CN108428010B - Method and system for determining direct current receiving end simultaneous-stop maintenance scheme based on power angle stability - Google Patents
Method and system for determining direct current receiving end simultaneous-stop maintenance scheme based on power angle stability Download PDFInfo
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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 power angle stability, wherein the method comprises the following steps: aiming at each alternative simultaneous-stop maintenance scheme, calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network, and determining the risk level corresponding to each generator node fault; respectively calculating the topology entropy value of the electric network of each alternative simultaneous maintenance scheme; respectively calculating the sum of the duty ratio of the load motor and the rotation availability ratio of the unit in the time period corresponding to each alternative simultaneous shutdown 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. The method can directly obtain the optimal scheme for the power angle stability problem of the receiving-end system through simple numerical calculation, realize the rapid evaluation of the optimal scheme of the comprehensive maintenance and power failure plan, and improve the working efficiency and quality of the evaluation of the maintenance scheme.
Description
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 power angle 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 power angle stability, which aim 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 power angle stability, the method including:
aiming at each alternative simultaneous maintenance scheme, calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network, and determining the risk level corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault;
respectively calculating the topology entropy value of the electric network of each alternative simultaneous maintenance scheme;
respectively calculating the sum of the duty ratio of the load motor and the rotation availability ratio of the unit in the time period corresponding to each alternative simultaneous shutdown 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 maintenance and repair scheme, a full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network, and determining a risk level corresponding to each generator node fault according to the full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault includes:
determining typical fault types, and aiming at each alternative simultaneous shutdown maintenance scheme, performing transient stability calculation based on a power system analysis comprehensive program PSASP (power system analysis and analysis software package) to determine a power angle oscillation curve of each generator caused by the fault of each generator node and a characteristic damping ratio corresponding to the power angle oscillation curve of each generator;
calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault by using an average power angle oscillation characteristic damping ratio calculation formula according to the characteristic damping ratio corresponding to the power angle oscillation curve of each generator determined by each generator node fault;
and determining a grade interval of each risk grade, and determining a risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault and the grade interval of each risk grade.
Preferably, wherein
The calculation formula of the average power angle oscillation characteristic damping ratio is as follows:
the level interval for the kth risk level is:
wherein, Avg sigmaiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; m is the number of nodes of the generator; sigmajThe characteristic damping ratio of an oscillation curve corresponding to the generator node j when the generator node i fails is set; f is the number of risk grades; avg sigmamaxThe maximum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault; avg sigmaminAnd the minimum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault.
Preferably, the calculating the electric network topology entropy value of each alternative simultaneous maintenance scheduling scheme respectively includes:
wherein m isiThe degree of the generator node i; σ ═ σ [ σ ]1,σ2,σ3...,σm]The number of sequence elements is m in constant sequence; n iskIs the number m of degreesi∈(σk,σk+1]Number of generator nodes in interval; p (k) is the number of generator nodes degree at (σ)k,σk+1]A probability of an interval; l (k) is the number m of generator nodesi∈(σk,σk+1]N of (A) to (B)kThe average power angle oscillation characteristic damping ratio of the generator node of the receiving end power grid after the fault of the generator node; l iskiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; h is the electric network topology entropy value of a same-stop maintenance scheme.
Preferably, the calculating the sum of the duty ratio of the load motor and the rotational availability of the unit in the time period corresponding to each alternative simultaneous maintenance scheme respectively includes:
wherein PMqThe sum of the duty ratio of a load motor and the rotation availability ratio of a unit in the electric network corresponding to the qth same-stop maintenance scheme; 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 ratio of the ith node of the qth synchronous shutdown maintenance scheme is calculated; m isq,iThe degree of the ith node corresponding to the qth synchronous-stop maintenance scheme; APowerqThe sum of the active power values of the receiving-end power grid; pgenqThe unit rotation standby rate is the unit rotation standby rate corresponding to the qth same-stop maintenance scheme, and is obtained by subtracting the maximum load value from the installed capacity during maintenance and dividing the maximum load value by the total installed capacity; a and b are correction coefficients, and the values of the correction coefficients are selected according to experience; the larger the motor fraction the greater the risk.
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 isqThe risk degree of the q-th simultaneous-shutdown maintenance scheme is obtained; h0Is the initial network entropy, i.e. the initial entropy corresponding to the network without taking any outage, HqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme; 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 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 power angle stability, the system including:
the risk grade determining unit is used for calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network aiming at each alternative synchronous-stop maintenance scheme, and determining the risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault;
the electric network topology entropy calculation unit is used for calculating the electric network topology entropy of each alternative simultaneous maintenance scheme;
the load motor proportion and unit rotation availability sum calculating unit is used for calculating the load motor proportion and unit rotation availability sum of each alternative same-stop maintenance scheme corresponding time interval respectively;
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 maintenance and repair scheme, calculates a full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network, and determines a risk level corresponding to each generator node fault according to the full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault, including:
determining typical fault types, and aiming at each alternative simultaneous shutdown maintenance scheme, performing transient stability calculation based on a power system analysis comprehensive program PSASP (power system analysis and analysis software package) to determine a power angle oscillation curve of each generator caused by the fault of each generator node and a characteristic damping ratio corresponding to the power angle oscillation curve of each generator;
calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault by using an average power angle oscillation characteristic damping ratio calculation formula according to the characteristic damping ratio corresponding to the power angle oscillation curve of each generator determined by each generator node fault;
and determining a grade interval of each risk grade, and determining a risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault and the grade interval of each risk grade.
Preferably, wherein
The calculation formula of the average power angle oscillation characteristic damping ratio is as follows:
the level interval for the kth risk level is:
wherein, Avg sigmaiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; m is the number of nodes of the generator; sigmajThe characteristic damping ratio of an oscillation curve corresponding to the generator node j when the generator node i fails is set; f is the number of risk grades; avg sigmamaxThe maximum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault; avg sigmaminAnd the minimum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator 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:
wherein m isiThe degree of the generator node i; σ ═ σ [ σ ]1,σ2,σ3...,σm]The number of sequence elements is m in constant sequence; n iskIs the number m of degreesi∈(σk,σk+1]Number of generator nodes in interval; p (k) is the number of generator nodes degree at (σ)k,σk+1]A probability of an interval; l (k) is the number m of generator nodesi∈(σk,σk+1]N of (A) to (B)kThe average power angle oscillation characteristic damping ratio of the generator node of the receiving end power grid after the fault of the generator node; l iskiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; h is the electric network topology entropy value of a same-stop maintenance scheme.
Preferably, the load motor ratio and rotation availability sum calculating unit respectively calculates the load motor ratio and the set rotation availability sum in the time period corresponding to each alternative synchronous-stop maintenance scheme, and includes:
wherein PMqThe sum of the duty ratio of a load motor and the rotation availability ratio of a unit in the electric network corresponding to the qth same-stop maintenance scheme; 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 ratio of the ith node of the qth synchronous shutdown maintenance scheme is calculated; m isq,iThe degree of the ith node corresponding to the qth synchronous-stop maintenance scheme; APowerqThe sum of the active power values of the receiving-end power grid; pgenqThe unit rotation standby rate is the unit rotation standby rate corresponding to the qth same-stop maintenance scheme, and is obtained by subtracting the maximum load value from the installed capacity during maintenance and dividing the maximum load value by the total installed capacity; a and b are correction coefficients, and the values of the correction coefficients are selected according to experience; electric driveThe greater the duty cycle, the greater the risk.
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 isqThe risk degree of the q-th simultaneous-shutdown maintenance scheme is obtained; h0Is the initial network entropy, i.e. the initial entropy corresponding to the network without taking any outage, HqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme; 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-stop maintenance scheme based on power angle stability.
Drawings
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 method 100 for determining a dc receiving-end simultaneous-shutdown maintenance scheme based on power angle stability according to an embodiment of the present invention; and
fig. 2 is a schematic structural diagram of a dc receiving-end simultaneous-outage maintenance scheme determination system 200 based on power angle 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 method 100 for determining a dc receiving-end simultaneous-outage maintenance scheme based on power angle stability according to an embodiment of the present invention. According to the method 100 for determining the direct-current receiving-end simultaneous-stop maintenance scheme based on the power angle stability, provided by the embodiment of the invention, through the risk assessment of the receiving-end power grid comprehensive maintenance power failure plan of single super direct current, the problem of receiving-end system power angle stability can be directly obtained through simple numerical calculation to obtain the optimal scheme, the rapid assessment of the optimal scheme of the comprehensive maintenance power failure plan is realized, the problem that the conventional comprehensive maintenance power failure plan is subjected to a processing mode of repeated calculation and check is solved, and the working efficiency and quality of maintenance scheme assessment are improved. The method 100 for determining the power-angle-stability-based direct-current receiving-end simultaneous maintenance scheme provided by the embodiment of the invention starts from step 101, calculates the damping ratio of the full-network average power-angle oscillation characteristic corresponding to each generator node fault in the electric network for each alternative simultaneous maintenance scheme in step 101, and determines the risk level corresponding to each generator node fault according to the damping ratio of the full-network average power-angle oscillation characteristic corresponding to each generator node fault.
Preferably, the calculating, for each alternative simultaneous maintenance and repair scheme, a full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network, and determining a risk level corresponding to each generator node fault according to the full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault includes:
determining typical fault types, and aiming at each alternative simultaneous shutdown maintenance scheme, performing transient stability calculation based on a power system analysis comprehensive program PSASP (power system analysis and analysis software package) to determine a power angle oscillation curve of each generator caused by the fault of each generator node and a characteristic damping ratio corresponding to the power angle oscillation curve of each generator;
calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault by using an average power angle oscillation characteristic damping ratio calculation formula according to the characteristic damping ratio corresponding to the power angle oscillation curve of each generator determined by each generator node fault;
and determining a grade interval of each risk grade, and determining a risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault and the grade interval of each risk grade.
Preferably, the calculation formula of the damping ratio of the characteristic of the average power angle oscillation is as follows:
the level interval for the kth risk level is:
wherein, Avg sigmaiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; m is the number of nodes of the generator; sigmajIs a generator node jThe characteristic damping ratio of the corresponding oscillation curve when the generator node i fails; f is the number of risk grades; avg sigmamaxThe maximum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault; avg sigmaminAnd the minimum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator 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 loss of voltage of a bus of a generator node is taken as a typical fault.
Step 1: and performing transient stability calculation by adopting a PSASP 7.31 version power system analysis comprehensive program PSASP, and sequentially calculating a power angle oscillation curve of the i-th node with the voltage loss fault. Setting 0 second to start simulation calculation, wherein the total simulation time is 40 seconds, and if 1 second fails, taking the initial power angle delta before the failure with the voltage of 0.5 second as the given jth nodej,t＝0.5Taking the stable work angle after the fault of the given jth node at the 35 th second moment as deltaj,t＝35Then, by carrying out PRONY analysis on the power angle oscillation curve in the period of 0.5-30 seconds, the damping ratio numerical value of the lowest damping ratio term is taken as the characteristic damping ratio sigma of the oscillation curvej. Calculating the average power angle oscillation characteristic damping ratio Avg sigma of the full alternating current network caused by each generator node according to the average power angle oscillation characteristic damping ratio calculation formulai。
Step 2: the network average power angle oscillation characteristic damping ratio Avg sigma corresponding to M given node faults obtained from the Step1iAnd (6) sorting.
Step 3: setting the number of risk levels as F, wherein F is less than the number of nodes M-1, determining the grade interval of each risk level, and dividing the network nodes into F sets according to the total network average power angle oscillation characteristic damping ratio caused by the fault of each node and the grade 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:
wherein m isiThe degree of the generator node i; σ ═ σ [ σ ]1,σ2,σ3...,σm]The number of sequence elements is m in constant sequence; n iskIs the number m of degreesi∈(σk,σk+1]Number of generator nodes in interval; p (k) is the number of generator nodes degree at (σ)k,σk+1]A probability of an interval; l (k) is the number m of generator nodesi∈(σk,σk+1]N of (A) to (B)kThe average power angle oscillation characteristic damping ratio of the generator node of the receiving end power grid after the fault of the generator node; l iskiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; h is the electric network topology entropy value of a same-stop maintenance scheme.
Preferably, the sum of the duty ratio of the load motor and the rotational availability of the unit in the time interval corresponding to each alternative simultaneous maintenance scheme is calculated in step 103.
Preferably, the calculating the sum of the duty ratio of the load motor and the rotational availability of the unit in the time period corresponding to each alternative simultaneous maintenance scheme respectively includes:
wherein PMqThe sum of the duty ratio of a load motor and the rotation availability ratio of a unit in the electric network corresponding to the qth same-stop maintenance scheme; 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 ratio of the ith node of the qth synchronous shutdown maintenance scheme is calculated; m isq,iThe degree of the ith node corresponding to the qth synchronous-stop maintenance scheme; APowerqThe sum of the active power values of the receiving-end power grid; pgenqThe unit rotation standby rate is the unit rotation standby rate corresponding to the qth same-stop maintenance scheme, and is obtained by subtracting the maximum load value from the installed capacity during maintenance and dividing the maximum load value by the total installed capacity; a and b are correction coefficients, and the values of the correction coefficients are selected according to experience; the larger the motor fraction the greater the risk.
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 isqThe risk degree of the q-th simultaneous-shutdown maintenance scheme is obtained; h0Is the initial network entropy, i.e. the initial entropy corresponding to the network without taking any outage, HqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme; 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, 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-outage maintenance scheme determination system 200 based on power angle stability according to an embodiment of the present invention. As shown in fig. 2, a dc receiving-end simultaneous outage maintenance scheme determination system 200 based on power angle stability according to an embodiment of the present invention includes: the system comprises a risk level determining unit 201, an electric network topology entropy value calculating unit 202, a load motor ratio and rotation availability ratio sum calculating unit 203, a comprehensive risk assessment value calculating unit 204 and an optimal simultaneous shutdown and overhaul scheme determining unit 205. Preferably, in the risk level determining unit 201, for each alternative simultaneous maintenance and repair scheme, a full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network is calculated, and a risk level corresponding to each generator node fault is determined according to the full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault.
Preferably, the risk level determining unit, for each alternative simultaneous maintenance and repair scheme, calculates a full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network, and determines a risk level corresponding to each generator node fault according to the full-network average power-angle oscillation characteristic damping ratio corresponding to each generator node fault, including: determining typical fault types, and aiming at each alternative simultaneous shutdown maintenance scheme, performing transient stability calculation based on a power system analysis comprehensive program PSASP (power system analysis and analysis software package) to determine a power angle oscillation curve of each generator caused by the fault of each generator node and a characteristic damping ratio corresponding to the power angle oscillation curve of each generator; calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault by using an average power angle oscillation characteristic damping ratio calculation formula according to the characteristic damping ratio corresponding to the power angle oscillation curve of each generator determined by each generator node fault; and determining a grade interval of each risk grade, and determining a risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault and the grade interval of each risk grade.
Preferably, the calculation formula of the damping ratio of the characteristic of the average power angle oscillation is as follows:
the level interval for the kth risk level is:
wherein, Avg sigmaiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; m is the number of nodes of the generator; sigmajThe characteristic damping ratio of an oscillation curve corresponding to the generator node j when the generator node i fails is set; f is the number of risk grades; avg sigmamaxThe maximum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault; avg sigmaminAnd the minimum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault.
Preferably, in the electric network topology entropy calculation unit 202, the electric network topology entropy value of each alternative simultaneous maintenance scheduling scheme is calculated.
Preferably, the electric network topology entropy calculation unit calculates the electric network topology entropy of each alternative simultaneous maintenance scheduling scheme, respectively, and includes:
wherein m isiThe degree of the generator node i; σ ═ σ [ σ ]1,σ2,σ3...,σm]The number of sequence elements is m in constant sequence; n iskIs the number m of degreesi∈(σk,σk+1]Number of generator nodes in interval; p (k) is the number of generator nodes degree at (σ)k,σk+1]A probability of an interval; l (k) is the number m of generator nodesi∈(σk,σk+1]N of (A) to (B)kThe average power angle oscillation characteristic damping ratio of the generator node of the receiving end power grid after the fault of the generator node; l iskiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; h is the electric network topology entropy value of a same-stop maintenance scheme.
Preferably, in the load motor ratio and unit rotation availability sum calculating unit 203, the load motor ratio and unit rotation availability sum of the time interval corresponding to each alternative simultaneous maintenance scheme is calculated respectively.
Preferably, the load motor ratio and rotation availability sum calculating unit respectively calculates the load motor ratio and the set rotation availability sum in the time period corresponding to each alternative synchronous-stop maintenance scheme, and includes:
wherein PMqThe duty ratio of a load motor and the unit rotation in the electric network corresponding to the q-th simultaneous-stop maintenance schemeSum of conversion and reserve rates; 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 ratio of the ith node of the qth synchronous shutdown maintenance scheme is calculated; m isq,iThe degree of the ith node corresponding to the qth synchronous-stop maintenance scheme; APowerqThe sum of the active power values of the receiving-end power grid; pgenqThe unit rotation standby rate is the unit rotation standby rate corresponding to the qth same-stop maintenance scheme, and is obtained by subtracting the maximum load value from the installed capacity during maintenance and dividing the maximum load value by the total installed capacity; a and b are correction coefficients, and the values of the correction coefficients are selected according to experience; the larger the motor fraction the greater the risk.
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 isqThe risk degree of the q-th simultaneous-shutdown maintenance scheme is obtained; h0Is the initial network entropy, i.e. the initial entropy corresponding to the network without taking any outage, HqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme; 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 power-angle-stability-based dc-receiving-end simultaneous outage and repair scheme determination system 200 in the embodiment of the present invention corresponds to the power-angle-stability-based dc-receiving-end simultaneous outage and repair scheme determination method 100 in 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 direct current receiving end simultaneous shutdown maintenance scheme determination method based on power angle stability is characterized by comprising the following steps:
aiming at each alternative simultaneous maintenance scheme, calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network, and determining the risk level corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault;
respectively calculating the topology entropy value of the electric network of each alternative simultaneous maintenance scheme;
respectively calculating the sum of the duty ratio of the load motor and the rotation availability ratio of the unit in the time period corresponding to each alternative simultaneous shutdown 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 full-grid average power-angle oscillation characteristic damping ratio corresponding to each generator node fault in the electrical network, and determining a risk level corresponding to each generator node fault according to the full-grid average power-angle oscillation characteristic damping ratio corresponding to each generator node fault comprises:
determining typical fault types, and aiming at each alternative simultaneous shutdown maintenance scheme, performing transient stability calculation based on a power system analysis comprehensive program PSASP (power system analysis and analysis software package) to determine a power angle oscillation curve of each generator caused by the fault of each generator node and a characteristic damping ratio corresponding to the power angle oscillation curve of each generator;
calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault by using an average power angle oscillation characteristic damping ratio calculation formula according to the characteristic damping ratio corresponding to the power angle oscillation curve of each generator determined by each generator node fault;
and determining a grade interval of each risk grade, and determining a risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault and the grade interval of each risk grade.
3. The method of claim 2,
the calculation formula of the average power angle oscillation characteristic damping ratio is as follows:
the level interval for the kth risk level is:
wherein, Avg sigmaiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; m is the number of nodes of the generator; sigmajThe characteristic damping ratio of an oscillation curve corresponding to the generator node j when the generator node i fails is set; f is the number of risk grades; avg sigmamaxThe maximum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault; avg sigmaminAnd the minimum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator 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:
wherein m isiThe degree of the generator node i; σ ═ σ [ σ ]1,σ2,σ3...,σm]The number of sequence elements is m in constant sequence; n iskIs the number m of degreesi∈(σk,σk+1]Number of generator nodes in interval; p (k) is the number of generator nodes degree at (σ)k,σk+1]A probability of an interval; l (k) is the number m of generator nodesi∈(σk,σk+1]N of (A) to (B)kThe average power angle oscillation characteristic damping ratio of the generator node of the receiving end power grid after the fault of the generator node; l iskiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; h is the electric network topology entropy value of a same-stop maintenance scheme.
5. The method according to claim 1, wherein the separately calculating the sum of the duty ratio of the load motor and the rotational availability of the unit in the time interval corresponding to each alternative simultaneous maintenance scheme comprises:
wherein PMqThe sum of the duty ratio of a load motor and the rotation availability ratio of a unit in the electric network corresponding to the qth same-stop maintenance scheme; 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 ratio of the ith node of the qth synchronous shutdown maintenance scheme is calculated; m isq,iThe degree of the ith node corresponding to the qth synchronous-stop maintenance scheme; APowerqThe sum of the active power values of the receiving-end power grid; pgenqThe unit rotation standby rate is the unit rotation standby rate corresponding to the qth same-stop maintenance scheme, and is obtained by subtracting the maximum load value from the installed capacity during maintenance and dividing the maximum load value by the total installed capacity; a and b are correction coefficients, and the values of the correction coefficients are selected according to experience; the larger the motor fraction the greater the risk.
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 isqThe risk degree of the q-th simultaneous-shutdown maintenance scheme is obtained; h0Is the initial network entropy, i.e. the initial entropy corresponding to the network without taking any outage, HqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme; 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 power angle stability is characterized by comprising:
the risk grade determining unit is used for calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault in the electric network aiming at each alternative synchronous-stop maintenance scheme, and determining the risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault;
the electric network topology entropy calculation unit is used for calculating the electric network topology entropy of each alternative simultaneous maintenance scheme;
the load motor proportion and unit rotation availability sum calculating unit is used for calculating the load motor proportion and unit rotation availability sum of each alternative same-stop maintenance scheme corresponding time interval respectively;
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, for each alternative simultaneous outage and maintenance solution, calculates a full-grid average power-angle oscillation characteristic damping ratio corresponding to each generator node fault in the electrical network, and determines the risk level corresponding to each generator node fault according to the full-grid average power-angle oscillation characteristic damping ratio corresponding to each generator node fault, including:
determining typical fault types, and aiming at each alternative simultaneous shutdown maintenance scheme, performing transient stability calculation based on a power system analysis comprehensive program PSASP (power system analysis and analysis software package) to determine a power angle oscillation curve of each generator caused by the fault of each generator node and a characteristic damping ratio corresponding to the power angle oscillation curve of each generator;
calculating the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault by using an average power angle oscillation characteristic damping ratio calculation formula according to the characteristic damping ratio corresponding to the power angle oscillation curve of each generator determined by each generator node fault;
and determining a grade interval of each risk grade, and determining a risk grade corresponding to each generator node fault according to the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault and the grade interval of each risk grade.
10. The system of claim 9,
the calculation formula of the average power angle oscillation characteristic damping ratio is as follows:
the level interval for the kth risk level is:
wherein, Avg sigmaiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; m is the number of nodes of the generator; sigmajThe characteristic damping ratio of an oscillation curve corresponding to the generator node j when the generator node i fails is set; f is the number of risk grades; avg sigmamaxThe maximum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator node fault; avg sigmaminAnd the minimum value of the full-network average power angle oscillation characteristic damping ratio corresponding to each generator 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:
wherein m isiDegree of generator node i；σ＝[σ1,σ2,σ3...,σm]The number of sequence elements is m in constant sequence; n iskIs the number m of degreesi∈(σk,σk+1]Number of generator nodes in interval; p (k) is the number of generator nodes degree at (σ)k,σk+1]A probability of an interval; l (k) is the number m of generator nodesi∈(σk,σk+1]N of (A) to (B)kThe average power angle oscillation characteristic damping ratio of the generator node of the receiving end power grid after the fault of the generator node; l iskiThe characteristic damping ratio of the full-network average power angle oscillation corresponding to the fault of the generator node i is obtained; h is the electric network topology entropy value of a same-stop maintenance scheme.
12. The system according to claim 8, wherein the load motor ratio and rotation availability ratio sum calculating unit respectively calculates the load motor ratio and the set rotation availability ratio sum of each alternative same-stop maintenance scheme corresponding time interval, and includes:
wherein PMqThe sum of the duty ratio of a load motor and the rotation availability ratio of a unit in the electric network corresponding to the qth same-stop maintenance scheme; 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 ratio of the ith node of the qth synchronous shutdown maintenance scheme is calculated; m isq,iThe degree of the ith node corresponding to the qth synchronous-stop maintenance scheme; APowerqThe sum of the active power values of the receiving-end power grid; pgenqThe unit rotation standby rate is the unit rotation standby rate corresponding to the qth same-stop maintenance scheme, and is obtained by subtracting the maximum load value from the installed capacity during maintenance and dividing the maximum load value by the total installed capacity; a and b are correction coefficients, and the values of the correction coefficients are selected according to experience; the larger the motor fraction the greater the risk.
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 isqThe risk degree of the q-th simultaneous-shutdown maintenance scheme is obtained; h0Is the initial network entropy, i.e. the initial entropy corresponding to the network without taking any outage, HqThe network entropy value corresponding to the qth scheme; kqThe short-circuit current ratio of the qth synchronous-stop maintenance scheme; 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.
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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