CN109301845B - Active fluctuation stabilizing method of extra-high voltage tie line based on master-slave type energy storage coordination control - Google Patents
Active fluctuation stabilizing method of extra-high voltage tie line based on master-slave type energy storage coordination control Download PDFInfo
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Abstract
An active fluctuation stabilizing method of an extra-high voltage tie line based on master-slave energy storage coordination control. The utility model relates to the technical field of secondary frequency modulation of a power grid, in particular to an active fluctuation stabilizing method of an extra-high voltage tie line based on master-slave energy storage coordination control. The active fluctuation stabilizing method of the extra-high voltage interconnection line based on the master-slave energy storage coordination control is provided, and the actual requirements of the extra-high voltage interconnection network are met according to the frequency modulation characteristics of BESS. The invention can realize the decoupling control of BESS on the power and frequency fluctuation of the tie line, and can effectively inhibit the power fluctuation of the tie line on the premise of ensuring the frequency stability of the power grid so as to meet the requirement of the regional power grid with extra-high voltage connection on the stability of the exchange power of the tie line; the invention takes the control performance standard CPS as a judgment index to ensure that the regional power grid conforms to the evaluation index of a power grid company.
Description
Technical Field
The invention relates to the technical field of secondary frequency modulation of a power grid, in particular to an active fluctuation stabilizing method of an extra-high voltage tie line based on master-slave energy storage coordination control.
Background
The frequency of the power system is one of three indexes representing the quality of electric energy, and is closely related to the safe and stable operation of a power grid. Automatic Generation Control (AGC) is an important technical means for maintaining the frequency stability of a system, and is important for a power system. With the rapid development of power systems, the interconnection degree between regional power grids is increasingly strengthened. Compared with a non-interconnected power grid, the interconnected power grid needs to ensure stable frequency and maintain planned operation of inter-regional power grid tie line exchange power. Meanwhile, in order to avoid the influence on the frequency stability of the whole power system caused by the fact that a certain regional power grid in the interconnected power grid pushes down frequency modulation responsibility, a power grid company establishes a series of assessment standards so as to achieve the purposes of evaluating the adjusting capacity of each regional power grid and limiting the speculative behavior.
The evaluation of automatic power generation control internationally today usually employs Control Performance Standards (CPS), including both CPS1 and CPS2 standards. Specifically, the CPS1 measures the change characteristics of the regional power grid and the relation between the change characteristics and the system frequency deviation by adopting a mathematical statistic method, and the CPS1 is used for evaluating the frequency deviation; CPS2 is then used to evaluate the ability of regional grid control tie-line tidal current deviations. The CPS standard is basically adopted in the electric power system at the present stage of China.
Currently, there are two methods listed in the following patents for AGC control strategy in power system with energy storage.
The patent name is 'an extra-high voltage tie line power control method considering responsibility indexes', and Chinese patent with application number '201410046792.6' proposes that: establishing a main control area in an AGC system, realizing area control of an interconnected network, setting a qualified threshold value of power fluctuation of the interconnected network and the interconnected network tie line of the area network, calculating a responsibility index of ACE and tie line power fluctuation of the control area according to an area control mode, calculating a responsibility component according to the responsibility index, calculating a regulation power demand according to the calculated responsibility index of ACE and tie line power fluctuation, and finally distributing the power regulation demand among control units.
The Chinese patent with the patent number of 201510888434.4, named as 'AGC control method and control system for energy storage to participate in secondary frequency modulation of power grid', proposes: generating a real-time area control error and a real-time area control instruction of the power grid according to the frequency deviation of the power grid and the exchange power deviation of the tie line; and according to the control interval in which the real-time region control error is positioned, distributing the adjustment quantity of the battery energy storage system and the initial charge state of the battery energy storage system by using the real-time region control instruction and the preset control logic to determine the real-time charge state of the battery energy storage system, and accordingly determining the actual adjustment quantity of the battery energy storage system.
However, the above method cannot meet the requirement of the regional power grid of the extra-high voltage connection on the stability of the exchange power of the tie line.
In recent years, the participation of large-scale battery energy storage power stations (BESS) in grid frequency modulation is receiving wide attention from the industry. The BESS has the advantages of high response speed, flexible and accurate control and the like in power grid frequency modulation, can improve the frequency modulation effect to a great extent, and implements a more flexible frequency modulation means than the traditional unit. How to flexibly control the BESS in the interconnected network to stabilize the frequency deviation of the interconnected network and the power fluctuation of a connecting line is a key problem to be solved by the AGC of the interconnected network under the participation of the BESS.
In the existing control, aiming at the participation of BESS, fewer active stabilizing methods for effectively stabilizing the interconnection network tie line are provided. Meanwhile, a regional power grid connected by an extra-high voltage also puts a high requirement on the stability of the exchange power of the tie line, so an effective extra-high voltage tie line active stabilizing method must be put forward to meet the requirement.
Disclosure of Invention
Aiming at the problems, the invention provides the active fluctuation stabilizing method of the extra-high voltage tie line based on the master-slave energy storage coordination control, which meets the actual needs of the extra-high voltage interconnected power grid according to the self frequency modulation characteristics of BESS.
The technical scheme of the invention is as follows: the method comprises the following steps:
1) acquiring AGC basic information required in the extra-high voltage interconnected power grid;
2) calculating frequency modulation control performance standards CPS1 and CPS2 of two adjacent power grid control areas;
3) calculating participation factors of each area power grid BESS
4) Determining the charge and discharge indexes and the common participation factor K of the BESSB；
5) And controlling BESS to execute the charging and discharging instruction.
The AGC basic information required in the step 1) includes the following information:
firstly, frequency deviation delta f of adjacent control areas of interconnected power gridi，Δfj
Control error ACE of adjacent control areas of interconnected power gridi，ACEj
Active power deviation delta P of tie line between adjacent areas of interconnected power gridij
ACEi＝ΔPij+BiΔfi(1)
ACEj＝-ΔPij+BjΔfj(2)
When the subscript i is added to the parameter, the parameter refers to the corresponding parameter of the area i; when the subscript j is added, the corresponding parameters of region j are referred to. And B is a frequency deviation coefficient set by a regional power grid, the unit is MW/0.1HZ, and a positive sign is taken.
CPS1 and CPS2 in the step 2) are calculated according to the following formulas:
CPS1＝100％(2-AyG{CF1}) (3)
wherein,1the control target value of the root mean square value of the frequency average deviation of 1 minute in the whole year by the regional power grid is shown, and the unit is Hz; Δ F1Means of frequency deviation, ACE, of 1 minute10Means the average value of the control errors of the interconnected network region within 10 minutes; l is10Refers to the control limit for the absolute value of the average value of ACE over 10 minutes; the CF1 is used for evaluating the influence of AGC control of a control area on the frequency of the whole interconnected system; CF2 refers to the ratio of average value of ACE every 10 minutes to control limit.
The participation factor of each area power grid BESS in the step 3)
Calculated according to the following formula:
said step (c) is4) Middle common participation factor KBThe determination method comprises the following steps:
when KBi *Less than KBj *And K isBi *When not less than 0, KBIs equal to KBj *，BESSiBeing primary BESS, BESSjIs called BESS;
when KBj *Less than KBi *And K isBj *When not less than 0, KBIs equal to KBi *，BESSjBeing primary BESS, BESSiIs called BESS;
③ when KBi *And KBj *All equal to 0, using existing AGC control for Δ PijThe recovery of (1).
The charging and discharging powers of the regional power grid i and the regional power grid j in the step 5) are respectively PBiAnd PBj，PBiAnd PBjThe sizes are the same, and the charging and discharging directions are opposite;
by comparing PBi *And PBj *The absolute value is taken as the smaller value to obtain PBiAnd PBjValue of (A), PBi *And PBj *The calculation method of (2) is as follows, when the SoC isi＜SoCminAnd the battery is required to be further discharged, or SoCi＞SoCmaxAnd further charging of the battery is required,
rest conditions
In the same way, can be calculated
Where SoC represents the state of charge of the battery's stored energy.
The invention has the beneficial effects that: according to the method, based on the requirement of the ultrahigh-voltage connected regional power grid on the exchange power stability of the interconnection line, based on the characteristics of the ultrahigh-voltage interconnected power grid, CPS1 and CPS2 frequency modulation control performance standards are adopted to determine the BESS charge and discharge index of the regional power grid, and finally, a charge and discharge instruction is executed, so that the active fluctuation of the interconnection line of the interconnected power grid is effectively suppressed. In addition, since the BESS does not directly compensate for the active imbalance between the power generation and the load, the present invention has a greatly reduced demand for BESS power capacity; different from the characteristic that the traditional unit is synchronously coupled with the power grid frequency, the decoupling control of BESS on the power and frequency fluctuation of the tie line can be realized, and the power fluctuation of the tie line can be effectively inhibited on the premise of ensuring the stability of the power grid frequency so as to meet the requirement of the stability of the exchange power of the tie line by the regional power grid connected with the extra-high voltage; the invention takes the control performance standard CPS as a judgment index to ensure that the regional power grid conforms to the evaluation index of a power grid company.
Drawings
Figure 1 is a flow chart of the operation of the present invention,
figure 2 is a qualified operating area under the CPS1 standard,
in fig. 3 a is a CPS variation curve of the regional power grid 1 and the regional power grid 2 in the embodiment of the present invention,
b in fig. 3 is the participation factor variation curve of each of the two regional power grids in the embodiment of the invention,
in fig. 3 c is a common participation factor variation curve of two regional power grids in the embodiment of the invention,
figure 3 d is a graph of the variation of the BESS output in the two-area grid in an embodiment of the invention,
fig. 4 is a power variation curve of a tie line in the master-slave energy storage coordination control method according to the embodiment of the present invention.
Detailed Description
The present invention will be described in detail with reference to the accompanying drawings.
As shown in fig. 1, the active fluctuation stabilizing method for the extra-high voltage tie line based on the master-slave energy storage coordination control of the invention comprises the following steps:
step 1: obtaining AGC basic information required in extra-high voltage interconnected power grid
The frequency modulation power supply of the extra-high voltage interconnected power grid comprises a traditional unit and a battery energy storage power station, and the basic information of the power supply comprises
Firstly, frequency deviation delta f of adjacent control areas of interconnected power gridi，Δfj
Control error ACE of adjacent control areas of interconnected power gridi，ACEj
Active power deviation delta P of tie line between adjacent areas of interconnected power gridij
ACEi＝ΔPij+BiΔfi(I)
ACEj＝-ΔPij+BjΔfj(2)
When the subscript i is added to the parameter, the parameter refers to the corresponding parameter of the area i; when the subscript j is added, the corresponding parameters of region j are referred to. B is a frequency deviation coefficient set by the regional power grid, which is a constant and has a unit of MW/0.1HZ, and takes a positive sign [ generally determined by the power grid company, and is usually determined according to a primary frequency modulation (the difference coefficient σ represents the relative change of the generator voltage when the reactive current increases from zero to a rated value) of the motor, for example, the difference coefficient is 3% to 5%, and the value B may take 0.5 to 2 times of the reciprocal thereof, i.e., 10 to 66.6 ].
Regional frequency deviation Δ fiAnd Δ fjThe difference value of the power grid frequency of the region and the power grid determined frequency is shown, and the power grid determined frequency in China is 50 Hz. Delta PijIs the deviation between the real-time power exchange and the planned power exchange between the two control areas. Δ fi，ΔfjAnd Δ PijFrom the system SCADA (Data acquisitionWith a supervisory control system) in real time.
Step 2: computing grid control area frequency modulation Control Performance Standard (CPS)
The master-slave mode energy storage coordination control-based active fluctuation stabilizing method for the extra-high voltage tie line needs to calculate the frequency modulation control performance standards of two adjacent regional power grids respectively, and the method adopts CPS standards which are widely used in China and comprise two standards of CPS1 and CPS 2. The specific calculation mode of the regional power grid frequency modulation control performance index based on the CPS standard is shown in formulas (3) to (6):
CPS1＝100％(2-AVG{CF1}) (3)
wherein,1the unit is Hz (is a frequency deviation constant from a certain target frequency, and usually the root mean square value of the average frequency of one minute and the rated frequency deviation in the last year is taken, and the values of adjacent control areas are the same); Δ F1Means of 1 minute frequency deviation; ACE10Means the average value of the control errors of the interconnected network region within 10 minutes; l is10Refers to the control limit for the absolute value of the average value of ACE over 10 minutes. The CF1 is used for evaluating the influence of AGC control of a control area on the frequency of the whole interconnected system and is a basic control variable in the CPS 1; CF2 refers to the ratio of average value of ACE every 10 minutes to control limit.
L10Calculated according to the following formula:
wherein,10the mean square root value (unit Hz) of the average value of the actual frequency and the standard frequency deviation of 10 minutes in a given year is given, Bi is the frequency deviation coefficient of a control area i, and Bs is the total frequency deviation coefficient of the interconnected power system and is the average value of the frequency deviation coefficients of the control areas.
And step 3: respective evaluation of regional grid frequency modulation Control Performance Standard (CPS)
Determining participation factors of each regional power grid BESS according to the CPS calculation result in the step 2
The participation factor is calculated to ensure that the BESS of each regional power grid can stabilize the exchange power of the extra-high voltage connecting line and avoid the condition that the CPS of the regional power grid is not up to the standard and is sanctioned.
Since the CPS2 mainly reflects the control degree of the AGC on the link, this method is used to smooth the link fluctuation, that CPS2 must not exceed the standard, and the calculation period of CPS2 is 10 minutes, this time scale cannot match the control time scale, therefore, only CPS1 is considered in this case.
Fig. 2 shows qualified operating regions under the CPS1 standard, when the CPS1 is greater than 200%, the system frequency recovery is less urgent, when the CPS1 is from 200% to 150%, the urgent degree is increased gradually, the urgent degree is considered to be more urgent from 150% to 100%, and the CPS1 is not qualified operating region less than 100%.
The qualified operation area of the CPS1 is shown as a range in the figure, namely CPS1 belongs to [ 100%, 200% ], the direction of ACE is opposite to the direction of delta f (delta f is multiplied by ACE < 0), namely the second quadrant and the fourth quadrant in the figure 2, which shows that the system has low urgency degree on frequency recovery, and the power deviation of a connecting line can be preferably stabilized, and the method of the invention is executed; similarly, the direction of ACE is the same as that of Δ f (Δ f × ACE > 0), namely, the first quadrant and the third quadrant in the graph, along with the decrease of the CPS1 value, the urgency degree of the system to frequency recovery is continuously increased, the priority degree of suppressing the power deviation of the tie line is gradually reduced, and once the CPS1 is less than or equal to 150%, the method is stopped.
Therefore, the factor is participated in according to the calculation result of CPS
The following three situations may occur, as specified below:
case 1: if Δ f and ACE are of opposite sign (positive or negative), CPS1 for this region exceeds 200%. In this case, BESS may consider only the stabilizing Δ PijWhile ignoring the recovery of Δ f, when K isB *Take the maximum value KB，max，KB，maxRepresenting the maximum parameter that BESS can participate in the active fluctuation stabilization of the stabilizing tie line, and the value of the value is selected through the root tracing graph.
Case 2: if Δ f and ACE are of the same sign (either positive or negative) and the value of CPS1 is greater than 150%, BESS needs to compromise the grid-to-grid pair Δ PijAnd Δ f, at which KB *Take a value of
Case 3: if Δ f and ACE are the same and the value of CPS1 is less than 150%, BESS does not need to compromise the grid-to-grid pair Δ PijAnd Δ f, while BESS must be operated to facilitate Δ f recovery, when K isB *The value is 0.
And 4, step 4: determining charge and discharge indexes and common participation factors of local power grid BESS
In this step, according to K in the previous stepBi *And KBj *The value of (A) is used for calculating a common participation factor K of a neighboring area power grid BESSBAnd the charging and discharging state of each BESS, wherein the step is the core of the active fluctuation stabilizing method of the extra-high voltage tie line based on master-slave energy storage coordination control. When the regional power grid is disturbed, the participation factor K of the neighboring regional power gridBi *And KBj *The following three cases can be discussed to determine KBThe value of (a). The concrete description is as follows:
case 1: kBi *Less than KBj *And K isBi *Not less than 0
In this case, the CPS1 of the area grid j is large, the BESS of the area grid i is the master BESS, and the BESS of the area grid j is the slave BESS. BESS as a slave-area networkjAttention may be paid only to the stabilization of Δ PijRegardless of the recovery of af. At the same time, because BESSiThe operating condition of (1) is necessarily favorable for recovering the delta f, so the charge and discharge index of the BESS refers to the charge and discharge index of the BESS in the local power grid i. I.e. if BESSiPerforming a charging action, BESSjA discharging action is performed and vice versa. However, due to BESSjIs not good for the recovery of the local grid Δ f, so that the common participation factor K of the adjacent area grids BESSBIs equal to KBj *。
Suppose that a step increase in load occurs in the regional grid i, resulting in Δ f within secondsi，ΔfjAnd Δ PijIs negative, wherein Δ PijNegative means that active power is transferred from the regional power grid j to the regional power grid i. ACE of regional grid i according to equation (1)iIs negative, and Δ fiThe symbols are the same. Generally, when the CPS1 of the regional power grid i is poor, the BESS in the regional power grid should be recovered by the priority of delta fi. BESS onlyiDischarge, then Δ f can be stabilized simultaneouslyiAnd Δ Pij. Accordingly, BESSiMust operate in a discharge mode, so BESSjShould operate in a charging mode. The case of regional grid j can then be according to equation (2), ACEjIs given a symbol of- Δ PijAnd BjΔfjAlgebraic sum of (c). When- Δ PijWhen larger, CPS1 is greater than 200%; when-BjΔfjAt larger, CPS1 is also typically greater than 150%. Therefore, the regional power grid CPS1 has a larger margin, BESSjCan focus on stabilizing Δ PijFluctuating. However, due to BESSjIs not favorable for recovering delta f of the regional power gridjTherefore, the charging power level of the BESS must be carefully considered. Therefore, the common factor K of the two local networks BESSBAre all equal to KBj *. In summary, the BESS performs the method of the present inventioniDischarge, BESSjAnd charging, wherein the absolute values of the power of the two are equal. In this case, the control of the master-slave BESS is advantageous for Δ PijThe recovery of (1). Furthermore, although Δ fjNei BESSjBut can be limited to a certain range by monitoring CPS 1. If the CPS1 of the regional power grid j does not meet the requirements, the situation is excessive to other two situations.
Case 2: kBj *Less than KBi *And K isBj *Is not less than0
Case 2 is the opposite of case 1. According to the operation rule of the master-slave type energy storage coordination control method, the BESS charging and discharging state in each regional power grid is changed from KBj *Determine, at this time KBj *Less than KBi *. In this case, the common factor K of the adjacent-area electrical networks BESSBIs equal to KBi *。
Case 3: kBi *And KBj *Are all equal to 0
Case 3 represents a situation where both regional grids are disturbed, when the existing AGC control is advantageous for Δ PijDoes not require the use of said method for the stabilization of Δ Pij. In the traditional sense, the AGC responds to an ACE component generated by frequency offset and an ACE component generated by tie line exchange power offset through proportional integral control, and the output of a control unit enables the system frequency and the regional tie line exchange power to be maintained at a planned value.
And 5: controlling BESS to execute charge and discharge instructions
And determining the charge and discharge indexes of the interconnected network BESS and the common participation factors of the adjacent power grids according to the steps, wherein the step requires the BESS to execute a charge and discharge instruction according to a result, and the charge and discharge of the main BESS and the slave BESS are the same in size and opposite in direction.
However, the practical behavior of BESS is limited by battery characteristics, such as the power rating PB,ratedRated capacity EB_ratedAnd state of charge SoC. First, the active power of the BESS is between the rated maximum discharge power PB,rated maxAnd rated maximum charging power PB,rated -maxIn the meantime. While the SoC must remain within an acceptable range, e.g., between 20% and 80%, in real time. During the execution of this step, when (SoC)<SoCmin&PB>0) Or (SoC)>SoCmax&PB<0) At this time BESS is cut off to avoid overcharging or overdischarging. The calculation formulas of SoC are shown in (7) and (8).
Wherein EB(tn) And EB(tn-1) Are respectively tnAnd tn-1Energy stored at time BESS, PB(tn) Is the output power of BESS (sign positive for discharging and vice versa for charging), η+And η-In particular the charge-discharge efficiency of BESS, in the scheme, eta is taken+＝0.9、η-＝0.95，SoC(tn) Represents tnState of charge of battery energy storage at all times, EB.ratedRepresenting the rated capacity, P, of the BESSBIs PBiAnd PBjIs a general representation of (a).
In the step, P is calculated according to the output provided by BESS of the local power grid of the power gridBi *And PBj *. The calculation method is as follows, when the SoCi＜SoCminAnd the battery is required to be further discharged, or SoCi＞SoCmaxAnd further charging of the battery is required,
rest conditions
In the same way, can be calculated
Since the control method requires that the charge and discharge power of the batteries in the adjacent control areas are the same and the charge and discharge directions are opposite, P is further comparedBi *And PBj *Determining the final output P of BESSBiAnd PBj. Specifically, PBiAnd PBjIs taken as PBi *And PBj *The smaller of the absolute values, the charge-discharge direction PBiIs the same as PBi *，PBjIs the same as PBj *。
In summary, by implementing and applying these 5 steps, the method of the present invention can effectively suppress Δ P in AGCijAnd the recovery effect of Δ f is improved to some extent. In addition, the AGC performance of each area grid is still guaranteed by monitoring the CPS and guaranteeing the SoC of the BESS within a controllable range.
The following describes advantageous effects of the technical solution of the present invention with reference to examples.
Extracting key data according to the actual operation condition of a power grid, and simulating two interconnected regional power grids, wherein the generated power of the regional power grid 1 is 2500MW, and the load is 2400 MW; the power generation power of the regional power grid 2 is 1900MW, and the load is 2000 MW; the exchange power of the tie lines among the regional power grids is 100MW, and the direction is from the regional power grid 1 to the regional power grid 2; the value of the difference adjustment coefficient of the traditional unit is 5%, the value of the inertia constant H is 5 when 100MW is taken as a reference, and the synchronous torque coefficient is 1.2. The BESS parameter in each region was 25MW/5 MWh; the whole system takes 2000MW as a reference value calculated by per unit value.
The invention uses simulink (a visual simulation tool in MATLAB) software in MATLAB to calculate, and inputs randomly given net load fluctuation into the simulink, such as step load fluctuation of 0.05% (1MW) p.u. of the regional power grid 2 in 10s, and the power grid frequency and control region error change along with the step load fluctuation, as the power grid basic information required by the step 1. Then the software calculates each value in step 2) in turn and draws each correlation curve. Fig. 3(a) is a CPS variation curve of the regional power grid 1 and the regional power grid 2 in this embodiment; fig. 3(b) is a variation curve of each participation factor of the two regional power grids; FIG. 3(c) is a common participation factor variation curve of two regional power grids; fig. 3(d) is a graph of the variation of the BESS output in a two-area power grid. Calculating a CPS value in real time by a CPS calculation module, as shown in fig. 3 (a); then calculating the participation factors of the corresponding regional power grids
And
as shown in FIG. 3 (b); under chargingIn the discharge module, the case is calculated to belong to case 2, i.e.
Is greater than
According to the rules of the method, at this time, KBIs equal to
The common participation factor of the two regional grids is shown in fig. 3 (c). Thus, the charging and discharging of the two-area grid BESS is obtained as shown in fig. 3 (d).
Fig. 4 is a tie line power change curve of the master-slave energy storage coordination control method and the conventional AGC control method, and it can be known from the graph that, compared with the conventional AGC method, the method can significantly reduce the peak of tie line power fluctuation, so the method can effectively suppress the tie line power fluctuation on the premise of ensuring the stability of the grid frequency.
Claims (5)
1. An active fluctuation stabilizing method of an extra-high voltage tie line based on master-slave type energy storage coordination control is characterized by comprising the following steps:
1) acquiring AGC basic information required in the extra-high voltage interconnected power grid;
2) calculating frequency modulation control performance standards CPS1 and CPS2 of two adjacent power grid control areas;
3) calculating participation factors of each area power grid BESS
Calculated according to the following formula:
4) determining the charge and discharge indexes and the common participation factor K of the BESSB；
5) Controlling BESS to execute a charging and discharging instruction;
wherein, KB.maxRepresents the maximum parameter that the BESS can participate in the suppression of the active fluctuation of the tie line.
2. The active fluctuation stabilizing method for the extra-high voltage tie line based on the master-slave energy storage coordination control of claim 1, wherein the AGC basic information required in the step 1) comprises the following information:
firstly, frequency deviation delta f of adjacent control areas of interconnected power gridi，Δfj
Control error ACE of adjacent control areas of interconnected power gridi，ACEj
Active power deviation delta P of tie line between adjacent areas of interconnected power gridij
ACEi＝ΔPij+BiΔfi(1)
ACEj＝-ΔPij+BjΔfj(2)
When the subscript i is added to the parameter, the parameter refers to the corresponding parameter of the area i; when subscript j is added, the corresponding parameters of region j are referred to; and B is a frequency deviation coefficient set by a regional power grid, the unit is MW/0.1HZ, and a positive sign is taken.
3. The active fluctuation stabilizing method for the extra-high voltage tie line based on the master-slave energy storage coordination control as claimed in claim 1, wherein in the step 2), the CPS1 and CPS2 are calculated according to the following formula:
CPS1＝100％(2-AVG{CF1}) (3)
wherein,1the control target value of the root mean square value of the frequency average deviation of 1 minute in the whole year by the regional power grid is shown, and the unit is Hz; Δ F1Means of frequency deviation, ACE, of 1 minute10Means the average value of the control errors of the interconnected network region within 10 minutes; l is10Refers to the control limit for the absolute value of the average value of ACE over 10 minutes; the CF1 is used for evaluating the influence of AGC control of a control area on the frequency of the whole interconnected system; CF2 refers to the ratio of average value of ACE every 10 minutes to control limit.
4. The active fluctuation stabilizing method for extra-high voltage tie lines based on master-slave energy storage coordination control according to claim 1, wherein the common participation factor K in step 4)BThe determination method comprises the following steps:
when KBi *Less than KBj *And K isBi *When not less than 0, KBIs equal to KBj *，BESSiBeing primary BESS, BESSjIs called BESS;
when KBj *Less than KBi *And K isBj *When not less than 0, KBIs equal to KBi *，BESSjBeing primary BESS, BESSiIs called BESS;
③ when KBi *And KBj *All equal to 0, using existing AGC control for Δ PijRecovery of (1);
wherein, Δ PijThe active power deviation of the tie line between the regional power grid i and the regional power grid j.
5. The active fluctuation stabilizing method for the extra-high voltage tie line based on master-slave energy storage coordination control according to claim 1, wherein in the step 5), the charging and discharging powers of a regional power grid i and a regional power grid j are respectively PBiAnd PBj，PBiAnd PBjThe sizes are the same, and the charging and discharging directions are opposite;
by comparing PBi *And PBj *The absolute value is taken as the smaller value to obtain PBiAnd PBjValue of (A), PBi *And PBj *The calculation method of (2) is as follows, when the SoC isi＜SoCminAnd the battery is required to be further discharged, or SoCi＞SoCmaxAnd further charging of the battery is required,
rest conditions
In the same way, can be calculated
Where SoC represents the state of charge of the battery, Δ PijThe active power deviation of the tie line between the regional power grid i and the regional power grid j.
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