CN115149556B - AGC coordinated control method for energy storage power station group power grid in consideration of SOC - Google Patents
AGC coordinated control method for energy storage power station group power grid in consideration of SOC Download PDFInfo
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/28—Arrangements for balancing of the load in a network by storage of energy
- H02J3/32—Arrangements for balancing of the load in a network by storage of energy using batteries with converting means
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/002—Flicker reduction, e.g. compensation of flicker introduced by non-linear load
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/24—Arrangements for preventing or reducing oscillations of power in networks
- H02J3/241—The oscillation concerning frequency
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
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- H02J7/00—Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries
- H02J7/0029—Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries with safety or protection devices or circuits
- H02J7/00302—Overcharge protection
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J7/00—Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries
- H02J7/0029—Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries with safety or protection devices or circuits
- H02J7/00306—Overdischarge protection
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- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
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- H02J7/0068—Battery or charger load switching, e.g. concurrent charging and load supply
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J7/00—Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries
- H02J7/02—Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries for charging batteries from ac mains by converters
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
- H02J2203/10—Power transmission or distribution systems management focussing at grid-level, e.g. load flow analysis, node profile computation, meshed network optimisation, active network management or spinning reserve management
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
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Abstract
The invention provides an AGC coordinated control method for an energy storage power station group power grid taking SOC into consideration, which comprises the following steps: step one, dividing SOC and ACE; step two, according to the SOC of the energy storage power station divided in the step one, a charge-discharge control model of the energy storage power station is established, and the frequency modulation output of the energy storage power station is controlled in a segmented mode; and thirdly, adjusting dynamic distribution coefficients of dynamic power distribution of the energy storage power station group according to the partitioning condition of the connecting lines divided in the first step, and smoothly adjusting the energy storage power distribution in the energy storage power station group. According to the invention, the dynamic distribution coefficient of the dynamic power distribution of the energy storage power station group is regulated, so that the energy storage power distribution in the energy storage power station group is regulated smoothly, the phenomena of overshoot and overdischarge of the energy storage system are prevented, and the cycle life of the energy storage battery system is effectively prolonged.
Description
Technical Field
The invention relates to the field of novel energy storage, in particular to an AGC coordinated control method for an energy storage power station group power grid considering SOC.
Background
At present, the research level of the energy storage system is mainly divided into a frequency modulation signal time/frequency domain decomposition control strategy, a proportional allocation consideration control strategy and a priority consideration control strategy. Taking the united states as an example, it has long been studied and continually adjusted in practical use to schedule fast energy storage strategies. The control strategy adopts a scheduling strategy of 'fast frequency modulation resource priority', namely, for frequency modulation response, the fast frequency modulation resource of energy storage is scheduled preferentially, and the state of charge (SOC) of the energy storage resource is controlled in real time; the method is characterized in that a regional control deviation (ACE, area control error) signal is decomposed, a high-frequency adjusting component of the ACE is given to a quick energy storage frequency modulation resource, a low-frequency signal is given to a common frequency modulation unit, and the complementary advantages of different frequency modulation resources can be realized.
The traditional energy storage power station participates in system frequency modulation, mainly a fixed distribution coefficient, but the current operation control strategy does not consider the state of charge (SOC) of an energy storage battery, and can cause the phenomena of overshoot and overdischarge of the energy storage system, thereby directly influencing the cycle life of the energy storage battery system. The invention provides a battery energy storage system which participates in an AGC control strategy based on the consideration of priority scheduling of quick energy storage resources.
Disclosure of Invention
The invention aims to provide an AGC coordinated control method for an energy storage power station group power grid, which considers the dynamic perception of the state of charge (SOC) of each energy storage power station and the frequency modulation requirement of the power grid, and determines the dynamic distribution coefficient of ACE between the energy storage power station group and a thermal power unit and the dynamic distribution coefficient of ACE between each energy storage power station in the energy storage power station group by defining and calculating the expected dynamic frequency modulation capacity of each frequency modulation power source so as to distribute the output of each frequency modulation power source.
An AGC coordinated control method for an energy storage power station group power grid considering SOC comprises the following steps:
Dividing the state of charge (SOC) according to the state of charge (SOC) of the energy storage power station, and dividing the SOC into grades of different SOC; according to the control deviation ACE condition of the regional interconnecting line, carrying out ACE partitioning and dividing into safety regions with different frequencies;
step two, according to the SOC of the energy storage power station divided in the step one, a charge-discharge control model of the energy storage power station is established, and the frequency modulation output of the energy storage power station is controlled in a segmented mode;
and thirdly, adjusting dynamic distribution coefficients of dynamic power distribution of the energy storage power station group according to the partitioning condition of the connecting lines divided in the first step, and smoothly adjusting the energy storage power distribution in the energy storage power station group.
Further, in the first step, according to the state of charge condition of the energy storage power station, the states of charge are divided into levels of different states of charge, which specifically includes:
For the capacity of the SOC, the segments are divided according to the interval 0-S oc,min,Soc,min～Soc,low,Soc,low～0.5,0.5～Soc,high,Soc,high～Soc,max, where S oc,min represents the minimum state of charge of the energy storage power station, typically 0.1, S oc,low represents the lower state of charge of the energy storage power station, typically 0.2, S oc,high represents the higher state of charge of the energy storage power station, typically 0.8, and S oc,max represents the maximum state of charge of the energy storage power station, typically 0.9.
Further, in the first step, according to the control deviation ACE condition of the regional interconnection line, the ACE is partitioned into safety regions with different frequencies, which specifically includes:
The regulation dead zone-a ce,min～Ace,min divides the ACE into zones according to emergency regulation zones-a ce,max and a ce,max, secondary emergency regulation zones-a ce,max～-Ace,mid and a ce,mid～Ace,mid, normal regulation zones-a ce,mid～-Ace,min and a ce,min～Ace,mid, wherein a ce,max represents a maximum value of the zone control deviation, a ce,mid represents an intermediate value of the zone control deviation, and a ce,min represents a minimum value of the zone control deviation.
Further, the second step specifically includes:
when the SOC is in different intervals, the SOC of the energy storage battery and the maximum discharge power thereof are established Maximum charging powerThe piecewise linear relation between the two is expressed as:
in the method, in the process of the invention, The modified frequency modulation power upper limit of the ith energy storage power station is set; Representing the lower limit of the frequency modulation power after the modification of the ith energy storage power station; p bess,N is the rated charge and discharge power of the energy storage battery; k 1、K2 is a set adjusting parameter; s oc,min、Soc,low、Soc,high、Soc,max is the demarcation point of the charge state partition; s oc,i is the current state of charge of the ith energy storage power station.
Further, the step of dynamically adjusting the ability of the energy storage power station group to participate in the system frequency modulation AGC by dynamically adjusting the allocation coefficient α specifically includes:
the calculation formulas of ACE values dynamically allocated to the energy storage power station group and ACE values dynamically allocated to all thermal power units are as follows:
Ace,bess＝αAce,α∈[0,1] (3)
Ace,g＝(1-α)Ace (4)
Wherein A ce,g represents ACE values dynamically allocated to all thermal power units; a ce,bess represents ACE values dynamically assigned to the energy storage power plant population; alpha represents ACE dynamic allocation coefficient of the energy storage power station group; 1-alpha represents ACE dynamic allocation coefficients of the thermal power generating unit;
Wherein k ace represents the relative severity of the regional control bias at time t; representing the duty ratio of the energy storage power station group at the moment t on the dynamic adjustable capacity in all frequency modulation equipment;
wherein, beta l represents the influence degree of k ace on the dynamic distribution coefficient of the thermal power unit;
the dynamic allocation coefficient between the energy storage power stations is directly determined based on the respective dynamic frequency modulation capacity;
Ace,i＝ρiAce,bess (8)
∑ρi＝1 (9)
Wherein A ce,i represents the ACE value dynamically allocated to the ith energy storage power station; ρ i represents the ACE dynamic allocation coefficient of the ith energy storage power station; d aa,i (t) represents the dynamic frequency modulation capability of the ith energy storage power station; Representing the duty cycle of the dynamic frequency modulation capability of the ith energy storage power station in the population of energy storage power stations.
According to the invention, the expected dynamic frequency modulation capacity of various frequency modulation power supplies is defined and calculated, so that the dynamic distribution coefficient of ACE between the energy storage power station group and the thermal power unit and the dynamic distribution coefficient of ACE between energy storage power stations in the energy storage power station group are determined, the output of each frequency modulation power supply is distributed, the phenomena of overshoot and overdischarge of the energy storage system are prevented, and the cycle life of the energy storage battery system is effectively prolonged.
Drawings
FIG. 1 is a schematic diagram of SOC interval partitioning;
fig. 2 is an ACE interval division diagram;
FIG. 3 is a graph of frequency fluctuation of the system after disturbance occurs under the condition of adopting a traditional proportional allocation strategy and a dynamic allocation strategy of the invention respectively;
FIG. 4 is a graph showing the output of a unit and two energy storage power stations after a disturbance occurs under the condition of adopting a conventional proportional distribution strategy and a dynamic distribution strategy according to the invention;
FIG. 5 is a plot of the change in SOC of the #1 energy storage power station after a disturbance occurs;
FIG. 6 is a plot of the change in SOC of the #2 energy storage power station after a disturbance occurs.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention, and it is apparent that the described embodiments are some embodiments of the present invention, but not all embodiments of the present invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
The embodiment of the invention provides an AGC coordinated control method for an energy storage power station group power grid in consideration of SOC, which comprises the following steps:
Step one, dividing the states of charge into different levels of states of charge according to the states of charge of an energy storage power station; according to the control deviation ACE condition of the regional interconnecting line, carrying out ACE partitioning and dividing into safety regions with different frequencies; the method comprises the following steps:
The output of the frequency modulation power supply needs to consider both the frequency modulation requirement of the system and the self-state limitation. Because the overcharge and overdischarge of the energy storage battery can seriously affect the service life of the battery, in order to ensure the utilization rate of the energy storage battery, the SOC is a factor which needs to be considered at first, so that the SOC is divided into sections, and the SOC capacity is divided into sections of 0-S oc,min,Soc,min～Soc,low,Soc,low～0.5,0.5～Soc,high,Soc,high～Soc,max, wherein S oc,min represents the minimum value of the state of charge of the energy storage power station, 0.1 is generally taken, S oc,low represents the lower value of the state of charge of the energy storage power station, 0.2 is generally taken, S oc,high represents the higher value of the state of charge of the energy storage power station, 0.8 is generally taken, S oc,max represents the maximum value of the state of charge of the energy storage power station, and 0.9 is generally taken. As shown in fig. 1.
The absolute value of the regional control deviation ACE reflects the severity of the regional frequency deviation and the frequency modulation requirement, and the regional control deviation is divided into sections according to emergency regulation areas-A ce,max and A ce,max, secondary emergency regulation areas-A ce,max～-Ace,mid and A ce,mid～Ace,mid, normal regulation areas-A ce,mid～-Ace,min and A ce,min～Ace,mid and regulation dead areas-A ce,min～Ace,min, wherein A ce,max represents the maximum value of the regional control deviation, A ce,mid represents the intermediate value of the regional control deviation and A ce,min represents the minimum value of the regional control deviation. When ACE is in different states, the active output of each frequency modulation power supply participating in AGC is necessarily influenced, so the ACE is divided into intervals, and the policy allocation of battery energy storage is developed according to the operation requirement of the ACE.
Step two, according to the charge state of the energy storage power station divided in the step one, a charge and discharge control model of the energy storage power station is established, and the frequency modulation output of the energy storage power station is controlled in a segmented mode, wherein the method comprises the following steps:
Considering the influence of the state of charge (SOC) of the energy storage battery, when the SOC is in different intervals, the energy storage frequency modulation output is expected to be limited to a certain extent, so that the SOC of the energy storage battery and the maximum discharge power of the SOC are established Maximum charging powerThe piecewise linear relation between the two is expressed as:
in the method, in the process of the invention, The modified frequency modulation power upper limit of the ith energy storage power station is set; Representing the lower limit of the frequency modulation power after the modification of the ith energy storage power station; p bess,N is the rated charge and discharge power of the energy storage battery; k 1、K2 is a set adjusting parameter; s oc,min、Soc,low、Soc,high、Soc,max is the demarcation point of the state of charge partition as shown in FIG. 1; s oc,i is the current state of charge of the ith energy storage power station.
And thirdly, adjusting dynamic distribution coefficients of dynamic power distribution of the energy storage power station group according to the partitioning condition of the connecting lines divided in the first step, and smoothly adjusting the energy storage power distribution in the energy storage power station group.
The larger the area control deviation, the larger the output requirement of the A ce frequency modulation power supply is. On the basis of considering the limitation of the capacity of the energy storage power station, when the frequency modulation requirement of the power system is large, the rapid response advantage of the energy storage power station is hoped to be exerted in best effort. The dynamic frequency modulation capability of the frequency modulation power supply shows the current supporting capability of each frequency modulation power supply to frequency. The invention dynamically adjusts the capacity of the energy storage power station group participating in the system frequency modulation AGC through the adjustment of the dynamic distribution coefficient alpha. Moreover, the relative severity of the regional control deviation and the influence degree of the two indexes of the dynamic frequency modulation capability of the frequency modulation power supply on the allocation coefficient are different in different ACE states, and proper adjustment is needed according to actual conditions. The calculation formula is as follows:
Ace,bess＝αAce,α∈[0,1] (3)
Ace,g＝(1-α)Ace (4)
Wherein A ce,g represents ACE values dynamically allocated to all thermal power units; a ce,bess represents ACE values dynamically assigned to the energy storage power plant population; alpha represents ACE dynamic allocation coefficient of the energy storage power station group; 1-alpha represents ACE dynamic allocation coefficients of the thermal power generating unit;
Wherein k ace represents the relative severity of the regional control bias at time t; representing the duty ratio of the energy storage power station group at the moment t on the dynamic adjustable capacity in all frequency modulation equipment;
wherein, beta l represents the influence degree of k ace on the dynamic distribution coefficient of the thermal power unit;
the dynamic allocation coefficient between the energy storage power stations is directly determined based on the respective dynamic frequency modulation capacity;
Ace,i＝ρiAce,bess (8)
∑ρi＝1 (9)
Wherein A ce,i represents the ACE value dynamically allocated to the ith energy storage power station; ρ i represents the ACE dynamic allocation coefficient of the ith energy storage power station; d aa,i (t) represents the dynamic frequency modulation capability of the ith energy storage power station; Representing the duty cycle of the dynamic frequency modulation capability of the ith energy storage power station in the population of energy storage power stations.
The conventional control strategy is that the distribution coefficient is fixed, and the utilization rate of the energy storage power station is reduced due to the fact that the coefficient of the energy storage power station is too small; excessive distribution coefficients, due to lack of consideration based on the limitation of the energy storage SOC, can lead to shortened duration of operation of the energy storage battery, and even secondary dropping of the power grid frequency due to sudden loss of frequency modulation capability when the SOC is out of limit. Therefore, the invention has better frequency modulation effect under the dynamic allocation strategy, and the energy storage power station participates in frequency modulation to make the contribution electric quantity larger while maintaining the energy storage SOC, thereby improving the utilization rate of the energy storage battery.
And (3) carrying out calculation analysis:
And simulating a single-area AGC response process containing two energy storage power stations. The traditional frequency modulation unit is a thermal power unit, the rated power is 100MW, the climbing rate is 6MW/min (6%), the rated power and capacity of the two energy storage power stations are 12.5MW/2.5MW & h, and the AGC command scheduling period is 1min. After each parameter is subjected to per unit conversion by taking the maximum rated power 100MW and the rated frequency 50Hz of the system unit as reference values, the simulation parameters of the system are shown in the following table 1, and the relevant parameters of the control strategy are shown in the following table 2.
Table 1 system simulation parameters
| Parameters (parameters) | Numerical value | Parameters (parameters) | Numerical value |
| M | 10 | B | 30 |
| D | 1 | 1/R | 20 |
| Kp、Kin | 0.822、0.16 | Tbess,1 | 0.01 |
| Tg | 0.08 | Tq | 0.3 |
Table 2 control strategy related parameters
| Parameters (parameters) | Numerical value | Parameters (parameters) | Numerical value |
| Ace,max | 0.3 | Soc,ini | 0.8/0.25 |
| Soc,min | 0.1 | Soc,low | 0.3 |
| Soc,high | 0.7 | Soc,max | 0.9 |
| K1 | 0.5 | K2 | 2.25 |
Step load disturbance with the amplitude of 0.05p.u. is added into the regional power grid respectively, the simulation result is as follows, and FIG. 3 is a frequency fluctuation curve of the system under the condition that a proportional allocation strategy and a dynamic allocation strategy are adopted respectively after disturbance occurs; FIG. 4 is a graph of the output of a unit and two energy storage power stations after a disturbance occurs under the condition of respectively adopting a proportional distribution strategy and a dynamic distribution strategy; fig. 5 and 6 are graphs showing the change in SOC of two energy storage power stations after a disturbance occurs. According to the simulation curve, the dynamic distribution of the regulating coefficient between the dynamic energy storage power station group and the thermal power unit can be faster than the traditional solid distribution, and the response performance of the system is faster and the overshoot of the step response is smaller.
The foregoing is merely illustrative embodiments of the present invention, and the present invention is not limited thereto, and any changes or substitutions that may be easily contemplated by those skilled in the art within the scope of the present invention should be included in the scope of the present invention. Therefore, the protection scope of the present invention should be subject to the protection scope of the claims.
Claims (2)
1. An energy storage power station group power grid AGC coordinated control method considering SOC is characterized in that: the method comprises the following steps:
Dividing the state of charge (SOC) according to the state of charge (SOC) of the energy storage power station, and dividing the SOC into grades of different SOC; according to the control deviation ACE condition of the regional interconnecting line, carrying out ACE partitioning and dividing into safety regions with different frequencies;
step two, according to the SOC of the energy storage power station divided in the step one, a charge-discharge control model of the energy storage power station is established, and the frequency modulation output of the energy storage power station is controlled in a segmented mode;
Step three, according to the partitioning condition of the connecting lines divided in the step one, adjusting the dynamic distribution coefficient of the dynamic power distribution of the energy storage power station group, and smoothly adjusting the energy storage power distribution in the energy storage power station group;
In the first step, according to the state of charge condition of the energy storage power station, the state of charge is divided into different levels of states of charge, and the method specifically comprises the following steps:
for the capacity of the SOC, dividing according to a section of 0-S oc,min,Soc,min～Soc,low,Soc,low～0.5,0.5～Soc,high,Soc,high～Soc,max, wherein S oc,min represents the minimum value of the state of charge of the energy storage power station, S oc,low represents the lower value of the state of charge of the energy storage power station, generally 0.2, S oc,high represents the higher value of the state of charge of the energy storage power station, 0.8, S oc,max represents the maximum value of the state of charge of the energy storage power station, and 0.9;
The second step specifically comprises:
when the SOC is in different intervals, the SOC of the energy storage battery and the maximum discharge power thereof are established Maximum charging powerThe piecewise linear relation between the two is expressed as:
in the method, in the process of the invention, The modified frequency modulation power upper limit of the ith energy storage power station is set; Representing the lower limit of the frequency modulation power after the modification of the ith energy storage power station; p bess,N is the rated charge and discharge power of the energy storage battery; k 1、K2 is a set adjusting parameter; s oc,min、Soc,low、Soc,high、Soc,max is the demarcation point of the charge state partition; s oc,i is the current state of charge of the ith energy storage power station;
The step three is to dynamically adjust the capacity of the energy storage power station group participating in the system frequency modulation AGC by dynamically adjusting the distribution coefficient alpha, and specifically comprises the following steps:
the calculation formulas of ACE values dynamically allocated to the energy storage power station group and ACE values dynamically allocated to all thermal power units are as follows:
Ace,bess＝αAce,α∈[0,1] (3)
Ace,g＝(1-α)Ace (4)
Wherein A ce,g represents ACE values dynamically allocated to all thermal power units; a ce,bess represents ACE values dynamically assigned to the energy storage power plant population; alpha represents ACE dynamic allocation coefficient of the energy storage power station group; 1-alpha represents ACE dynamic allocation coefficients of the thermal power generating unit;
Wherein k ace represents the relative severity of the regional control bias at time t; representing the duty ratio of the energy storage power station group at the moment t on the dynamic adjustable capacity in all frequency modulation equipment;
wherein, beta l represents the influence degree of k ace on the dynamic distribution coefficient of the thermal power unit;
the dynamic allocation coefficient between the energy storage power stations is directly determined based on the respective dynamic frequency modulation capacity;
Ace,i＝ρiAce,bess (8)
∑ρi＝1 (9)
Wherein A ce,i represents the ACE value dynamically allocated to the ith energy storage power station; ρ i represents the ACE dynamic allocation coefficient of the ith energy storage power station; d aa,i (t) represents the dynamic frequency modulation capability of the ith energy storage power station; Representing the duty cycle of the dynamic frequency modulation capability of the ith energy storage power station in the population of energy storage power stations.
2. The SOC-considered power storage station cluster grid AGC coordinated control method of claim 1, wherein: in the first step, according to the control deviation ACE condition of the regional interconnecting line, the ACE is partitioned into safety regions with different frequencies, and the method specifically comprises the following steps:
The regulation dead zone-a ce,min～Ace,min divides the ACE into zones according to emergency regulation zones-a ce,max and a ce,max, secondary emergency regulation zones-a ce,max～-Ace,mid and a ce,mid～Ace,mid, normal regulation zones-a ce,mid～-Ace,min and a ce,min～Ace,mid, wherein a ce,max represents a maximum value of the zone control deviation, a ce,mid represents an intermediate value of the zone control deviation, and a ce,min represents a minimum value of the zone control deviation.
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| CN107069789A (en) * | 2017-05-13 | 2017-08-18 | 东北电力大学 | A kind of energy-storage system control strategy towards power network AGC frequency modulation |
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