CN108364077B - Voltage stability-based method and system for determining simultaneous-stop maintenance scheme of direct current receiving end - Google Patents

Voltage stability-based method and system for determining simultaneous-stop maintenance scheme of direct current receiving end Download PDF

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CN108364077B
CN108364077B CN201810145350.5A CN201810145350A CN108364077B CN 108364077 B CN108364077 B CN 108364077B CN 201810145350 A CN201810145350 A CN 201810145350A CN 108364077 B CN108364077 B CN 108364077B
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熊浩清
易俊
安军
张建立
徐友平
徐遐龄
镐俊杰
刘轶
孙冉
张振安
姚峰
饶宇飞
白梁军
崔召辉
高峰
唐晓骏
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State Grid Corp of China SGCC
China Electric Power Research Institute Co Ltd CEPRI
State Grid Henan Electric Power Co Ltd
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Abstract

The invention discloses a method and a system for determining a direct current receiving end simultaneous-stop maintenance scheme based on voltage stability, wherein the method comprises the following steps: aiming at each alternative simultaneous maintenance scheme, calculating a total network average voltage drop value caused by each node fault in the electric network, and determining a risk level corresponding to each node fault according to the total network average voltage drop value caused by each node fault; respectively calculating the topology entropy value of the electric network of each alternative simultaneous maintenance scheme; respectively calculating the duty ratio of the load motor in the time period corresponding to each alternative synchronous stop and overhaul scheme; respectively calculating a comprehensive risk evaluation value of each alternative simultaneous maintenance scheme; and determining an optimal simultaneous maintenance scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance scheme. According to the invention, the voltage stability analysis, the electric network topology entropy value and the load motor ratio under the maintenance scheme are combined to determine the optimal synchronous-stop maintenance scheme, so that the working efficiency and quality of maintenance scheme evaluation are improved.

Description

Voltage stability-based method and system for determining simultaneous-stop maintenance scheme of direct current receiving end
Technical Field
The invention relates to the technical field of maintenance schemes of power systems, in particular to a method and a system for determining a direct-current receiving end simultaneous-stop maintenance scheme based on voltage stability.
Background
The comprehensive maintenance plan of the power grid is one of important daily works in the field of power system production, the actual full-line operation state of the power grid only exists in a blocking period (the blocking period is usually 7-8 months and 1 month), and the power grid is in a non-full-wiring state for a long time due to more scheduled maintenance of routine equipment in most other periods. And a large number of elements stop simultaneously in a non-full-wiring state, for example, a main line, a main transformer, a generator and the like are in a simultaneous shutdown state, so that the grid structure of the power grid is in a greatly weakened state relative to full-wiring. The reasonable formulation of the simultaneous maintenance scheme can effectively reduce the operation risk of the power grid to a certain extent. Conventionally, all the faults of the electric network N-1 are traversed by checking simulation calculation of an electric network element N-1, and the method has the following defects: 1) traversing transient stability simulation calculation is carried out on all the network element N-1 faults as required, then risk assessment is carried out by adopting various stability analysis criteria and artificial experience, and calculation is time-consuming; 2) in the traditional simulation calculation, a fixed value set by statistical experience on the duty ratio of the load motor cannot account for the influence of the actual duty ratio of the load motor on the risk in the same stopping period; 3) most importantly, the weakening degree of the whole net rack under multiple simultaneous parking schemes cannot be rapidly identified.
The self-organized critical evolution theory is taken as a theory for researching grid cascading failure and blackout accidents, and has been widely concerned by academia in recent years. The self-organization critical theory considers that: there are two diametrically opposed forces within the power system. On one hand, as the load continuously increases, the safety margin of the system is continuously reduced, and meanwhile, people can build the power grid and increase the load capacity of the power grid; on the other hand, the power grid can generate random disturbance such as short circuit, and meanwhile, the system can adopt safety measures such as adjusting the output of the generator. The two acting forces in opposite directions drive the power grid to evolve to a critical operation state, namely a self-organization critical state. In this state, a small disturbance will trigger a chain reaction and cause a blackout accident.
The self-organized critical evolution theory is used as a method for evaluating the risk level of the power grid, so that the risk under the maintenance state can be quickly evaluated, and the multi-scheme evaluation of the whole maintenance plan of the power grid is facilitated. Meanwhile, with the continuous development of power grids, the traditional alternating current transmission grid is gradually converted into an alternating current-direct current series-parallel connection type transmission grid, and the voltage stability of a direct current receiving end power grid is one of the key concerns of power grid maintenance.
Disclosure of Invention
The invention provides a method and a system for determining a DC receiving end simultaneous shutdown maintenance scheme based on voltage stability, and aims to solve the problem of how to efficiently and accurately determine the simultaneous shutdown maintenance scheme.
In order to solve the above problem, according to an aspect of the present invention, there is provided a method for determining a dc receiving end simultaneous outage maintenance scheme based on voltage stability, the method including:
aiming at each alternative simultaneous maintenance scheme, calculating a total network average voltage drop value caused by each node fault in the electric network, and determining a risk level corresponding to each node fault according to the total network average voltage drop value caused by each node fault;
respectively calculating the topology entropy value of the electric network of each alternative simultaneous maintenance scheme;
respectively calculating the duty ratio of the load motor in the time period corresponding to each alternative synchronous stop and overhaul scheme;
respectively calculating a comprehensive risk evaluation value of each alternative simultaneous maintenance scheme;
and determining an optimal simultaneous maintenance scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance scheme.
Preferably, the calculating, for each alternative simultaneous outage maintenance scheme, a total network average voltage sag value caused by each node fault in the electrical network, and determining a risk level corresponding to each node fault according to the total network average voltage sag value caused by each node fault includes:
determining typical fault types, and performing transient stability calculation on the basis of a power system analysis integration program PSASP (power system analysis integration protocol analysis software package) aiming at each alternative simultaneous shutdown maintenance scheme to determine a time domain curve of each node fault;
determining the average voltage drop value of the whole network caused by each node fault by using an average voltage drop value calculation formula according to the time domain curve of each node fault;
and determining the grade interval of each risk grade, and determining the risk grade corresponding to each node fault according to the whole network average voltage drop value caused by each node fault and the grade interval of each risk grade.
Preferably, wherein
The average voltage drop value calculation formula is as follows:
Figure GDA0002927174300000031
the level interval for the kth risk level is:
Figure GDA0002927174300000032
wherein, Delta AvgViThe voltage drop value of the whole network caused by the fault of the node i is obtained; m is the number of nodes; delta Vi,jThe voltage drop difference value of the node j caused by the fault of the node i; f is the number of risk grades; delta AvgVmaxThe maximum value of the total network average voltage drop value caused by each node fault is obtained; delta AvgVminThe minimum value of the total network average voltage drop value caused by each node fault.
Preferably, the calculating the electric network topology entropy value of each alternative simultaneous maintenance scheduling scheme respectively includes:
Figure GDA0002927174300000033
Figure GDA0002927174300000034
Figure GDA0002927174300000035
Figure GDA0002927174300000036
Figure GDA0002927174300000037
wherein m isiIs the degree of node i; u ═ U1,U2,U3...,Um]Setting the number of sequence elements as a constant sequence and m in total; n iskIs the number m of degreesi∈(Uk,Uk+1]The number of nodes in the interval; p (k) is the number of node degrees in (U)k,Uk+1]A probability of an interval; l (k) is the node degree mi∈(Uk,Uk+1]N of (A) to (B)kThe average voltage drop value of the nodes of the receiving end power grid after the node faults; l iskiThe voltage drop value of the whole network caused by the fault of the node i is obtained; h is the topology entropy value of a given electrical network.
Preferably, the calculating the duty ratio of the load motor in the time interval corresponding to each alternative synchronous stop and overhaul scheme respectively comprises:
Figure GDA0002927174300000041
wherein PMqThe duty ratio of a load motor in the electric network corresponding to the same-stop maintenance scheme in the q-th step; powerq,iThe active power predicted value of the ith node of the qth synchronous-stop maintenance scheme is obtained; PM (particulate matter)q,iThe induction motor of the ith node of the qth synchronous shutdown maintenance scheme has a specific active power value; APowerqThe larger the motor ratio is, the larger the risk is for the sum of the active power values of the receiving-end power grid.
Preferably, the calculating the comprehensive risk assessment value of each alternative simultaneous maintenance and repair solution separately includes:
Rq＝(H0-Hq)+λ1/Kq+λ2PMq (9)
wherein R isqRisk for the qth scenario; h0The initial network entropy value is the initial entropy value corresponding to the network when no shutdown is adopted; hqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme is obtained; lambda [ alpha ]1And λ2As a weight coefficient, determining the duty ratio and the short-circuit ratio of the load motor according to the actual condition of the maintenance periodAnd (4) the weight of each.
Preferably, the determining an optimal simultaneous maintenance plan according to the combined risk assessment value of each alternative simultaneous maintenance plan includes:
and selecting the alternative simultaneous maintenance-stopping scheme corresponding to the minimum comprehensive risk assessment value as the optimal simultaneous maintenance-stopping scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance-stopping scheme.
According to another aspect of the present invention, there is provided a dc receiving end simultaneous outage maintenance scheme determination system based on voltage stability, the system including:
the risk grade determining unit is used for calculating a whole network average voltage drop value caused by the fault of each node in the electric network aiming at each alternative simultaneous shutdown maintenance scheme, and determining a risk grade corresponding to the fault of each node according to the whole network average voltage drop value caused by the fault of each node;
the electric network topology entropy calculation unit is used for respectively calculating the electric network topology entropy of each alternative simultaneous maintenance scheme;
the load motor ratio calculating unit is used for respectively calculating the load motor ratio of the time interval corresponding to each alternative synchronous stop and overhaul scheme;
the comprehensive risk assessment value calculation unit is used for calculating the comprehensive risk assessment value of each alternative simultaneous maintenance scheme;
and the optimal simultaneous maintenance scheme determining unit is used for determining the optimal simultaneous maintenance scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance scheme.
Preferably, the risk level determining unit, for each alternative simultaneous outage maintenance scheme, calculates a total network average voltage sag value caused by each node fault in the electrical network, and determines a risk level corresponding to each node fault according to the total network average voltage sag value caused by each node fault, including:
the time domain curve determining module is used for determining typical fault types, carrying out transient stability calculation on the basis of a power system analysis comprehensive program PSASP aiming at each alternative synchronous-stop maintenance scheme, and determining a time domain curve of each node fault;
the whole-network average voltage sag value determining module is used for determining a whole-network average voltage sag value caused by each node fault by utilizing an average voltage sag value calculation formula according to a time domain curve of each node fault;
and the risk grade determining module is used for determining the grade interval of each risk grade, and determining the risk grade corresponding to each node fault according to the whole network average voltage drop value caused by each node fault and the grade interval of each risk grade.
Preferably, wherein
The average voltage drop value calculation formula is as follows:
Figure GDA0002927174300000051
the level interval for the kth risk level is:
Figure GDA0002927174300000052
wherein, Delta AvgViThe voltage drop value of the whole network caused by the fault of the node i is obtained; m is the number of nodes; delta Vi,jThe voltage drop difference value of the node j caused by the fault of the node i; f is the number of risk grades; delta AvgVmaxThe maximum value of the total network average voltage drop value caused by each node fault is obtained; delta AvgVminThe minimum value of the total network average voltage drop value caused by each node fault.
Preferably, the electric network topology entropy calculation unit calculates the electric network topology entropy of each alternative simultaneous maintenance scheduling scheme, respectively, and includes:
Figure GDA0002927174300000061
Figure GDA0002927174300000062
Figure GDA0002927174300000063
Figure GDA0002927174300000064
Figure GDA0002927174300000065
wherein m isiIs the degree of node i; u ═ U1,U2,U3...,Um]Setting the number of sequence elements as a constant sequence and m in total; n iskIs the number m of degreesi∈(Uk,Uk+1]The number of nodes in the interval; p (k) is the number of node degrees in (U)k,Uk+1]A probability of an interval; l (k) is the node degree mi∈(Uk,Uk+1]N of (A) to (B)kThe average voltage drop value of the nodes of the receiving end power grid after the node faults; l iskiThe voltage drop value of the whole network caused by the fault of the node i is obtained; h is the topology entropy value of a given electrical network.
Preferably, the load-motor ratio calculating unit calculates the load-motor ratio of the time interval corresponding to each alternative synchronous-stop maintenance scheme, respectively, and includes:
Figure GDA0002927174300000066
wherein PMqThe duty ratio of a load motor in the electric network corresponding to the same-stop maintenance scheme in the q-th step; powerq,iThe active power predicted value of the ith node of the qth synchronous-stop maintenance scheme is obtained; PM (particulate matter)q,iThe induction motor of the ith node of the qth synchronous shutdown maintenance scheme has a specific active power value; APowerqThe larger the motor ratio is, the larger the risk is for the sum of the active power values of the receiving-end power grid.
Preferably, the calculating unit of comprehensive risk assessment value calculates the comprehensive risk assessment value of each alternative simultaneous maintenance and repair solution, respectively, and includes:
Rq＝(H0-Hq)+λ1/Kq+λ2PMq (9)
wherein R isqRisk for the qth scenario; h0The initial network entropy value is the initial entropy value corresponding to the network when no shutdown is adopted; hqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme is obtained; lambda [ alpha ]1And λ2And determining the weight between the duty ratio and the short-circuit ratio of the load motor according to the actual condition of the maintenance period as a weight coefficient.
Preferably, the optimal simultaneous maintenance and repair plan determining unit determines the optimal simultaneous maintenance and repair plan according to the comprehensive risk assessment value of each alternative simultaneous maintenance and repair plan, and includes:
and selecting the alternative simultaneous maintenance-stopping scheme corresponding to the minimum comprehensive risk assessment value as the optimal simultaneous maintenance-stopping scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance-stopping scheme.
The invention provides a method and a system for determining a direct current receiving end simultaneous shutdown maintenance scheme based on voltage stability.
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A more complete understanding of exemplary embodiments of the present invention may be had by reference to the following drawings in which:
fig. 1 is a flowchart of a dc receiving end simultaneous shutdown maintenance scheme determination method 100 based on voltage stability according to an embodiment of the present invention; and
fig. 2 is a schematic structural diagram of a dc receiving-end simultaneous shutdown maintenance scheme determination system 200 based on voltage stability according to an embodiment of the present invention.
Detailed Description
The exemplary embodiments of the present invention will now be described with reference to the accompanying drawings, however, the present invention may be embodied in many different forms and is not limited to the embodiments described herein, which are provided for complete and complete disclosure of the present invention and to fully convey the scope of the present invention to those skilled in the art. The terminology used in the exemplary embodiments illustrated in the accompanying drawings is not intended to be limiting of the invention. In the drawings, the same units/elements are denoted by the same reference numerals.
Unless otherwise defined, terms (including technical and scientific terms) used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs. Further, it will be understood that terms, such as those defined in commonly used dictionaries, should be interpreted as having a meaning that is consistent with their meaning in the context of the relevant art and will not be interpreted in an idealized or overly formal sense.
Fig. 1 is a flowchart of a dc receiving end simultaneous shutdown maintenance scheme determination method 100 based on voltage stability according to an embodiment of the present invention. As shown in fig. 1, in the method 100 for determining a dc receiving-end simultaneous shutdown maintenance scheme based on voltage stability according to the embodiment of the present invention, a voltage stability analysis, an electric network topology entropy value and a load motor ratio under the maintenance scheme are combined to determine a comprehensive risk assessment value of each simultaneous shutdown maintenance scheme, and an optimal simultaneous shutdown maintenance scheme is determined according to the comprehensive risk assessment value, so that the work efficiency and quality of maintenance scheme assessment are improved. The method 100 for determining the voltage stability-based direct-current receiving-end simultaneous shutdown maintenance scheme provided by the embodiment of the invention starts from step 101, calculates a total network average voltage drop value caused by each node fault in an electric network aiming at each alternative simultaneous shutdown maintenance scheme in step 101, and determines a risk level corresponding to each node fault according to the total network average voltage drop value caused by each node fault.
Preferably, the calculating, for each alternative simultaneous outage maintenance scheme, a total network average voltage sag value caused by each node fault in the electrical network, and determining a risk level corresponding to each node fault according to the total network average voltage sag value caused by each node fault includes: determining typical fault types, and performing transient stability calculation on the basis of a power system analysis integration program PSASP (power system analysis integration protocol analysis software package) aiming at each alternative simultaneous shutdown maintenance scheme to determine a time domain curve of each node fault; determining the average voltage drop value of the whole network caused by each node fault by using an average voltage drop value calculation formula according to the time domain curve of each node fault; and determining the grade interval of each risk grade, and determining the risk grade corresponding to each node fault according to the whole network average voltage drop value caused by each node fault and the grade interval of each risk grade.
Preferably, the average voltage sag value is calculated by the following formula:
Figure GDA0002927174300000081
the level interval for the kth risk level is:
Figure GDA0002927174300000091
wherein, Delta AvgViThe voltage drop value of the whole network caused by the fault of the node i is obtained; m is the number of nodes; delta Vi,jThe voltage drop difference value of the node j caused by the fault of the node i; f is the number of risk grades; delta AvgVmaxThe maximum value of the total network average voltage drop value caused by each node fault is obtained; delta AvgVminThe minimum value of the total network average voltage drop value caused by each node fault.
For example, a network with N nodes is provided, except for a single dc converter station, there are M ac network nodes, M is 1,2, … i, j, … M; (i ∈ M, 1< i < M). The node bus voltage loss is taken as a typical fault.
Step 1: performing transient stability calculation by adopting PSASP 7.31 version power system analysis integration program PSASP, and sequentially calculating the time when the voltage loss fault occurs in the ith nodeA domain curve. Setting 0 second to start simulation calculation, wherein the total simulation time is 40 seconds, and if 1 second fails, taking the voltage at the moment of 0.5 second as the initial voltage V before the failure of the given jth nodej,t＝0.5Taking the 35 th second time as the given jth node's stabilized voltage value after the fault Vj,t＝35And the voltage drop rate of the node j of the node i with the bus voltage loss fault is defined as delta Vi,j＝Vi,j,t＝35-Vi,j,t＝0. Calculating the average voltage drop value delta AvgV of the full alternating current network caused by each node according to the average voltage drop value calculation formulai。
Step 2: network average voltage drop value delta AvgV corresponding to M given node faults obtained from the Step1iAnd (6) sorting.
Step 3: setting the number of risk levels to be F, wherein F is less than the number of nodes M-1, determining the level interval of each risk level, and dividing the network nodes into F sets according to the total network average voltage drop value caused by the fault of each node and the level interval of each risk level.
Preferably, the electrical network topology entropy values for each alternative co-stop service plan are calculated separately at step 102.
Preferably, the calculating the electric network topology entropy value of each alternative simultaneous maintenance scheduling scheme respectively includes:
Figure GDA0002927174300000092
Figure GDA0002927174300000093
Figure GDA0002927174300000101
Figure GDA0002927174300000102
Figure GDA0002927174300000103
wherein m isiIs the degree of node i; u ═ U1,U2,U3...,Um]Setting the number of sequence elements as a constant sequence and m in total; n iskIs the number m of degreesi∈(Uk,Uk+1]The number of nodes in the interval; p (k) is the number of node degrees in (U)k,Uk+1]A probability of an interval; l (k) is the node degree mi∈(Uk,Uk+1]N of (A) to (B)kThe average voltage drop value of the nodes of the receiving end power grid after the node faults; l iskiThe voltage drop value of the whole network caused by the fault of the node i is obtained; h is the topology entropy value of a given electrical network. L iskiEquivalent to Δ AvgViI.e. Lki≡ΔAvgVi。
Preferably, the duty ratio of the load motor in the time interval corresponding to each alternative synchronous stop and overhaul scheme is respectively calculated in step 103.
Preferably, the calculating the duty ratio of the load motor in the time interval corresponding to each alternative synchronous stop and overhaul scheme respectively comprises:
Figure GDA0002927174300000104
wherein PMqThe duty ratio of a load motor in the electric network corresponding to the same-stop maintenance scheme in the q-th step; powerq,iThe active power predicted value of the ith node of the qth synchronous-stop maintenance scheme is obtained; PM (particulate matter)q,iThe induction motor of the ith node of the qth synchronous shutdown maintenance scheme has a specific active power value; APowerqThe larger the motor ratio is, the larger the risk is for the sum of the active power values of the receiving-end power grid.
Preferably, a composite risk assessment value is calculated for each alternative co-stop service option at step 104.
Preferably, the calculating the comprehensive risk assessment value of each alternative simultaneous maintenance and repair solution separately includes:
Rq＝(H0-Hq)+λ1/Kq+λ2PMq (9)
wherein R isqRisk for the qth scenario; h0The initial network entropy value is the initial entropy value corresponding to the network when no shutdown is adopted; hqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme is obtained; lambda [ alpha ]1And 22And determining the weight between the duty ratio and the short-circuit ratio of the load motor according to the actual condition of the maintenance period as a weight coefficient.
Preferably, an optimal co-stop maintenance schedule is determined in step 105 based on the combined risk assessment value for each alternative co-stop maintenance schedule.
Preferably, the determining an optimal simultaneous maintenance plan according to the combined risk assessment value of each alternative simultaneous maintenance plan includes: and selecting the alternative simultaneous maintenance-stopping scheme corresponding to the minimum comprehensive risk assessment value as the optimal simultaneous maintenance-stopping scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance-stopping scheme.
Fig. 2 is a schematic structural diagram of a dc receiving-end simultaneous shutdown maintenance scheme determination system 200 based on voltage stability according to an embodiment of the present invention. As shown in fig. 2, the dc receiving-end simultaneous shutdown maintenance scheme determining system 200 based on voltage stability provided by the embodiment of the present invention includes: the system comprises a risk level determination unit 201, an electric network topology entropy value calculation unit 202, a load motor ratio calculation unit 203, a comprehensive risk assessment value calculation unit 204 and an optimal simultaneous shutdown and overhaul scheme determination unit 205. Preferably, in the risk level determining unit 201, for each alternative simultaneous maintenance and overhaul scheme, a full-network average voltage drop value caused by each node fault in the electrical network is calculated, and a risk level corresponding to each node fault is determined according to the full-network average voltage drop value caused by each node fault.
Preferably, the risk level determining unit, for each alternative simultaneous outage maintenance scheme, calculates a total network average voltage sag value caused by each node fault in the electrical network, and determines a risk level corresponding to each node fault according to the total network average voltage sag value caused by each node fault, including: a time domain curve determining module 2011, a whole network average voltage sag value determining module 2012 and a risk level determining module 2013.
Preferably, in the time domain curve determining module 2011, the typical fault type is determined, and for each alternative simultaneous outage and maintenance scheme, transient stability calculation is performed based on the power system analysis integration program PSASP to determine the time domain curve of each node fault.
Preferably, in the whole-network average voltage drop value determining module 2012, the whole-network average voltage drop value caused by each node fault is determined by using an average voltage drop value calculation formula according to the time domain curve of each node fault.
Preferably, in the risk level determining module 2013, a level interval of each risk level is determined, and a risk level corresponding to each node fault is determined according to the full-network average voltage drop value caused by each node fault and the level interval of each risk level.
Preferably, wherein
The average voltage drop value calculation formula is as follows:
Figure GDA0002927174300000121
the level interval for the kth risk level is:
Figure GDA0002927174300000122
wherein, Delta AvgViThe voltage drop value of the whole network caused by the fault of the node i is obtained; m is the number of nodes; delta Vi,jThe voltage drop difference value of the node j caused by the fault of the node i; f is the number of risk grades; delta AvgVmaxThe maximum value of the total network average voltage drop value caused by each node fault is obtained; delta AvgVminThe minimum value of the total network average voltage drop value caused by each node fault.
Preferably, in the electric network topology entropy calculation unit 202, the electric network topology entropy of each alternative simultaneous maintenance scheduling scheme is calculated respectively.
Preferably, the electric network topology entropy calculation unit calculates the electric network topology entropy of each alternative simultaneous maintenance scheduling scheme, respectively, and includes:
Figure GDA0002927174300000123
Figure GDA0002927174300000124
Figure GDA0002927174300000125
Figure GDA0002927174300000126
Figure GDA0002927174300000127
wherein m isiIs the degree of node i; u ═ U1,U2,U3...,Um]Setting the number of sequence elements as a constant sequence and m in total; n iskIs the number m of degreesi∈(Uk,Uk+1]The number of nodes in the interval; p (k) is the number of node degrees in (U)k,Uk+1]A probability of an interval; l (k) is the node degree mi∈(Uk,Uk+1]N of (A) to (B)kThe average voltage drop value of the nodes of the receiving end power grid after the node faults; l iskiThe voltage drop value of the whole network caused by the fault of the node i is obtained; h is the topology entropy value of a given electrical network.
Preferably, in the load motor ratio calculating unit 203, the load motor ratio of the time interval corresponding to each alternative synchronous stop and overhaul scheme is calculated respectively.
Preferably, the load-motor ratio calculating unit calculates the load-motor ratio of the time interval corresponding to each alternative synchronous-stop maintenance scheme, respectively, and includes:
Figure GDA0002927174300000131
wherein PMqThe duty ratio of a load motor in the electric network corresponding to the same-stop maintenance scheme in the q-th step; powerq,iThe active power predicted value of the ith node of the qth synchronous-stop maintenance scheme is obtained; PM (particulate matter)q,iThe induction motor of the ith node of the qth synchronous shutdown maintenance scheme has a specific active power value; APowerqThe larger the motor ratio is, the larger the risk is for the sum of the active power values of the receiving-end power grid.
Preferably, in the integrated risk assessment value calculation unit 204, an integrated risk assessment value of each alternative simultaneous maintenance and repair solution is calculated respectively.
Preferably, the calculating unit of comprehensive risk assessment value calculates the comprehensive risk assessment value of each alternative simultaneous maintenance and repair solution, respectively, and includes:
Rq＝(H0-Hq)+λ1/Kq+λ2PMq (9)
wherein R isqRisk for the qth scenario; h0The initial network entropy value is the initial entropy value corresponding to the network when no shutdown is adopted; hqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme is obtained; lambda [ alpha ]1And λ2And determining the weight between the duty ratio and the short-circuit ratio of the load motor according to the actual condition of the maintenance period as a weight coefficient.
Preferably, in the optimal simultaneous maintenance and repair plan determining unit 205, the optimal simultaneous maintenance and repair plan is determined according to the comprehensive risk assessment value of each alternative simultaneous maintenance and repair plan.
Preferably, the optimal simultaneous maintenance and repair plan determining unit determines the optimal simultaneous maintenance and repair plan according to the comprehensive risk assessment value of each alternative simultaneous maintenance and repair plan, and includes:
and selecting the alternative simultaneous maintenance-stopping scheme corresponding to the minimum comprehensive risk assessment value as the optimal simultaneous maintenance-stopping scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance-stopping scheme.
The voltage stability-based dc receiving end simultaneous shutdown and overhaul scheme determination system 200 according to the embodiment of the present invention corresponds to the voltage stability-based dc receiving end simultaneous shutdown and overhaul scheme determination method 100 according to another embodiment of the present invention, and details thereof are not repeated here.
The invention has been described with reference to a few embodiments. However, other embodiments of the invention than the one disclosed above are equally possible within the scope of the invention, as would be apparent to a person skilled in the art from the appended patent claims.
Generally, all terms used in the claims are to be interpreted according to their ordinary meaning in the technical field, unless explicitly defined otherwise herein. All references to "a/an/the [ device, component, etc ]" are to be interpreted openly as referring to at least one instance of said device, component, etc., unless explicitly stated otherwise. The steps of any method disclosed herein do not have to be performed in the exact order disclosed, unless explicitly stated.

Claims (14)

1. A method for determining a DC receiving end simultaneous shutdown maintenance scheme based on voltage stability is characterized by comprising the following steps:
aiming at each alternative simultaneous maintenance scheme, calculating a total network average voltage drop value caused by each node fault in the electric network, and determining a risk level corresponding to each node fault according to the total network average voltage drop value caused by each node fault;
respectively calculating the topology entropy value of the electric network of each alternative simultaneous maintenance scheme;
respectively calculating the duty ratio of the load motor in the time period corresponding to each alternative synchronous stop and overhaul scheme;
respectively calculating a comprehensive risk evaluation value of each alternative simultaneous maintenance scheme;
and determining an optimal simultaneous maintenance scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance scheme.
2. The method of claim 1, wherein the calculating, for each alternative simultaneous outage maintenance scheme, a total network average voltage sag value caused by each node fault in the electrical network, and determining a risk level corresponding to each node fault according to the total network average voltage sag value caused by each node fault comprises:
determining typical fault types, and performing transient stability calculation on the basis of a power system analysis integration program PSASP (power system analysis integration protocol analysis software package) aiming at each alternative simultaneous shutdown maintenance scheme to determine a time domain curve of each node fault;
determining the average voltage drop value of the whole network caused by each node fault by using an average voltage drop value calculation formula according to the time domain curve of each node fault;
and determining the grade interval of each risk grade, and determining the risk grade corresponding to each node fault according to the whole network average voltage drop value caused by each node fault and the grade interval of each risk grade.
3. The method of claim 2,
the average voltage drop value calculation formula is as follows:
Figure FDA0002927174290000011
the level interval for the kth risk level is:
Figure FDA0002927174290000021
wherein, Delta AvgViThe voltage drop value of the whole network caused by the fault of the node i is obtained; m is the number of nodes; delta Vi,jThe voltage drop difference value of the node j caused by the fault of the node i; f is the number of risk grades; delta AvgVmaxThe maximum value of the total network average voltage drop value caused by each node fault is obtained; delta AvgVminThe minimum value of the total network average voltage drop value caused by each node fault.
4. The method of claim 3, wherein the separately calculating an electrical network topology entropy value for each alternative co-stop service plan comprises:
Figure FDA0002927174290000022
Figure FDA0002927174290000023
Figure FDA0002927174290000024
Figure FDA0002927174290000025
Figure FDA0002927174290000026
wherein m isiIs the degree of node i; u ═ U1,U2,U3...,Um]Setting the number of sequence elements as a constant sequence and m in total; n iskIs the number m of degreesi∈(Uk,Uk+1]The number of nodes in the interval; p (k) is the number of node degrees in (U)k,Uk+1]A probability of an interval; l (k) is the node degree mi∈(Uk,Uk+1]N of (A) to (B)kThe average voltage drop value of the nodes of the receiving end power grid after the node faults;Lkithe voltage drop value of the whole network caused by the fault of the node i is obtained; h is the topology entropy value of a given electrical network.
5. The method of claim 1, wherein the separately calculating the duty ratio of the load motor for the time period corresponding to each alternative co-stop service plan comprises:
Figure FDA0002927174290000027
wherein PMqThe duty ratio of a load motor in the electric network corresponding to the same-stop maintenance scheme in the q-th step; powerq,iThe active power predicted value of the ith node of the qth synchronous-stop maintenance scheme is obtained; PM (particulate matter)q,iThe induction motor of the ith node of the qth synchronous shutdown maintenance scheme has a specific active power value; APowerqThe larger the motor ratio is, the larger the risk is for the sum of the active power values of the receiving-end power grid.
6. The method of claim 5, wherein the separately calculating a composite risk assessment value for each alternative co-stop service option comprises:
Rq＝(H0-Hq)+λ1/Kq+λ2PMq (9)
wherein R isqRisk for the qth scenario; h0The initial network entropy value is the initial entropy value corresponding to the network when no shutdown is adopted; hqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme is obtained; lambda [ alpha ]1And λ2And determining the weight between the duty ratio and the short-circuit ratio of the load motor according to the actual condition of the maintenance period as a weight coefficient.
7. The method of claim 1, wherein determining an optimal co-stop service plan from the composite risk assessment value for each alternative co-stop service plan comprises:
and selecting the alternative simultaneous maintenance-stopping scheme corresponding to the minimum comprehensive risk assessment value as the optimal simultaneous maintenance-stopping scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance-stopping scheme.
8. A direct current receiving end simultaneous-stop maintenance scheme determining system based on voltage stability is characterized by comprising:
the risk grade determining unit is used for calculating a whole network average voltage drop value caused by the fault of each node in the electric network aiming at each alternative simultaneous shutdown maintenance scheme, and determining a risk grade corresponding to the fault of each node according to the whole network average voltage drop value caused by the fault of each node;
the electric network topology entropy calculation unit is used for respectively calculating the electric network topology entropy of each alternative simultaneous maintenance scheme;
the load motor ratio calculating unit is used for respectively calculating the load motor ratio of the time interval corresponding to each alternative synchronous stop and overhaul scheme;
the comprehensive risk assessment value calculation unit is used for calculating the comprehensive risk assessment value of each alternative simultaneous maintenance scheme;
and the optimal simultaneous maintenance scheme determining unit is used for determining the optimal simultaneous maintenance scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance scheme.
9. The system of claim 8, wherein the risk level determining unit calculates, for each alternative simultaneous outage maintenance scheme, a total network average voltage sag value caused by each node fault in the electrical network, and determines the risk level corresponding to each node fault according to the total network average voltage sag value caused by each node fault, and the risk level determining unit includes:
the time domain curve determining module is used for determining typical fault types, carrying out transient stability calculation on the basis of a power system analysis comprehensive program PSASP aiming at each alternative synchronous-stop maintenance scheme, and determining a time domain curve of each node fault;
the whole-network average voltage sag value determining module is used for determining a whole-network average voltage sag value caused by each node fault by utilizing an average voltage sag value calculation formula according to a time domain curve of each node fault;
and the risk grade determining module is used for determining the grade interval of each risk grade, and determining the risk grade corresponding to each node fault according to the whole network average voltage drop value caused by each node fault and the grade interval of each risk grade.
10. The system of claim 9,
the average voltage drop value calculation formula is as follows:
Figure FDA0002927174290000041
the level interval for the kth risk level is:
Figure FDA0002927174290000042
wherein, Delta AvgViThe voltage drop value of the whole network caused by the fault of the node i is obtained; m is the number of nodes; delta Vi,jThe voltage drop difference value of the node j caused by the fault of the node i; f is the number of risk grades; delta AvgVmaxThe maximum value of the total network average voltage drop value caused by each node fault is obtained; delta AvgVminThe minimum value of the total network average voltage drop value caused by each node fault.
11. The system of claim 10, wherein the electrical network topology entropy calculation unit is configured to calculate the electrical network topology entropy for each alternative simultaneous outage and repair solution, respectively, and comprises:
Figure FDA0002927174290000043
Figure FDA0002927174290000051
Figure FDA0002927174290000052
Figure FDA0002927174290000053
Figure FDA0002927174290000054
wherein m isiIs the degree of node i; u ═ U1,U2,U3...,Um]Setting the number of sequence elements as a constant sequence and m in total; n iskIs the number m of degreesi∈(Uk,Uk+1]The number of nodes in the interval; p (k) is the number of node degrees in (U)k,Uk+1]A probability of an interval; l (k) is the node degree mi∈(Uk,Uk+1]N of (A) to (B)kThe average voltage drop value of the nodes of the receiving end power grid after the node faults; l iskiThe voltage drop value of the whole network caused by the fault of the node i is obtained; h is the topology entropy value of a given electrical network.
12. The system of claim 8, wherein the load-motor ratio calculating unit calculates the load-motor ratio of the time interval corresponding to each alternative simultaneous maintenance solution, respectively, and comprises:
Figure FDA0002927174290000055
wherein PMqFor the negative in the electric network corresponding to the q-th simultaneous maintenance schemeCharge motor ratio; powerq,iThe active power predicted value of the ith node of the qth synchronous-stop maintenance scheme is obtained; PM (particulate matter)q,iThe induction motor of the ith node of the qth synchronous shutdown maintenance scheme has a specific active power value; APowerqThe larger the motor ratio is, the larger the risk is for the sum of the active power values of the receiving-end power grid.
13. The system of claim 12, wherein the integrated risk assessment value calculation unit calculates an integrated risk assessment value for each alternative co-stop service option, respectively, comprising:
Rq＝(H0-Hq)+λ1/Kq+λ2PMq (9)
wherein R isqRisk for the qth scenario; h0The initial network entropy value is the initial entropy value corresponding to the network when no shutdown is adopted; hqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme is obtained; lambda [ alpha ]1And 22And determining the weight between the duty ratio and the short-circuit ratio of the load motor according to the actual condition of the maintenance period as a weight coefficient.
14. The system of claim 8, wherein the optimal co-stop maintenance schedule determination unit determines an optimal co-stop maintenance schedule based on the composite risk assessment value for each alternative co-stop maintenance schedule, comprising:
and selecting the alternative simultaneous maintenance-stopping scheme corresponding to the minimum comprehensive risk assessment value as the optimal simultaneous maintenance-stopping scheme according to the comprehensive risk assessment value of each alternative simultaneous maintenance-stopping scheme.
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