CN117335493A - Regional power grid-oriented inertia evaluation method for each control region - Google Patents
Regional power grid-oriented inertia evaluation method for each control region Download PDFInfo
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Abstract
The application discloses a regional power grid-oriented inertia evaluation method for each control region, which can estimate inertia of each region by using a rotor motion equation when only the whole network frequency exists, and correct the inertia by using a double-layer iteration strategy. The method comprises the following steps: constructing an inertia correction model, and setting operation parameters for the inertia correction model; according to an inertia equation, calculating according to initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to a non-disturbance control area; and calculating the inertia of a second region to be screened and the total inertia to be screened of the first region to be screened based on the inner iteration and the outer iteration of the inertia correction model, storing the inertia of the second region to be screened and the total inertia to be screened in a record table, selecting a target group to be screened meeting preset conditions from a plurality of groups to be screened in the record table, and taking the inertia of the first region to be screened and the inertia of the second region to be screened stored in the target group to be screened as the inertia of the target region of each control region.
Description
Technical Field
The application relates to the field of control of power systems, in particular to an inertia evaluation method for each control area facing a regional power grid.
Background
In an electrical power system, the degree of stability of frequency is defined as the ability to maintain or restore the balance between the power generation and the load of the system, and in an electrical grid, the degree of stability of the frequency is mainly dependent on the inertia response and the frequency modulation capability of the system. Conventionally, when a disturbance occurs, because the frequency modulation response dead zone affects, the response cannot be timely participated, and an electric power system generally relies on inertia provided by a synchronous generator to provide necessary energy buffering, so that rapid frequency drop caused by sudden power imbalance can be well prevented.
With the innovation of energy structures, a large number of new energy sources replace synchronous generators to be integrated into a power grid, at present, most of new energy sources are connected into the power grid through power electronic converter equipment, direct inertia response cannot be provided, for a control area, frequency data of each unit in the control area after disturbance can be obtained, then the frequency data are averaged to be used as frequency data of the control area, and further inertia evaluation of the control area is carried out by using the frequency data and tie line change data.
In carrying out the present application, the applicant has found that the related art has at least the following problems:
in an actual power grid, the number of units is huge, the whole interconnected power grid generally only has one frequency data, namely the whole network frequency, and the frequency data of each unit in each control area after disturbance is difficult to obtain, so that the existing evaluation method cannot be suitable for the existing interconnected power grid.
Disclosure of Invention
In view of this, the present application provides a method for evaluating inertia of each control area facing to a regional power grid, which mainly aims to solve the problem that in the actual power grid, the number of units is huge, the whole interconnected power grid generally only has whole network frequency, and it is difficult to obtain frequency data of each unit in each control area after disturbance, so that the existing evaluating method cannot be applicable to the current interconnected power grid.
According to a first aspect of the present application, there is provided a method for evaluating inertia of each control area facing to a regional power grid, the method comprising:
an inertia correction model is built, operation parameters are set for the inertia correction model, the operation parameters comprise model super-parameters, inner layer maximum iteration times and outer layer maximum iteration times, and the inertia correction model is a double-iteration model;
according to an inertia equation, calculating according to initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to a non-disturbance control area, wherein the control area comprises the non-disturbance control area and a disturbance control area;
performing iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area;
Calculating the inertia of a second area to be screened of the disturbance control area based on the outer layer iteration of the inertia correction model, calculating total inertia to be screened according to the inertia of the first area to be screened and the inertia of the second area to be screened, correlating the inertia of the first area to be screened, the inertia of the second area to be screened and the total inertia to be screened, storing the first area to be screened, serving as a group to be screened in a record table, updating the first average frequency change curve, entering the inner layer iteration again, and carrying out inertia correction by adopting the updated first average frequency change curve until the iteration number of the outer layer iteration is larger than the maximum iteration number of the outer layer;
and selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of a first to-be-screened area and the inertia of a second to-be-screened area stored in the target to-be-screened group as the inertia of a target area of each control area.
By means of the technical scheme, the regional power grid-oriented inertia evaluation method for each control region is suitable for an evaluation system, the system firstly builds an inertia correction model, and sets operation parameters for the inertia correction model, wherein the operation parameters comprise model super-parameters, inner layer maximum iteration times and outer layer maximum iteration times. And then, calculating according to an inertia equation and the initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to the non-disturbance control area, wherein the control area comprises the non-disturbance control area and the disturbance control area. And then, carrying out iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area. Further, based on outer layer iteration of the inertia correction model, calculating second area inertia to be screened of the disturbance control area, calculating total inertia to be screened according to the first area inertia to be screened and the second area inertia to be screened, correlating the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened, storing the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened as a group to be screened in a record table, updating a first average frequency change curve, entering inner layer iteration again, carrying out inertia correction by adopting the updated first average frequency change curve until the iteration times of the outer layer iteration are larger than the maximum iteration times of the outer layer. And finally, selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of the first to-be-screened area and the inertia of the second to-be-screened area stored in the target to-be-screened group as the inertia of the target area of each control area. According to the method and the device, when the full-network frequency is only available, the inertia of each area can be estimated by using a rotor motion equation, inertia is corrected by using a double-layer iteration strategy, and the purpose of reasonably estimating the inertia of each area under limited data is achieved.
The foregoing description is only an overview of the technical solutions of the present application, and may be implemented according to the content of the specification in order to make the technical means of the present application more clearly understood, and in order to make the above-mentioned and other objects, features and advantages of the present application more clearly understood, the following detailed description of the present application will be given.
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Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the application. Also, like reference numerals are used to designate like parts throughout the figures. In the drawings:
fig. 1 shows a flow chart of a method for evaluating inertia of each control area facing to an area power grid according to an embodiment of the present application;
fig. 2 is a schematic flow chart of a method for evaluating inertia of each control area facing to an area power grid according to an embodiment of the present application;
fig. 3 is a schematic diagram of transient frequency response process of each control area inertia evaluation method facing to an area power grid according to an embodiment of the present application;
fig. 4 is a schematic diagram of an interconnected power grid architecture of a method for evaluating inertia of each control area facing to a regional power grid according to an embodiment of the present application;
Fig. 5 is a schematic diagram of an inertia estimation process of each control area inertia evaluation method facing to an area power grid according to an embodiment of the present application;
fig. 6 shows a schematic diagram of total inertia of each control area for an area grid according to an embodiment of the present application;
fig. 7 is a schematic diagram of an outer layer iteration frequency curve change process of an area grid-oriented inertia evaluation method of each control area according to an embodiment of the present application;
FIG. 8 shows a sum h of inertia of each region of the regional power grid-oriented method for evaluating inertia of each control region according to an embodiment of the present application SUM A schematic diagram of a graph;
fig. 9 is a schematic diagram of each area inertia estimated value of each control area inertia evaluating method facing to an area power grid according to an embodiment of the present application;
fig. 10 shows a flow chart of a method for evaluating inertia of each control area facing to a regional power grid according to an embodiment of the present application.
Detailed Description
Exemplary embodiments of the present application will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the present application are shown in the drawings, it should be understood that the present application may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.
In an electrical power system, the degree of stability of frequency is defined as the ability to maintain or restore the balance between the power generation and the load of the system, and in an electrical grid, the degree of stability of the frequency is mainly dependent on the inertia response and the frequency modulation capability of the system. Conventionally, when a disturbance occurs, because the frequency modulation response dead zone affects, the response cannot be timely participated, and an electric power system generally relies on inertia provided by a synchronous generator to provide necessary energy buffering, so that rapid frequency drop caused by sudden power imbalance can be well prevented. With the innovation of energy structures, a large number of new energy sources replace synchronous generators to be integrated into a power grid, at present, most of new energy sources are connected into the power grid through power electronic converter equipment, direct inertia response cannot be provided, for a control area, frequency data of each unit in the control area after disturbance can be obtained, then the frequency data are averaged to be used as frequency data of the control area, and further inertia evaluation of the control area is carried out by using the frequency data and tie line change data. However, the applicant realizes that in an actual power grid, the number of units is huge, the whole interconnected power grid generally only has one frequency data, namely the whole network frequency, the frequency data of each unit in each control area after disturbance is difficult to obtain, and the existing evaluation method cannot be suitable for the existing interconnected power grid. Therefore, the method for evaluating the inertia of each control area facing the regional power grid is suitable for an evaluation system, the system firstly builds an inertia correction model, and sets operation parameters for the inertia correction model, wherein the operation parameters comprise model super-parameters, inner layer maximum iteration times and outer layer maximum iteration times. And then, calculating according to an inertia equation and the initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to the non-disturbance control area, wherein the control area comprises the non-disturbance control area and the disturbance control area. And then, carrying out iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area. Further, based on outer layer iteration of the inertia correction model, calculating second area inertia to be screened of the disturbance control area, calculating total inertia to be screened according to the first area inertia to be screened and the second area inertia to be screened, correlating the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened, storing the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened as a group to be screened in a record table, updating a first average frequency change curve, entering inner layer iteration again, carrying out inertia correction by adopting the updated first average frequency change curve until the iteration times of the outer layer iteration are larger than the maximum iteration times of the outer layer. And finally, selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of the first to-be-screened area and the inertia of the second to-be-screened area stored in the target to-be-screened group as the inertia of the target area of each control area. According to the method and the device, when the full-network frequency is only available, the inertia of each area can be estimated by using a rotor motion equation, inertia is corrected by using a double-layer iteration strategy, and the purpose of reasonably estimating the inertia of each area under limited data is achieved.
The embodiment of the application provides a regional power grid-oriented inertia evaluation method for each control region, as shown in fig. 1, comprising the following steps:
101. an inertia correction model is built, operation parameters are set for the inertia correction model, the operation parameters comprise model super-parameters, the maximum iteration times of an inner layer and the maximum iteration times of an outer layer, and the inertia correction model is a double-iteration model.
102. And calculating according to an inertia equation and the initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to the non-disturbance control area, wherein the control area comprises the non-disturbance control area and the disturbance control area.
103. And carrying out iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area.
104. And calculating the inertia of a second area to be screened of the disturbance control area based on the outer layer iteration of the inertia correction model, calculating total inertia to be screened according to the inertia of the first area to be screened and the inertia of the second area to be screened, correlating the inertia of the first area to be screened, the inertia of the second area to be screened and the total inertia to be screened, storing the first area to be screened, the inertia of the second area to be screened and the total inertia to be screened as a group to be screened in a record table, updating a first average frequency change curve, entering the inner layer iteration again, and carrying out inertia correction by adopting the updated first average frequency change curve until the iteration times of the outer layer iteration are larger than the maximum iteration times of the outer layer.
105. And selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of the first to-be-screened area and the inertia of the second to-be-screened area stored in the target to-be-screened group as the inertia of the target area of each control area.
According to the regional power grid-oriented inertia evaluation method for each control region, firstly, an inertia correction model is constructed, and operating parameters are set for the inertia correction model, wherein the operating parameters comprise model super-parameters, inner layer maximum iteration times and outer layer maximum iteration times. And then, calculating according to an inertia equation and the initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to the non-disturbance control area, wherein the control area comprises the non-disturbance control area and the disturbance control area. And then, carrying out iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area. Further, based on outer layer iteration of the inertia correction model, calculating second area inertia to be screened of the disturbance control area, calculating total inertia to be screened according to the first area inertia to be screened and the second area inertia to be screened, correlating the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened, storing the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened as a group to be screened in a record table, updating a first average frequency change curve, entering inner layer iteration again, carrying out inertia correction by adopting the updated first average frequency change curve until the iteration times of the outer layer iteration are larger than the maximum iteration times of the outer layer. And finally, selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of the first to-be-screened area and the inertia of the second to-be-screened area stored in the target to-be-screened group as the inertia of the target area of each control area. According to the method and the device, when the full-network frequency is only available, the inertia of each area can be estimated by using a rotor motion equation, inertia is corrected by using a double-layer iteration strategy, and the purpose of reasonably estimating the inertia of each area under limited data is achieved.
Further, as a refinement and expansion of the specific implementation manner of the foregoing embodiment, in order to fully describe the implementation process of the embodiment, the embodiment of the present application provides a method for evaluating inertia of each control area facing to a regional power grid, as shown in fig. 2, where the method includes:
201. an inertia correction model is built, operation parameters are set for the inertia correction model, the operation parameters comprise model super-parameters, the maximum iteration times of an inner layer and the maximum iteration times of an outer layer, and the inertia correction model is a double-iteration model.
In the embodiment of the application, the evaluation system firstly builds an inertia evaluation model, and inputs relevant operation parameters and other input parameters to the inertia evaluation model, so that the inertia correction model can correct initial inertia estimated values of all areas, and finally reasonable estimation of the inertia values of all areas is realized. It should be noted that, the initial inertia estimation value of each region may be calculated using an existing inertia estimation method. In the power system, the stability of the frequency depends on the power generation side and the power utilization side to realize dynamic balance, and when disturbance (taking power shortage as an example) occurs, the power system takes certain measures to inhibit the reduction of the frequency and gradually returns to a steady state value. The response of the power system to disturbance is mainly divided into three stages of inertia response, primary frequency modulation and secondary frequency modulation on a time scale, as shown in fig. 3, different influences are exerted on different time scales according to the frequency change of the system, so that the frequency is effectively prevented from continuously dropping and gradually restored to a steady-state value. In fig. 3, t 0 -t nadir In the inertia response stage, when unbalance and instant of active power occur between the system power generation and the load, unbalance of mechanical power and electromagnetic power occur in the synchronous generator set, and kinetic energy existing in a rotor of the set can be transferred to the electromagnetic power through the characteristic of a work angle, so that a small amount of unbalanced power is compensated, and the effect of inhibiting rapid reduction of frequency is achieved. When the frequency reaches the lowest point, the unbalanced power becomes 0, the system frequency is not reduced any more, and the inertia response process is ended. t is t d -t ss In the primary frequency modulation stage, taking a thermal power unit speed regulator as an example, after a response delay (usually 1 s) of a certain time, the opening of an air inlet valve is adjusted according to the change of the rotating speed of a rotor, and the size of active power is adjusted by changing the air inflow, so that unbalanced power is reduced. However, since primary frequency modulation is poorly tuned, combined with the load frequency response, it will eventually settle at a new frequency point, and the overall process will typically last for 10-30s. t is t ss And in the secondary frequency modulation stage, the AGC controller is used for recovering the system frequency to a stable level by additionally injecting active power into the system according to the difference value between the frequency and a preset value and changing the output force of the generator set.
The degree of frequency stability of an electrical power system is defined as the ability to maintain or restore the balance between the power generation and the load of the system, and is primarily dependent on the inertia response and frequency modulation capabilities of the system in the electrical grid. Conventionally, when a disturbance occurs, because the frequency modulation response dead zone affects, the response cannot be timely participated, and an electric power system generally relies on inertia provided by a synchronous generator to provide necessary energy buffering, so that rapid frequency drop caused by sudden power imbalance can be well prevented. The inertia of an electric power system is therefore also defined as the ability to prevent rapid changes in the frequency of the electric power system during disturbances, which is one of the important indicators of the stability of the electric power system. The inertia of the traditional synchronous generator is directly and physically connected with the power grid, and the new energy power supply is mostly connected with the power grid through the power electronic converter device and cannot provide direct inertia response. With the innovation of energy structures, a large amount of new energy replaces synchronous generators to be integrated into a power grid, the inertia level of the system is greatly reduced, and the safety risk under system disturbance is increased. Meanwhile, the measures capable of providing equivalent inertia support are increasingly increased, such as load voltage characteristics, energy storage rapid frequency response, new energy virtual inertia and the like, and the traditional power system inertia index and inertia estimation method are not applicable any more and need to be expanded to a brand new concept: the equivalent inertia index, which is used to represent the equivalent inertia response provided by the non-inertia unit in addition to the conventional inertia in the system, reflects the capability of the system to suppress the disturbance at the moment of disturbance. Therefore, it is important to design a method to reasonably estimate the inertia level of the power system, so that the method has important guiding significance for energy structure, unit regulation and control and reserve planning of the power grid, and when the inertia level is too low, the system overall inertia level can be improved by starting the synchronous generator unit, adjusting the output proportion of new energy and increasing the equivalent inertia response provided by other non-inertia units, thereby being beneficial to improving the safety and stability of the power grid
For a single synchronous generator, the inertia of its shaft is a fixed constant, which can be expressed as:wherein H is the inertia constant of the generator, the unit is seconds(s), J is the rotational inertia of the shaft, omega n For the rated angular velocity S B Is the rated capacity of the unit. The equation of motion of the rotor can be used to describe the relationship between the speed of the generator rotor and the stored energy, which can be approximated by equation 1 below due to the narrow range of speed variation of the power system:
equation 1:
wherein dΔf (t)/dt is the rate of change of frequency, p m (t) is the mechanical power for driving the rotor to move, p e And (t) is the generated power, and the values are per unit. When unbalance occurs to the power at the two sides of the machine end, the kinetic energy in the rotor of the generator can compensate the unbalance of the power, so that the rotation speed is changed, and the frequency is changed. However, the above equation 1 can be rewritten as the following equation 2 due to the characteristic that the mechanical power changes slowly with respect to the generated power:
equation 2:
wherein Δp e And (t) is the difference value of the power of the machine end of the single generator, and H is the inertia constant of the single generator.
For a regional power system, where a regional power system is connected to a number of machines, each having its own fixed inertia constant, the total system inertia can be considered as the sum of all the machine inertias contained therein, however, there are also non-inertial units in the power system that can also provide equivalent inertial responses, and the regional level of inertia cannot be determined by simple inertial summation alone. The whole power system can be regarded as an equivalent generator, and the equivalent inertia of the system is estimated through a rotor motion equation, as shown in the following formula 3:
Equation 3:
where Δp (t) is the unbalanced power at the power generation side and the load side in the region, dΔf (t)/dt is the region frequency change rate, and H is the region equivalent inertia constant.
For the interconnected power system, as shown in fig. 4, a plurality of areas are included, a tie line exists between the areas for exchanging power, when one area is disturbed, the power system of the other area supports the disturbed area through the power change of the tie line, so that in the transient process of the disturbance, the delta P of each area is different, the frequencies of each area are different, but with the power change of the tie line, the frequencies of each area quickly tend to be uniform after short destabilization, and finally, the frequencies are restored to the nominal frequency through the frequency modulation means of each area.
When a certain region in the interconnected power system is disturbed, the power change on the connecting lines of each region is a main cause of the frequency change in the region before the speed regulation system acts due to the dead zone effect of the speed regulation system. Thus for the non-perturbed region i Δp (t) can be expressed as the amount of power change on the region tie-line Δp i ＝p l -p l0 Wherein p is l0 And p l Representing pre-disturbance and post-disturbance link power, respectively. For disturbance zone i, Δp (t) may be expressed as the sum of the power change on the link and the disturbance inside the zone,wherein the signs represent disturbance areas, +.>Representing the disturbance power level. The equivalent area inertia can be defined as the suppression effect of the rotation inertia of the synchronous unit and the non-inertia unit on disturbance in one area, and the accurate time synchronization PMU data is needed, one area of the power transmission system is required to be bounded by PMU measurement, and when a disturbance event is detected, the net boundary power and frequency data in the area are measured and then estimated by using the formula 2. Passing throughAs shown in fig. 5, the process is generally shown in fig. 5, where data acquisition is performed first to obtain daily updated data, timely data and additional recorded data, then data retrieval is performed, whether disturbance occurs is determined by a frequency change rate, then after disturbance occurs, a region link change amount and a region frequency change rate are calculated, the region link change amount and the region frequency change rate are adopted to replace unbalanced power Δp (t) and region frequency change rate dΔf (t)/dt in formula 2 respectively, region inertia is calculated, stability is finally determined, an inertia response stage is identified, and a screened inertia result is output.
The inertia evaluation condition in the prior art is that for a region, frequency data of the region after disturbance and link change data are required to be obtained, the frequency data of each unit in the region can be obtained in the simulation system of the calculation example, and then the frequency data are averaged to be used as the frequency data of the region, but in an actual power grid, the number of units is huge, and the method is not practical. In practice, for the whole interconnected network, there is usually only one frequency data, i.e. the frequency of the whole network, and it is difficult to obtain independent frequencies of the respective control areas, so that the prior art is no longer applicable. In order to solve the technical problem that reasonable inertia estimation cannot be performed on each control area in a power grid when only the whole network frequency of an interconnected power grid exists, the application provides an area power grid-oriented inertia estimation method for each control area, and inertia level estimation is performed on each control area of a large power grid by only using one whole network frequency and each area tie line data after disturbance occurs.
In the step, firstly, a rotor motion equation, namely the formula 2 is changed, two sides of the equation are integrated simultaneously to obtain an inertia equation, and the inertia equation is specifically shown in the following formula 4;
Equation 4:
wherein t is 0 Is the moment at which the disturbance occurs. Further, obtaining the disturbed full-network frequency variation, the disturbance power and the connecting line of each control areaThe power variation of the (4) is replaced by the full-network frequency variation and the disturbance power to calculate the initial full-network inertia h area . Meanwhile, the delta f (t) and delta p (t) in the formula 4 are replaced by the whole network frequency variation and the power variation on the connecting line of each control area, and the initial area inertia h of each control area is calculated init . Next, an inertia correction model is constructed, operation parameters are set for the inertia correction model, the operation parameters comprise model super-parameters alpha, epsilon, delta, the maximum iteration number of an inner layer and the maximum iteration number of an outer layer, and the inertia correction model is a double-iteration model and comprises inner layer iteration and outer layer iteration. Further, a disturbance control region identifier d, a non-disturbance control region identifier set U, the total number of regions n of each control region and the total network frequency variation delta f are input real (t), the power variation delta p on the interconnecting line of each control area, the initial full network inertia h area Initial zone inertia h corresponding to each control zone init . Finally, the inertia correction model is adopted to carry out inertia correction on the initial area inertia of each control area.
For example, an interconnected network having 6 independent control regions is provided, and the overall network frequency data of the interconnected network when a disturbance occurs, the link line data of each region, the disturbance magnitude, and the disturbance occurrence region (represented by region 1) are obtained, and the initial overall network inertia h is calculated by the above formula 4 area Wherein Δp (t) is the disturbance magnitude, and Δf (t) is the total network frequency variation. As a result, as shown in FIG. 6, by calculating the stability index, the inertia response phase (shown by the bold line) was identified, and the average value of the inertia at this phase was 186.16 (unit: s). Similarly, initial inertia estimates for each control region can be obtained, as shown in table 1 below, because this disturbance occurs in region 1, when only the full-grid frequency is used, the non-disturbance region has a portion of inertia support for the disturbance region, which can make the disturbance region inertia larger and the non-disturbance region inertia smaller. Therefore, inertia correction is required.
TABLE 1 inertia of regions to be corrected
| Zone 1 | Zone 2 | Zone 3 | Zone 4 | Zone 5 | Zone 6 | |
| Inertia/s | 70.21 | 25.10 | 8.20 | 57.12 | 30.01 | 4.22 |
202. And calculating according to an inertia equation and the initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to the non-disturbance control area, wherein the control area comprises the non-disturbance control area and the disturbance control area.
In this step, an initialization operation is first performed, specifically, an inertia parameter h=h is set init The inertia equation is transformed to obtain the frequency variation of each control region, specifically as shown in the following formula 5:
equation 5:
further, the frequency variation of each control area is added and averaged to obtain an initial first average frequency variation curve delta f un (t)，Δf un (t)＝mean(Δf init (t)) substituting the power variation on the interconnecting line of each non-disturbance control area and the initial area inertia of each non-disturbance control area into an inertia equation to transform, thereby obtaining the frequency variation of each non-disturbance control area, which is specifically shown in the following formula 6:
equation 6:
adding and averaging the frequency variation of each non-disturbance control region to obtain a second average frequency variation curve delta f u (t)，Δf u (t)＝mean(Δf i (t)). The control region includes a disturbance control region where disturbance occurs and a plurality of non-disturbance control regions.
203. And carrying out iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area.
In the step, after an algorithm of the inertia correction model enters an inner layer iteration, whether an error between a first average frequency change curve and a second average frequency change curve is smaller than an error threshold epsilon in a model super-parameter is judged. If yes, jumping out of the inner layer iteration, and recording the inertia h of the first area to be screened of the non-disturbance control area u And go into outer layer iterations. If not, continuously updating the area inertia of each non-disturbance control area by adopting a first average frequency change curve and a second average frequency change curve according to the following formula 7 and the following formula 8 until the iteration number of the inner layer is equal to the maximum iteration number of the inner layer, jumping out of the iteration of the inner layer, recording the inertia of a first area to be screened of the non-disturbance control area, and entering into the iteration of the outer layer.
Equation 7: h is a U ＝h U -α*d L /dh U
Equation 8: l= Σ t *(Δf u (t)-Δf un (t)) 2
Wherein h is U The area inertia, L, is the loss function, Δf, is the area inertia of the non-disturbance control area un (t) is a first average frequency variation curve, Δf u And (t) is a second average frequency variation curve.
204. And calculating the inertia of a second area to be screened of the disturbance control area based on the outer layer iteration of the inertia correction model, calculating total inertia to be screened according to the inertia of the first area to be screened and the inertia of the second area to be screened, correlating the inertia of the first area to be screened, the inertia of the second area to be screened and the total inertia to be screened, storing the first area to be screened, the inertia of the second area to be screened and the total inertia to be screened as a group to be screened in a record table, updating a first average frequency change curve, entering the inner layer iteration again, and carrying out inertia correction by adopting the updated first average frequency change curve until the iteration times of the outer layer iteration are larger than the maximum iteration times of the outer layer.
In this step, according to the disturbance-derived total network frequency variation Δf real (t) and a second average frequency variation curve Deltaf u (t) calculating a disturbance frequency variation curve of the disturbance control region, specifically as shown in the following equation 9:
equation 9: Δf d (t)＝n*Δf real (t)-Δf u (t)
Wherein Δf d (t) is the disturbance frequency of the disturbance control zone; Δf u (t)＝∑ i∈U Δf i (t)，Δf i And (t) is the non-disturbance-controlled zone frequency. And then, calculating the frequency variation on the connecting line of the disturbance frequency variation curve and the disturbance control area by adopting an inertia equation to obtain the inertia of the second area to be screened. Then, based on the following formula 10, adding the sum of the inertia of the first area to be screened and the inertia of the second area to be screened to obtain total inertia h to be screened SUM And correlating the inertia of the first area to be screened, the inertia of the second area to be screened and the total inertia to be screened, and storing the first area to be screened, the second area to be screened and the total inertia to be screened in a record table as a group to be screened.
Equation 10: h is a SUM ＝h d +∑ i∈U h i
Wherein h is i For the region inertia of the ith non-disturbance control region, h can be calculated as shown in equation 7 above U Is searched. Further, it is determined whether the number of iterations of the outer layer is greater than the maximum number of iterations of the outer layer. If so, jumping out of the outer layer iteration. If not, updating the first average frequency change curve delta f un (t), in particular, maintaining a first average frequency variation curve Δf un The initial value of (t) is unchanged, and the first average frequency change curve delta f is obtained according to the slope parameter delta in the model super-parameter un The slope of (t) increases by δ. And finally, performing inner layer iteration again, and performing inertia correction by adopting the updated first average frequency change curve until the iteration number of outer layer iteration is greater than the maximum iteration number of the outer layer. Continuing to take the interconnected power grids of the 6 independent control areas as an example for explanation, iterating by the method, and increasing the number of times of outer layer loop iteration, wherein Deltaf un (t) the curve is continuously rising, Δf d The curve (t) drops off as shown in fig. 7. Every time an outer layer cycle passes, an h is recorded SUM Recorded h SUM As shown in fig. 8.
205. And selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of the first to-be-screened area and the inertia of the second to-be-screened area stored in the target to-be-screened group as the inertia of the target area of each control area.
Reading total inertia to be screened of each group to be screened in all groups to be screened in a record table, and extracting a designated group to be screened, wherein the difference between the total inertia to be screened and the initial total network inertia is smaller than a preset value;
And selecting a target to-be-screened group of the to-be-screened group, wherein the inertia of the first to-be-screened area and the inertia of the second to-be-screened area meet the proportional relation of the power generation body quantity between each control area.
Continuing to describe the interconnected power grid of the 6 independent control areas as an example, the method can obtain the sum h area Two points of equal value, corresponding to two sets of dataAs can be seen from fig. 9, these two sets of data are shown in table 2 below, respectively.
Table 2 record table h SUM And h area Equivalent target to be screened group
The amount of power generated in each control region can be known from practice, in this example, the amount of power generated in region 4 is the largest, and regions 3 and 6 are the smallest, so it is apparent that the second set of data is more in accordance with the actual logic, so the second set of data is selected as the final output.
In summary, as shown in fig. 10, the number of disturbance occurrence regions, non-disturbance regions and total regions is first determined, and then an operation parameter is set for the inertia correction model, where the operation parameter includes model super parameters α, ε, δ, an inner layer maximum iteration number and an outer layer maximum iteration number, and the inertia correction model is a dual-iteration model, including an inner layer iteration and an outer layer iteration. Further, a disturbance control region identifier d, a non-disturbance control region identifier set U, the total number of regions n of each control region and the total network frequency variation delta f are input real (t), the power variation delta p on the interconnecting line of each control area, the initial full network inertia h area Initial zone inertia h corresponding to each control zone init . And correcting the inertia of the initial area through inner layer iteration and outer layer iteration, and finally screening out the inertia of the target area.
According to the method provided by the embodiment of the application, firstly, an inertia correction model is constructed, and operating parameters are set for the inertia correction model, wherein the operating parameters comprise model super-parameters, the maximum iteration times of an inner layer and the maximum iteration times of an outer layer. And then, calculating according to an inertia equation and the initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to the non-disturbance control area, wherein the control area comprises the non-disturbance control area and the disturbance control area. And then, carrying out iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area. Further, based on outer layer iteration of the inertia correction model, calculating second area inertia to be screened of the disturbance control area, calculating total inertia to be screened according to the first area inertia to be screened and the second area inertia to be screened, correlating the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened, storing the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened as a group to be screened in a record table, updating a first average frequency change curve, entering inner layer iteration again, carrying out inertia correction by adopting the updated first average frequency change curve until the iteration times of the outer layer iteration are larger than the maximum iteration times of the outer layer. And finally, selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of the first to-be-screened area and the inertia of the second to-be-screened area stored in the target to-be-screened group as the inertia of the target area of each control area. According to the method and the device, when the full-network frequency is only available, the inertia of each area can be estimated by using a rotor motion equation, inertia is corrected by using a double-layer iteration strategy, and the purpose of reasonably estimating the inertia of each area under limited data is achieved.
It should be noted that, other corresponding descriptions of each functional unit related to the device for evaluating inertia of each control area for a regional power grid provided in the embodiment of the present application may refer to corresponding descriptions in fig. 1 and fig. 2 to fig. 10, and are not repeated here.
Based on the above methods as shown in fig. 1 and fig. 2 to fig. 10, correspondingly, the present embodiment further provides a storage medium, on which a computer program is stored, where the computer program is executed by a processor to implement the steps of the method for evaluating inertia of each control area facing the regional power grid.
From the description of the above embodiments, it will be apparent to those skilled in the art that the present application may be implemented by means of software plus necessary general hardware platforms. By applying the technical scheme, firstly, an inertia correction model is constructed, and operating parameters are set for the inertia correction model, wherein the operating parameters comprise model super-parameters, the maximum iteration times of an inner layer and the maximum iteration times of an outer layer. And then, calculating according to an inertia equation and the initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to the non-disturbance control area, wherein the control area comprises the non-disturbance control area and the disturbance control area. And then, carrying out iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area. Further, based on outer layer iteration of the inertia correction model, calculating second area inertia to be screened of the disturbance control area, calculating total inertia to be screened according to the first area inertia to be screened and the second area inertia to be screened, correlating the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened, storing the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened as a group to be screened in a record table, updating a first average frequency change curve, entering inner layer iteration again, carrying out inertia correction by adopting the updated first average frequency change curve until the iteration times of the outer layer iteration are larger than the maximum iteration times of the outer layer. And finally, selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of the first to-be-screened area and the inertia of the second to-be-screened area stored in the target to-be-screened group as the inertia of the target area of each control area. Compared with the prior art, the method and the device have the advantages that when the full-network frequency is only available, the inertia of each area can be estimated by using the rotor motion equation, inertia is corrected by using the double-layer iteration strategy, and the purpose of reasonably estimating the inertia of each area under limited data is achieved.
Those skilled in the art will appreciate that the drawings are merely schematic illustrations of one preferred implementation scenario, and that the modules or flows in the drawings are not necessarily required to practice the present application.
The foregoing application serial numbers are merely for description, and do not represent advantages or disadvantages of the implementation scenario.
The foregoing disclosure is merely a few specific implementations of the present application, but the present application is not limited thereto and any variations that can be considered by a person skilled in the art shall fall within the protection scope of the present application.
Claims (8)
1. The regional power grid-oriented inertia evaluation method for each control region is characterized by comprising the following steps of:
an inertia correction model is built, operation parameters are set for the inertia correction model, the operation parameters comprise model super-parameters, inner layer maximum iteration times and outer layer maximum iteration times, and the inertia correction model is a double-iteration model;
according to an inertia equation, calculating according to initial area inertia of each control area, and determining a first average frequency change curve and a second average frequency change curve corresponding to a non-disturbance control area, wherein the control area comprises the non-disturbance control area and a disturbance control area;
performing iterative correction on the initial area inertia of the non-disturbance control area based on the inner layer iteration of the inertia correction model to obtain the first area inertia to be screened of the non-disturbance control area;
Calculating the inertia of a second area to be screened of the disturbance control area based on the outer layer iteration of the inertia correction model, calculating total inertia to be screened according to the inertia of the first area to be screened and the inertia of the second area to be screened, correlating the inertia of the first area to be screened, the inertia of the second area to be screened and the total inertia to be screened, storing the first area to be screened, serving as a group to be screened in a record table, updating the first average frequency change curve, entering the inner layer iteration again, and carrying out inertia correction by adopting the updated first average frequency change curve until the iteration number of the outer layer iteration is larger than the maximum iteration number of the outer layer;
and selecting a target to-be-screened group meeting preset conditions from a plurality of to-be-screened groups in the record table, and taking the inertia of a first to-be-screened area and the inertia of a second to-be-screened area stored in the target to-be-screened group as the inertia of a target area of each control area.
2. The method of claim 1, wherein prior to the constructing the inertia correction model, the method further comprises:
determining the inertia equation according to a rotor motion equation;
Obtaining the disturbance total network frequency variation, the disturbance magnitude and the power variation on the connecting lines of each control area, calculating the total network frequency variation and the disturbance magnitude by adopting the inertia equation to obtain initial total network inertia, and calculating the total network frequency variation and the power variation on the connecting lines of each control area by adopting the inertia equation to obtain initial area inertia of each control area.
3. The method of claim 1, wherein after the constructing the inertia correction model, the method further comprises:
and taking disturbance control area identification, non-disturbance control area identification, total area number of each control area, the full-network frequency variation, power variation on a connecting line of each control area, initial full-network inertia and initial area inertia corresponding to each control area as input parameters, and inputting the parameters into the inertia correction model.
4. The method of claim 1, wherein the calculating, according to the inertia equation, according to the initial area inertia of each control area, to determine the first average frequency variation curve and the second average frequency variation curve corresponding to the non-disturbance control area includes:
Calculating the power variation on the connecting line of each control area and the initial area inertia of each control area by adopting the inertia equation to obtain the frequency variation of each control area;
adding and averaging the frequency variation of each control area to obtain a first average frequency variation curve;
calculating the power variation on the connecting line of each non-disturbance control area and the initial area inertia of each non-disturbance control area by adopting the inertia equation to obtain the frequency variation of each non-disturbance control area;
and adding and averaging the frequency variation of each non-disturbance control area to obtain the second average frequency variation curve.
5. The method of claim 1, wherein iteratively correcting the initial area inertia of the non-disturbance-controlled area based on the inner layer iteration of the inertia correction model to obtain a first area inertia to be screened of the non-disturbance-controlled area comprises:
entering the inner layer iteration, and judging whether the error between the first average frequency change curve and the second average frequency change curve is smaller than an error threshold value in the model super-parameter;
If yes, jumping out of the inner layer iteration, recording inertia of a first area to be screened of the non-disturbance control area, and entering the outer layer iteration;
if not, continuously updating the area inertia of each non-disturbance control area by adopting the first average frequency change curve and the second average frequency change curve according to the following expression,
h U ＝h U -α*d L /dh U
L＝∑ t *(Δf u (t)-Δf un (t)) 2
jumping out the inner layer iteration until the inner layer iteration times are equal to the maximum inner layer iteration times, recording the inertia of a first area to be screened of the non-disturbance control area, and entering the outer layer iteration, wherein h is as follows U The area inertia of the non-disturbance control area is L is a loss function, and Deltaf un (t) is the first average frequency variation curve, Δf u (t) is the second average frequency variation curve.
6. The method of claim 1, wherein the calculating the second area inertia to be screened for the disturbance control area based on the outer layer iteration of the inertia correction model, calculating the total inertia to be screened based on the first area inertia to be screened and the second area inertia to be screened, and associating the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened, storing the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened as a group to be screened in a record table, updating the first average frequency change curve, re-entering the inner layer iteration, and performing inertia correction by using the updated first average frequency change curve until the number of iterations of the outer layer iteration is greater than the maximum number of iterations of the outer layer, comprises:
Calculating a disturbance frequency change curve of the disturbance control area according to the disturbed full-network frequency change quantity and the second average frequency change curve;
calculating the disturbance frequency change curve and the frequency change quantity on the connecting line of the disturbance control area by adopting the inertia equation to obtain the inertia of the second area to be screened;
adding the sum of the first area inertia to be screened and the second area inertia to be screened to obtain the total inertia to be screened, and associating the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened, and storing the first area inertia to be screened, the second area inertia to be screened and the total inertia to be screened in a record table as a group to be screened;
judging whether the iteration number of the outer layer iteration is larger than the maximum iteration number of the outer layer or not;
if yes, jumping out of the outer layer iteration;
if not, updating the first average frequency change curve, entering the inner layer iteration again, and carrying out inertia correction by adopting the updated first average frequency change curve until the iteration number of the outer layer iteration is larger than the maximum iteration number of the outer layer.
7. The method of claim 6, wherein the updating the first average frequency profile comprises:
And keeping the initial value of the first average frequency change curve unchanged, and increasing the slope of the first average frequency change curve according to the slope parameter in the model super-parameter.
8. The method according to claim 1, wherein selecting, in the record table, a target to-be-screened group that satisfies a preset condition from a plurality of to-be-screened groups includes:
reading the total inertia to be screened of each group to be screened in all groups to be screened in the record table, and extracting the designated group to be screened, wherein the difference between the total inertia to be screened and the initial total network inertia is smaller than a preset value;
selecting the target to-be-screened group of the to-be-screened groups, wherein the inertia of the first to-be-screened area and the inertia of the second to-be-screened area meet the proportional relation of the power generation body quantity between each control area.
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