy, power sources and load types have been greatly enriched. With the access of various new energy power sources and the use of various new home appliances and new production equipment, the line grid structure has gradually transitioned from a single radial structure to a complex structure with multiple power outputs and multiple load types. At the same time, with the proposal of building a new power system, higher requirements are put forward for the power supply quality, making the current reactive compensation device control unable to effectively meet the power grid's demand for reactive compensation control.

[0003] At present, the reactive power compensation devices in distribution networks are still mainly slow-motion devices, which have a certain response time. However, the cost of replacing them with fast-action devices is relatively high. For a certain period of time, the reactive power compensation devices in distribution networks will still be mainly slow-motion devices. As the frequency of changes in reactive power demand gradually increases, the action frequency of reactive power compensation equipment also increases synchronously. However, due to the limitation of the response time of the slow-motion equipment itself, there is a phenomenon of poor timeliness between reactive power demand and reactive power compensation. At the same time, frequent equipment action will reduce the service life of the equipment, which will weaken the compensation effect. Summary of the invention

[0004] The technical problem to be solved by the present invention is to provide a distribution network reactive power compensation control method, device, equipment and storage medium to improve the timeliness of reactive power compensation.

[0005] In order to solve the above technical problems, the present invention provides a distribution network reactive power compensation control method, comprising:

[0006] Obtain the first current and voltage data of all distribution transformers in the line, and at the same time obtain the line dispatching operation instructions of the day and the first historical active load data of all distribution transformers;

[0007] Determine whether there is a line topology change between the system scoring time and the current time according to the line dispatching operation instruction of the day, and if so, update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line;

[0008] Calculate the predicted active power of each distribution transformer at the system scoring time according to the updated first historical active load data, and calculate the predicted reactive power of each distribution transformer at the system scoring time according to the updated first current and voltage data and the predicted active power;

[0009] The predicted active power and the predicted reactive power are subjected to flow calculation to obtain a predicted reactive power compensation control scheme at the system scoring moment, so that reactive power compensation control is performed on the distribution network according to the predicted reactive power compensation control scheme.

[0010] In a possible implementation, after obtaining the predicted reactive power compensation control scheme at the system scoring moment, the method further includes:

[0011] Determine whether the comparison feature value of the predicted reactive power compensation control scheme is 1. If so, implement the predicted reactive power compensation control scheme at a preset time. If not, abandon the predicted reactive power compensation control scheme and maintain the current reactive power compensation control scheme.

[0012] In a possible implementation manner, the determining whether the comparison eigenvalue of the predicted reactive power compensation control scheme is 1 specifically includes:

[0013] Calculating the difference between the reactive compensation amount of the current reactive compensation control scheme and the predicted reactive compensation control scheme at each distribution transformer, generating a difference data group, and calculating the difference average value of the difference data group;

[0014] Determine whether there is a value greater than a first specified value in the difference data group, and if so, output the comparison characteristic value of the predicted reactive power compensation control scheme as 1;

[0015] If not, determine whether the difference average value is greater than a second specified value. If so, output the comparison characteristic value of the predicted reactive power compensation control scheme as 1; if not, output the comparison characteristic value of the predicted reactive power compensation control scheme as not 1.

[0016] In a possible implementation, updating the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line specifically includes:

[0017] According to the line dispatching operation instruction of the day, determine whether the change in the number of distribution transformers in the line is a transfer to the distribution transformer of the current line; if so, collect the second current and voltage data of the transfer to the distribution transformer of the current line, and the second historical active load data of the transfer to the distribution transformer of the current line, and add the second current and voltage data and the second historical active load data to the first current and voltage data and the first historical active load data accordingly, so as to update the first current and voltage data and the first historical active load data;

[0018] According to the line dispatching operation instructions of the day, determine whether the change in the number of distribution transformers in the line is the transfer of distribution transformers from this line. If so, collect the third current and voltage data of the distribution transformer transferred from this line, and the third historical active load data of the distribution transformer transferred from this line, and delete the third current and voltage data and the third historical active load data in the first current and voltage data and the first historical active load data to update the first current and voltage data and the first historical active load data.

[0019] In a possible implementation, the step of calculating the predicted active power of each distribution transformer at the system scoring time according to the updated first historical active load data specifically includes:

[0020] The updated first historical active load data includes a first interval active load data group and a second interval active load data group;

[0021] Preprocessing the first interval active load data group to obtain a first active load value at the system scoring moment;

[0022] Determine whether the first active load value needs to be corrected. If so, correct the first active load value according to the second interval active load data group, and use the corrected first active load value as the predicted active power of each distribution transformer at the system scoring moment. If not, use the first active load value as the predicted active power of each distribution transformer at the system scoring moment.

[0023] In a possible implementation, the calculating, according to the updated first current and voltage data and the predicted active power, the predicted reactive power of each distribution transformer at the system scoring time specifically includes:

[0024] Obtaining and calculating the power factor corresponding to each distribution transformer based on the current phase angle and voltage phase angle in the updated first current and voltage data;

[0025] Based on the power factor and the predicted active power, the predicted reactive power of each distribution transformer at the system scoring moment is calculated.

[0026] In a possible implementation manner, before performing power flow calculation on the predicted active power and the predicted reactive power, the method further includes:

[0027] respectively correcting the predicted reactive power and the predicted active power;

[0028] Determine whether the impact of the external environment change at the system scoring moment compared to the current moment on the reactive power exceeds a first preset threshold, and if so, set corresponding environmental coefficients to the predicted reactive power and the predicted active power respectively;

[0029] If not, determine whether the influence of the line change at the system scoring moment compared to the current moment on the reactive power exceeds a second preset threshold, and if so, set corresponding line coefficients to the predicted reactive power and the predicted active power respectively;

[0030] If not, determine whether the load of each distribution transformer has changed compared to the current moment at the system scoring moment, and if so, determine the active power change value and the reactive power change value respectively;

[0031] The corrected predicted reactive power and the predicted active power are calculated according to the environmental coefficient, the line coefficient, the active power change value and the reactive power change value.

[0032] The present invention also provides a distribution network reactive power compensation control device, comprising a main control module, a communication module, a current acquisition module, a voltage acquisition module and a line data storage module;

[0033] Wherein, the main control module is connected to the communication module and the line data storage module respectively;

[0034] The communication module is connected to the current acquisition module and the voltage acquisition module respectively;

[0035] The main control module includes a distribution transformer data acquisition unit, a distribution transformer data update unit, a data prediction unit and a solution generation unit;

[0036] The distribution transformer data acquisition unit is used to acquire the first current and voltage data of all distribution transformers in the line acquired by the voltage acquisition module and the current acquisition module through the communication module, and acquire the line scheduling operation instructions of the day and the first historical active load data of all distribution transformers through the line data storage module;

[0037] The distribution transformer data updating unit is used to determine whether there is a line topology change between the system scoring time and the current time according to the line scheduling operation instruction of the day, and if so, update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line;

[0038] The data prediction unit is used to calculate the predicted active power of each distribution transformer at the system scoring moment according to the updated first historical active load data, and to calculate the predicted reactive power of each distribution transformer at the system scoring moment according to the updated first current and voltage data and the predicted active power;

[0039] The scheme generating unit is used to perform power flow calculation on the predicted active power and the predicted reactive power to obtain the predicted reactive compensation control scheme at the system scoring moment, so as to perform reactive compensation control on the distribution network according to the predicted reactive compensation control scheme.

[0040] In a possible implementation, the main control module further includes: a scheme verification unit;

[0041] The scheme verification unit is used to determine whether the comparison feature value of the predicted reactive power compensation control scheme is 1. If so, the predicted reactive power compensation control scheme is implemented at a preset time. If not, the predicted reactive power compensation control scheme is abandoned and the current reactive power compensation control scheme is maintained.

[0042] In a possible implementation, the scheme verification unit is used to determine whether the comparison eigenvalue of the predicted reactive power compensation control scheme is 1, specifically including:

[0043] Calculating the difference between the reactive compensation amount of the current reactive compensation control scheme and the predicted reactive compensation control scheme at each distribution transformer, generating a difference data group, and calculating the difference average value of the difference data group;

[0044] Determine whether there is a value greater than a first specified value in the difference data group, and if so, output the comparison characteristic value of the predicted reactive power compensation control scheme as 1;

[0045] If not, determine whether the difference average value is greater than a second specified value. If so, output the comparison characteristic value of the predicted reactive power compensation control scheme as 1; if not, output the comparison characteristic value of the predicted reactive power compensation control scheme as not 1.

[0046] In a possible implementation, the distribution transformer data updating unit is used to update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line, specifically including:

[0047] According to the line dispatching operation instruction of the day, determine whether the change in the number of distribution transformers in the line is a transfer to the distribution transformer of the current line; if so, collect the second current and voltage data of the transfer to the distribution transformer of the current line, and the second historical active load data of the transfer to the distribution transformer of the current line, and add the second current and voltage data and the second historical active load data to the first current and voltage data and the first historical active load data accordingly, so as to update the first current and voltage data and the first historical active load data;

[0048] According to the line dispatching operation instructions of the day, determine whether the change in the number of distribution transformers in the line is the transfer of distribution transformers from this line. If so, collect the third current and voltage data of the distribution transformer transferred from this line, and the third historical active load data of the distribution transformer transferred from this line, and delete the third current and voltage data and the third historical active load data in the first current and voltage data and the first historical active load data to update the first current and voltage data and the first historical active load data.

[0049] In a possible implementation, the data prediction unit is used to calculate the predicted active power of each distribution transformer at the system scoring time according to the updated first historical active load data, specifically including:

[0050] The updated first historical active load data includes a first interval active load data group and a second interval active load data group;

[0051] Preprocessing the first interval active load data group to obtain a first active load value at the system scoring moment;

[0052] Determine whether the first active load value needs to be corrected. If so, correct the first active load value according to the second interval active load data group, and use the corrected first active load value as the predicted active power of each distribution transformer at the system scoring moment. If not, use the first active load value as the predicted active power of each distribution transformer at the system scoring moment.

[0053] In a possible implementation, the data prediction unit is used to calculate the predicted reactive power of each distribution transformer at the system scoring time according to the updated first current and voltage data and the predicted active power, specifically including:

[0054] Obtaining and calculating the power factor corresponding to each distribution transformer based on the current phase angle and voltage phase angle in the updated first current and voltage data;

[0055] Based on the power factor and the predicted active power, the predicted reactive power of each distribution transformer at the system scoring moment is calculated.

[0056] In a possible implementation manner, the solution generating unit is used, before performing power flow calculation on the predicted active power and the predicted reactive power, to:

[0057] respectively correcting the predicted reactive power and the predicted active power;

[0058] Determine whether the impact of the external environment change at the system scoring moment compared to the current moment on the reactive power exceeds a first preset threshold, and if so, set corresponding environmental coefficients to the predicted reactive power and the predicted active power respectively;

[0059] If not, determine whether the influence of the line change at the system scoring moment compared to the current moment on the reactive power exceeds a second preset threshold, and if so, set corresponding line coefficients to the predicted reactive power and the predicted active power respectively;

[0060] If not, determine whether the load of each distribution transformer has changed compared to the current moment at the system scoring moment, and if so, determine the active power change value and the reactive power change value respectively;

[0061] The corrected predicted reactive power and the predicted active power are calculated according to the environmental coefficient, the line coefficient, the active power change value and the reactive power change value.

[0062] The present invention also provides a terminal device, comprising a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor, wherein when the processor executes the computer program, the distribution network reactive compensation control method as described in any one of the above items is implemented.

[0063] The present invention also provides a computer-readable storage medium, which includes a stored computer program, wherein when the computer program is running, the device where the computer-readable storage medium is located is controlled to execute the distribution network reactive power compensation control method as described in any one of the above.

[0064] The embodiment of the present invention provides a distribution network reactive power compensation control method, device, equipment and storage medium, which have the following beneficial effects compared with the prior art:

[0065] By acquiring relevant first current and voltage data and first historical active load data of each distribution transformer in the line, and based on the change of the line topology structure, the first current and voltage data and the first historical active load data are updated; according to the updated first historical active load data, the predicted active power of each distribution transformer at the system scoring moment is calculated, and according to the updated first current and voltage data and the predicted active power, the predicted reactive power of each distribution transformer at the system scoring moment is calculated; the predicted active power and the predicted reactive power are calculated to obtain the predicted reactive compensation control scheme at the system scoring moment, so that the distribution network is subjected to reactive compensation control according to the predicted reactive compensation control scheme. Compared with the prior art, the present invention utilizes ultra-short-term load forecasting to realize the pre-determination of the reactive compensation control scheme. By implementing the predicted reactive compensation control scheme in advance, the situation of poor timeliness between reactive demand and reactive compensation can be effectively alleviated, thereby improving the timeliness of reactive compensation. BRIEF DESCRIPTION OF THE DRAWINGS

[0066] Figure 1 It is a flow chart of an embodiment of a distribution network reactive power compensation control method provided by the present invention;

[0067] Figure 2 It is a structural schematic diagram of an embodiment of a distribution network reactive power compensation control device provided by the present invention;

[0068] Figure 3 is a structural schematic diagram of an embodiment of a main control module provided by the present invention;

[0069] Figure 4 is a structural schematic diagram of another embodiment of the main control module provided by the present invention;

[0070] Figure 5 It is a structural schematic diagram of another embodiment of a distribution network reactive power compensation control device provided by the present invention. DETAILED DESCRIPTION

[0071] The following will be combined with the accompanying drawings in the present invention to clearly and completely describe the technical solutions in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0072] Example 1

[0073] See also Figure 1 , Figure 1 FIG. 1 is a flow chart of an embodiment of a reactive power compensation control method for a distribution network provided by the present invention. Figure 1As shown, the method includes steps 101 to 104, which are specifically as follows:

[0074] Step 101: Acquire the first current and voltage data of all distribution transformers in the line, and simultaneously acquire the line dispatching operation instructions of the day and the first historical active load data of all distribution transformers.

[0075] In one embodiment, first current data I0 and first voltage data U0 of all distribution transformers in the line are obtained.

[0076] In one embodiment, the first current data I0 and the first voltage data U0 can be expressed by vectors, as Where I and U are the effective values ​​of the collected current and voltage respectively. are the phase angles of the collected current and voltage respectively.

[0077] In one embodiment, the line dispatching operation instructions of the day and the first historical active load data of all distribution transformers are obtained, wherein the first historical active load data includes a first interval active load data group D01 of each distribution transformer at an interval of 15 minutes 10 days before the day and a second interval active load data group D02 of each distribution transformer at an interval of 15 minutes on the day 2 years before the current year.

[0078] In one embodiment, the first interval active load data group D01 is the active load data of 15 minutes interval 10 days before the day when reactive compensation prediction is required for all distribution transformers of the line. For example, the date when reactive compensation prediction is required is January 4, 2022, then the first interval active load data group D01 should include the active load data of 15 minutes interval of the line from December 26, 2021 to December 31, 2021 and from January 1, 2022 to January 4, 2022, a total of 10 days. And they are sorted in chronological order from early to late.

[0079] The second interval active load data group D02 is the active load data at 15-minute intervals on the day when reactive compensation prediction is required for the line in the previous three years of this year. For example, if the date when reactive compensation prediction is required is January 4, 2022, the second interval active load data group D02 should contain the active load data at 15-minute intervals on the line on January 4, 2021 and January 4, 2020, a total of 2 days. And they are sorted in chronological order from early to late.

[0080] Step 102: Determine whether there is a line topology change between the system scoring time and the current time according to the line dispatching operation instruction of the day, and if so, update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line.

[0081] In one embodiment, it is determined whether there is a scheduling instruction at the line system scoring time t1 compared with the current time t0. If yes, it is considered that there is a line topology change; if not, it is considered that there is no line topology change.

[0082] In one embodiment, when there is a change in the line topology, it is determined whether the change in the number of distribution transformers in the line is a transfer to the distribution transformer of the line according to the line scheduling operation instruction of the day. If so, the second current and voltage data of the transfer to the distribution transformer of the line and the second historical active load data of the transfer to the distribution transformer of the line are collected, and the second current and voltage data and the second historical active load data are added to the first current and voltage data and the first historical active load data accordingly, so as to update the first current and voltage data and the first historical active load data. Specifically: the current data and voltage value data of the transfer to the distribution transformer of the line are collected, and the corresponding active power and reactive power are calculated, and the first interval active load data group corresponding to the transfer to the distribution transformer of the line with an interval of 15 minutes on the day 10 days ago and the second interval active load data group corresponding to the day 2 years ago of the year are collected, and the original first current and voltage data and the first historical active load data are updated.

[0083] In one embodiment, it is determined whether the change in the number of distribution transformers in the line is a distribution transformer transferred out of the line according to the line dispatching operation instruction of the day. If so, the third current and voltage data of the distribution transformer transferred out of the line and the third historical active load data of the distribution transformer transferred out of the line are collected, and the third current and voltage data and the third historical active load data in the first current and voltage data and the first historical active load data are deleted to update the first current and voltage data and the first historical active load data. Specifically: the power supply data, voltage data, active load value and reactive load value corresponding to the distribution transformer transferred out of the line are removed from the first current and voltage data; the first interval active load data group corresponding to the distribution transformer transferred out of the line with an interval of 15 minutes on the day 10 days ago and the first interval active load data group corresponding to the day 2 years ago of the current year are removed from the first historical active load data, and the original first current and voltage data and the first historical active load data are updated.

[0084] In one embodiment, if there is no line topology change, the original first current and voltage data and the first historical active load data are used as the updated first current and voltage data and the first historical active load data.

[0085] Step 103: Calculate the predicted active power of each distribution transformer at the system scoring time according to the updated first historical active load data, and calculate the predicted reactive power of each distribution transformer at the system scoring time according to the updated first current and voltage data and the predicted active power.

[0086] In one embodiment, the first interval active load data group in the updated first historical active load data is preprocessed to obtain the first active load value at the system scoring moment.

[0087] Specifically: perform weighted averaging on the data from the first to ninth days in the updated first interval active load data group D01, fit the weighted average data using a polynomial function, substitute the data from the tenth day into the fitted polynomial function to obtain the first active load value P1 at the system scoring time t1.

[0088] The first active load value P1 is added to the updated first interval active load data group D01 as data of the system scoring time t1 on the tenth day in the updated first interval active load data group D01.

[0089] In this embodiment, when weighted averaging is performed on the data from the first day to the ninth day in the updated first interval active load data group D01, the weighted value of each data can be set by oneself.

[0090] As an example in this embodiment, the weighted value is 0.25 for the first to third days, 0.35 for the fourth to sixth days, and 0.4 for the seventh to ninth days. For example, at the system scoring time t1, the active power value from the first to ninth days is p 1 、p 2 、p 3 、p 4 、p 5 、p 6 、p 7 、p 8 、p 9 , then the first active load value of the weighted system scoring time t1, P t1 =0.25×(p 1 +p 2 +p 3 )+0.35×(p 4 +p 5 +p 6 )+0.4×(p 7 +p 8 +p 9 ).

[0091] In one embodiment, it is determined whether the first active load value needs to be corrected. If so, the first active load value is corrected according to the second interval active load data group, and the corrected first active load value is used as the predicted active power P of each distribution transformer at the system scoring moment. If not, the first active load value is used as the predicted active power P of each distribution transformer at the system scoring moment.

[0092] Specifically: calculate the first average value of the active load data at the corresponding time of each day in the updated second interval active load data group D02 to obtain the average value data group ED02; and calculate the absolute value of the difference between each active load data in the second interval active load data group D02 and the active load data at the corresponding time of the average value data group to obtain the first absolute value data group ΔED02; calculate the absolute value of the difference between the active load data at each time of each day in the second interval active load data group D02 and the active load data at the corresponding time of the tenth day in the first interval active load data group D01 to generate the second absolute value data group ΔD02.

[0093] As an example in this embodiment: there are 2 days of data in the D02 data group, namely D021 and D022. The data of the two days at time t1 are D021t1 and D022t1 respectively. Then the first average value of the active load data at time t1 is ED02t1=(D021t1+D022t1) / 2, and the data of all times in the ED02 data group are calculated in sequence; the absolute values ​​of the load difference of the two days at time t1 are ΔED021t1 and ΔED022t1 respectively, ΔED021t1=|ED02t 1-D021t1|, ΔED022t1=|ED02t1-D022t1|, calculate the data of all time points in the ΔED02 data group in sequence; the data at time t1 of the tenth day in the D01 data group is D0110t1, and the absolute values ​​of the difference with time t1 of each day in the D02 data group are ΔD021t1 and ΔD022t1 respectively, then ΔD021t1=|D0110t1-D021t1|, ΔD021t1=|D0110t1-D022t1|, calculate the data in ΔD02 in sequence.

[0094] In one embodiment, it is determined whether there is any active load data at any moment in the second absolute value data group that is greater than a first preset threshold, and whether all absolute value data in the first absolute value data group are less than a second preset threshold. If so, the second average value of all absolute value data at the system scoring moment in the second absolute value data group is calculated, and based on the second average value, the first active load value is updated to obtain a second active load value, and the second active load value is used as the predicted active power of each distribution transformer at the system scoring moment; if not, the first active load value is used as the predicted active power of each distribution transformer at the system scoring moment.

[0095] Specifically, based on the acquired second absolute value data group ΔD02, determine whether there is at least one moment in the second absolute value data group ΔD02 in which the value in the data group is greater than 25% of the moment corresponding to the data of the tenth day in D01, and whether the data in the first absolute value data group ΔED02 are all less than 0.5MW; if so, calculate the average value EΔD02t1 of the data at time t1 in the second absolute value data group ΔD02, and obtain the second active load value P2 based on a preset formula, wherein the preset formula is: P2=0.7×P1+0.3×EΔD02t1; if not, do not modify the first active load value.

[0096] In one embodiment, the predicted reactive power of each distribution transformer at the system scoring time is calculated based on the updated first current and voltage data and the predicted active power.

[0097] In this embodiment, by obtaining and based on the current phase angle in the updated first current and voltage data and voltage phase angle Calculate the power factor corresponding to each distribution transformer in

[0098] Based on the power factor and the predicted active power P, calculate the predicted reactive power Q of each distribution transformer at the time of system scoring, where:

[0099] Step 104: Perform power flow calculation on the predicted active power and the predicted reactive power to obtain a predicted reactive compensation control scheme at the system scoring moment, so as to perform reactive compensation control on the distribution network according to the predicted reactive compensation control scheme.

[0100] In one embodiment, before performing power flow calculation on the predicted active power and the predicted reactive power, the method further includes respectively correcting the predicted reactive power and the predicted active power.

[0101] It is determined whether the impact of the external environment change at the time of system scoring compared to the current time on the reactive power exceeds the first preset threshold. If so, the corresponding environmental coefficients are set for the predicted reactive power and the predicted active power respectively. The external environment includes temperature and humidity, and the information comes from the weather forecast of the meteorological department. The change of power load is determined based on the impact of temperature, humidity, etc. on the user's power consumption habits.

[0102] Specifically: Set the suggested function to y 1 =(ax+b) 2 , where y 1is the value of the temperature or humidity impact to be determined; x is the change in temperature or humidity at time t1 compared to time t0; a and b are setting parameters used to set the user's sensitivity to temperature or humidity changes. Calculate y 1 Then it is compared with the first preset threshold δ1 to determine whether the environmental change has an impact on the load. δ1 is a manually set value, which is set according to the user's sensitivity to environmental changes. And the environmental coefficient λ corresponding to the predicted reactive power 11 and the environmental factor λ for predicting active power settings 12 It can also be set manually. In this embodiment, a piecewise function is used to determine the environmental coefficient corresponding to the predicted reactive power and the predicted active power. The piecewise function is as follows:

[0103]

[0104] As an example in this embodiment: for a factory with constant temperature and humidity requirements, the environmental impact expression adopted is y 1 =(0.5x+0.1) 2 , δ1=1.1, the system scoring time t1 is 14:00, the current time t0 is 13:30, the system scoring time t1 is 2 degrees higher than the current time t0, and the humidity increases by 1%, that is, 0.01, then the temperature impact value is y 1 =(0.5×2+0.1) 2 =1.21, the humidity influence is y 1 =(0.5×0.01+0.1) 2 =0.01, then the total impact degree y 1 =1.21+0.01=1.22,y 1 is 1.11 times of δ1, so λ 11 =1.05,λ 12 =1.07.

[0105] In one embodiment, it is determined whether the impact of the line's own changes at the system scoring moment compared to the current moment on the reactive power exceeds a second preset threshold. If so, corresponding line coefficients are set for the predicted reactive power and the predicted active power, respectively; wherein, the line's own changes are changes only caused by the line's own composition, such as a certain branch line being changed from an overhead line to a cable line, and the line's own change data comes from scheduling, and it is determined whether there is a change in the line composition from the current moment to the system scoring moment, and based on the change, the change in the power load is determined.

[0106] Specifically: The influence of line changes on load is measured by y 2 =ax+b, where y 2is the influence degree of the line to be determined; x is the length of the line itself that changes at time t1 compared to time t0; a and b are setting parameters used to set the sensitivity of the line load to the change of line composition. Calculate y 2 Then with δ 2 Compare and determine the impact of line composition changes on load changes. 2 Artificially set value, set according to the line load characteristics and line length, predict the line coefficient λ corresponding to reactive power 21 , the line coefficient λ22 corresponding to the predicted active power can also be set manually. In this embodiment, a piecewise function is used to determine the line coefficient corresponding to the predicted reactive power and the predicted active power. The piecewise function is as follows:

[0107] When changing from an overhead line to a cable line:

[0108] When changing from cable line to overhead line:

[0109] As an example in this embodiment: a line changes a 1.2 km cable line to an overhead line between the current time and the system scoring time, and takes δ 2 =0.5,y 2 =0.1x+0.5=0.1×1.2+0.5=0.62, y 2 is δ 2 1.24 times, then λ 21 =0.99,λ 22 =0.99.

[0110] In one embodiment, it is determined whether the load of each distribution transformer has changed compared to the current moment at the time of system scoring. If so, the active power change value and the reactive power change value are determined respectively. Among them, the factors of the load change of each distribution transformer include the factors that the user actively increases or decreases the motor load, the user changes the single-phase power supply to the three-phase power supply, and other factors that cause the user to maintain the changed state for a long time due to production or life needs, and the data source is scheduling.

[0111] Specifically, the active power change expression is set to λ 31 =ax, the reactive power change expression is λ 32 =by, where x and y are the active power change value and reactive power change value respectively; a and b are the active power effective change rate and reactive power effective change rate respectively.

[0112] As an example in this embodiment, a factory adds a production line due to production capacity demand. The rated active load of the production line is 0.3MW, the reactive load is 0.8MVar, and the active load effectiveness is 0.8, and the reactive load effectiveness is 0.5. Then the factory adds an active load λ 31 0.3×0.8=0.24MW, the newly added reactive load λ 32 It is 0.8×0.5=0.4MVar.

[0113] In one embodiment, the corrected predicted reactive power and the predicted active power are calculated based on the environmental coefficient, the line coefficient, the active power change value, and the reactive power change value.

[0114] Specifically, after superimposing the environmental coefficient, the line coefficient, the active power change value and the reactive power change value, at time t1, the corrected predicted active power P11=P×λ11×λ21+λ31, and the corrected predicted reactive power Q11=Q×λ12×λ22+λ32.

[0115] In one embodiment, the obtained corrected active power and corrected reactive power are subjected to power flow calculation to obtain a predicted reactive power compensation control scheme at the system scoring moment.

[0116] In this embodiment, the power flow calculation is taken as the core and the optimal algorithm is nested to obtain the optimal compensation solution.

[0117] Among them, the power flow calculation method can be selected according to the actual situation. The present invention recommends the use of the Newton-Raphson method. First, the nodes of the line are established and modeled. The output load value of each node is determined by the corrected active and reactive loads. The impedance data of each branch comes from the system line information. If there is no scheduling instruction at time t1 compared to time t0, the power supply data uses the power supply data at time t0. If there is a scheduling instruction, the power supply data at time t1 is determined according to the scheduling instruction. After substituting the above data into the Newton-Raphson method, the voltage value of each node and the line loss value of each branch can be obtained.

[0118] Among them, the optimal algorithm can be selected according to actual conditions. The present invention recommends the use of a particle swarm method. First, the power output, the allowable voltage value, and the reactive compensation capacity of each node are used as boundary conditions, and the line loss value and the operating cost are used as evaluation criteria. The particle swarm method is used to set the first generation of multiple sets of node reactive compensation commissioning data, and each set of reactive compensation commissioning is substituted into the line data to obtain multiple sets of line data with different compensation amounts. The Newton-Raphson method is used to perform flow calculations on each set of data, and then the evaluation criteria are compared to obtain a relatively optimal solution. During the iteration process, each set of reactive compensation commissioning data is combined with the relative optimal solution and its own optimal solution to obtain the second generation of multiple sets of reactive compensation commissioning data. When each set of data tends to be unified or iterates to a specified number of times, such as 10 times, the optimal solution in the final number of iterations is selected. The optimal solution is the reactive capacity value that each node should compensate at time t1, which is the predicted reactive compensation control scheme.

[0119] In this embodiment, when using the optimal algorithm for calculation, the following constraints need to be added on top of the boundary conditions:

[0120] (1) Avoid selecting a reactive power compensation device that is still in the lock stage for operation. The lock stage is the period from the last operation to the next allowed operation time, which is a manually set value. If it cannot be avoided, the device can be selected for operation and penalty measures can be set.

[0121] (2) On the basis of realizing constraint condition (1), based on the reactive power compensation capacity of each distribution transformer of the current line, the reactive power compensation amount of each distribution transformer of the line is minimized.

[0122] (3) Based on constraints (1) and (2), the focus should be on increasing reactive power compensation in the middle and rear sections of the trunk line; the focus should be on increasing reactive power compensation in the middle and rear sections of important branch lines or branch lines with large loads.

[0123] (4) Based on constraints (1), (2) and (3), reactive power compensation should be added to multiple distribution transformers as much as possible, and reactive power compensation should be avoided at a single distribution transformer as much as possible.

[0124] The setting of the above-mentioned penalty measures can avoid frequent operation of the same reactive power compensation equipment; the recommended method in this embodiment is: if the equipment is forced to operate in the locking stage, the locking duration of the next locking stage of the equipment should be 1.25 times the current duration of the equipment. If the number of operations in the locking stage reaches 3 times within 1 day, an alarm shall be issued and reported to the maintenance personnel for processing; for example, if the current locking stage of a certain equipment is 2.5 hours, the forced operation record is 1 time, and after being forced to operate again in the locking stage, the next locking stage duration will be 3.125 hours, and the forced operation record will be recorded as 2 times.

[0125] The above-mentioned trunk line is the line segment that is connected from the substation and is responsible for the main power transmission. The important branch line is the line segment that is connected to the non-trunk line with key users or important users of level 3 or above. The branch line with a large load is the line segment that is not the trunk line of the line segment and the load connected is greater than or equal to 10% of the total line load.

[0126] In this embodiment, after obtaining the predicted reactive power compensation control scheme, it is also necessary to determine whether the comparison characteristic value of the predicted reactive power compensation control scheme is 1. If so, the predicted reactive power compensation control scheme is implemented at a preset time so that the distribution network is subjected to reactive power compensation control according to the predicted reactive power compensation scheme. If not, the predicted reactive power compensation control scheme is abandoned and the current reactive power compensation control scheme is maintained so that the distribution network is subjected to reactive power compensation control according to the current reactive power compensation scheme.

[0127] Specifically: calculating the difference between the reactive compensation amount of the current reactive compensation control scheme and the predicted reactive compensation control scheme at each distribution transformer, generating a difference data group ΔSi=|S0-S1|, and calculating the difference average value ES of the difference data group;

[0128] Determine whether there is a difference value greater than a first specified value α in the difference data group 1 If so, then the comparative eigenvalue β of the predicted reactive power compensation control scheme is output 1 is 1;

[0129] If not, determine whether the average difference is greater than a second specified value α 2 If so, then the comparative eigenvalue β of the predicted reactive power compensation control scheme is output 2 is 1, the comprehensive time of reactive compensation action is Δt, and time T01 is the time Δt ahead of time t1, and the predicted reactive compensation control scheme S1 obtained by load forecasting is implemented at time T01; if not, the comparison eigenvalue of the predicted reactive compensation control scheme is not 1, and the current reactive compensation control scheme S0 is kept unchanged.

[0130] As an example in this embodiment, the first specified value α 1 , the first specified value α 2 All are specified values, β, β 1 , β 2 is the judgment value. 1 ΔSi is the maximum allowable value of the data in the data set, which can be set manually. The recommended value of the present invention is 0.5MVar; α 2 is α 1 The average value of the data set can be set manually, and the recommended value of the present invention is 0.3MVar; β 1 is α 1 The judgment value is used to characterize the judgment result; β 2is α 2 The judgment value is used to characterize the judgment result; when there is at least one value greater than α in the ΔSi array 1 When 1 is 1, otherwise β 1 is 0; when ES is greater than α 2 When 2 is 1, otherwise β 2 is 0. When β 1 or β 2 If there is at least one value that is 1, β is 1, otherwise β is 0.

[0131] In this embodiment, whether the reactive compensation scheme needs to be changed in time is determined according to the reactive load changes in the future, and the appropriate reactive compensation scheme is applied in time to realize reactive compensation control of the distribution network, which can effectively reduce the action frequency of reactive compensation and ensure the high-quality operation of the power grid.

[0132] Example 2

[0133] See also Figure 2 , Figure 2 FIG. 1 is a schematic diagram of a structure of an embodiment of a reactive power compensation control device for a distribution network provided by the present invention. Figure 2 As shown, the device includes a main control module 10, a communication module 20, a current acquisition module 30, a voltage acquisition module 40 and a line data storage module 50, which are specifically as follows:

[0134] Wherein, the main control module 10 is connected to the communication module 20 and the line data storage module 50 respectively;

[0135] The communication module 20 is connected to the current acquisition module 30 and the voltage acquisition module 40 respectively; the number of the current acquisition modules 30 and the voltage acquisition modules 40 is equal to the number of line distribution transformers, and each line distribution transformer is provided with a current acquisition module 30 and a voltage acquisition module 40 on the high-voltage side;

[0136] The main control module 10 includes a distribution transformer data acquisition unit 11, a distribution transformer data update unit 12, a data prediction unit 13 and a solution generation unit 14. Figure 3 As shown, Figure 3 is a structural schematic diagram of an embodiment of the main control module;

[0137] The distribution transformer data acquisition unit 11 is used to acquire the first current and voltage data of all distribution transformers in the line acquired by the voltage acquisition module 40 and the current acquisition module 30 through the communication module 20, and acquire the line scheduling operation instructions of the day and the first historical active load data of all distribution transformers through the line data storage module 50;

[0138] The distribution transformer data updating unit 12 is used to determine whether there is a line topology change between the system scoring time and the current time according to the line scheduling operation instruction of the day, and if so, update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line;

[0139] The data prediction unit 13 is used to calculate the predicted active power of each distribution transformer at the system scoring moment according to the updated first historical active load data, and calculate the predicted reactive power of each distribution transformer at the system scoring moment according to the updated first current and voltage data and the predicted active power;

[0140] The scheme generating unit 14 is used to perform power flow calculation on the predicted active power and the predicted reactive power to obtain the predicted reactive compensation control scheme at the system scoring moment, so as to perform reactive compensation control on the distribution network according to the predicted reactive compensation control scheme.

[0141] In one embodiment, the main control module 10 further includes: a solution verification unit 15, such as Figure 4 As shown, Figure 4 It is a structural diagram of another embodiment of the main control module; the scheme verification unit 15 is used to determine whether the comparison characteristic value of the predicted reactive power compensation control scheme is 1. If so, the predicted reactive power compensation control scheme is implemented at a preset time; if not, the predicted reactive power compensation control scheme is abandoned and the current reactive power compensation control scheme is maintained.

[0142] In one embodiment, the scheme verification unit 15 is used to determine whether the comparison eigenvalue of the predicted reactive power compensation control scheme is 1, specifically including: calculating the difference between the reactive power compensation amount of the current reactive power compensation control scheme and the predicted reactive power compensation control scheme at each distribution transformer, generating a difference data group, and calculating the difference average value of the difference data group; determining whether there is a value greater than a first specified value in the difference data group, and if so, outputting the comparison eigenvalue of the predicted reactive power compensation control scheme as 1; if not, determining whether the difference average value is greater than a second specified value, and if so, outputting the comparison eigenvalue of the predicted reactive power compensation control scheme as 1, and if not, outputting the comparison eigenvalue of the predicted reactive power compensation control scheme as not 1.

[0143] In one embodiment, the distribution transformer data updating unit 12 is used to update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line, specifically including: judging whether the change in the number of distribution transformers in the line is a transfer of the distribution transformer to the line according to the line scheduling operation instruction of the day, and if so, collecting the second current and voltage data of the distribution transformer transferred to the line, and the second historical active load data of the distribution transformer transferred to the line, and adding the second current and voltage data and the second historical active load data to the first current and voltage data and the first historical active load data accordingly, so as to update the first current and voltage data and the first historical active load data; judging whether the change in the number of distribution transformers in the line is a transfer of the distribution transformer to the line according to the line scheduling operation instruction of the day, and if so, collecting the third current and voltage data of the distribution transformer transferred to the line, and the third historical active load data of the distribution transformer transferred to the line, and deleting the third current and voltage data and the third historical active load data in the first current and voltage data and the first historical active load data, so as to update the first current and voltage data and the first historical active load data.

[0144] In one embodiment, the data prediction unit 13 is used to calculate the predicted active power of each distribution transformer at the system scoring moment according to the updated first historical active load data, specifically including: the updated first historical active load data includes a first interval active load data group and a second interval active load data group; the first interval active load data group is preprocessed to obtain a first active load value at the system scoring moment; it is determined whether the first active load value needs to be corrected, and if so, the first active load value is corrected according to the second interval active load data group, and the corrected first active load value is used as the predicted active power of each distribution transformer at the system scoring moment, if not, the first active load value is used as the predicted active power of each distribution transformer at the system scoring moment.

[0145] In one embodiment, the data prediction unit 13 is used to calculate the predicted reactive power of each distribution transformer at the system scoring moment according to the updated first current and voltage data and the predicted active power, specifically including: obtaining and calculating the power factor corresponding to each distribution transformer based on the current phase angle and voltage phase angle in the updated first current and voltage data; and calculating the predicted reactive power of each distribution transformer at the system scoring moment based on the power factor and the predicted active power.

[0146] In one embodiment, the scheme generating unit 14 is used to respectively correct the predicted reactive power and the predicted active power before performing power flow calculation on the predicted active power and the predicted reactive power.

[0147] Determine whether the impact of the external environment changes at the system scoring moment compared to the current moment on the reactive power exceeds the first preset threshold value. If so, set the corresponding environmental coefficients for the predicted reactive power and the predicted active power respectively; if not, determine whether the impact of the line changes at the system scoring moment compared to the current moment on the reactive power exceeds the second preset threshold value. If so, set the corresponding line coefficients for the predicted reactive power and the predicted active power respectively; if not, determine whether the loads of each distribution transformer have changed at the system scoring moment compared to the current moment. If so, determine the active power change value and the reactive power change value respectively; calculate the corrected predicted reactive power and the predicted active power according to the environmental coefficient, the line coefficient, the active power change value and the reactive power change value.

[0148] In one embodiment, the distribution network reactive power compensation control device further includes a reactive power compensation device control module 60, a data display module 70, a human-computer interaction module 80 and a plurality of action modules 90, such as Figure 5 As shown, Figure 5 It is a structural schematic diagram of another embodiment of a distribution network reactive power compensation control device.

[0149] In one embodiment, the reactive compensation device control module 60 is used to obtain the reactive compensation scheme generated in the main control module 10, convert the reactive compensation scheme into corresponding reactive compensation action signals of each distribution transformer, and send them to each distribution transformer reactive compensation device; the data display module 70 is used to display relevant data during the calculation process and the program running process; the human-computer interaction module 80 is used to receive necessary parameters set by the operator; the action module 90 is used to operate the reactive compensation device to perform corresponding actions according to the signal sent by the reactive compensation device control module.

[0150] In one embodiment, the main control module 10 is also connected to the data display module 70, the reactive compensation device control module 60 and the human-computer interaction module 80 respectively; the reactive compensation device control module 60 is connected to multiple action modules 90 respectively; each action module 90 is connected to a single line distribution transformer.

[0151] Those skilled in the art can clearly understand that, for the convenience and brevity of description, the specific working process of the device described above can refer to the corresponding process in the aforementioned method embodiment, and will not be repeated here.

[0152] It should be noted that the above-mentioned embodiments of the reactive power compensation control device for distribution network are merely illustrative, wherein the modules described as separate components may or may not be physically separated, and the components displayed as modules may or may not be physical units, that is, they may be located in one place, or may be distributed on multiple network units. Some or all of the modules may be selected according to actual needs to achieve the purpose of the solution of this embodiment.

[0153] Based on the above-mentioned embodiment of the distribution network reactive compensation control method, another embodiment of the present invention provides a distribution network reactive compensation control terminal device, which includes a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor. When the processor executes the computer program, the distribution network reactive compensation control method of any embodiment of the present invention is implemented.

[0154] Exemplarily, in this embodiment, the computer program may be divided into one or more modules, which are stored in the memory and executed by the processor to complete the present invention. The one or more modules may be a series of computer program instruction segments capable of completing specific functions, which are used to describe the execution process of the computer program in the distribution network reactive power compensation control terminal device.

[0155] The distribution network reactive power compensation control terminal device may be a computing device such as a desktop computer, a notebook, a palm computer, a cloud server, etc. The distribution network reactive power compensation control terminal device may include, but is not limited to, a processor and a memory.

[0156] The processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor may be a microprocessor or any conventional processor, etc. The processor is the control center of the distribution network reactive compensation control terminal device, and uses various interfaces and lines to connect various parts of the entire distribution network reactive compensation control terminal device.

[0157] The memory can be used to store the computer program and / or module, and the processor realizes various functions of the distribution network reactive compensation control terminal device by running or executing the computer program and / or module stored in the memory, and calling the data stored in the memory. The memory can mainly include a program storage area and a data storage area, wherein the program storage area can store an operating system, at least one application required for a function, etc.; the data storage area can store data created according to the use of the mobile phone, etc. In addition, the memory can include a high-speed random access memory, and can also include a non-volatile memory, such as a hard disk, a memory, a plug-in hard disk, a smart memory card (Smart Media Card, SMC), a secure digital (Secure Digital, SD) card, a flash card (Flash Card), at least one disk storage device, a flash memory device, or other volatile solid-state storage devices.

[0158] Based on the above-mentioned embodiment of the distribution network reactive compensation control method, another embodiment of the present invention provides a storage medium, wherein the storage medium includes a stored computer program, wherein when the computer program is running, the device where the storage medium is located is controlled to execute the distribution network reactive compensation control method of any embodiment of the present invention.

[0159] In this embodiment, the storage medium is a computer-readable storage medium, and the computer program includes computer program code, which may be in source code form, object code form, executable file or some intermediate form, etc. The computer-readable medium may include: any entity or device capable of carrying the computer program code, recording medium, USB flash drive, mobile hard disk, magnetic disk, optical disk, computer memory, read-only memory (ROM), random access memory (RAM), electric carrier signal, telecommunication signal and software distribution medium, etc. It should be noted that the content contained in the computer-readable medium may be appropriately increased or decreased according to the requirements of legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable media do not include electric carrier signals and telecommunication signals.

[0160] In summary, the present invention provides a distribution network reactive power compensation control method, device, equipment and storage medium, which obtains relevant first current and voltage data and first historical active load data of each distribution transformer in the line, and updates the first current and voltage data and the first historical active load data based on the change of the line topology structure; calculates the predicted active power of each distribution transformer at the system scoring moment according to the updated first historical active load data, and calculates the predicted reactive power of each distribution transformer at the system scoring moment according to the updated first current and voltage data and the predicted active power; performs flow calculation on the predicted active power and the predicted reactive power to obtain a predicted reactive compensation control scheme at the system scoring moment, so that the distribution network is subjected to reactive compensation control according to the predicted reactive compensation control scheme. Compared with the prior art, the present invention utilizes ultra-short-term load forecasting to realize the pre-determination of the reactive compensation control scheme, which can effectively alleviate the situation of poor timeliness of reactive compensation, and at the same time judges whether it is necessary to change the compensation scheme in time according to the reactive load changes in the future period, effectively reduces the action frequency of reactive compensation, and ensures the high-quality operation of the power grid.

[0161] The above is only a preferred embodiment of the present invention. It should be pointed out that for ordinary technicians in this technical field, several improvements and substitutions can be made without departing from the technical principles of the present invention. These improvements and substitutions should also be regarded as the scope of protection of the present invention.

Claims

1. A distribution network reactive power compensation control method, characterized in that: include: Obtain the first current and voltage data of all distribution transformers in the line, and at the same time obtain the line dispatching operation instructions of the day and the first historical active load data of all distribution transformers; Determine whether there is a line topology change between the system scoring time and the current time according to the line dispatching operation instruction of the day, and if so, update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line; Calculate the predicted active power of each distribution transformer at the system scoring time according to the updated first historical active load data, and calculate the predicted reactive power of each distribution transformer at the system scoring time according to the updated first current and voltage data and the predicted active power; Performing power flow calculation on the predicted active power and the predicted reactive power to obtain a predicted reactive power compensation control scheme at the system scoring moment, so as to perform reactive power compensation control on the distribution network according to the predicted reactive power compensation control scheme; The updating of the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line specifically includes: According to the line dispatching operation instruction of the day, determine whether the change in the number of distribution transformers in the line is a transfer to the distribution transformer of the current line; if so, collect the second current and voltage data of the transfer to the distribution transformer of the current line, and the second historical active load data of the transfer to the distribution transformer of the current line, and add the second current and voltage data and the second historical active load data to the first current and voltage data and the first historical active load data accordingly, so as to update the first current and voltage data and the first historical active load data; According to the line dispatching operation instructions of the day, determine whether the change in the number of distribution transformers in the line is the transfer of distribution transformers from this line. If so, collect the third current and voltage data of the distribution transformer transferred from this line, and the third historical active load data of the distribution transformer transferred from this line, and delete the third current and voltage data and the third historical active load data in the first current and voltage data and the first historical active load data to update the first current and voltage data and the first historical active load data.

2. A distribution network reactive power compensation control method as claimed in claim 1, characterized in that: After obtaining the predicted reactive power compensation control scheme at the system scoring time, the method further includes: Determine whether the comparison feature value of the predicted reactive power compensation control scheme is 1. If so, implement the predicted reactive power compensation control scheme at a preset time. If not, abandon the predicted reactive power compensation control scheme and maintain the current reactive power compensation control scheme.

3. A distribution network reactive power compensation control method as claimed in claim 2, characterized in that: The determining whether the comparison eigenvalue of the predicted reactive power compensation control scheme is 1 specifically includes: Calculating the difference between the reactive compensation amount of the current reactive compensation control scheme and the predicted reactive compensation control scheme at each distribution transformer, generating a difference data group, and calculating the difference average value of the difference data group; Determine whether there is a value greater than a first specified value in the difference data group, and if so, output the comparison characteristic value of the predicted reactive power compensation control scheme as 1; If not, determine whether the difference average value is greater than a second specified value. If so, output the comparison characteristic value of the predicted reactive power compensation control scheme as 1; if not, output the comparison characteristic value of the predicted reactive power compensation control scheme as not 1.

4. A distribution network reactive power compensation control method as claimed in claim 1, characterized in that: The step of calculating the predicted active power of each distribution transformer at the system scoring time according to the updated first historical active load data specifically includes: The updated first historical active load data includes a first interval active load data group and a second interval active load data group; Preprocessing the first interval active load data group to obtain a first active load value at the system scoring moment; Determine whether the first active load value needs to be corrected. If so, correct the first active load value according to the second interval active load data group, and use the corrected first active load value as the predicted active power of each distribution transformer at the system scoring moment. If not, use the first active load value as the predicted active power of each distribution transformer at the system scoring moment.

5. A distribution network reactive power compensation control method as claimed in claim 4, characterized in that: The step of calculating the predicted reactive power of each distribution transformer at the system scoring time according to the updated first current and voltage data and the predicted active power specifically includes: Obtaining and calculating the power factor corresponding to each distribution transformer based on the current phase angle and the voltage phase angle in the updated first current and voltage data; Based on the power factor and the predicted active power, the predicted reactive power of each distribution transformer at the system scoring moment is calculated.

6. A distribution network reactive power compensation control method as claimed in claim 1, characterized in that: Before performing power flow calculation on the predicted active power and the predicted reactive power, the method further includes: respectively correcting the predicted reactive power and the predicted active power; Determine whether the impact of the external environment change at the system scoring moment compared to the current moment on the reactive power exceeds a first preset threshold, and if so, set corresponding environmental coefficients to the predicted reactive power and the predicted active power respectively; If not, determine whether the influence of the line change at the system scoring moment compared to the current moment on the reactive power exceeds a second preset threshold, and if so, set corresponding line coefficients to the predicted reactive power and the predicted active power respectively; If not, determine whether the load of each distribution transformer has changed compared to the current moment at the system scoring moment, and if so, determine the active power change value and the reactive power change value respectively; The corrected predicted reactive power and the predicted active power are calculated according to the environmental coefficient, the line coefficient, the active power change value and the reactive power change value.

7. A reactive power compensation control device for a distribution network, characterized in that: It includes a main control module, a communication module, a current acquisition module, a voltage acquisition module and a line data storage module; Wherein, the main control module is connected to the communication module and the line data storage module respectively; The communication module is connected to the current acquisition module and the voltage acquisition module respectively; The main control module includes a distribution transformer data acquisition unit, a distribution transformer data update unit, a data prediction unit and a solution generation unit; The distribution transformer data acquisition unit is used to acquire the first current and voltage data of all distribution transformers in the line acquired by the voltage acquisition module and the current acquisition module through the communication module, and acquire the line scheduling operation instructions of the day and the first historical active load data of all distribution transformers through the line data storage module; The distribution transformer data updating unit is used to determine whether there is a line topology change between the system scoring time and the current time according to the line scheduling operation instruction of the day, and if so, update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line; The data prediction unit is used to calculate the predicted active power of each distribution transformer at the system scoring moment according to the updated first historical active load data, and to calculate the predicted reactive power of each distribution transformer at the system scoring moment according to the updated first current and voltage data and the predicted active power; The scheme generating unit is used to perform power flow calculation on the predicted active power and the predicted reactive power to obtain the predicted reactive compensation control scheme at the system scoring moment, so as to perform reactive compensation control on the distribution network according to the predicted reactive compensation control scheme; The distribution transformer data updating unit is used to update the first current and voltage data and the first historical active load data according to the change in the number of distribution transformers in the line, specifically including: the distribution transformer data updating unit determines whether the change in the number of distribution transformers in the line is the transfer of the distribution transformer to the line according to the line scheduling operation instruction of the day, and if so, collects the second current and voltage data of the distribution transformer transferred to the line, and the second historical active load data of the distribution transformer transferred to the line, and adds the second current and voltage data and the second historical active load data to the first current and voltage data and the first historical active load data accordingly, so as to update the first current and voltage data and the first historical active load data; determines whether the change in the number of distribution transformers in the line is the transfer of the distribution transformer out of the line according to the line scheduling operation instruction of the day, and if so, collects the third current and voltage data of the distribution transformer transferred out of the line, and the third historical active load data of the distribution transformer transferred out of the line, and deletes the third current and voltage data and the third historical active load data in the first current and voltage data and the first historical active load data, so as to update the first current and voltage data and the first historical active load data.

8. A terminal device, characterized in that: The method comprises a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor, wherein when the processor executes the computer program, the method for controlling reactive power compensation of a distribution network as claimed in any one of claims 1 to 6 is implemented.

9. A computer-readable storage medium, characterized in that: The computer-readable storage medium includes a stored computer program, wherein when the computer program is executed, the device where the computer-readable storage medium is located is controlled to execute the distribution network reactive power compensation control method according to any one of claims 1 to 6.

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