CN112434936A - Power system inertia security domain evaluation method and system, electronic equipment and readable storage medium - Google Patents

Power system inertia security domain evaluation method and system, electronic equipment and readable storage medium Download PDF

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CN112434936A
CN112434936A CN202011320152.1A CN202011320152A CN112434936A CN 112434936 A CN112434936 A CN 112434936A CN 202011320152 A CN202011320152 A CN 202011320152A CN 112434936 A CN112434936 A CN 112434936A
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inertia
power system
frequency
security domain
electric power
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CN112434936B (en
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文云峰
林晓煌
李元臣
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Hunan University
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    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
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Abstract

The invention discloses a method and a system for evaluating an inertia security domain of an electric power system, electronic equipment and a readable storage medium, wherein the method comprises the following steps: acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints; the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into the electric power system inertia safety domain evaluation model, and carrying out model solving to obtain the inertia safety domain of the electric power system.

Description

Power system inertia security domain evaluation method and system, electronic equipment and readable storage medium
Technical Field
The invention belongs to the technical field of power system operation scheduling, and particularly relates to a method and a system for evaluating an inertia security domain of a power system, electronic equipment and a readable storage medium.
Background
With the continuous incorporation of asynchronous power supplies such as wind power, photovoltaic and direct current, the number and capacity of converters connected into a power grid rapidly rise, so that the converters gradually develop into a converter high-ratio power system. As new energy, direct current and other asynchronous components are connected to a power grid through a power electronic converter, transmission power of the new energy, direct current and other asynchronous components is decoupled from power grid frequency under conventional control, and inertia support cannot be actively provided for a system under active disturbance. The full-chain and large-scale grid connection of the source-grid-load converter can replace a large number of mechanical synchronous rotating devices, greatly reduce the level of the rotational inertia of the system and seriously weaken the inertia response and the frequency regulation capability of the system under active disturbance.
Under the condition that the rotational inertia level of the system is too low, once active disturbance events such as tripping operation of a large unit or direct current blocking occur, the frequency of the power system can be changed rapidly, and the actions of a safety automatic protection device of a third defense line of the power system such as a low-frequency load reduction machine or a high-frequency generator tripping machine are easily triggered, so that large-area power failure accidents are caused. Therefore, power system operators including British power grids, Ireland power grids and the like establish a system rotational inertia monitoring system, real-time monitoring is carried out on the system rotational inertia level, and the system is prevented from falling into an ultra-low inertia operation scene.
However, an effective inertia safety judgment basis is still lacked in the current power system scheduling operation process, so that related workers still cannot judge the level of the inertia value after knowing the system rotational inertia. Therefore, under the background of accessing a large-scale converter, a power grid operation and scheduling staff urgently needs an evaluation method capable of effectively judging whether the rotational inertia of a power system is within a safety range, so as to assist in analyzing whether the overall rotational inertia level of the system in a current or planned operation scene is enough to support that the power grid frequency does not exceed a safety stability limit value under the condition of large disturbance, and further ensure that the system frequency in the transient process cannot trigger low-frequency load reduction protection to cause serious consequences such as large-area power failure.
Therefore, a more accurate and effective inertia safety judgment and evaluation means is needed to meet the requirements of the power system.
Disclosure of Invention
The invention aims to provide a brand-new means for realizing the evaluation of the inertia security domain of the power system, the area maximization of the inertia security domain is taken as an optimization objective function, and the lower bound of the inertia security domain and the upper bound of the inertia security domain are integrated in an evaluation result.
The invention provides a method for evaluating an inertia security domain of an electric power system, which comprises the following steps:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
The inertia safety domain calculated by the solution model is a range determined by available total inertia (an upper boundary of the inertia safety domain) and an inertia safety critical value (a lower boundary of the inertia safety domain) of the power system in the research period T. After the inertia security domain in the target scene can be obtained through research by using the method, the safety of the system inertia in the target operation scene can be judged in real time based on the inertia security domain. Further preferably, the objective function is as follows:
Figure BDA0002792614290000021
wherein phi isHThe area size of the inertia security domain is represented,
Figure BDA0002792614290000022
representing the total available inertia of the power system during the t period; hSIL(T) represents an inertia safety critical value of the power system at the T-th period, and T represents the length of the evaluation period.
Because the area of the inertia safety domain is equal to the integral value of the difference between the total available inertia of the system and the inertia safety critical value, the invention takes the area maximization of the inertia safety domain as an optimization target, so that when the area of the inertia safety domain reaches the maximum value in the solving process, the total available inertia of the system and the inertia safety critical value respectively reach the maximum value and the minimum value, and further, the model can be solved, the actual inertia requirement of the power system in the target research scene can be obtained, and the adjustable space of the inertia of the system can be obtained.
Optionally, the frequency-stable safety constraint comprises a transient frequency extremum fextremumConstraining and limiting the transient frequency limit value fextremumCarrying out linearization processing on the coupling relation with the system inertia so as to further carry out the transient frequency extreme value fextremumThe constraint transforms into a constraint as follows:
Figure BDA0002792614290000023
in the formula, HISR(t) represents a inertia security domain boundary value, fNRepresenting the rated frequency of the power system, D representing the damping effect of the power system, fdbIs a primary frequency modulation dead zone of the generator set, PfShowing the magnitude of the active disturbance caused by a standard fault, fmin、fmaxAnd respectively representing the stability lower limit and the stability upper limit of the frequency, wherein R is the integral frequency modulation speed of the system under the condition of disturbance caused by the standard fault.
In an alternative embodiment of the present invention, the transient frequency is limited to fextremumAnd (3) constraint: f. ofmin≤fextremum(t)≤fmaxThe constraint conditions are converted into the above constraint conditions, and the power system inertia security domain evaluation model constructed based on consideration relates to system inertia and transient frequencyThe strong nonlinear relation of the efficiency extreme value is difficult to solve directly and has solving time efficiency and accuracy. According to the method, the integral frequency modulation speed evaluation model of the system is established in advance, wherein the strong nonlinear relation between the inertia of the system and the transient frequency extreme value is subjected to linearization processing, so that the integral inertia safety domain evaluation model is converted into a linear optimization model, the model can be rapidly solved on the premise of ensuring the accuracy, and the safety requirement of the operation of the power system and the real-time judgment of system inertia level of a dispatcher can be met. In addition, based on the constrained model, the coupling relation between the system inertia and the transient frequency extreme value is comprehensively considered, so that the transient frequency extreme value approaches to a stability limit under the condition of large disturbance when the system inertia level approaches to the inertia safety critical value, the conservative degree of the model is reduced, and the accuracy of the finally obtained inertia safety critical value is greatly improved.
Particularly, compared with the existing frequency Change Rate constraint method, the method is characterized in that when the minimum rotational inertia requirement of the power system is analyzed, the safety critical value of the inertia of the power system is solved under the constraint that the frequency Change Rate does not exceed a certain maximum limit value by considering the relationship between the integral inertia level of the system and the frequency Change Rate (rocaf). However, because the frequency change rate constraint method ignores the coupling relation between the system inertia and the transient frequency extreme value, the analysis result generally tends to be conservative, and the method has the defect of insufficient evaluation precision, and is not beneficial to supporting the deep consumption of the power system on new energy and promoting the sufficient sharing of cross-regional power resources.
Compared with the existing time domain simulation approximation method, the method has the advantages that the dynamic model of the target power system is built for simulation, the system inertia level is adjusted according to the frequency curve obtained by simulation, and when the simulation frequency result (frequency change rate and transient frequency extreme value) is in a certain neighborhood of a corresponding specified value, the corresponding inertia level value is used as the inertia safety critical value of the power system. However, the inertia requirement of the power system can only be calculated off-line by means of simulation software, and the urgent requirements of real-time monitoring and rapid evaluation of the safety of the inertia level of the power system operation and scheduling personnel under multiple complex uncertainties cannot be met. The method utilizes the linear processing, greatly accelerates the model solving speed, and meets the requirement of rapidly evaluating the safety of the system inertia level.
In response to the understanding, the above alternative takes into account the transient frequency limit fextremumConstraining, performing linear processing, and in other alternative ways, considering the transient frequency extreme value fextremumNot performing linear processing under constraint, using fmin≤fextremum(t)≤fmaxThe original constraint constrains the relevant parameters in the model, except that the model of linear processing has better corresponding solution and faster solution speed compared with the model of linear processing.
Optionally, the frequency-stable safety constraint comprises a transient frequency extremum fextremumConstraints and frequency change rate constraints, as follows:
RoCoFmin≤RoCoFinertial(t)≤RoCoFmax
fmin≤fextremum(t)≤fmax
in the formula, RoCoFinertial(t) represents the frequency change rate of the power system at the moment after the standard fault corresponding to the time period t occurs; RoCoFmaxAnd RoCoFminRespectively representing the maximum and minimum values of frequency variation, f, prescribed for safe operation of the power systemmaxAnd fminRespectively representing the maximum value and the minimum value of the frequency specified by the safe operation of the power system;
the power system inertia security domain evaluation model further comprises a system integral inertia level constraint, and the method comprises the following steps:
Figure BDA0002792614290000041
wherein Hmax、HminRespectively representing the upper limit and the lower limit of the overall inertia of the system.
In the above alternative, the model constraint includes a system global inertia level constraint and a frequency stability safety constraint.
Optionally, the standard fault is a limit expected fault, and the limit expected fault is the most serious fault of the power system in the range of the studied scenes;
wherein in critical N-2 failure set
Figure BDA0002792614290000042
The fault with the largest induced active disturbance is taken as the limit predicted fault, and the following steps are carried out:
Figure BDA0002792614290000043
wherein, PfThe magnitude of active disturbance, | F, caused by the ultimate predicted faultmnCorresponding to the magnitude of active disturbance caused by the simultaneous loss of the mth element and the nth element of the power system;
Figure BDA0002792614290000044
representing a set of critical N-2 faults, NtotalIndicating the total number of single failures.
Wherein the total number of single faults Ntotal＝NSG+NDC+NRE，NSGFor the total number of synchronous generator sets in the system, NDCFor the total number of DC transmission lines in the system, NREThe total number of the wind power, photovoltaic and other new energy source units in the system. It should be understood that in the present embodiment, a failure of losing 2 elements at the same time is considered, and a failure of losing another number of elements, such as 1 or 3, may be considered in other feasible manners; meanwhile, the limit expected fault is determined by taking the active disturbance caused by the limit expected fault as a standard, and in other feasible embodiments, other parameters for measuring the influence of the system fault can be used as the standard to determine the limit expected fault. Similarly, in other possible embodiments, faults determined by other influences or other rule criteria may also be taken as standard faults, and the standard faults are essentially fault criteria of the inertia security domain.
Optionally, when the standard fault is an extreme expected fault, the overall frequency modulation speed R of the system in the case of disturbance caused by the standard fault is determined according to the following formula:
Figure BDA0002792614290000045
wherein R isSG,i、RDC,jAnd RRE,kRespectively representing the active regulation speed R of the conventional generator set i, the direct current transmission line j and the new energy source set k when the system suffers serious active disturbanceSPEquivalent frequency modulation rate, y, representing a stability control schemeSG,i、yDC,jAnd yRE,kAll the variables are binary variables, and represent the loss elements of the system after the limit expected fault occurs, if a conventional generator set i, a direct current transmission line j and a new energy source set k exist, the corresponding ySG,i、yDC,jAnd yRE,kThe value is 0, if the element is in the operating state, the corresponding ySG,i、yDC,jAnd yRE,kThe value is taken to be 1.
Wherein, the serious active disturbance refers to the active regulation speed when the frequency modulation capability of the power system reaches saturation when the fault is serious to a certain degree.
Optionally, the method further comprises: after obtaining the inertia security domain of the electric power system, measuring the evaluation accuracy of the inertia security domain of the electric power system by adopting the relative error of the frequency change rate and the relative error of the transient frequency extreme value, as follows:
Figure BDA0002792614290000051
Figure BDA0002792614290000052
wherein epsilonrRepresenting the relative error of the rate of change of frequency, epsilonfRepresenting the relative error of the extreme value of the transient frequency;
Figure BDA0002792614290000053
Figure BDA0002792614290000054
respectively representing the instantaneous frequency change rate and the transient frequency extreme value after the standard fault is simulated under the standard fault after the integral inertia of the system is set as the lower boundary value of the inertia security domain; RoCoFmin、RoCoFmaxRespectively representing a stable lower limit value and a stable upper limit value of the frequency change rate; f. ofmin、fmaxRespectively representing the maximum and minimum frequency values, P, prescribed for safe operation of the power systemfIndicating the magnitude of active disturbance caused by a standard fault.
In a second aspect, the present invention further provides an evaluation system for an inertia security domain of an electric power system, including:
an acquisition module of an inertia security domain evaluation model of the power system: the method comprises the steps of obtaining an electric power system inertia security domain evaluation model, wherein the electric power system inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stabilization security constraints;
a performance parameter acquisition module: the method comprises the steps of obtaining performance parameters of the power system to be evaluated;
a model solving module: and substituting the performance parameters into the power system inertia safety domain evaluation model to perform model solution to obtain the inertia safety domain of the power system, wherein the performance parameters are parameters required for solving the power system inertia safety domain evaluation model.
In a third aspect, the present invention further provides an electronic terminal, including a processor and a memory, where the memory stores a computer program, and the processor calls the computer program to execute:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
In a fourth aspect, the present invention also provides a readable storage medium storing a computer program, the computer program being invoked by a processor to perform:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
Advantageous effects
According to the evaluation method provided by the invention, the area maximization of the inertia safety domain is taken as an optimization objective function, and then the lower bound of the inertia safety domain and the upper bound of the inertia safety domain are comprehensively obtained in the evaluation result.
In a further preferred scheme, the model only takes into account the linear relationship between the system inertia and the rocef index, which is different from a frequency change rate constraint method, and the method comprehensively considers the coupling relationship between the system inertia, the frequency change rate and the transient frequency extreme value when defining the lower bound of an inertia safety domain, namely an inertia safety critical value, so that the system frequency change rate does not exceed a limit value under the condition of large disturbance and the transient frequency extreme value approaches a stability limit under the condition of large disturbance can be more effectively ensured, the conservative degree of the model is reduced, and the accuracy of the finally obtained inertia safety critical value is greatly improved. Particularly, the strong nonlinear relation between the system inertia and the transient frequency extreme value is subjected to linearization processing, so that the whole inertia security domain evaluation model is converted into a linear optimization model, the model can be rapidly solved on the premise of ensuring the accuracy, and the safety requirement of the power system operation and dispatching personnel on real-time judgment of the system inertia level can be met.
Drawings
Fig. 1 is a schematic diagram of a flow of a method for evaluating an inertia security domain of an electrical power system according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a transient frequency extremum constrained linearization process according to an embodiment of the present invention;
FIG. 3 is a diagram of a new England system topology provided by an embodiment of the present invention;
fig. 4 is a schematic diagram of an inertia security domain evaluation result according to an embodiment of the present invention.
Detailed Description
In order that the above objects, features and advantages of the present invention can be more clearly understood, a more particular description of the invention will be rendered by reference to the appended drawings. It should be noted that the embodiments and features of the embodiments of the present application may be combined with each other without conflicting with each other. In the following description, numerous specific details are set forth in order to provide a thorough understanding of the present invention, however, the present invention may be practiced in other ways than those specifically described and thus the scope of the present invention is not limited by the specific embodiments disclosed below.
The invention provides a method for evaluating an inertia security domain of an electric power system, which mainly comprises the following steps: the method comprises the steps of obtaining an electric power system inertia safety domain evaluation model, obtaining performance parameters of an electric power system to be evaluated, substituting the performance parameters into the electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system. Wherein the objective function is as follows:
Figure BDA0002792614290000071
wherein phi isHThe area size of the inertia security domain is represented,
Figure BDA0002792614290000072
representing the available total inertia of the power system in the t period, namely an upper bound of an inertia security domain; hSIL(T) represents an inertia safety critical value of the power system at the T-th period, namely a lower bound of an inertia safety domain, and T represents the length of the evaluation period.
In order to solve the above objective function, optional ranges or optional requirements of an upper boundary of the inertia security domain and a lower boundary of the inertia security domain during the period t in the evaluation period are required to be known, and for this reason, constraint conditions are set.
Example (b):
aiming at the framework, the performance parameters of the power system in the embodiment of the invention at least comprise potential limit predicted faults and the overall frequency modulation speed of the system in a prediction research scene, further the limit predicted faults in the research scene are obtained by screening the maximum active disturbance power from the key N-2 faults in a centralized manner, and the overall frequency modulation speed of the system can be predicted based on the rotating reserve capacity and the speed regulation rate of a generator set, the Frequency Limit Control (FLC) regulation space and the regulation speed of a direct current transmission line and the stability control scheme corresponding to the limit predicted faults; and substituting the obtained limit expected fault and the integral frequency modulation speed of the system into the power system inertia safety domain evaluation model, and solving the inertia safety domain evaluation model to obtain the inertia safety domain of the target power system in the current or planned operation scene.
Screening for extreme forecast faults
Enumerating system generator set tripping faults and direct current blocking faults to form an N-2 fault set
Figure BDA0002792614290000073
And then screening is carried out. In the embodiment, the model solution is enlarged to avoid time-consuming traversal and verification of all potential expected faults in the solution process of the inertia security domain evaluation modelSolving time cost, firstly screening the most serious fault possibly suffered by the system under a researched operation scene, namely the ultimate predicted fault before evaluating the inertia security domain of the power system, specifically: in critical N-2 fault set
Figure BDA0002792614290000085
Screening out the fault causing the maximum active disturbance, and determining the fault as the limit expected fault of the subsequent estimation inertia security domain boundary:
Figure BDA0002792614290000081
wherein, PfThe size of active disturbance caused by faults is predicted for the limit; i FmnCorresponding to the magnitude of active disturbance caused by the simultaneous loss of the mth element and the nth element (a generator or a direct current transmission line) of the power system;
Figure BDA0002792614290000082
representing a critical N-2 fault set containing faults including genset trip and dc blocking faults.
Critical N-2 failure set
Figure BDA0002792614290000086
The expression of (a) is:
Figure BDA0002792614290000083
wherein N istotalRepresenting the total number of single faults, Ntotal＝NSG+NDC+NRE；NSGThe total number of synchronous generator sets in the system; n is a radical ofDCThe total number of the direct current transmission lines in the system; n is a radical ofREThe total number of the wind power, photovoltaic and other new energy source units in the system.
Pre-estimating the frequency modulation speed of the system:
the primary frequency modulation of a conventional generator set and new energy, the frequency modulation of a direct current transmission line FLC and stability control measures are integrated, and the frequency modulation speed of the power system under the limit expected fault is obtained:
Figure BDA0002792614290000084
wherein R is the integral frequency modulation speed of the system; rSG,i、RDC,jAnd RRE,kRespectively representing the active regulation speeds of a conventional generator set i, a direct current transmission line j and a new energy source set k when the system suffers serious active disturbance; rSPRepresenting the equivalent frequency modulation rate of a stability control scheme (stability control load reduction or stability control tripping measure); y isSG,i、yDC,jAnd yRE,kThe y values corresponding to the elements (the conventional generator set i, the direct current transmission line j and the new energy source set k) lost by the system after the limit expected fault occurs are 0, if the other elements are in the running state, the y values are 1, and if the other elements are not in the running state, the y values are 0.
Power system inertia security domain evaluation model
The objective function of the evaluation model is as in the above formula (1), wherein the set constraints are expressed as:
Figure BDA0002792614290000091
wherein, F (x, z)g) 0 represents the system power flow equation; g (x, z)g)≤B1Representing an operational safety constraint; f (P)f,R,H)≤B2Representing a frequency stability safety constraint; h (z)g)≤B3Representing the system integral inertia level constraint; x is the node injection power PgAnd a node voltage phase delta vector; z is a radical ofgThe vector is the running state vector of the generator set; pfRepresenting the magnitude of active disturbance caused by the limit expected fault; r is the system frequency modulation rate under the condition of large disturbance; h is the integral inertia level of the system.
In this embodiment, when solving the inertia security domain in the power system, the first 3 constraint conditions are all conventional settings in the art, and therefore, the following two constraint conditions will be described in detail.
Regarding frequency stability safety constraints: including frequency rate of change constraints and transient frequency extremum constraints.
1) The frequency rate of change constraint is:
RoCoFmin≤RoCoFinertial(t)≤RoCoFmax (6)
wherein, RoCoFinertial(t) represents the frequency change rate of the power system at the moment after the limit expected failure corresponding to the time period t occurs; RoCoFmaxAnd RoCoFminRespectively represent the maximum value and the minimum value of frequency change specified by the safe operation of the power system, namely the stability limit value of the frequency change rate.
2) Transient frequency extremum constraint:
fmin≤fextremum(t)≤fmax (7)
wherein f isextremum(t) represents a transient frequency extreme value of the power system at the moment after the limit expected fault corresponding to the time period t occurs; f. ofmaxAnd fminRespectively represent the maximum value and the minimum value of the frequency specified by the safe operation of the power system, namely the stability limit value of the frequency. When the system frequency does not exceed the stability limit, the actions of safety automatic devices such as low-frequency load reduction or high-frequency cutter cutting can be prevented, and the large-area power failure accident can be avoided.
In this embodiment, in order to improve the solving efficiency and the solving accuracy of the model, the transient frequency extremum constraint is linearized as follows:
after the limit expected fault occurs, describing the frequency response process of the system by adopting an equivalent rotor motion equation:
Figure BDA0002792614290000092
wherein H represents system inertia; f (t) represents the system frequency corresponding to time t, fNRepresenting a rated frequency of the power system; (P)m-Pe) The overall active power balance condition of the system is reflected; d is a damping coefficient; Δ f (t) is the frequency deviation, i.e. f (t) -fN。
To obtain the transient frequency extremum, equation (8) is run from [0, text]Integration is performed to obtain:
Figure BDA0002792614290000101
wherein, textThe time at which the system frequency reaches the transient extremum.
The linear processing idea of the coupling relationship between the system inertia and the transient frequency extreme value in the model is shown in fig. 2:
after the limit expected fault occurs, the system frequency begins to fall or rise, and when the frequency deviation reaches the primary frequency modulation dead zone f of the generator setdbThen, the primary frequency modulation control of the generator set starts to act, and unbalanced power caused by limit expected faults is reduced; when the frequency deviation continuously breaks through the action dead zone of the direct current frequency limit control or the fault occurrence time reaches the preset time of the frequency stability control (such as accurate load reduction and stable control generator tripping) matched with the fault, the primary frequency modulation control of the generator set is cooperated with the direct current frequency limit control and the frequency stability control measure to balance the unbalanced power caused by the limit expected fault. When the total active regulation power of the primary frequency modulation control, the direct current frequency limit control and the frequency stabilization control measures of the generator set reaches the initial active disturbance power caused by the limit expected fault, the system frequency reaches an extreme value fextremum. Therefore, after the limit expected failure occurs, the frequency-active regulation process in the system is mainly divided into two stages:
1) stage one: the frequency deviation temporarily does not reach the primary frequency modulation dead zone (corresponding to time [0, t ]db]) Overall unbalanced power (P) of the systemm-Pe) Is maintained at (-P)f) The change is not changed;
2) and a second stage: the frequency regulation related control (such as primary frequency modulation control, direct current frequency limit control and frequency stabilization control measure of the generator set) starts to act (corresponding to the time [ t ]db,text]) Overall unbalanced power (P) of the systemm-Pe) And begins to taper. Considering the primary regulation of the generator setThe active regulation power of frequency-related control such as frequency and direct current frequency limit control is mainly in direct proportion to the frequency deviation of the system, in order to linearize the formula (7), it is reasonably assumed that in this stage, the frequency modulation speed of the system is:
Figure BDA0002792614290000102
wherein, tdbFor the primary frequency modulation action time of the generator set, the integral frequency modulation speed R of the system can be calculated by the formula (4), and the integral frequency modulation speed R of the system and the time t can be obtained by utilizing the formuladbObtaining the time t corresponding to the frequency reaching the transient extreme valueext。
From [0, t ] to formula (8)db]Integration is performed to obtain:
Figure BDA0002792614290000103
wherein the system inertia H is characterized as follows:
H＝Hi·PN,i·ySG,i+HRE,k·PN,k·yRE,k (12)
PN,i、PN,krespectively representing rated power of the conventional generator set i and rated power of the new energy source set k; hi、HRE,kRespectively representing an inertia time constant of the conventional generator set i and a virtual inertia parameter of the new energy source generator set k; y isSG,i、yRE,kThe y values corresponding to the elements (the conventional generator set i, the direct current transmission line j and the new energy source set k) lost by the system after the limit expected fault occurs are 0, if the other elements are in the running state, the y values are 1, and if the other elements are not in the running state, the y values are 0.
To solve the equation (11), there are:
Figure BDA0002792614290000111
the integral equation (9) is solved by means of the linearization idea illustrated in fig. 2, according to which(10) The transient frequency extremum shown corresponds to time textSpeed R and time t of frequency modulation of the whole systemdbRelationship between to eliminate textAnd finally finishing to obtain:
Figure BDA0002792614290000112
by substituting formula (13) for formula (14), it is possible to obtain:
Figure BDA0002792614290000113
using equation (15), then the constraint (7) can be converted into a linear constraint as follows:
Figure BDA0002792614290000114
in the present embodiment, the above-mentioned constraint formula (16) and formula (6) correspond to the constraint condition in formula (5): f (P)f,R,H)≤B2. Horizontal constraint H (z) on the overall inertia of the systemg)≤B3
The expansion in this embodiment is:
Figure BDA0002792614290000115
wherein Hmax、HminRespectively representing the upper limit and the lower limit of the integral inertia of the system, in this embodiment, the upper limit H of the integral inertia of the systemmaxAnd a lower limit of HminIs set according to the power system. In view of the above, the performance parameters of the power system in this embodiment at least include the limit expected fault and the system frequency modulation speed R, where the limit expected fault is related to the system frequency modulation speed R and the system inertia H, and the system frequency modulation speed R is related to the calculation of the formula (15), thereby affecting the model content. It should also be understood that the performance parameters also include other known parameters in the model, such as,
collecting data required for model calculation, including: the system load level, the generated power and the reserve capacity of new energy sources (wind power, photovoltaic and the like), the transmission power and the adjusting space of a direct current transmission line, the output of a conventional generating set (hydroelectric power and thermal power), the inertia time constant of a rotary reserve generator and the conventional generating set, the frequency modulation speed of the rotary reserve generator and the conventional generating set and the like in the researched operation scene.
And substituting the collected performance parameters into the constructed model to obtain an inertia security domain in the evaluation period, wherein the inertia security domain is a range determined by an upper bound and a lower bound of the inertia security domain.
Therefore, as shown in fig. 1, the flow of the method in practical application in this embodiment can be represented as:
1: data is acquired.
2: and (4) screening limit expected faults and calculating the comprehensive frequency modulation speed R of the system.
3: and substituting the model, wherein the model takes the maximized inertia security domain as an optimization target and comprises frequency security and stability constraints and the like.
4: and solving the model to obtain an inertia security domain, and optionally carrying out visual display.
5: and performing operation analysis based on the inertia safety domain, and judging whether the actual inertia is in the inertia safety domain, wherein if the actual inertia is in the inertia safety domain, the requirement is met, and if the actual inertia is not in the inertia safety domain, the requirement is not met.
In some embodiments, after obtaining the inertia security domain of the power system, the estimation accuracy of the inertia security domain of the power system is further measured by using the frequency change rate relative error and the transient frequency extremum relative error, and the specific formula refers to the foregoing.
In summary, the constraint condition of the formula (5) is set in this embodiment, in other feasible embodiments, the constraint condition may be locally adjusted based on the objective function, and the adjusted constraint condition constrains values of an upper bound of the inertia security domain and a lower bound of the inertia security domain in the objective function.
In other embodiments, the present invention further provides an evaluation system for an inertia security domain of a power system, including: the system comprises an electric power system inertia security domain evaluation model obtaining module, a performance parameter obtaining module and a model solving module.
An acquisition module of an inertia security domain evaluation model of the power system: the method comprises the steps of obtaining an electric power system inertia safety domain evaluation model, wherein the electric power system inertia safety domain evaluation model takes the area maximization of an inertia safety domain as an optimization objective function and at least comprises frequency stabilization safety constraints. The contents of the model are specifically described with reference to the foregoing method.
A performance parameter acquisition module: the method comprises the steps of obtaining performance parameters of the power system to be evaluated; the performance parameters are parameters required for model calculation.
A model solving module: and substituting the performance parameters into the power system inertia safety domain evaluation model to perform model solution to obtain the inertia safety domain of the power system.
In some embodiments, the power system inertia safety domain evaluation model obtaining module includes a constructing unit and an extracting unit, the constructing unit is configured to construct a power system inertia safety domain evaluation model, and the extracting unit is configured to obtain the power system inertia safety domain evaluation model from the constructing unit. In other possible embodiments, the power system inertia security domain evaluation model may also be pre-constructed so as to be implemented specifically, and only need to be called.
In some embodiments, the evaluation system further includes an operation analysis module configured to determine whether the actual inertia is within the inertia safety domain, and if so, satisfy the requirement, and if not, do not satisfy the requirement.
In some embodiments, the evaluation system further includes an evaluation module, and the evaluation module is configured to, after obtaining the inertia security domain of the power system, measure the evaluation accuracy of the inertia security domain of the power system by using the frequency change rate relative error and the transient frequency extremum relative error.
It should be understood that, the specific implementation process of the above unit module refers to the method content, and the present invention is not described herein in detail, and the division of the above functional module unit is only a division of a logic function, and there may be another division manner in the actual implementation, for example, multiple units or components may be combined or may be integrated into another system, or some features may be omitted, or may not be executed. Meanwhile, the integrated unit can be realized in a hardware form, and can also be realized in a software functional unit form.
In still other embodiments, the present invention also provides an electronic terminal comprising a processor and a memory, the memory storing a computer program, the processor invoking the computer program to perform:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
In some embodiments, the processor calls the computer program to further perform: and the method is used for judging whether the actual inertia is in the inertia safety domain, if so, the requirement is met, and if not, the requirement is not met.
In some embodiments, the processor calls the computer program to further perform: and after obtaining the inertia security domain of the electric power system, measuring the evaluation accuracy of the inertia security domain of the electric power system by using the relative error of the frequency change rate and the relative error of the transient frequency extreme value.
The contents of the model are described with reference to the foregoing method.
In still other embodiments, the present invention also provides a readable storage medium storing a computer program for execution by a processor to:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
In some embodiments, the computer program is further invoked by the processor to perform: and the method is used for judging whether the actual inertia is in the inertia safety domain, if so, the requirement is met, and if not, the requirement is not met.
In some embodiments, the computer program is further invoked by the processor to perform: and after obtaining the inertia security domain of the electric power system, measuring the evaluation accuracy of the inertia security domain of the electric power system by using the relative error of the frequency change rate and the relative error of the transient frequency extreme value.
The contents of the model are described with reference to the foregoing method.
It should be understood that in the embodiments of the present invention, the Processor may be a Central Processing Unit (CPU), and the Processor may also be other general purpose processors, Digital Signal Processors (DSPs), Application Specific Integrated Circuits (ASICs), Field Programmable Gate Arrays (FPGAs) or other Programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, and the like. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like. The memory may include both read-only memory and random access memory, and provides instructions and data to the processor. The portion of memory may also include non-volatile random access memory. For example, the memory may also store device type information.
The readable storage medium is a computer readable storage medium, which may be an internal storage unit of the controller according to any of the foregoing embodiments, for example, a hard disk or a memory of the controller. The readable storage medium may also be an external storage device of the controller, such as a plug-in hard disk, a Smart Media Card (SMC), a Secure Digital (SD) Card, a Flash memory Card (Flash Card), and the like provided on the controller. Further, the readable storage medium may also include both an internal storage unit of the controller and an external storage device. The readable storage medium is used for storing the computer program and other programs and data required by the controller. The readable storage medium may also be used to temporarily store data that has been output or is to be output.
Data verification:
the embodiment applies the proposed method for evaluating the inertia security domain of the power system to a new england system of IEEE to evaluate the inertia security domain of the power system, wherein the evaluation period is 24 hours. The data on the IEEE new england system used are: 9 thermal power generating units with total capacity of 6327 MW; 1 hydroelectric generating set with rated generating power of 1040 MW; 5 wind power plants with the total capacity of 1180 MW; 3 photovoltaic power stations with the total capacity of 1020 MW; the system load levels for each hour of the evaluation period are shown in table 1; the locations of the various power sources and the network topology of the system are seen in fig. 3. The control measures are considered as follows: primary frequency modulation control of new energy, primary frequency modulation control of a synchronous generator set and accurate load reduction control aiming at tripping of the generator set.
Table 1 evaluation of load level of new england system during period
Time/h load/MW Time/h load/MW Time/h load/MW
1 2501.69 9 4503.05 17 5003.38
2 2376.61 10 5003.38 18 4878.30
3 2251.52 11 5316.10 19 4690.68
4 2564.23 12 5628.81 20 4002.71
5 2626.78 13 5503.72 21 4065.25
6 3002.03 14 5003.38 22 3564.91
7 3314.74 15 4940.84 23 3439.83
8 3439.83 16 4940.84 24 3314.74
The above example data is used in the method for evaluating the inertia safety domain of the power system proposed by the present invention, so as to obtain the inertia safety domain of the IEEE new england system in the evaluation period (24 hours), and the shape characteristics of the inertia safety domain are shown in fig. 4. The boundary value (including the upper boundary value) of the inertia security domain
Figure BDA0002792614290000151
And a lower bound value HSIL) Plotted as a table to obtain table 2. Power grid operation scheduling personnel can compare and evaluate the lower bound H of the inertia security domain and the inertia of the actual system in the periodSILTo assess the safety and adequacy of the system inertia. Compare H in Table 2SILAs known from the actual system inertia H, the IEEE New England system can support the safe and stable operation of the system even if the system encounters extreme expected faults in the operation scene.
TABLE 2 boundary values of the new England System inertia Security Domain and the actual System inertia
Figure BDA0002792614290000152
Respectively setting the integral inertia of the system as the upper bound of an inertia safety domain
Figure BDA0002792614290000153
And a lower bound value HSILThen, the failure P is predicted at the limitfAnd the lower simulation obtains the extreme value of the transient frequency change rate and the transient frequency after the occurrence of the limit expected fault. As can be seen from tables 3 and 4, when the system inertia is between the upper and lower boundaries of the inertia safety domain estimated by the proposed method, i.e. the system inertia is within the safety domain estimated by the proposed method, the system frequency and the variation rate thereof do not exceed the safety stability range even if severe active disturbance occurs (in this example, the safety stability range of the frequency is 49.0 to 50.8Hz, and the safety stability range of the frequency variation rate is-2 to 2Hz · s-1) (ii) a And when the system inertia is equal to the inertia security domain lower bound H obtained by the method evaluationSILIn the process, the extreme value of the transient frequency after the expected fault is close to the stability limit (49.0Hz), and the precision of the inertia safety domain evaluation result obtained by the method is high.
TABLE 3 transient frequency extremum for New England System with integral inertia level at Critical value
Figure BDA0002792614290000161
Table 4 maximum frequency change rate of new england system integral inertia level under critical value
Figure BDA0002792614290000162
Figure BDA0002792614290000171
TABLE 5 inertia security domain boundary values based on frequency change rate constraint method evaluation
Figure BDA0002792614290000172
TABLE 6 transient frequency extrema corresponding to inertia security domain boundary values based on frequency rate of change constraint method
Figure BDA0002792614290000173
Figure BDA0002792614290000181
Comparing table 3 and table 6, it can be seen that compared with the frequency change rate constraint method, the inertia security domain evaluated by the method has higher accuracy, the actual inertia security domain of the power system is more accurately described based on the inertia security domain evaluated by the method, when the actual inertia of the system is located in the inertia security domain obtained by the method, it can be effectively confirmed that the actual inertia is enough to support the system frequency not to exceed the stability limit in the face of large disturbance, and the actions of safety automatic devices such as low-frequency load reduction and the like can be effectively avoided, so that the occurrence of large-area power failure accidents is prevented.
TABLE 7 comparison of the calculation costs of the method and the time domain simulation method
Figure BDA0002792614290000182
In summary, the inertia security domain evaluation method provided by the method simultaneously takes into account various frequency control measures and dual frequency index constraints, and compared with the traditional frequency change rate constraint method, the accuracy of an evaluation result is greatly improved by the critical value of the inertia security domain obtained by evaluation; the time consumed by evaluation and calculation is in millisecond level and is far shorter than that of a time domain simulation method; on the whole, the inertia safety domain evaluation method provided by the method has better calculation speed on the premise of ensuring the calculation precision, and can meet the requirements of inertia safety and adequacy evaluation of a power system under the condition of accessing of a mass of converters.
It should be emphasized that the examples described herein are illustrative and not restrictive, and thus the invention is not to be limited to the examples described herein, but rather to other embodiments that may be devised by those skilled in the art based on the teachings herein, and that various modifications, alterations, and substitutions are possible without departing from the spirit and scope of the present invention.

Claims (10)

1. A method for evaluating an inertia security domain of an electric power system is characterized by comprising the following steps: the method comprises the following steps:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
2. The method of claim 1, wherein: the objective function is as follows:
Figure FDA0002792614280000011
wherein phi isHThe area size of the inertia security domain is represented,
Figure FDA0002792614280000012
representing the total available inertia of the power system during the t period; hSIL(T) represents an inertia safety critical value of the power system at the T-th period, and T represents the length of the evaluation period.
3. The method of claim 2, wherein: the frequency-stable safety constraint comprises a transient frequency limit fextremumConstraining and limiting the transient frequency limit value fextremumCarrying out linearization processing on the coupling relation with the system inertia so as to further carry out the transient frequency extreme value fextremumThe constraint transforms into a constraint as follows:
Figure FDA0002792614280000013
in the formula, HISR(t) represents a inertia security domain boundary value, fNRepresenting the rated frequency of the power system, D representing the damping effect of the power system, fdbIs a primary frequency modulation dead zone of the generator set, PfShowing the magnitude of the active disturbance caused by a standard fault, fmin、fmaxAnd respectively representing the stability lower limit and the stability upper limit of the frequency, wherein R is the integral frequency modulation speed of the system under the condition of disturbance caused by the standard fault.
4. The method of claim 2, wherein: the frequency-stable safety constraint comprises a transient frequency limit fextremumConstraints and frequency change rate constraints, as follows:
RoCoFmin≤RoCoFinertial(t)≤RoCoFmax
fmin≤fextremum(t)≤fmax
in the formula, RoCoFinertial(t) represents the frequency change rate of the power system at the moment after the standard fault corresponding to the time period t occurs; RoCoFmaxAnd RoCoFminRespectively representing the maximum and minimum values of frequency variation, f, prescribed for safe operation of the power systemmaxAnd fminRespectively representing the maximum value and the minimum value of the frequency specified by the safe operation of the power system;
the power system inertia security domain evaluation model further comprises a system integral inertia level constraint, and the method comprises the following steps:
Figure FDA0002792614280000021
wherein Hmax、HminRespectively representing the upper limit and the lower limit of the overall inertia of the system.
5. The method according to claim 3 or 4, characterized in that: the standard fault is a limit expected fault which is the most serious fault of the power system in the range of the studied scene;
wherein in critical N-2 failure set
Figure FDA0002792614280000022
The fault with the largest induced active disturbance is taken as the limit predicted fault, and the following steps are carried out:
Figure FDA0002792614280000023
wherein, PfThe magnitude of active disturbance, | F, caused by the ultimate predicted faultmnCorresponding to the magnitude of active disturbance caused by the simultaneous loss of the mth element and the nth element of the power system;
Figure FDA0002792614280000024
representing a set of critical N-2 faults, NtotalIndicating the total number of single failures.
6. The method of claim 3, wherein: when the standard fault is a limit expected fault, the overall frequency modulation speed R of the system under the condition of disturbance caused by the standard fault is determined according to the following formula:
Figure FDA0002792614280000025
wherein R isSG,i、RDC,jAnd RRE,kRespectively representing the active regulation speed R of the conventional generator set i, the direct current transmission line j and the new energy source set k when the system suffers serious active disturbanceSPEquivalent frequency modulation rate, y, representing a stability control schemeSG,i、yDC,jAnd yRE,kAll the variables are binary variables, and represent the loss elements of the system after the limit expected fault occurs, if a conventional generator set i, a direct current transmission line j and a new energy source set k exist, the corresponding ySG,i、yDC,jAnd yRE,kThe value is 0, if the element is in the operating state, the corresponding ySG,i、yDC,jAnd yRE,kThe value is taken to be 1.
7. The method of claim 1, wherein: further comprising: after obtaining the inertia security domain of the electric power system, measuring the evaluation accuracy of the inertia security domain of the electric power system by adopting the relative error of the frequency change rate and the relative error of the transient frequency extreme value, as follows:
Figure FDA0002792614280000031
Figure FDA0002792614280000032
wherein epsilonrRepresenting the relative error of the rate of change of frequency, epsilonfRepresenting the relative error of the extreme value of the transient frequency;
Figure FDA0002792614280000033
Figure FDA0002792614280000034
respectively representing the instantaneous frequency change rate and the transient frequency extreme value after the standard fault is simulated under the standard fault after the integral inertia of the system is set as the lower boundary value of the inertia security domain; RoCoFmin、RoCoFmaxLower limit value of stability respectively representing frequency change rateAnd an upper limit value; f. ofmin、fmaxRespectively representing the maximum and minimum frequency values, P, prescribed for safe operation of the power systemfIndicating the magnitude of active disturbance caused by a standard fault.
8. An evaluation system of an inertia security domain of a power system, characterized by: the method comprises the following steps:
an acquisition module of an inertia security domain evaluation model of the power system: the method comprises the steps of obtaining an electric power system inertia security domain evaluation model, wherein the electric power system inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stabilization security constraints;
a performance parameter acquisition module: the method comprises the steps of obtaining performance parameters of the power system to be evaluated;
a model solving module: and substituting the performance parameters into the power system inertia safety domain evaluation model to perform model solution to obtain the inertia safety domain of the power system, wherein the performance parameters are parameters required for solving the power system inertia safety domain evaluation model.
9. An electronic terminal, characterized by: comprising a processor and a memory, the memory storing a computer program that the processor calls to perform:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
10. A readable storage medium, characterized by: a computer program is stored, which is invoked by a processor to perform:
acquiring an inertia security domain evaluation model of the electric power system, wherein the inertia security domain evaluation model takes the area maximization of an inertia security domain as an optimization objective function and at least comprises frequency stability security constraints;
the method comprises the steps of obtaining performance parameters of the electric power system to be evaluated, substituting the performance parameters into an electric power system inertia safety domain evaluation model, and carrying out model solving to obtain an inertia safety domain of the electric power system, wherein the performance parameters are parameters required for solving the electric power system inertia safety domain evaluation model.
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CN114285076A (en) * 2021-12-24 2022-04-05 国网青海省电力公司经济技术研究院 Virtual inertia configuration method considering dynamic frequency response process
CN115189397A (en) * 2022-07-07 2022-10-14 国网湖南省电力有限公司 New energy access capacity calculation method of power system
CN115842376A (en) * 2022-12-12 2023-03-24 湖南大学 Method, device and medium for evaluating equivalent inertia trend and safety state of power system
CN115842376B (en) * 2022-12-12 2023-07-18 湖南大学 Electric power system equivalent inertia trend and safety state evaluation method, equipment and medium
CN115965288A (en) * 2022-12-29 2023-04-14 国网湖北省电力有限公司经济技术研究院 Active power distribution network frequency safety assessment method based on IWO (interactive Web service) optimization BiLSTM (binary local maximum transmission)
CN115965288B (en) * 2022-12-29 2023-11-03 国网湖北省电力有限公司经济技术研究院 IWO (IWO-based optimization BiLSTM) based active power distribution network frequency security assessment method

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