Energy storage capacity configuration method for providing short-time active support for energy storage auxiliary new energy

Abstract

The invention relates to an energy storage capacity configuration method for assisting new energy in providing short-time active support through energy storage. The method comprises the following steps that S100, a short-time active support capacity model of a new energy station containing power type energy storage is established; s200, constructing a power system coordinated scheduling model which considers power type energy storage auxiliary new energy and provides short-time frequency support and voltage support at the same time; s300, constructing a power system active support demand model considering power type energy storage and new energy short-time active support capability; and step S400, constructing an energy storage capacity analytic expression facing the active support demand, establishing a mapping relationship between the short-time active support demand of the system and the energy storage capacity, and further completing energy storage capacity configuration capable of assisting new energy to provide short-time active support. According to the invention, short-time frequency support and short-time voltage support can be provided at the same time by using the new energy field station containing energy storage.

Description

Technical Field

[0001] This invention belongs to the field of energy storage capacity configuration technology, and relates to an energy storage capacity configuration method, particularly an energy storage capacity configuration method that provides short-term active support for new energy sources through energy storage. Background Technology

[0002] As the proportion of renewable energy sources continues to increase, new power systems face issues such as frequency stability and voltage stability. The high flexibility of energy storage allows it to provide short-term active support to renewable energy sources, offering a solution to these problems. Rational allocation of energy storage capacity can maximize its comprehensive benefits; therefore, it is necessary to study methods for configuring energy storage capacity to support renewable energy sources.

[0003] There are already many research results on energy storage capacity configuration methods both domestically and internationally. For example, Reference 1, "Optimal Configuration of Battery Energy Storage System for Tracking Planned Output of Wind Farms" (Yang Shuili, Li Jianlin, Hui Dong, Li Xiangjun, Hu Juan, Niu Hu. Power System Technology, 2014, 38(06): 1485-1491.), analyzes the characteristic relationship between energy storage power and power prediction error based on the distribution characteristics of wind farm prediction error, and uses the cutoff normal distribution method to configure energy storage capacity. Reference 2, "Energy Storage Site Selection and Capacity Planning Method Considering Dynamic Frequency Support" (Zhang Zhi, Zhou Ming, Wu Zhaoyuan, Liu Jianqin, Liu Siwei, Guo Zun. Proceedings of the CSEE, 2023, 43(07): 2708-2721.), plans energy storage with the goal of providing dynamic frequency support. It adopts the method of solving the optimization planning model, guides energy storage site selection by evaluating the system inertia distribution, and plans energy storage capacity with the goal of minimizing investment and system operating costs. Reference 3, "System-level Energy Storage Capacity Demand Analysis for Peak Shaving and Frequency Regulation in High-Peak New Energy Systems" (Wang Sen, Li Fengting, Zhang Gaohang, Yin Chunya, Li Yuan. Electric Power Automation Equipment, 2024, 44(01):24-31.), proposes a system-level energy storage capacity determination method for peak shaving and frequency regulation in high-penetration new energy systems from a system perspective. Based on quantile regression analysis and Gaussian mixture model clustering, a scenario set is generated. The optimal power of energy storage participating in peak shaving and frequency regulation during operation is obtained by using a conventional thermal power unit and energy storage joint optimization operation model without energy storage capacity constraints. The deviation of energy storage power and the growth rate of operating costs are used as indicators to correct the energy storage power and capacity demand.

[0004] However, current research on energy storage capacity configuration methods mostly focuses on a single active support function and usually adopts the method of solving optimization planning models, which fails to make full use of the flexibility of energy storage converters and lacks characterization of the mapping relationship between system active support requirements and energy storage capacity.

[0005] A search revealed no publicly available literature of the same or similar prior art as this invention. Summary of the Invention

[0006] The purpose of this invention is to overcome the shortcomings of the prior art and provide a method for configuring energy storage capacity to assist new energy sources in providing short-term active support. This method can replace the optimization planning model and form an analytical expression for power-type energy storage capacity for new energy power plants with the system's active support demand as the variable. It establishes a direct link between the system's active support demand and the energy storage capacity, providing a new method for configuring energy storage capacity for new energy power plants.

[0007] The present invention solves its practical problem by adopting the following technical solution:

[0008] A method for configuring energy storage capacity to assist new energy sources in providing short-term active support includes the following steps:

[0009] Step S100: Establish a short-term active support capability model for new energy power stations containing power storage.

[0010] Step S200: Based on the short-term active support capability model constructed in step S100, construct a power system coordinated dispatch model that considers power-type energy storage assisting new energy sources while providing short-term frequency support and voltage support.

[0011] Step S300: Based on the power system coordinated dispatch model constructed in step S200, and combined with system operation requirements, construct a power system active support demand model that considers the short-term active support capabilities of power-type energy storage and new energy sources.

[0012] Step S400: Construct an analytical expression for energy storage capacity oriented towards active support demand. Using the power system active support demand model considering the short-term active support capabilities of energy storage and new energy sources constructed in step S300 as an intermediate variable, establish a mapping relationship between the system's short-term active support demand and energy storage capacity, thereby completing the configuration of energy storage capacity that can assist new energy sources in providing short-term active support.

[0013] Moreover, the short-time active support capability model of the new energy power station with power storage established in step S100 includes: short-time frequency support capability model and short-time voltage support capability model.

[0014] Furthermore, the short-time frequency support capability model includes the inertia model H of the new energy power station. station and primary frequency regulation backup model R station ;

[0015] Inertia Model H of New Energy Power Station station Including the inertia H of internal new energy sources RES and the inertia H of energy storage ESS ;

[0016] The inertia model H of the new energy power station station for:

[0017]

[0018] Among them, H r For the inertia of new energy r, H s Let be the inertia of the stored energy s;

[0019] The inertia level of new energy r is proportional to its actual output. Its inertia model H r as follows:

[0020] H r =h r (1-d r %P r f .

[0021] Among them, h r Let d be the equivalent inertia constant of the new energy source r. r % represents the load reduction rate of new energy vehicle r. This represents the predicted output value of the new energy source r.

[0022] The inertia level of energy storage s is related to its own capacity and is constrained by the day-ahead call of the current state of charge. Its inertia model H s as follows:

[0023] H s =k s SOC s ,

[0024]

[0025] Where, k s The short-term maximum charge / discharge rate of energy storage s; SOC s Let be the charge of the energy storage s; P represents the maximum continuous output power of the energy storage s; s The day-ahead planned output of energy storage s; f0 is the system rated frequency; RoCoF max This represents the maximum allowable rate of frequency change for the system.

[0026] The primary frequency regulation reserve model for renewable energy power plants includes: the primary frequency regulation reserve R of internal renewable energy sources. RES And primary frequency regulation backup R of energy storage ESS ;

[0027] Primary frequency regulation backup model R of new energy power stations station as follows:

[0028]

[0029] Among them, R r R is a backup for primary frequency regulation of new energy source r. s It serves as a backup for primary frequency regulation of energy storage s.

[0030] The primary frequency regulation reserve of new energy r is affected by its own load reduction rate d r % constraint, its primary frequency regulation reserve model R r as follows:

[0031]

[0032] The primary frequency regulation reserve of energy storage s is constrained by the maximum continuous output power and the energy storage capacity. Its primary frequency regulation reserve model R s as follows:

[0033]

[0034] R s Δt PFR ≤η d (SOC s -SOC min E s

[0035] Where, Δt PFR η is the duration of a single frequency modulation process. d For energy storage discharge efficiency; SOC min The minimum charge allowed for energy storage operation; E s s is the rated capacity of energy storage.

[0036] To maximize the utilization of new energy sources, the reactive power reserve of new energy power plants is provided by energy storage, and its reactive power reserve model ΔQ station as follows:

[0037]

[0038] Where, ΔQ ESS For reactive power reserve in energy storage systems; ΔQ s This serves as a reactive power backup for the energy storage device s.

[0039] The active and reactive power control loops of the energy storage converter are decoupled, and the active and reactive power outputs are only related through the converter capacity.

[0040] The reactive power reserve model ΔQ of energy storage s as follows:

[0041]

[0042] Among them, P sThe active power output of energy storage s; The grid-connected converter capacity is for energy storage s.

[0043] Furthermore, the specific steps of step S200 include:

[0044] The constructed power system coordinated dispatch model, which considers power-type energy storage to assist new energy sources while providing short-term frequency and voltage support, includes: the basic optimized operation model of the power system and its constraints, frequency stability constraints, voltage stability constraints, and active and reactive power coupling constraints.

[0045] Furthermore, the objective function of the basic optimization operation model of the power system is to minimize the system operating cost:

[0046] min.VC+RC+PC.

[0047] Where VC is the unit output cost, its expression is: RC represents the unit's standby cost, and its expression is: PC represents the cost of wind curtailment penalty for wind turbines, and its expression is: In the formula, Ω G For the collection of generator units; Ω RES For new energy sources; P g,t cs represents the output of unit g at time t. g R represents the power generation cost coefficient of unit g; g,t This indicates that unit g is on standby at time t, and cr g This represents the standby cost coefficient for unit g; d represents the predicted power output of wind farm r at time t. r,t % represents the wind curtailment rate of wind farm r at time t, cw r This represents the wind curtailment cost coefficient for wind farm r.

[0048] Moreover, the constraints of the power system basic optimization operation model include: conventional unit constraints, grid constraints, new energy constraints, and energy storage constraints;

[0049] The constraints of the conventional generating units include:

[0050] Unit active power output constraints:

[0051] Unit reactive power output constraints:

[0052] Unit primary frequency regulation standby constraints:

[0053] in, and Q represents the lower and upper boundaries of the output of unit g, respectively; g,tThis represents the reactive power output of unit g at time t; and These represent the lower and upper boundaries of the reactive power of unit g, respectively. This represents the maximum reserve capacity of unit g.

[0054] The space frame constraint adopts a second-order conical power flow, including:

[0055] Node voltage constraint: (V i min ) 2 ≤W ii ≤(V i max ) 2 ,i∈Ω N ;

[0056] Power balance constraints:

[0057]

[0058] Second-order cone constraint:

[0059] Among them, V i V represents the voltage vector at node i; i min and V i max Ω represents the lower and upper boundaries of the voltage amplitude at node i, respectively. N A set of nodes; and All are directed branch sets. (i,j) represents a directed branch with endpoints i and j and a positive direction of i→j; W ij For the introduced auxiliary variables, P ij and Q ij G represents the active and reactive power flowing from node i into branch (i,j); ij and B ij Let represent the conductance and susceptance of branch (i,j), respectively; and P represents the functions that take the real and imaginary parts of a complex variable, respectively; i g and P represents the active power and reactive power injected at node i, respectively; i d and These represent the active load and reactive load of node i, respectively.

[0060] The constraints on new energy sources include:

[0061] Constraints on new energy output: d w %≤d% max ;

[0062] New energy inertia constraint: H r =h r (1-d r %P r f ;

[0063] Primary frequency regulation reserve constraints for new energy sources:

[0064] Among them, d% max Limits on wind turbine load reduction rate.

[0065] The energy storage constraints include:

[0066] Energy storage charge and discharge constraints:

[0067] Energy storage charge constraints:

[0068] Energy storage inertia constraint: H s =k s SOC s ;

[0069] Energy storage primary frequency regulation reserve constraints: R s Δt PFR £η d (SOC s -SOC min E s .

[0070] Among them, P s,t This represents the power output of the energy storage s at time t, with positive numbers indicating discharge and negative numbers indicating charging; and Let q represent the discharge power and charging power of energy storage s at time t, respectively. These two powers cannot coexist; that is, energy storage cannot both charge and discharge simultaneously. s,t This represents the charging and discharging flag of the energy storage s at time t, and is a 0-1 variable, with 1 for charging and 0 for discharging; P s chmax and P s dismax These represent the maximum charging power and maximum discharging power in steady state, respectively; SOC s,t η represents the state of charge of the energy storage s at time t; c and η d These are the charging efficiency and discharging efficiency of energy storage, respectively. and These represent the lower and upper boundaries of the charge capacity of energy storage s, respectively; SOC s,T and These represent the state of charge of energy storage s at the end of a scheduling cycle T and the initial state of charge of energy storage, respectively.

[0071] The frequency stability constraints include:

[0072] Frequency change rate constraint:

[0073] Minimum frequency constraint: R sync +R RES +R ESS ≥ΔP disturb ;

[0074] Wherein, ΔP disturb For active power disturbances occurring in the system, a certain proportion of the net load P can usually be taken. NL That is, ΔP disturb =k P %P NL H sys H represents the overall inertia level of the system. sys =H sync +H RES +H ESS H syn H RES and H ESS These represent the total inertia levels of synchronous generators, new energy sources, and energy storage, respectively; RoCoF max To limit the rate of change of the system's frequency; R sync R RES and R ESS These are the sum of primary frequency regulation reserves for synchronous generators, new energy sources, and energy storage, respectively; R g For primary frequency regulation standby of unit g; v g Ω represents the maximum power change rate of unit g; G For a collection of synchronous generator units; f db This represents the system's primary frequency regulation dead zone; since the response and operating speed of power electronic devices are much higher than those of synchronous machines, the ramp-up limitations of new energy sources and energy storage are ignored. ΔP′ disturb The frequency modulation task that the synchronous machine needs to undertake, and the power disturbance ΔP disturb Excluding the R undertaken by new energy power stations RES and R ESS The remaining portion.

[0075] The voltage stability constraints include:

[0076] Bus voltage fluctuation constraints:

[0077] Reactive power reserve constraint:

[0078] Where, ΔQ i Take a certain proportion of reactive load Q NL That is, ΔQ i =k Q %Q NL ; The voltage sensitivity coefficient is obtained by inverting the Jacobian matrix.

[0079] The active and reactive power coupling constraints include:

[0080] Capacity constraints when only voltage support is provided:

[0081] It also provides capacity constraints for primary frequency regulation backup and voltage support:

[0082] Simultaneously providing capacity constraints for both inertia and voltage support:

[0083] Furthermore, the power system active support demand model constructed in step S300, which considers the short-term active support capabilities of power-type energy storage and new energy sources, includes: the system's frequency change rate deficit model Δx. RoCoF The minimum frequency demand deficit model Δx of the system nadir and the system's voltage regulation demand deficit Δx U .

[0084] Furthermore, the frequency change rate deficit model Δx of the system RoCoF The expression is:

[0085] This represents the maximum active power disturbance the system should withstand within a scheduling cycle, and is a certain percentage of the net load. This value corresponds to the time of maximum net load during a typical day.

[0086] The minimum frequency demand deficit model Δx of the system nadir The expression is:

[0087]

[0088] Δf ext The lowest allowed frequency f of the system min The deviation from the system's rated frequency, Δf ext =f0-f db -f min ;

[0089] The system's voltage regulation demand shortfall Δx U The expression is:

[0090]

[0091] ΔQ is the maximum reactive disturbance that the system should withstand within a scheduling cycle, which is a certain proportion of the reactive load and corresponds to the moment when the system's reactive load is at its maximum. The maximum value of the sensitivity coefficient of the bus voltage to the reactive power of the node is calculated, assuming that ΔQ occurs at the node that has the greatest impact on the bus of the new energy power station.

[0092] Step S400: Construct an analytical formula for energy storage capacity oriented towards active support demand. Using the power system active support demand model considering the short-term active support capabilities of energy storage and new energy sources constructed in step S300 as an intermediate variable, establish the mapping relationship between the system's short-term active support demand and energy storage capacity, and then complete the configuration of energy storage capacity that can assist new energy sources in providing short-term active support.

[0093] The analytical formula for energy storage capacity oriented towards active support needs in step S400 includes: analytical formula for energy storage inertia level, analytical formula for energy storage primary frequency regulation allocation, and analytical formula for energy storage reactive power reserve.

[0094] The analytical expression for the energy storage inertia level is:

[0095]

[0096] The analytical expression for the primary frequency regulation backup energy storage is:

[0097] When Δx RoCoF ≠0 o'clock:

[0098]

[0099] When Δx RoCoF =0:

[0100]

[0101] The reactive power reserve of the energy storage is expressed as follows:

[0102] ΔQ ESS =K U Δx U .

[0103] Advantages and beneficial effects of the present invention:

[0104] 1. This invention proposes an energy storage capacity configuration method that enables energy storage to provide short-term active support for new energy sources. This method can simultaneously provide short-term frequency support and short-term voltage support using new energy power plants with energy storage. It overcomes the shortcomings of current energy storage capacity configuration methods that mostly focus on a single active support function, and makes fuller use of the capacity of the energy storage grid-connected converter.

[0105] 2. This invention provides an easy-to-solve analytical method for configuring energy storage capacity to meet active support needs. It establishes a mapping relationship between the system's short-term active support needs and energy storage capacity, thus overcoming the limitations of the current method of using optimization planning models for energy storage capacity configuration. Attached Figure Description

[0106] Figure 1 A schematic diagram of the overall process of the capacity configuration method for providing short-term active support for energy storage to assist new energy sources in the embodiments of the present invention;

[0107] Figure 2 This is a basic structural diagram of a new energy power station with power storage in an embodiment of the present invention;

[0108] Figure 3 This is a flowchart illustrating the coordinated dispatching process of a power system that considers energy storage assisting new energy sources while simultaneously providing short-term frequency and voltage support, as described in this embodiment of the invention.

[0109] Figure 4 This is a parameter correspondence diagram of the analytical expression of energy storage capacity for active support requirements in an embodiment of the present invention.

[0110] Figure 5 This is a schematic diagram of the capacity configuration analysis method for providing short-term active support for new energy sources using energy storage in an embodiment of the present invention. Detailed Implementation

[0111] The embodiments of the present invention will be further described in detail below with reference to the accompanying drawings:

[0112] A method for configuring energy storage capacity to provide short-term active support for renewable energy sources, such as... Figure 1 As shown, it includes the following steps:

[0113] Step S100: Establish a short-term active support capability model for new energy power stations containing power storage.

[0114] The short-time active support capability model of the new energy power station with power storage established in step S100 includes: short-time frequency support capability model and short-time voltage support capability model.

[0115] The short-time frequency support capability model includes the inertia model H of the new energy power station. station and primary frequency regulation backup model R station ;

[0116] Inertia Model H of New Energy Power Station station Including the inertia H of internal new energy sources RES and the inertia H of energy storage ESS ;

[0117] The inertia model H of the new energy power station station for:

[0118]

[0119] Among them, H r For the inertia of new energy r, H s Let be the inertia of the stored energy s;

[0120] The inertia level of new energy r is proportional to its actual output. Its inertia model H r as follows:

[0121] H r =h r (1-d r %P r f .

[0122] Among them, h r Let d be the equivalent inertia constant of the new energy source r. r % represents the load reduction rate of new energy vehicle r. This represents the predicted output value of the new energy source r.

[0123] The inertia level of energy storage s is related to its own capacity and is constrained by the day-ahead call of the current state of charge. Its inertia model H s as follows:

[0124] H s =k s SOC s ,

[0125]

[0126] Where, k s The short-term maximum charge / discharge rate of energy storage s; SOC s Let be the charge of the energy storage s; P represents the maximum continuous output power of the energy storage s; s The day-ahead planned output of energy storage s; f0 is the system rated frequency; RoCoF max This represents the maximum allowable rate of frequency change for the system.

[0127] The primary frequency regulation reserve of the aforementioned new energy power station includes: the primary frequency regulation reserve R of the internal new energy source. RES And primary frequency regulation backup R of energy storage ESS ;

[0128] Primary frequency regulation reserve model R of new energy power stations station as follows:

[0129]

[0130] Among them, R r R is a backup for primary frequency regulation of new energy source r. s It serves as a backup for primary frequency regulation of energy storage S.

[0131] The primary frequency regulation reserve of new energy r is affected by its own load reduction rate d r % constraint, its primary frequency regulation reserve model R r as follows:

[0132]

[0133] The primary frequency regulation reserve of energy storage s is constrained by the maximum continuous output power and the energy storage capacity. Its primary frequency regulation reserve model R s as follows:

[0134]

[0135] R s Δt PFR ≤η d (SOC s -SOC min E s

[0136] Where, Δt PFR η is the duration of a single frequency modulation process. d For energy storage discharge efficiency; SOC min The minimum charge allowed for energy storage operation; E s s is the rated capacity of energy storage.

[0137] To maximize the utilization of new energy sources, the reactive power reserve of new energy power plants is provided by energy storage, and its reactive power reserve model ΔQ station as follows:

[0138]

[0139] Where, ΔQ ESS For reactive power reserve of energy storage systems; ΔQ s This serves as a reactive power backup for the energy storage device s.

[0140] The active and reactive power control loops of the energy storage converter are decoupled, and the active and reactive power outputs are only related through the converter capacity.

[0141] The reactive power reserve model ΔQ of energy storage s as follows:

[0142]

[0143] Among them, P s The active power output of energy storage s; The grid-connected converter capacity is for energy storage s.

[0144] The working principle of step S100 is as follows:

[0145] In this embodiment, the basic structure of a new energy power station with power storage is as follows: Figure 2 As shown in the diagram. Each new energy source and energy storage unit is equipped with a converter, which can be controlled independently, and the power station uses an AC bus for aggregation.

[0146] In this embodiment, the short-time active support capability model of the new energy power station with power storage described in S100 includes a short-time frequency support capability model and a short-time voltage support capability model. The short-time frequency support capability model includes an inertia model H. station and primary frequency regulation backup model R station .

[0147] In this embodiment, the inertia of the renewable energy power station includes the inertia H of the internal renewable energy sources. RES and the inertia H of energy storage ESS Inertia model H station for:

[0148]

[0149] Among them, H r For the inertia of new energy r, H s Let s be the inertia of the stored energy.

[0150] In this embodiment, the inertia level of the new energy source r is proportional to its actual output. Its inertia model H r as follows:

[0151] H r =h r (1-d r %P r f .

[0152] Among them, h r Let d be the equivalent inertia constant of the new energy source r. r % represents the load reduction rate of new energy vehicle r. This represents the predicted output value of the new energy source r.

[0153] In this embodiment, the inertia level of energy storage s is related to its own capacity and is constrained by the current state of charge day-ahead call. Its inertia model H s as follows:

[0154] H s =k s SOC s ,

[0155]

[0156] Where, k s The short-term maximum charge / discharge rate of energy storage s; SOC s Let be the charge of the energy storage s; P represents the maximum continuous output power of the energy storage s; s The day-ahead planned output of energy storage s; f0 is the system rated frequency; RoCoF max This represents the maximum allowable rate of frequency change for the system.

[0157] In this embodiment, the primary frequency regulation reserve of the new energy power station includes the primary frequency regulation reserve R of the internal new energy source. RES And primary frequency regulation backup R of energy storage ESS The primary frequency regulation reserve model R of renewable energy power plants station as follows:

[0158]

[0159] Among them, R r R is a backup for primary frequency regulation of new energy source r. s It serves as a backup for primary frequency regulation of energy storage S.

[0160] In this embodiment, the primary frequency regulation reserve of the new energy source r is affected by its own load shedding rate d. r % constraint, its primary frequency regulation reserve model R r as follows:

[0161]

[0162] In this embodiment, the primary frequency regulation reserve of energy storage s is constrained by the maximum continuous output power and the energy storage capacity, and its primary frequency regulation reserve model R s as follows:

[0163]

[0164] R s Δt PFR £η d (SOC s -SOC min E s .

[0165] Where, Δt PFR η is the duration of a single frequency modulation process. d For energy storage discharge efficiency; SOC min The minimum charge allowed for energy storage operation; E s s is the rated capacity of energy storage.

[0166] In this embodiment, the short-time reactive power support capability of the new energy power station is expressed as the station's reactive power reserve ΔQ. station Characterization. Providing reactive power reserve requires the use of grid-connected converter capacity. To reduce converter investment costs, it is assumed that renewable energy power plants only output active power during steady-state operation. To maximize the utilization of renewable energy, the reactive power reserve of renewable energy power plants is provided by energy storage, and its reactive power reserve model ΔQ station as follows:

[0167]

[0168] Where, ΔQ ESS For reactive power reserve of energy storage systems; ΔQ s This serves as a reactive power backup for the energy storage device s.

[0169] In this embodiment, the active and reactive power control loops of the energy storage converter are decoupled, and the active and reactive power outputs are only related through the converter capacity. The reactive power reserve model ΔQ of the energy storage is... s as follows:

[0170]

[0171] Among them, P s The active power output of energy storage s; The grid-connected converter capacity is for energy storage s.

[0172] Step S200: Based on the short-term active support capability model constructed in step S100, construct a power system coordinated dispatch model that considers power-type energy storage assisting new energy sources while providing short-term frequency support and voltage support.

[0173] The specific steps of step S200 include:

[0174] The constructed power system coordinated dispatch model, which considers power-type energy storage to assist new energy sources while providing short-term frequency and voltage support, includes: the basic optimized operation model of the power system and its constraints, frequency stability constraints, voltage stability constraints, and active and reactive power coupling constraints.

[0175] The objective function of the basic optimized operation model of the power system is to minimize the system operating cost.

[0176] min.VC+RC+PC.

[0177] Where VC is the unit output cost, its expression is: RC represents the unit's standby cost, and its expression is: PC represents the cost of wind curtailment penalty for wind turbines, and its expression is: In the formula, Ω G For the collection of generator units; Ω RES For new energy sources; Pg,t cs represents the output of unit g at time t. g R represents the power generation cost coefficient of unit g; g,t This indicates that unit g is on standby at time t, and cr g This represents the standby cost coefficient for unit g; d represents the predicted power output of wind farm r at time t. r,t % represents the wind curtailment rate of wind farm r at time t, cw r This represents the wind curtailment cost coefficient for wind farm r.

[0178] The constraints for constructing the basic optimized operation model of the power system include: conventional unit constraints, grid constraints, new energy constraints, and energy storage constraints;

[0179] The constraints of the conventional generating units include:

[0180] Unit active power output constraints:

[0181] Unit reactive power output constraints:

[0182] Unit primary frequency regulation standby constraints:

[0183] in, and Q represents the lower and upper boundaries of the output of unit g, respectively; g,t This represents the reactive power output of unit g at time t; and These represent the lower and upper boundaries of the reactive power of unit g, respectively. This represents the maximum reserve capacity of unit g.

[0184] The space frame constraint adopts a second-order conical power flow, including:

[0185] Node voltage constraint: (V i min ) 2 ≤W ii ≤(V i max ) 2 ,i∈Ω N ;

[0186] Power balance constraints:

[0187]

[0188] Second-order cone constraint:

[0189] Among them, V i V represents the voltage vector at node i;i min and V i max Ω represents the lower and upper boundaries of the voltage amplitude at node i, respectively. N A set of nodes; and All are directed branch sets. (i,j) represents a directed branch with endpoints i and j and a positive direction of i→j; W ij For the introduced auxiliary variables, P ij and Q ij G represents the active and reactive power flowing from node i into branch (i,j); ij and B ij Let represent the conductance and susceptance of branch (i,j), respectively; and P represents the functions that take the real and imaginary parts of a complex variable, respectively; i g and P represents the active power and reactive power injected at node i, respectively; i d and These represent the active load and reactive load of node i, respectively.

[0190] The constraints on new energy sources include:

[0191] Constraints on new energy output:

[0192] New energy inertia constraint: H r =h r (1-d r %P r f ;

[0193] Primary frequency regulation reserve constraints for new energy sources:

[0194] Among them, d% max Limits on wind turbine load reduction rate.

[0195] The energy storage constraints include:

[0196] Energy storage charge and discharge constraints:

[0197] Energy storage charge constraints:

[0198] Energy storage inertia constraint: H s =k s SOC s ;

[0199] Energy storage primary frequency regulation reserve constraints: R s Δt PFR £η d (SOC s -SOC min E s .

[0200] Among them, P s,t This represents the power output of the energy storage s at time t, with positive numbers indicating discharge and negative numbers indicating charging; and Let q represent the discharge power and charging power of energy storage s at time t, respectively. These two powers cannot coexist; that is, energy storage cannot both charge and discharge simultaneously. s,t This represents the charging and discharging flag of the energy storage s at time t, and is a 0-1 variable, with 1 for charging and 0 for discharging; P s chmax and P s dismax These represent the maximum charging power and maximum discharging power in steady state, respectively; SOC s,t η represents the state of charge of the energy storage s at time t; c and η d These are the charging efficiency and discharging efficiency of energy storage, respectively. and These represent the lower and upper boundaries of the charge capacity of energy storage s, respectively; SOC s,T and These represent the state of charge of energy storage s at the end of a scheduling cycle T and the initial state of charge of energy storage, respectively.

[0201] The frequency stability constraints include:

[0202] Frequency change rate constraint:

[0203] Minimum frequency constraint: R sync +R RES +R ESS ≥ΔP disturb ;

[0204] Wherein, ΔP disturb For active power disturbances occurring in the system, a certain proportion of the net load P can usually be taken. NL That is, ΔP disturb =k P %P NL H sys H represents the overall inertia level of the system. sys =H sync +H RES +H ESS H synH RES and H ESS These represent the total inertia levels of synchronous generators, new energy sources, and energy storage, respectively; RoCoF max To limit the rate of change of the system's frequency; R sync R RES and R ESS These are the sum of primary frequency regulation reserves for synchronous generators, new energy sources, and energy storage, respectively; R g For primary frequency regulation standby of unit g; v g Ω represents the maximum power change rate of unit g; G For a collection of synchronous generator units; f db This represents the system's primary frequency regulation dead zone; since the response and operating speed of power electronic devices are much higher than those of synchronous machines, the ramp-up limitations of new energy sources and energy storage are ignored. ΔP′ disturb The frequency modulation task that the synchronous machine needs to undertake, and the power disturbance ΔP disturb Excluding the R undertaken by new energy power stations RES and R ESS The remaining portion.

[0205] The voltage stability constraints include:

[0206] Bus voltage fluctuation constraints:

[0207] Reactive power reserve constraint:

[0208] Where, ΔQ i Take a certain proportion of reactive load Q NL That is, ΔQ i =k Q %Q NL ; The voltage sensitivity coefficient is obtained by inverting the Jacobian matrix.

[0209] The active and reactive power coupling constraints include:

[0210] Capacity constraints when only voltage support is provided:

[0211] It also provides capacity constraints for primary frequency regulation backup and voltage support:

[0212] Simultaneously providing capacity constraints for both inertia and voltage support:

[0213] The working principle of step S200 is as follows:

[0214] Step S200: Construct a power system coordinated dispatch model that considers power-type energy storage to assist new energy sources while providing short-term frequency support and voltage support.

[0215] In this embodiment, the power system coordinated dispatch model considering power-type energy storage assisting new energy sources to simultaneously provide short-term frequency and voltage support, as described in S200, comprises four parts: a basic optimized operation model of the power system, frequency stability constraints, voltage stability constraints, and active and reactive power coupling constraints. The dispatch flowchart of the power system coordinated dispatch model considering power-type energy storage assisting new energy sources to simultaneously provide short-term frequency and voltage support is as follows: Figure 3 As shown.

[0216] The objective function of the basic optimization operation model is to minimize the system operating cost.

[0217] min.VC+RC+PC.

[0218] Where VC is the unit output cost, its expression is: RC represents the unit's standby cost, and its expression is: PC represents the cost of wind curtailment penalty for wind turbines, and its expression is: In the formula, Ω G For the collection of generator units; Ω RES For new energy sources; P g,t cs represents the output of unit g at time t. g R represents the power generation cost coefficient of unit g; g,t This indicates that unit g is on standby at time t, and cr g This represents the standby cost coefficient for unit g; d represents the predicted power output of wind farm r at time t. r,t % represents the wind curtailment rate of wind farm r at time t, cw r This represents the wind curtailment cost coefficient for wind farm r.

[0219] In this embodiment, the constraints of the basic optimized operation model of the power system include conventional unit constraints, grid constraints, new energy constraints, and energy storage constraints.

[0220] In this embodiment, the constraints of the conventional unit include:

[0221] Unit active power output constraints:

[0222] Unit reactive power output constraints:

[0223] Unit primary frequency regulation standby constraints:

[0224] in, and Q represents the lower and upper boundaries of the output of unit g, respectively; g,t This represents the reactive power output of unit g at time t; and These represent the lower and upper boundaries of the reactive power of unit g, respectively. This represents the maximum reserve capacity of unit g.

[0225] In this embodiment, the grid constraint adopts a second-order conical power flow, including:

[0226] Node voltage constraint: (V i min ) 2 ≤W ii ≤(V i max ) 2 ,i∈Ω N ;

[0227] Power balance constraints:

[0228]

[0229] Second-order cone constraint:

[0230] Among them, V i V represents the voltage vector at node i; i min and V i max Ω represents the lower and upper boundaries of the voltage amplitude at node i, respectively. N A set of nodes; and All are directed branch sets. (i,j) represents a directed branch with endpoints i and j and a positive direction of i→j; W ij For the introduced auxiliary variables, P ij and Q ij G represents the active and reactive power flowing from node i into branch (i,j); ij and B ij Let represent the conductance and susceptance of branch (i,j), respectively; and P represents the functions that take the real and imaginary parts of a complex variable, respectively; i g and P represents the active power and reactive power injected at node i, respectively; i d and These represent the active load and reactive load of node i, respectively.

[0231] In this embodiment, the new energy constraints include:

[0232] Constraints on new energy output: d w %≤d% max ;

[0233] New energy inertia constraint: H r =h r (1-d r %P r f ;

[0234] Primary frequency regulation reserve constraints for new energy sources:

[0235] Among them, d% max Limits on wind turbine load reduction rate.

[0236] In this embodiment, the energy storage constraints include:

[0237] Energy storage charge and discharge constraints:

[0238] Energy storage charge constraints:

[0239] Energy storage inertia constraint: H s =k s SOC s ;

[0240] Energy storage primary frequency regulation reserve constraints: R s Δt PFR £η d (SOC s -SOC min E s .

[0241] Among them, P s,t This represents the power output of the energy storage s at time t, with positive numbers indicating discharge and negative numbers indicating charging; and Let q represent the discharge power and charging power of energy storage s at time t, respectively. These two powers cannot coexist; that is, energy storage cannot both charge and discharge simultaneously. s,t This represents the charging and discharging flag of the energy storage s at time t, and is a 0-1 variable, with 1 for charging and 0 for discharging; P s chmax and P s dismax These represent the maximum charging power and maximum discharging power in steady state, respectively; SOC s,t η represents the state of charge of the energy storage s at time t; c and η d These are the charging efficiency and discharging efficiency of energy storage, respectively. and These represent the lower and upper boundaries of the charge capacity of energy storage s, respectively; SOC s,T and These represent the state of charge of energy storage s at the end of a scheduling cycle T and the initial state of charge of energy storage, respectively.

[0242] In this embodiment, the frequency stability constraint includes:

[0243] Frequency change rate constraint:

[0244] Minimum frequency constraint: R sync +R RES +R ESS ≥ΔP disturb ;

[0245] Wherein, ΔP disturb For active power disturbances occurring in the system, a certain proportion of the net load P can usually be taken. NL That is, ΔP disturb =k P %P NL H sys H represents the overall inertia level of the system. sys =H sync +H RES +H ESS H syn H RES and H ESS These represent the total inertia levels of synchronous generators, new energy sources, and energy storage, respectively; RoCoF max To limit the rate of change of the system's frequency; R sync R RES and R ESS These are the sum of primary frequency regulation reserves for synchronous generators, new energy sources, and energy storage, respectively; R g For primary frequency regulation standby of unit g; v g Ω represents the maximum power change rate of unit g; G For a collection of synchronous generator units; f db This represents the system's primary frequency regulation dead zone; since the response and operating speed of power electronic devices are much higher than those of synchronous machines, the ramp-up limitations of new energy sources and energy storage are ignored. ΔP′ disturb The frequency modulation task that the synchronous machine needs to undertake, and the power disturbance ΔP disturb Excluding the R undertaken by new energy power stations RES and R ESS The remaining portion.

[0246] In this embodiment, the voltage stability constraint includes:

[0247] Bus voltage fluctuation constraints:

[0248] Reactive power reserve constraint:

[0249] Where, ΔQ i Take a certain proportion of reactive load Q NL That is, ΔQ i =k Q %Q NL ; The voltage sensitivity coefficient is obtained by inverting the Jacobian matrix.

[0250] In this embodiment, the active and reactive power coupling constraint includes:

[0251] Capacity constraints when only voltage support is provided:

[0252] It also provides capacity constraints for primary frequency regulation backup and voltage support:

[0253] Simultaneously providing capacity constraints for both inertia and voltage support:

[0254] Step S300: Based on the power system coordinated dispatch model constructed in step S200, and combined with system operation requirements, construct a power system active support demand model that considers the short-term active support capabilities of power-type energy storage and new energy sources.

[0255] The active support demand model for the power system constructed in step S300, which considers the short-term active support capabilities of power-type energy storage and new energy sources, includes: the system's frequency change rate deficit model Δx. RoCoF The minimum frequency demand deficit model Δx of the system nadir and the system's voltage regulation demand deficit Δx U ;

[0256] Among them, the frequency change rate deficit model Δx of the system RoCoF The expression is:

[0257] This represents the maximum active power disturbance the system should withstand within a scheduling cycle, and is a certain percentage of the net load. This value corresponds to the time of maximum net load during a typical day.

[0258] The minimum frequency demand deficit model Δx of the system nadir The expression is:

[0259]

[0260] Δf ext The lowest allowed frequency f of the system min The deviation from the system's rated frequency, Δfext =f0-f db -f min ;

[0261] The system's voltage regulation demand shortfall Δx U The expression is:

[0262]

[0263] ΔQ is the maximum reactive disturbance that the system should withstand within a scheduling cycle, which is a certain proportion of the reactive load and corresponds to the moment when the system's reactive load is at its maximum. The maximum value of the sensitivity coefficient of the bus voltage to the reactive power of the node is calculated, assuming that ΔQ occurs at the node that has the greatest impact on the bus of the new energy power station.

[0264] The working principle of step S300 is as follows:

[0265] Step S300: Construct a power system active support demand model that considers the short-term active support capabilities of power-type energy storage and new energy sources.

[0266] In this embodiment, the power system active support demand model considering the short-term active support capabilities of power-type energy storage and new energy sources, as described in S300, includes a frequency support demand model and a voltage support demand model. The frequency support demand model further includes a frequency change rate demand model and a minimum frequency demand model.

[0267] In this embodiment, when the system's maximum frequency does not meet the condition, the system's frequency change rate deficit is as follows:

[0268]

[0269] in, This represents the maximum active power disturbance the system must withstand within a scheduling cycle, and is a certain percentage of the net load. This value corresponds to the time of maximum net load during a typical day; Δx RoCoF This is to address the demand shortfall in the rate of change of frequency.

[0270] In this embodiment, when the minimum frequency of the system does not meet the condition, the minimum frequency requirement shortfall of the system is as follows:

[0271]

[0272] Where, Δf ext The lowest allowed frequency f of the system min The deviation from the system's rated frequency, Δf ext =f0-f db -f min ;Δx nadir This is the minimum frequency demand shortfall.

[0273] In this embodiment, the voltage support requirement only includes the voltage regulation requirement model. When the bus voltage fluctuation of the system in the energy-free system exceeds the specified range, the voltage regulation requirement shortfall is as follows:

[0274]

[0275] Wherein, ΔQ is the maximum reactive disturbance that the system should withstand within a scheduling cycle, which is a certain proportion of reactive load, corresponding to the moment when the system's reactive load is at its maximum; The maximum value of the sensitivity coefficient of the bus voltage to the reactive power of the node is used, that is, assuming that ΔQ occurs at the node that has the greatest impact on the bus of the new energy power station, the voltage support requirement is calculated; Δx U This is to address the shortfall in voltage support requirements.

[0276] Step S400: Construct an analytical formula for energy storage capacity oriented towards active support demand. Using the power system active support demand model considering the short-term active support capabilities of energy storage and new energy sources constructed in step S300 as an intermediate variable, establish the mapping relationship between the system's short-term active support demand and energy storage capacity, and then complete the configuration of energy storage capacity that can assist new energy sources in providing short-term active support.

[0277] The specific steps of step S400 include:

[0278] The analytical formulas for energy storage capacity oriented towards active support needs include: analytical formulas for energy storage inertia level, analytical formulas for energy storage primary frequency regulation allocation, and analytical formulas for energy storage reactive power reserve.

[0279] The analytical expression for the energy storage inertia level is:

[0280]

[0281] The analytical expression for the primary frequency regulation backup energy storage is:

[0282] When Δx RoCoF ≠0 o'clock:

[0283]

[0284] When Δx RoCoF =0:

[0285]

[0286] The analytical expression for the energy storage reactive power reserve is:

[0287] ΔQ ESS =K U Δx U .

[0288] The working principle of step S400 is as follows:

[0289] In this embodiment, the analytical formula for power-type energy storage capacity oriented towards active support demand described in S400 uses the active support capability parameter of energy storage as an intermediate variable. It includes the mapping from the system's active support demand to the active support capability parameter of energy storage and the mapping from the active support capability parameter of energy storage to the energy storage capacity parameter. The parameter relationship diagram is as follows: Figure 4 As shown. The active energy storage support capability parameters include frequency support parameters and voltage support parameters. The frequency support parameters include the energy storage inertia level and the energy storage primary frequency regulation reserve, which have a one-to-one mapping relationship with the system frequency change rate requirement and minimum frequency requirement.

[0290] In this embodiment, the mapping relationship from the frequency change rate requirement to the energy storage inertia level is as follows:

[0291]

[0292] In this embodiment, the mapping relationship from minimum frequency demand to primary frequency regulation reserve of energy storage is related to the system operation, and the calculation formula is selected according to the target power system parameters:

[0293] When Δx RoCoF When ≠0, the system frequency stability is poor, so we take... The mapping relationship is as follows:

[0294]

[0295] When Δx RoCoF When = 0, the system frequency stability is relatively good, so we take = 0. The mapping relationship is as follows:

[0296]

[0297] In this embodiment, the energy storage voltage support parameter is the energy storage reactive power reserve. The mapping relationship from system voltage regulation requirements to energy storage reactive power reserve is as follows:

[0298] ΔQ ESS =K U Δx U .

[0299] In this embodiment, the energy storage capacity parameters include the maximum charge / discharge power of the energy storage, the rated capacity, and the grid-connected converter capacity. The mapping relationship between these parameters and the active support capability parameters of the energy storage is as follows:

[0300]

[0301] By establishing the mapping relationship of the aforementioned active support capability parameters for energy storage, the configuration of energy storage capacity that can assist new energy sources in providing short-term support capabilities can be completed.

[0302] A schematic diagram of energy storage capacity configuration methods is shown below. Figure 5 As shown.

[0303] In summary, this invention enables new energy power plants with power-type energy storage to simultaneously provide short-time frequency and voltage support, configuring power-type energy storage capacity while making fuller use of the capacity of the grid-connected energy storage converter. It also establishes an easily solvable analytical method for configuring power-type energy storage capacity to meet active support needs, and establishes a mapping relationship between the system's short-time active support requirements and the power-type energy storage capacity. Therefore, this application effectively overcomes the various shortcomings of existing technologies and has high industrial application value.

[0304] It should be emphasized that the embodiments described in this invention are illustrative rather than limiting. Therefore, this invention includes, but is not limited to, the embodiments described in the specific implementation. Any other implementations derived by those skilled in the art based on the technical solutions of this invention are also within the scope of protection of this invention.

Claims

1. A method for configuring energy storage capacity to provide short-term active support for new energy sources, characterized in that: Includes the following steps: Step S100: Establish a short-term active support capability model for new energy power stations containing power storage. Step S200: Based on the short-term active support capability model constructed in step S100, construct a power system coordinated dispatch model that considers power-type energy storage assisting new energy sources while providing short-term frequency support and voltage support. Step S300: Based on the power system coordinated dispatch model constructed in step S200, and combined with system operation requirements, construct a power system active support demand model that considers the short-term active support capabilities of power-type energy storage and new energy sources. Step S400: Construct an analytical expression for energy storage capacity oriented towards active support demand. Using the power system active support demand model considering the short-term active support capabilities of energy storage and new energy sources constructed in step S300 as an intermediate variable, establish a mapping relationship between the system's short-term active support demand and energy storage capacity, thereby completing the configuration of energy storage capacity that can assist new energy sources in providing short-term active support.

2. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 1, characterized in that: The short-time active support capability model for new energy power stations with power storage established in step S100 includes: a short-time frequency support capability model and a short-time voltage support capability model.

3. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 2, characterized in that: The short-time frequency support capability model includes the inertia model H of the new energy power station. station and primary frequency regulation backup model R station ; Inertia Model H of New Energy Power Station station Including the inertia H of internal new energy sources RES and the inertia H of energy storage ESS ; The inertia model H of the new energy power station station for: Among them, H r For the inertia of new energy r, H s Let be the inertia of the stored energy s; The inertia level of new energy r is proportional to its actual output. Its inertia model H r as follows: Among them, h r Let d be the equivalent inertia constant of the new energy source r. r % represents the load reduction rate of new energy vehicle r. This represents the predicted output value of the new energy source r. The inertia level of energy storage s is related to its own capacity and is constrained by the day-ahead call of the current state of charge. Its inertia model H s as follows: H s =k s SOC s , Where, k s The short-term maximum charge / discharge rate of energy storage s; SOC s Let be the charge of the energy storage s; P represents the maximum continuous output power of the energy storage s; s The day-ahead planned output of energy storage s; f0 is the system rated frequency; RoCoF max This represents the maximum allowable rate of frequency change for the system. The primary frequency regulation reserve model for renewable energy power plants includes: the primary frequency regulation reserve R of internal renewable energy sources. RES And primary frequency regulation backup R of energy storage ESS ; Primary frequency regulation backup model R of new energy power stations station as follows: Among them, R r R is a backup for primary frequency regulation of new energy source r. s It serves as a backup for primary frequency regulation of energy storage S. The primary frequency regulation reserve of new energy r is affected by its own load reduction rate d r % constraint, its primary frequency regulation reserve model R r as follows: The primary frequency regulation reserve of energy storage s is constrained by the maximum continuous output power and the energy storage capacity. Its primary frequency regulation reserve model R s as follows: R s Δt PFR ≤η d (SOC s -SOC min )IN s Where, Δt PFR η is the duration of a single frequency modulation process. d For energy storage discharge efficiency; SOC min The minimum charge allowed for energy storage operation; E s s is the rated capacity of energy storage. To maximize the utilization of new energy sources, the reactive power reserve of new energy power plants is provided by energy storage, and its reactive power reserve model ΔQ station as follows: Where, ΔQ ESS For reactive power reserve in energy storage systems; ΔQ s This serves as a reactive power backup for the energy storage device s. The active and reactive power control loops of the energy storage converter are decoupled, and the active and reactive power outputs are only related through the converter capacity. The reactive power reserve model ΔQ of energy storage s as follows: Among them, P s The active power output of energy storage s; The grid-connected converter capacity is for energy storage s.

4. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 1, characterized in that: The specific steps of step S200 include: The constructed power system coordinated dispatch model, which considers power-type energy storage to assist new energy sources while providing short-term frequency and voltage support, includes: the basic optimized operation model of the power system and its constraints, frequency stability constraints, voltage stability constraints, and active and reactive power coupling constraints.

5. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 4, characterized in that: The objective function of the basic optimization operation model of the power system is to minimize the system operating cost. min.VC+RC+PC. Where VC is the unit output cost, its expression is: RC represents the unit's standby cost, and its expression is: PC represents the cost of wind curtailment penalty for wind turbines, and its expression is: In the formula, Ω G For the collection of generator units; Ω RES For new energy sources; P g,t cs represents the output of unit g at time t. g R represents the power generation cost coefficient of unit g; g,t This indicates that unit g is on standby at time t, and cr g This represents the standby cost coefficient for unit g; d represents the predicted power output of wind farm r at time t. r,t % represents the wind curtailment rate of wind farm r at time t, cw r This represents the wind curtailment cost coefficient for wind farm r.

6. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 4, characterized in that: The constraints of the basic optimized operation model of the power system include: conventional unit constraints, grid constraints, new energy constraints, and energy storage constraints; The constraints of the conventional generating units include: Unit active power output constraints: Unit reactive power output constraints: Unit primary frequency regulation standby constraints: in, and Q represents the lower and upper boundaries of the output of unit g, respectively; g,t This represents the reactive power output of unit g at time t; and These represent the lower and upper boundaries of the reactive power of unit g, respectively. This represents the maximum reserve capacity of unit g. The space frame constraint adopts a second-order conical power flow, including: Node voltage constraints: Power balance constraints: Second-order cone constraint: Among them, V i V represents the voltage vector at node i; i min and V i max Ω represents the lower and upper boundaries of the voltage amplitude at node i, respectively. N A set of nodes; and All are directed branch sets. (i,j) represents a directed branch with endpoints i and j and a positive direction of i→j; W ij For the introduced auxiliary variables, P ij and Q ij G represents the active and reactive power flowing from node i into branch (i,j); ij and B ij Let represent the conductance and susceptance of branch (i,j), respectively; and Let these represent functions that take the real and imaginary parts of a complex variable, respectively. and These represent the active power and reactive power injected at node i, respectively. and These represent the active load and reactive load of node i, respectively. The constraints on new energy sources include: Constraints on new energy output: Inertia Constraints of New Energy Sources: Primary frequency regulation reserve constraints for new energy sources: Among them, d% max Limits on wind turbine load reduction rate. The energy storage constraints include: Energy storage charge and discharge constraints: Energy storage charge constraints: Energy storage inertia constraint: H s =k s SOC s ; Energy storage primary frequency regulation reserve constraints: Among them, P s,t This represents the power output of the energy storage s at time t, with positive numbers indicating discharge and negative numbers indicating charging; and Let q represent the discharge power and charging power of energy storage s at time t, respectively. These two powers cannot coexist; that is, energy storage cannot both charge and discharge simultaneously. s,t This represents the charging and discharging flag of the energy storage s at time t, and is a 0-1 variable, with 1 for charging and 0 for discharging; and These represent the maximum charging power and maximum discharging power in steady state, respectively; SOC s,t η represents the state of charge of the energy storage s at time t; c and η d These are the charging efficiency and discharging efficiency of energy storage, respectively. and These represent the lower and upper boundaries of the charge capacity of energy storage s, respectively; SOC s,T and These represent the state of charge of energy storage s at the end of a scheduling cycle T and the initial state of charge of energy storage, respectively. The frequency stability constraints include: Frequency change rate constraint: Minimum frequency constraint: R sync +R RES +R ESS ≥ΔP disturb ; Where, ΔP disturb For active power disturbances occurring in the system, a certain proportion of the net load P can usually be taken. NL That is, ΔP disturb =k P %P NL H sys H represents the overall inertia level of the system. sys =H sync +H RES +H ESS H syn H RES and H ESS These represent the total inertia levels of synchronous generators, new energy sources, and energy storage, respectively; RoCoF max To limit the rate of change of the system's frequency; R sync R RES and R ESS These are the sum of primary frequency regulation reserves for synchronous generators, new energy sources, and energy storage, respectively; R g For primary frequency regulation standby of unit g; v g Ω represents the maximum power change rate of unit g; G For a collection of synchronous generator units; f db This represents the system's primary frequency regulation dead zone; since the response and operating speed of power electronic devices are much higher than those of synchronous machines, the ramp-up limitations of new energy sources and energy storage are ignored. ΔP' disturb The frequency modulation task that the synchronous machine needs to undertake, and the power disturbance ΔP disturb Excluding the R undertaken by new energy power stations RES and R ESS The remaining portion. The voltage stability constraints include: Bus voltage fluctuation constraints: Reactive power reserve constraint: Where, ΔQ i Take a certain proportion of reactive load Q NL That is, ΔQ i =k Q %Q NL ; The voltage sensitivity coefficient is obtained by inverting the Jacobian matrix. The active and reactive power coupling constraints include: Capacity constraints when only voltage support is provided: It also provides capacity constraints for primary frequency regulation backup and voltage support: Simultaneously providing capacity constraints for both inertia and voltage support:

7. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 1, characterized in that: The power system active support demand model constructed in step S300, which considers the short-term active support capabilities of power-type energy storage and new energy sources, includes: the system's frequency change rate deficit model Δx. RoCoF The minimum frequency demand deficit model Δx of the system nadir and the system's voltage regulation demand deficit Δx U .

8. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 7, characterized in that: The frequency change rate deficit model Δx of the system RoCoF The expression is: This represents the maximum active power disturbance the system should withstand within a scheduling cycle, and is a certain percentage of the net load. This value corresponds to the time of maximum net load during a typical day. The minimum frequency demand deficit model Δx of the system nadir The expression is: Δf ext The lowest allowed frequency f of the system min The deviation from the system's rated frequency, Δf ext =f0-f db -f min ; The system's voltage regulation demand shortfall Δx U The expression is: ΔQ is the maximum reactive disturbance that the system should withstand within a scheduling cycle, which is a certain proportion of the reactive load and corresponds to the moment when the system's reactive load is at its maximum. The maximum value of the sensitivity coefficient of the bus voltage to the reactive power of the node is calculated, assuming that ΔQ occurs at the node that has the greatest impact on the bus of the new energy power station.

9. The energy storage capacity configuration method for providing short-term active support to new energy sources according to claim 1, characterized in that: The analytical formula for energy storage capacity oriented towards active support needs in step S400 includes: analytical formula for energy storage inertia level, analytical formula for energy storage primary frequency regulation allocation, and analytical formula for energy storage reactive power reserve. The analytical expression for the energy storage inertia level is: The analytical expression for the primary frequency regulation backup energy storage is: When Δx RoCoF ≠0 o'clock: When Δx RoCoF =0: The reactive power reserve of the energy storage is expressed as follows: ΔQ ESS =K U Δx U 。

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