CN114050578B - Power distribution network online load flow calculation method, device, equipment and medium - Google Patents
Power distribution network online load flow calculation method, device, equipment and medium Download PDFInfo
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- CN114050578B CN114050578B CN202210014641.7A CN202210014641A CN114050578B CN 114050578 B CN114050578 B CN 114050578B CN 202210014641 A CN202210014641 A CN 202210014641A CN 114050578 B CN114050578 B CN 114050578B
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/04—Circuit arrangements for ac mains or ac distribution networks for connecting networks of the same frequency but supplied from different sources
- H02J3/06—Controlling transfer of power between connected networks; Controlling sharing of load between connected networks
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
- H02J2203/10—Power transmission or distribution systems management focussing at grid-level, e.g. load flow analysis, node profile computation, meshed network optimisation, active network management or spinning reserve management
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
- H02J2203/20—Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
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Abstract
The invention belongs to the technical field of load flow calculation, and particularly discloses a method, a device, equipment and a medium for on-line load flow calculation of a power distribution network, which comprise the following steps: s1, acquiring a real-time load flow calculation range; s2, acquiring equipment archive data and topology data in the real-time load flow calculation range, and simplifying the topology data; s3, verifying the integrity, data consistency and topological connectivity of the data in the range; s4, setting on-line load flow calculation parameters and acquiring the operation time of the equipment; s5, integrating the acquired equipment archive data and the simplified topology data; s6, acquiring equipment operation data according to the equipment archive data and the equipment operation time; s7, performing online power flow calculation according to the online power flow calculation parameters, the integrated verified equipment archive data, the integrated verified simplified topological data and the equipment operation data; and S8, storing the calculation result into a database, and realizing on-line real-time calculation by automatically acquiring data to perform load flow calculation, so that the labor is saved, and the working efficiency is improved.
Description
Technical Field
The invention belongs to the technical field of load flow calculation, and particularly discloses a method, a device, equipment and a medium for on-line load flow calculation of a power distribution network.
Background
At present, power distribution network planning is guided by problems, and power grid diagnosis and analysis are carried out by means of load flow calculation. The tidal current calculation is an important analysis calculation of the power system to study various problems in system planning and operation. For the power system in the planning, whether the proposed power system planning scheme can meet the requirements of various operation modes can be checked through load flow calculation; for an operating power system, various load changes and changes of a network structure can be predicted through load flow calculation, the safety of the system can not be endangered, whether the voltage of all buses in the system is within an allowable range, whether overload occurs to various elements (lines, transformers and the like) in the system, and what preventive measures should be taken in advance when the overload may occur, and the like.
Through long-term practice, the following problems have been found to exist:
1. offline collection of basic data
In the traditional mode, archive data, electrical parameters and operation data required by power system simulation are filled and reported through lines, are gathered step by step, are manually combed and are led into a template, and time and labor are wasted; the power grid topology is drawn manually, the efficiency is not high, and deep analysis is difficult to carry out on large-scale and complex network frames.
2. Simulation calculation off-line development
In a traditional mode, C/S software is generally used for power system simulation, simulation analysis is carried out offline, and calculation results are exported offline, and the method is only suitable for high-voltage power grids with small scale and small node number.
Disclosure of Invention
The invention aims to provide a method, a device, equipment and a medium for calculating the online power flow of a power distribution network, so as to solve the technical problems of low working efficiency caused by acquisition under a basic data line and poor power grid simulation calculation effectiveness and accuracy caused by the fact that simulation calculation is not suitable for a large-scale multi-node high-voltage power grid.
The invention is realized by adopting the following technical scheme:
in a first aspect, 1, an online power flow calculation method for a power distribution network includes the following steps:
s1, acquiring a power distribution network real-time load flow calculation range;
s2, acquiring equipment archive data and topology data in the real-time load flow calculation range of the power distribution network, and simplifying the topology data;
s3, checking the integrity and the data consistency of equipment archive data in the real-time load flow calculation range of the power distribution network and the topological connectivity of simplified topological data;
s4, setting on-line load flow calculation parameters and acquiring the operation time of the equipment;
s5, integrating the acquired equipment archive data and the simplified topology data to obtain integrated verified equipment archive data and integrated verified simplified topology data;
s6, acquiring equipment operation data according to the equipment archive data and the equipment operation time;
s7, performing online power flow calculation according to the online power flow calculation parameters, the integrated verified equipment archive data, the integrated verified simplified topological data and the equipment operation data;
and S8, storing the online power flow calculation result into a database.
The invention is further improved in that: the real-time load flow calculation range is one or more transformer substations or one or more large feeder lines in S1.
The invention is further improved in that: the method specifically comprises the following steps in S3:
s31, verifying the key fields of the equipment archive data to complete the integrity verification of the equipment archive data;
s32, verifying the electrical connectivity of the simplified topological data according to the equipment archive data verified in the S31, and identifying and displaying isolated nodes in the topological data;
and S33, matching the equipment in the geographic map with the equipment archive data through the equipment ID, and finishing the data consistency check of the equipment archive data.
The invention is further improved in that: the device profile data includes:
the method comprises the following steps of (1) obtaining the name of the transformer substation equipment, the voltage grade of the transformer substation, the number of main transformer stations of the transformer substation, the transformation capacity of the transformer substation and the commissioning date of the transformer substation; the method comprises the following steps of (1) setting the name of a switch station device, the voltage grade of the switch station, the incoming line interval number of the switch station, the outgoing line interval number of the switch station, the standby outgoing line interval of the switch station and the operation date of the switch station;
the method comprises the following steps that (1) the name of equipment of the ring main unit, the voltage grade of the ring main unit, the incoming line interval number of the ring main unit, the outgoing line interval number of the ring main unit, the standby outgoing line interval of the ring main unit and the commissioning date of the ring main unit are obtained;
the method comprises the following steps of (1) assigning a name of equipment in a distribution room, a voltage level of the distribution room, the number of distribution room distribution transformers, the total capacity of the distribution room distribution transformers and the operation date of the distribution room; the method comprises the following steps of (1) carrying out on-line monitoring on the equipment name of a box-type substation, the voltage grade of the box-type substation, the number of distribution transformer stations of the box-type substation, the total capacity of the distribution transformer of the box-type substation and the operation date of the box-type substation;
the device name of the large feeder line, the voltage level of the large feeder line and the station to which the large feeder line belongs;
line equipment name, line voltage class, line erection mode, total line length, overhead line length, cable line length and line commissioning date;
the transformer comprises a main transformer name, a main transformer voltage grade, a main transformer model, a main transformer connection group, a main transformer voltage ratio, main transformer three-side rated voltage, main transformer three-side rated capacity, a main transformer winding form, a main transformer commissioning date, a main transformer operation state, a main transformer operation phase, a main transformer neutral point grounding mode, a main transformer grounding resistance and a main transformer grounding reactance;
the method comprises the following steps of (1) line segment name, line segment voltage grade, line segment lead type, line segment model, line segment length, line segment running state, line segment running phase, line segment maximum current-carrying capacity and line segment commissioning date;
the switch name, the switch voltage grade, the switch type, the switch model, the switch operation phase, the switch opening and closing state and the switch rated short circuit on-off current;
the distribution transformer comprises a distribution transformer name, a distribution transformer voltage grade, a distribution transformer type, a station room to which the distribution transformer belongs, a distribution transformer public and special transformer identifier, a distribution transformer model, a distribution transformer connection group, a distribution transformer voltage ratio, a distribution transformer high-voltage side rated voltage, a distribution transformer low-voltage side rated voltage, a distribution transformer high-voltage side rated capacity, a distribution transformer low-voltage side rated capacity, a distribution transformer winding form, a distribution transformer running state, a distribution transformer neutral point grounding mode, a distribution transformer grounding resistance, a distribution transformer grounding reactance and a distribution transformer commissioning date.
The invention is further improved in that: further comprising:
s9, calculating distribution transformation indexes, line segment indexes, large feeder line indexes, main transformer indexes and network loss rate at a specified moment in a range according to the service rules and the online load flow calculation results;
and S10, setting different rendering rules according to the indexes and the calculation result of the network loss rate, and performing coloring rendering on the geographic map. The invention is further improved in that: the distribution transformation indexes comprise distribution transformation voltage deviation, distribution transformation load rate and distribution transformation line loss rate in S9;
the line segment indexes comprise a line segment load rate, a line segment line loss rate and a line segment voltage curve;
the main transformer indexes comprise main transformer voltage deviation, main transformer load rate and main transformer line loss rate;
the large feeder indexes comprise large feeder voltage drop, large feeder load rate and large feeder line loss rate;
the invention is further improved in that: the distribution transformer voltage deviation:
distribution voltage deviation = [ node line voltage amplitude-rated voltage ]/rated voltage 100%;
the load ratio of the distribution transformer is as follows:
distribution transformer load rate = distribution transformer high-voltage side load apparent power/distribution transformer capacity 100%;
wherein, PA, PB and PC are three-phase active power at A, B, C of the high-voltage side of the distribution transformer, and QA, QB and QC are three-phase inactive power at A, B, C of the high-voltage side of the distribution transformer;
the distribution transformer line loss rate is as follows:
distribution transformer line loss ratio = distribution transformer active loss/distribution transformer input active power 100%;
in the formula, the active loss of the distribution transformer is a preset value; the distribution transformer input active power is the maximum value in the absolute value of the sum of the three-phase power on the two sides;
the line segment load rate:
line segment loading rate = { max [ line segment phase current (A, B, C) ] }/line segment maximum loading capacity = 100%
The line loss rate of the line segment is as follows:
line loss ratio = active loss/input active 100%;
in the formula, the active loss of the line segment is a preset value; the line segment input is successfully the maximum value in the absolute value of the sum of the three-phase power at the two ends;
the main transformer voltage deviation:
main transformer voltage deviation = [ main transformer node line voltage amplitude (AB, BC, AC) -main transformer rated voltage ]/main transformer rated voltage 100%;
the main load factor:
main transformer load rate = main transformer load apparent power/main transformer capacity 100%;
wherein, PA is high by 1、PIn A1、PA is lower than 1、PHeight B1、PB in 1、PB is low by 1、PC is high 1、PC in 1And PC is low 1A, B, C three-phase active Q of high-voltage side, medium-voltage side and low-voltage side of main transformerA1、QB1、QC1A, B, C three-phase reactive power of a high-voltage side, a medium-voltage side and a low-voltage side of the main transformer;
the main line loss rate:
main transformer line loss = main transformer active loss/main transformer input active power 100%;
in the formula, the active loss of a main transformer is a preset value; the main transformer input power is the maximum value in the absolute value of the sum of three-phase power on three sides;
the large feeder voltage drop:
voltage drop = (minimum value of line voltage amplitude of (AB, BC, CA) in all nodes on a feeder line-line voltage amplitude of first nodes (AB, BC, CA) of outgoing line switches of the feeder line)/line voltage amplitude of first nodes (AB, BC, CA) of outgoing line switches of the feeder line 100%;
the line loss rate of the large feeder line is as follows:
large feeder line loss ratio = lost electric quantity/supplied electric quantity 100%;
the loss electric quantity = the sum of active losses of all line sections under the feeder line at the moment;
the network loss rate is as follows:
system grid loss rate = total system loss/amount of system power in.
In a second aspect, an online power flow calculation device for a power distribution network includes:
the load flow calculation range acquisition module is used for acquiring a real-time load flow calculation range of the power distribution network;
the data acquisition module is used for acquiring equipment archive data and topology data in the real-time load flow calculation range of the power distribution network and simplifying the topology data;
the data verification module is used for verifying the integrity and the data consistency of the equipment archive data in the real-time load flow calculation range of the power distribution network and the topological connectivity of the simplified topological data;
the device operation time acquisition module is used for setting on-line load flow calculation parameters and acquiring the device operation time;
the data integration module is used for integrating the acquired equipment archive data and the simplified topological data to obtain the integrated verified equipment archive data and the integrated verified simplified topological data;
the equipment operation data acquisition module is used for acquiring equipment operation data according to the equipment archive data and the equipment operation time;
the online load flow calculation module is used for performing online load flow calculation according to the online load flow calculation parameters, the integrated verified equipment archive data, the integrated verified simplified topological data and the equipment operation data;
the data storage module is used for storing the online load flow calculation result into a database;
the index calculation module is used for calculating distribution transformation indexes, line segment indexes, large feeder line indexes, main transformer indexes and network loss rates at specified moments in a range according to the service rules and the online load flow calculation results;
and the map rendering module is used for setting different rendering rules according to the indexes and the calculation result of the network loss rate and performing coloring rendering on the geographic map.
In a third aspect, a computer device includes a memory, a processor, and a computer program stored in the memory and executable on the processor, and the processor implements the above-mentioned power distribution network online power flow calculation method when executing the computer program.
In a fourth aspect, a computer-readable storage medium stores a computer program, and the computer program is executed by a processor to implement the above-mentioned method for calculating the online power flow of a power distribution network.
Compared with the prior art, the invention at least comprises the following beneficial effects:
1. the invention realizes the unified integration and calling of electrical parameters by self-establishing a parameter library; the equipment files and the operation data are automatically obtained through a unified interface; the power grid topology is automatically extracted from the geographical map, online real-time calculation is realized by relying on a data center, labor is saved, and working efficiency is improved.
2. According to the method, the future operation situation of the power grid is deduced through the calculation of the predicted state power flow based on the current state grid frame and the predicted load, the problem is accurately positioned to a line segment and distribution transformation, and the necessity of a planning scheme is combed; and the planning state load flow calculation online verifies the problem solution condition, ensures the rationality of the planning scheme and forms a service logic closed loop.
3. The invention is convenient to view by rendering the calculated index on the map.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this specification, are included to provide a further understanding of the invention, and are incorporated in and constitute a part of this specification, illustrate exemplary embodiments of the invention and together with the description serve to explain the invention and not to limit the invention. In the drawings:
FIG. 1 is a flow chart of an online power flow calculation method for a power distribution network according to the invention;
fig. 2 is a structural block diagram of an online power flow calculation device for a power distribution network according to the present invention.
Detailed Description
The present invention will be described in detail below with reference to the embodiments with reference to the attached drawings. It should be noted that the embodiments and features of the embodiments may be combined with each other without conflict.
The following detailed description is exemplary in nature and is intended to provide further details of the invention. Unless otherwise defined, all technical terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs. The terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of exemplary embodiments according to the invention.
It will be appreciated by those skilled in the art that the invention may be embodied in other specific forms without departing from the spirit or essential characteristics thereof. The embodiments disclosed above are therefore to be considered in all respects as illustrative and not restrictive. All changes which come within the scope of or equivalence to the invention are intended to be embraced therein.
Example 1
As shown in fig. 1, an online power flow calculation method for a power distribution network includes the following steps:
s1, acquiring a power distribution network real-time load flow calculation range;
s2, acquiring equipment archive data and topology data in the real-time load flow calculation range of the power distribution network, and simplifying the topology data;
s3, checking the integrity and the data consistency of equipment archive data in the real-time load flow calculation range of the power distribution network and the topological connectivity of simplified topological data;
s4, setting on-line load flow calculation parameters and acquiring the operation time of the equipment;
s5, integrating the acquired equipment archive data and the simplified topology data to obtain integrated verified equipment archive data and integrated verified simplified topology data;
s6, acquiring equipment operation data according to the equipment archive data and the equipment operation time;
s7, performing online power flow calculation according to the online power flow calculation parameters, the integrated verified equipment archive data, the integrated verified simplified topological data and the equipment operation data;
s8, storing the online load flow calculation result into a database;
s9, calculating distribution transformation indexes, line segment indexes, large feeder line indexes, main transformer indexes and network loss rate at a specified moment in a range according to the service rules and the online load flow calculation results;
and S10, setting different rendering rules according to the indexes and the calculation result of the network loss rate, and performing coloring rendering on the geographic map. S2 specifically includes the following steps:
s21, interface description: the client and the server uniformly adopt the character string in the JSON format to interact service data, the client organizes the service data into the character string in the JSON format as an interface for accessing and calling the server, and the server analyzes the character string in the JSON format to perform service data processing service and organizes the result into the character string in the JSON format to be returned to the client.
S22, format convention: the business data is organized into character strings in JSON format to interact:
JSON grammar rules;
the JSON syntax is a subset of the JavaScript object notation syntax;
data in a key value pair; data are separated by commas; curly brackets save objects; the square brackets store an array; JSON name/value pair; the written format of JSON data is: name/value pairs;
s23 calling specification
When the service is called, three parameters of the serviceCode, the user and the data need to be written clearly, wherein the three parameters need to be filled and only have three parameters;
data is used for submitting data to each service, a json list data format is arranged inside, strJson at least needs to contain eight fields, and other fields are dynamically expanded according to service needs:
srvCode: service coding, must fill, changes according to specific services, such as:
serial No: serial number, must fill, unique id
funcCode: function item coding, filling, changing according to specific service
Other fields are filled according to the service requirement, and the overall data is as follows:
{
"serviceCode":"ele_calc_run_service",
"user":"22123213",
"data":[{
"srvCode": "00000001",
"serialNo": "000001",
"funcCode": "01",
"equipId": "objid1,objid2,objid3",
"periods": "2020-07-04 17:03:41",
"equipType ": "0302",
"type": "01",
"deptCode": "41311016110101101"-sg_code
}]
}
s24 Return to Specification
The return field comprises four fields of success, failCode, info and data, wherein
success: true/false indicates whether success or failure occurred
failCode: indicating a failure code
info: presentation of failure description
The data represents service return data
An example of successful return data is as follows:
{
"success": true,
"failCode": null,
"info": null,
"data": [{
"objid1": {"Periods:" 2020-07-04 17:03:41",
"PA":"1.111",
"PB":"2.111" },
"objid2": {"Periods:" 2020-07-04 17:03:41",
"PA":"1.111",
"PB":"2.111" },
"objid3": {"Periods:" 2020-07-04 17:03:41",
"PA":"1.111",
"PB":"2.111" }
}]
}
an example of failed return data is as follows:
{
"success": false,
"failCode": "AIG03",
"info": xxx error ",
"data": null
}
s25, data contract-transformer substation maximum load moment
Invocation-
{
"serviceCode":"ele_calc_run_service",
"user":"22123213",
"data":[{
"srvCode": "00000004",
"serialNo": "000001",
"funcCode": "01",
"equipId": "objid1,objid2,objid3",
"periods": "2020",
"equipType ": "0300",
"type": "01",
"sgcode": "41311016110101101",
"deptcode": "41311016110101101"
}]
}
And returning:
{ "failed code": 001"," data "{" d84c859b77d647b58b571636c12907c4": {" TRAN _ ZDDFHSK ":" } "732072346f064c15bfa c7636d844623": { "TRAN _ ZDDFHSK": "" }, "205511590bef4174a320b26385c625ac": { "TRAN _ ZDDFHSK": "},"193f8438143c4d07806412a49f 500542 "{" TRAN _ ZDDFHSK ": 2015-12-1917: 30:00" }, "d51466b3009b4826b fbb 3ccb0e6e5f7" { "TRAN _ ZDDFHSK:": TRAN _ ZDDFHSK ": TRAN 10-3: 15: 539 5b 35" } "Bc 7034 {" TRAN _ ZDFb 5b "}" 15b 5b "} 5b 5f # 35" } b "} 15b # 5b # 35" } b # 5c
S26, data contract-line maximum load time
Invocation-
{
"serviceCode":"ele_calc_run_service",
"user":"22123213",
"data":[{
"srvCode": 00000004 "// question type 00000001234
"serial No": 000001 "// random string
"funcCode": 01",// redundancy
"equivalent ID" "objid1, objid2, objid3",// device ID
"period": 2020",// year or time
"equype": 0303 "// device type, reference code table
"type": 01",//01 redundant, fixed value
"sgcode": 41311016110101101"// province company unit code
"depth code": 41311016110101101"// unit code
}]
}
Type of problem, as shown in table 1:
TABLE 1
And returning: { "failed code": 001"," data ": {" b8ea1f09ca30415ea3a726fd93eaa27d ": {" LINE _ ZDDFHSK ": 2015-03-2017: 00:00" }, "106b9ced5e254caca5063d0e5f14ac4d" { "LINE _ ZHSFDK": 2015-07-0108: 00"}, {" 1345dc078d694dd4a556f8d 8b8afa "{" LINE _ ZDDFHSK ": 2015-06-3022: 00:00" } } ], "success": true, "info": service call success "}
S3 specifically includes the following steps:
s31, equipment contained in the equipment archive data integrity check includes a transformer substation, a ring main unit, a switch station, a distribution room, a box-type transformer substation, a large feeder line, a circuit, a main transformer, a line segment, a switch and a distribution transformer, and the key fields of the check are as follows:
a transformer substation: verifying equipment name, voltage class, main transformer number, transformation capacity, commissioning date, rule: the key field is not null;
switching station: verifying equipment name, voltage class, incoming line interval number, outgoing line interval number, standby outgoing line interval and commissioning date, and regulating: the key field is not null;
ring main unit: verifying equipment name, voltage class, incoming line interval number, outgoing line interval number, standby outgoing line interval and commissioning date, and regulating: the key field is not null;
a power distribution room: verifying equipment name, voltage grade, distribution transformer number, distribution transformer total capacity and commissioning date, and regulating: the key field is not null;
a box-type substation: verifying equipment name, voltage grade, distribution transformer number, distribution transformer total capacity and commissioning date, and regulating: the key field is not null;
big feeder: verifying equipment name, voltage level and station to which the equipment belongs, and regulating: the key field is not null;
a circuit: calibration equipment name, voltage class, mode of erection, total line length, built on stilts length, cable length, commissioning date, rule: the key field is not null;
main transformation: checking name, voltage grade, model, connection group, voltage ratio, three-side rated voltage, three-side rated capacity, winding form, commissioning date, running state, running phase, neutral point grounding mode, grounding resistance and grounding reactance, and rules: rated voltage and rated capacity, a double-winding transformer is used for checking a high-voltage side and a low-voltage side, a three-winding transformer is used for checking a high side and a low side, a neutral point grounding mode is passed if one side of the neutral point grounding mode exists, grounding resistance and grounding reactance pass if one side of the neutral point grounding mode exists, and other fields do not pass if the other fields do not exist;
line segment: checking name, voltage grade, wire type, model, length, running state, running phase, maximum current-carrying capacity, commissioning date, rule: the key field is not null;
a switch: checking name, voltage grade, switch type, model, operation phase, opening and closing state, rated short circuit on-off current, and rule: the key field is not null;
distribution and transformation: the method comprises the following steps of checking name, voltage grade, distribution transformer type, station room belonging to the station, public and special transformer identification, model, connection group, voltage ratio, high-voltage side rated voltage, low-voltage side rated voltage, high-voltage side rated capacity, low-voltage side rated capacity, winding form, running state, neutral point grounding mode, grounding resistance, grounding reactance, commissioning date and rule: the grounding mode of the neutral point is that the neutral point passes through the grounding resistor and the grounding reactance when one side of the neutral point is in the grounding mode, and the other fields are not empty and pass through the grounding resistor and the grounding reactance when one side of the neutral point is in the grounding mode;
s32, checking the electrical connectivity on the basis of the equipment listed in the S31 by the topological connectivity check, and identifying and displaying the isolated nodes;
s33, data consistency check means that the equipment in the geographic map is matched with the equipment in the archive through equipment IDs, and the equipment is not missed or repeated.
Modifying corresponding parameters on a parameter setting interface in S4 to achieve the purpose of simulating and analyzing the power grid performance under different power grid states;
matching the archive data and the topology data of the equipment acquired at S2 at S5;
in S6, the device operating time is acquired in S4 by the device ID according to the device profile data acquired in S2, and the load data at the device-specified time is acquired by calling the operating data interface.
An online power flow calculation is performed at S7: and inputting the calculation parameters set in the step S4, the equipment basic data integrated in the step S5 and the operation data acquired in the step S5 into a power flow calculation algorithm for performing online power flow calculation.
And analyzing and storing the S7 online power flow calculation result file into a database in S8.
The distribution transformation index in S9 is that the distribution transformation index comprises distribution transformation voltage deviation, namely high-voltage side voltage deviation;
defining: distribution voltage deviation = [ node line voltage amplitude (AB, BC, AC) -rated voltage ]/rated voltage 100%
The range is as follows: the distribution transformer voltage deviation is over voltage, the distribution transformer voltage deviation is more than 7 percent and less than or equal to 7 percent, the distribution transformer is normal, the distribution transformer voltage deviation is less than-7 percent, and the low voltage refers to three-phase power supply of 10kV and below;
judging the node abnormity: one is over voltage, one is low voltage, and the other is normal.
Interface distribution statistics: only overvoltage is counted normally; counting the low voltage only when the voltage is low and normal; the voltage unbalance is calculated by the overvoltage and the low voltage; all the samples were normal and were counted without duplication.
And GIS rendering: and rendering to the distribution transformer according to overvoltage, low voltage, voltage unbalance and normal 4 colors.
Also include the load factor of the distribution transformer;
defining: distribution transformer load rate = distribution transformer high-voltage side load apparent power/distribution transformer capacity 100%
The range is as follows: overload is determined when the load rate of the distribution transformer is more than 100%; the heavy load is that the load rate of 80 percent and the distribution transformation load rate is less than or equal to 100 percent; the load rate of 20 percent and the distribution transformation load rate is less than or equal to 80 percent, and the method is normal; when the distribution transformation load rate is more than 0 and less than or equal to 20 percent, and the active power and the reactive power of the low-voltage side are not fully equal to 0, the light load is obtained; the active power and the reactive power on the low-voltage side are both equal to 0 and are in no-load state; taking the load which cannot obtain active power and reactive power as the load to be empty;
wherein, PA、PB、PCFor distributing and transforming A, B, C three-phase active power on high-voltage sideA、QB、QCA, B, C three-phase reactive power on the high-voltage side of the distribution transformer;
distribution transformer line loss rate
Defining: distribution transformer line loss ratio = distribution transformer active loss/distribution transformer input active power 100%;
description of the drawings: directly taking a preset value for the active loss of the distribution transformer; the distribution transformer input power takes the maximum value of the absolute value of the sum of the three-phase power at two sides; the range is as follows: the distribution transformer line loss rate is higher than 12%; when the line loss rate is more than 0 and less than or equal to 12 percent, the normal state is achieved; the distribution line loss rate =0 or the loss which cannot be calculated is lossless; and the distribution line loss rate <0 is negative loss.
The segment index comprises a segment load rate;
defining: line segment loading rate = { max [ line segment phase current (A, B, C) ] }/line segment maximum loading capacity = 100%
The range is as follows: overload is determined when the load rate of the line segment is more than 100%; the line segment load rate of 80 percent to 100 percent is the heavy load; the load rate of the line segment is less than or equal to 80 percent and is normal when the load rate is 20 percent; the light load is 0< the load rate of the line segment is less than or equal to 20 percent; and the load rate of the line segment is equal to 0 and is no load.
Line loss rate of line segment
Defining: line loss ratio of line segment = active loss of line segment/active input of line segment 100%
Description of the drawings: directly taking a preset value for the active loss of the line segment; the line segment input power takes the maximum value in the absolute value of the sum of the three-phase power at the two ends; the range is as follows: the line loss rate of the line segment is more than 10 percent, and the line loss is high; the line loss rate of the line segment is more than 0 and less than or equal to 10 percent, and the line segment is normal; the line loss rate of the line segment =0 or the loss can not be calculated; the line loss rate of the line segment is less than 0, which is negative loss.
Line segment voltage curve
From the outgoing switch, the voltage curve of each node line on the main line is drawn according to the distance length, and whether the initial switch voltage is low voltage or overvoltage is judged, if so, the node is marked with blue, overvoltage and red
The main transformer index comprises main transformer voltage deviation;
defining: main transformer voltage deviation = [ main transformer node line voltage amplitude (AB, BC, AC) -main transformer rated voltage ]/main transformer rated voltage 100%
The range is as follows: the main transformer voltage deviation is over voltage, the main transformer voltage deviation is more than 7 percent and less than or equal to 7 percent from-3 percent, the main transformer voltage deviation is normal, the main transformer voltage deviation is less than-3 percent, and the low voltage is 110KV and 35 kV.
The range is as follows: the main transformer voltage deviation is over voltage, the main transformer voltage deviation is more than 7 percent and less than 7 percent, the main transformer voltage deviation is normal, the main transformer voltage deviation is less than-7 percent, the main transformer voltage deviation is low voltage, and the low voltage is three-phase power supply of 10kV and below;
node abnormity judgment (high, middle and low voltage side judgment respectively): if one overvoltage is used, the overvoltage is calculated, and if one low voltage is used, the low voltage is calculated, and if the three voltages are normal, the repetition and the visibility in detail can be realized;
interface main transformer statistics: if overvoltage occurs on one side, if low voltage occurs on one side, the low voltage occurs on the other side, and the three sides are normal, and the statistics is repeated and can be seen in detail;
and (3) rendering a GIS interface: the main transformer with at least one abnormal side is rendered on a map according to a label, the first column is a winding, the winding is divided into high, middle and low voltage sides, the second column is an abnormal type, and the main transformer can be positioned from a transformer substation to the main transformer according to the map proportion.
The load factor of the main transformer is also included, three sides are calculated, and the load and the capacity are calculated by corresponding sides;
defining: main transformer load rate = main transformer load apparent power/main transformer capacity 100%;
the range is as follows: overload is caused when the load factor of the main transformer is more than 100%; the heavy load is that 80 percent of the main transformer load rate is less than or equal to 100 percent; the load rate of the main transformer is more than or equal to 20% and less than or equal to 80% and is normal; 0< main transformer load rate <20% and the side with active and reactive power not fully 0 is light load; the side with active and reactive power equal to 0 is unloaded.
Wherein, PA is high by 1、PIn A1、PA is lower than 1、PB is 1 part high,P1 part of B,PB is low by 1、PC is high 1、PC in 1And PC is low 1A, B, C three-phase active Q of high-voltage side, medium-voltage side and low-voltage side of main transformerA1、QB1、QC1A, B, C three-phase reactive power of a high-voltage side, a medium-voltage side and a low-voltage side of the main transformer.
Interface statistics: one side is overloaded, the active and reactive power of the middle and low voltage sides are not completely 0, even if the overload exists, one side is heavily loaded, the overload does not exist, the active and reactive power of the middle and low voltage sides are not completely 0, even if the overload exists, three sides are lightly loaded, even if the light load exists, the three sides are normal, and the active and reactive power of the middle and low voltage sides are 0, namely no load; there were no duplicates in statistics.
The method also comprises the main line loss rate;
defining: main transformer line loss = main transformer active loss/main transformer input active power 100%;
description of the drawings: directly taking a preset value for the active loss of a main transformer; the main transformer input power takes the maximum value in the absolute value of the sum of three-phase power on three sides; the range is as follows: the main line loss rate is higher than 6%; the line loss rate of the main transformer is less than or equal to 6 percent and is normal when 0< the line loss rate of the main transformer is less than or equal to 6 percent; the main line loss rate =0 or the loss which cannot be calculated is lossless; the line loss rate of the main transformer is less than 0, and the negative loss is obtained.
The large feeder indicator comprises a large feeder voltage drop;
defining: voltage drop = (minimum value of line voltage amplitude of (AB, BC, CA) in all nodes on a feeder line-line voltage amplitude of first nodes (AB, BC, CA) of outgoing line switches of the feeder line)/line voltage amplitude of first nodes (AB, BC, CA) of outgoing line switches of the feeder line 100%;
the range is as follows: the voltage drop is overvoltage when the voltage drop is-4 percent, the voltage drop is normal when the voltage drop is more than or equal to 4 percent and less than or equal to-8 percent, and the voltage drop is low voltage when the voltage drop is less than-8 percent;
and (3) exception statistics: the three line voltage drops are overvoltage if one overvoltage is existed, low voltage if one overvoltage is existed, voltage unbalance if both overvoltage and low voltage are existed, and normal if all three are normal
Judging the abnormity of the interface feeder line: only overvoltage is counted normally; counting the low voltage only when the voltage is low and normal; the voltage unbalance is calculated by the overvoltage and the low voltage; all the samples were normal and were counted without duplication.
And GIS rendering: rendering the whole feeder line according to over-voltage, low-voltage, voltage unbalance and normal 4 colors on a voltage level interface, clicking any line section in the feeder line to pop up a main line voltage drop curve of the feeder line and marking a voltage normal level curve, wherein the voltage curve is from an outgoing switch, drawing a voltage curve of each node line on the main line according to the distance length, judging whether each node is low-voltage, over-voltage and voltage unbalance, if the node is low-voltage, marking the node blue, over-voltage, marking the node red, marking the voltage unbalance node yellow, and marking the normal node green. Note: distribution transformer high-voltage side node diagnosis method for node voltage deviation abnormity diagnosis with three voltage curves AB, BC and CA
A large feeder load rate;
overload: counting overload when there is an overload line section under the feeder line, and counting the number of the overload line sections and the distribution variable number of the overload
Heavy loading: counting the heavy load of a heavy load line segment under the feeder line, and counting the number of the heavy load line segments and the heavy load distribution variable number under the feeder line
Light load: counting light load when a light load line segment is under the feeder line, and counting the number of the light load line segments and the distribution variable number of the light load under the feeder line
No-load, counting the number of no-load line segments and the number of no-load distribution variables under the feeder line when a no-load line segment is under the feeder line
And (3) normal: all the line sections under the feeder line are normal, the statistics is carried out, and the number of the normal line sections and the normal distribution variable number under the feeder line are counted
Description of the drawings: overload, heavy load, light load and no-load abnormal equipment can be repeated, and the equipment can be clearly seen through abnormality.
Large line loss rate of feeder
The line loss rate calculation formula of the feeder line is as follows: feeder line loss rate = lost electric quantity/power supply quantity 100%
Wherein, the loss electric quantity = the sum of the active losses of all the line sections under the feeder line at the moment,
the power supply quantity = 100% of positive power in active power at two end points of the first section of line below the feeder line
The range is as follows: the line loss rate of the large feeder line is more than 8 percent, and the large feeder line is high loss; the line loss rate of the large feeder line is less than or equal to 8 percent when the line loss rate is more than 0 percent, and the line loss rate is normal; the line loss rate of the large feeder line =0 or the loss can not be calculated; the line loss rate of the large feeder line is less than 0, and the large feeder line loss rate is negative loss.
High loss: the line loss rate of the large feeder line is greater than 8%, the high loss is counted by the feeder line, and the number of high loss line segments and the number of high loss distribution transformers under the feeder line are counted;
negative loss: the line loss rate of the large feeder line is less than 0, the negative loss is counted by the feeder line, and the number of negative loss line segments and the number of negative loss distribution variables under the feeder line are counted;
lossless: the line loss rate of the large feeder line =0 or the large feeder line cannot be calculated as lossless, the feeder line is subjected to lossless statistics, and the number of lossless line segments and the number of lossless distribution transformers under the feeder line are subjected to statistics;
and (3) normal: the line loss rate of the large feeder line is less than or equal to 8 percent when the line loss rate is more than 0, the feeder line is counted to be normal, and the number of normal line sections and the number of normal distribution transformers under the feeder line are counted;
the network loss rate;
the system grid loss rate = system total loss/system power supply amount;
and (3) displaying an index analysis result: according to the analysis result of the S9 index, rendering the indexes such as the voltage level, the load rate, the line loss rate and the like of the equipment on the GIS map:
in S10, according to the various indexes of the various equipment calculated in S9, rendering rules of different indexes and different levels are set, and the rendering is performed based on the geographic map through interface service transmission parameters.
S10 specifically includes the following steps:
s101 index Classification
And (3) rendering the trend flow direction: details of the current flowing to each device of the feeder line from the substation outlet switch as a starting point according to the actual flow direction of the power flow are represented by flowing dots or arrows;
line segment power: active power and reactive power details, P + jQ, input and output in the first and last sections of each section of the large feeder line, wherein P represents active power and Q represents reactive power.
And calculating and judging the line loss rate of the line segment, the load rate of the line segment, the line loss rate of the distribution transformer, the load rate of the distribution transformer and the voltage level of the distribution transformer according to the data calculated in the step S9.
Rendering the distribution transformer voltage level index, rendering red by voltage, rendering green by voltage normal, rendering blue by low voltage, rendering magenta by voltage unbalance, rendering gray without participating in calculation, rendering blue by line segment, rendering yellow by load being empty, and rendering red by switching off a switch.
The method comprises the steps of load level index rendering of distribution transformer, overload rendering of red, overload rendering of brown, normal load rendering of green, light load rendering of blue, no-load rendering of purple, non-calculation rendering of gray, no-load rendering of yellow and switch-off rendering of red.
And (4) rendering the distribution transformer loss level index, rendering red at high loss, rendering green at normal loss, rendering purple without loss, rendering gray without participating in calculation, rendering yellow at empty load, and rendering red by switching off a switch.
Rendering the load level index of the line segment, rendering red under overload, rendering brown under overload, rendering green under normal load, rendering blue under light load, rendering purple under no load, rendering gray without participating in calculation, rendering yellow under empty load, and rendering red by switching off a switch.
Rendering the loss level index of the line segment, rendering red with high loss, rendering green with normal loss, rendering purple without loss, rendering gray without participating in calculation, rendering yellow with empty load, and rendering red with the switch off.
S102 calculation result transmission and rendering
And the GIS transmits the task ID, acquires the device details and the corresponding indexes of S101 through the ID, transmits the indexes and the specific rendering rule to the GIS, and performs coloring and rendering according to the judgment rule.
Example 2
As shown in fig. 2, an online power flow calculation device for a power distribution network includes:
the load flow calculation range acquisition module is used for acquiring a real-time load flow calculation range of the power distribution network;
the data acquisition module is used for acquiring equipment archive data and topology data in the real-time load flow calculation range of the power distribution network and simplifying the topology data;
the data verification module is used for verifying the integrity and the data consistency of the equipment archive data in the real-time load flow calculation range of the power distribution network and the topological connectivity of the simplified topological data;
the device operation time acquisition module is used for setting on-line load flow calculation parameters and acquiring the device operation time;
the data integration module is used for integrating the acquired equipment archive data and the simplified topological data to obtain the integrated verified equipment archive data and the integrated verified simplified topological data;
the equipment operation data acquisition module is used for acquiring equipment operation data according to the equipment archive data and the equipment operation time;
the online load flow calculation module is used for performing online load flow calculation according to the online load flow calculation parameters, the integrated verified equipment archive data, the integrated verified simplified topological data and the equipment operation data;
the data storage module is used for storing the online load flow calculation result into a database;
the index calculation module is used for calculating distribution transformation indexes, line segment indexes, large feeder line indexes, main transformer indexes and network loss rates at specified moments in a range according to the service rules and the online load flow calculation results;
and the map rendering module is used for setting different rendering rules according to the indexes and the calculation result of the network loss rate and performing coloring rendering on the geographic map.
Example 3
A computer device comprising a memory, a processor and a computer program stored in the memory and executable on the processor, wherein the processor implements the power distribution network online power flow calculation method of embodiment 1 when executing the computer program.
Example 4
A computer-readable storage medium, which stores a computer program, wherein the computer program is executed by a processor, and the method in embodiment 1 is used for calculating the online power flow of a power distribution network.
As will be appreciated by one skilled in the art, embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solutions of the present invention and not for limiting the same, and although the present invention is described in detail with reference to the above embodiments, those of ordinary skill in the art should understand that: modifications and equivalents may be made to the embodiments of the invention without departing from the spirit and scope of the invention, which is to be covered by the claims.
Claims (8)
1. A power distribution network online load flow calculation method is characterized by comprising the following steps:
s1, acquiring a power distribution network real-time load flow calculation range;
s2, acquiring equipment archive data and topology data in the real-time load flow calculation range of the power distribution network, and simplifying the topology data;
s3, checking the integrity and the data consistency of equipment archive data in the real-time load flow calculation range of the power distribution network and the topological connectivity of simplified topological data;
s4, setting on-line load flow calculation parameters and acquiring the operation time of the equipment;
s5, integrating the acquired equipment archive data and the simplified topology data to obtain integrated verified equipment archive data and integrated verified simplified topology data;
s6, acquiring equipment operation data according to the equipment archive data and the equipment operation time;
s7, performing online power flow calculation according to the online power flow calculation parameters, the integrated verified equipment archive data, the integrated verified simplified topological data and the equipment operation data;
s8, storing the online load flow calculation result into a database;
the method specifically comprises the following steps in S3:
s31, verifying the key fields of the equipment archive data to complete the integrity verification of the equipment archive data;
s32, verifying the electrical connectivity of the simplified topological data according to the equipment archive data verified in the S31, and identifying and displaying isolated nodes in the topological data;
s33, matching the equipment in the geographic map with the equipment archive data through equipment IDs, and completing data consistency check of the equipment archive data;
the device profile data includes:
the method comprises the following steps of (1) obtaining the name of the transformer substation equipment, the voltage grade of the transformer substation, the number of main transformer stations of the transformer substation, the transformation capacity of the transformer substation and the commissioning date of the transformer substation;
the method comprises the following steps of (1) setting the name of a switch station device, the voltage grade of the switch station, the incoming line interval number of the switch station, the outgoing line interval number of the switch station, the standby outgoing line interval of the switch station and the operation date of the switch station;
the method comprises the following steps that (1) the name of equipment of the ring main unit, the voltage grade of the ring main unit, the incoming line interval number of the ring main unit, the outgoing line interval number of the ring main unit, the standby outgoing line interval of the ring main unit and the commissioning date of the ring main unit are obtained;
the method comprises the following steps of (1) assigning a name of equipment in a distribution room, a voltage level of the distribution room, the number of distribution room distribution transformers, the total capacity of the distribution room distribution transformers and the operation date of the distribution room;
the method comprises the following steps of (1) carrying out on-line monitoring on the equipment name of a box-type substation, the voltage grade of the box-type substation, the number of distribution transformer stations of the box-type substation, the total capacity of the distribution transformer of the box-type substation and the operation date of the box-type substation;
the device name of the large feeder line, the voltage level of the large feeder line and the station to which the large feeder line belongs;
line equipment name, line voltage class, line erection mode, total line length, overhead line length, cable line length and line commissioning date;
the transformer comprises a main transformer name, a main transformer voltage grade, a main transformer model, a main transformer connection group, a main transformer voltage ratio, main transformer three-side rated voltage, main transformer three-side rated capacity, a main transformer winding form, a main transformer commissioning date, a main transformer operation state, a main transformer operation phase, a main transformer neutral point grounding mode, a main transformer grounding resistance and a main transformer grounding reactance;
the method comprises the following steps of (1) line segment name, line segment voltage grade, line segment lead type, line segment model, line segment length, line segment running state, line segment running phase, line segment maximum current-carrying capacity and line segment commissioning date;
the switch name, the switch voltage grade, the switch type, the switch model, the switch operation phase, the switch opening and closing state and the switch rated short circuit on-off current;
the distribution transformer comprises a distribution transformer name, a distribution transformer voltage grade, a distribution transformer type, a station room to which the distribution transformer belongs, a distribution transformer public and special transformer identifier, a distribution transformer model, a distribution transformer connection group, a distribution transformer voltage ratio, a distribution transformer high-voltage side rated voltage, a distribution transformer low-voltage side rated voltage, a distribution transformer high-voltage side rated capacity, a distribution transformer low-voltage side rated capacity, a distribution transformer winding form, a distribution transformer running state, a distribution transformer neutral point grounding mode, a distribution transformer grounding resistance, a distribution transformer grounding reactance and a distribution transformer commissioning date.
2. The method of claim 1, wherein the real-time power flow calculation range in S1 is one or more substations or one or more large feeders.
3. The method for calculating the power distribution network online power flow according to claim 1, further comprising:
s9, calculating distribution transformation indexes, line segment indexes, large feeder line indexes, main transformer indexes and network loss rate at a specified moment in a range according to the service rules and the online load flow calculation results;
and S10, setting different rendering rules according to the indexes and the calculation result of the network loss rate, and performing coloring rendering on the geographic map.
4. The method for calculating the online power flow of the power distribution network according to claim 3, wherein the distribution transformation indexes comprise a distribution transformation voltage deviation, a distribution transformation load rate and a distribution transformation line loss rate in S9;
the line segment indexes comprise a line segment load rate, a line segment line loss rate and a line segment voltage curve;
the main transformer indexes comprise main transformer voltage deviation, main transformer load rate and main transformer line loss rate;
the large feeder indexes comprise large feeder voltage drop, large feeder load rate and large feeder line loss rate.
5. The method for calculating the power distribution network online power flow according to claim 4, wherein the distribution transformer voltage deviation:
distribution voltage deviation = [ node line voltage amplitude-rated voltage ]/rated voltage 100%;
the load ratio of the distribution transformer is as follows:
distribution transformer load rate = distribution transformer high-voltage side load apparent power/distribution transformer capacity 100%;
wherein, PA、PB、PCFor distributing and transforming A, B, C three-phase active power on high-voltage sideA、QB、QCA, B, C three-phase reactive power on the high-voltage side of the distribution transformer;
the distribution transformer line loss rate is as follows:
distribution transformer line loss ratio = distribution transformer active loss/distribution transformer input active power 100%;
in the formula, the active loss of the distribution transformer is a preset value; the distribution transformer input active power is the maximum value in the absolute value of the sum of the three-phase power on the two sides;
the line segment load rate:
segment loading rate = [ max (segment phase current) ]/segment maximum carrying capacity = 100%
The line loss rate of the line segment is as follows:
line loss ratio = active loss/input active 100%;
in the formula, the active loss of the line segment is a preset value; the line segment input is successfully the maximum value in the absolute value of the sum of the three-phase power at the two ends;
the main transformer voltage deviation:
main transformer voltage deviation = [ main transformer node line voltage amplitude-main transformer rated voltage ]/main transformer rated voltage 100%;
the main load factor:
main transformer load rate = main transformer load apparent power/main transformer capacity 100%;
wherein, PA is high by 1、PIn A1、PA is lower than 1、PB is 1 part high,P1 part of B,PB is low by 1、PC is high 1、PC in 1And PC is low 1A, B, C three-phase active Q of high-voltage side, medium-voltage side and low-voltage side of main transformerA is high by 1、QIn A1、QA is lower than 1、QB is 1 part high,Q1 part of B,QB is low by 1、QC is high 1、QC in 1And QC is low 1A, B, C three-phase reactive power of a high-voltage side, a medium-voltage side and a low-voltage side of the main transformer;
the main line loss rate:
main transformer line loss = main transformer active loss/main transformer input active power 100%;
in the formula, the active loss of a main transformer is a preset value; the main transformer input power is the maximum value in the absolute value of the sum of three-phase power on three sides;
the large feeder voltage drop:
voltage drop = (minimum value of voltage amplitude of center lines of all nodes on a feeder line-amplitude of line voltage of a first node of a feeder line outlet switch)/amplitude of line voltage of a first node of a feeder line outlet switch is 100%;
the line loss rate of the large feeder line is as follows:
large feeder line loss ratio = lost electric quantity/supplied electric quantity 100%;
the loss electric quantity = the sum of active losses of all line sections under the feeder line at the moment;
the network loss rate is as follows:
system grid loss rate = total system loss/amount of system power in.
6. An online power flow calculation device for a power distribution network is characterized by comprising:
the load flow calculation range acquisition module is used for acquiring a real-time load flow calculation range of the power distribution network;
the data acquisition module is used for acquiring equipment archive data and topology data in the real-time load flow calculation range of the power distribution network and simplifying the topology data;
the data verification module is used for verifying the integrity and the data consistency of the equipment archive data in the real-time load flow calculation range of the power distribution network and the topological connectivity of the simplified topological data;
the data checking module specifically comprises the following steps:
verifying key fields of the equipment archive data to complete integrity verification of the equipment archive data;
verifying the electrical connectivity of the simplified topological data according to the verified equipment archive data, and identifying and displaying isolated nodes in the topological data;
matching the equipment in the geographic map with the equipment archive data through equipment ID to complete data consistency check of the backup archive data;
the device profile data includes:
the method comprises the following steps of (1) obtaining the name of the transformer substation equipment, the voltage grade of the transformer substation, the number of main transformer stations of the transformer substation, the transformation capacity of the transformer substation and the commissioning date of the transformer substation;
the method comprises the following steps of (1) setting the name of a switch station device, the voltage grade of the switch station, the incoming line interval number of the switch station, the outgoing line interval number of the switch station, the standby outgoing line interval of the switch station and the operation date of the switch station;
the method comprises the following steps that (1) the name of equipment of the ring main unit, the voltage grade of the ring main unit, the incoming line interval number of the ring main unit, the outgoing line interval number of the ring main unit, the standby outgoing line interval of the ring main unit and the commissioning date of the ring main unit are obtained;
the method comprises the following steps of (1) assigning a name of equipment in a distribution room, a voltage level of the distribution room, the number of distribution room distribution transformers, the total capacity of the distribution room distribution transformers and the operation date of the distribution room;
the method comprises the following steps of (1) carrying out on-line monitoring on the equipment name of a box-type substation, the voltage grade of the box-type substation, the number of distribution transformer stations of the box-type substation, the total capacity of the distribution transformer of the box-type substation and the operation date of the box-type substation;
the device name of the large feeder line, the voltage level of the large feeder line and the station to which the large feeder line belongs;
line equipment name, line voltage class, line erection mode, total line length, overhead line length, cable line length and line commissioning date;
the transformer comprises a main transformer name, a main transformer voltage grade, a main transformer model, a main transformer connection group, a main transformer voltage ratio, main transformer three-side rated voltage, main transformer three-side rated capacity, a main transformer winding form, a main transformer commissioning date, a main transformer operation state, a main transformer operation phase, a main transformer neutral point grounding mode, a main transformer grounding resistance and a main transformer grounding reactance;
the method comprises the following steps of (1) line segment name, line segment voltage grade, line segment lead type, line segment model, line segment length, line segment running state, line segment running phase, line segment maximum current-carrying capacity and line segment commissioning date;
the switch name, the switch voltage grade, the switch type, the switch model, the switch operation phase, the switch opening and closing state and the switch rated short circuit on-off current;
the distribution transformer comprises a distribution transformer name, a distribution transformer voltage grade, a distribution transformer type, a station room to which the distribution transformer belongs, a distribution transformer public and special transformer identifier, a distribution transformer model, a distribution transformer connection group, a distribution transformer voltage ratio, a distribution transformer high-voltage side rated voltage, a distribution transformer low-voltage side rated voltage, a distribution transformer high-voltage side rated capacity, a distribution transformer low-voltage side rated capacity, a distribution transformer winding form, a distribution transformer running state, a distribution transformer neutral point grounding mode, a distribution transformer grounding resistance, a distribution transformer grounding reactance and a distribution transformer commissioning date;
the device operation time acquisition module is used for setting on-line load flow calculation parameters and acquiring the device operation time;
the data integration module is used for integrating the acquired equipment archive data and the simplified topological data to obtain the integrated verified equipment archive data and the integrated verified simplified topological data;
the equipment operation data acquisition module is used for acquiring equipment operation data according to the equipment archive data and the equipment operation time;
the online load flow calculation module is used for performing online load flow calculation according to the online load flow calculation parameters, the integrated verified equipment archive data, the integrated verified simplified topological data and the equipment operation data;
the data storage module is used for storing the online load flow calculation result into a database;
the index calculation module is used for calculating distribution transformation indexes, line segment indexes, large feeder line indexes, main transformer indexes and network loss rates at specified moments in a range according to the service rules and the online load flow calculation results;
and the map rendering module is used for setting different rendering rules according to the indexes and the calculation result of the network loss rate and performing coloring rendering on the geographic map.
7. Computer arrangement comprising a memory, a processor and a computer program stored in said memory and executable on said processor, characterized in that said processor when executing said computer program implements a method for power distribution network online power flow calculation according to any of claims 1-5.
8. A computer-readable storage medium, in which a computer program is stored, wherein the computer program, when being executed by a processor, is adapted to perform a method according to any one of claims 1 to 5 for online power flow calculation of a power distribution network.
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