Transmission and storage collaborative capacity expansion method of power system

Abstract

The invention discloses a transmission and storage collaborative capacity expansion method of a power system. The method comprises the following steps: constructing a segmented excitation type transmission and storage collaborative expansion model of a power system meeting transmission and storage constraints; and inputting the equipment cost parameters of the power system into the segmented excitation type transmission and storage cooperative capacity expansion model for processing, and solving by using a commercial solver to obtain the number of power transmission lines and energy storage equipment of the power system to be expanded so as to realize transmission and storage cooperative capacity expansion of the power system. Compared with a traditional power transmission network planning method, the power transmission network planning method is a power transmission network planning technology for improving the flexibility of the power transmission network, the power transmission blocking risk can be reduced, the safety and stability margin of power grid operation is improved, and renewable energy consumption is promoted.

Description

Technical Field

[0001] The present invention relates to a method for expanding the capacity of an electric power system, and to the technical field of power grid planning, and in particular to a method for coordinating the expansion of the capacity of an electric power system with transmission and storage. Background Art

[0002] As an important part of the energy industry, the power industry plays a key role. In this context, building a power grid with a high proportion of renewable energy generation can reduce carbon emissions and promote carbon neutrality. However, due to the uneven temporal and spatial distribution of wind power and photovoltaic power generation resources, coupled with the anti-peak characteristics and uncertainty of renewable energy, the power grid has problems such as temporal and spatial imbalance and unpredictability, increasing the risk of transmission congestion and severe reduction of renewable energy, and bringing great challenges to the safe and stable operation of the power grid. Summary of the invention

[0003] In order to solve the problems existing in the background technology, the present invention provides a method for coordinated expansion of transmission and storage in an electric power system.

[0004] The technical solution adopted by the present invention is:

[0005] The transmission and storage coordinated capacity expansion method of the power system of the present invention comprises:

[0006] Step S1: Construct a segmented incentive transmission and storage collaborative expansion model for the power system that meets the transmission and storage constraints.

[0007] Step S2: Input the equipment cost parameters of the power system into the segmented incentive transmission and storage collaborative expansion model for processing, and use a commercial solver to solve it to obtain the number of transmission lines and energy storage equipment in the power system to be expanded, so as to realize the transmission and storage collaborative expansion of the power system.

[0008] In step S1, the segmented incentive transmission and storage collaborative expansion model of the power system is specifically as follows:

[0009] min C total =C Ope +C Inv

[0010]

[0011] C Inv =A(∑ l∈L′ u l c l +∑ b∈B′ u b c b +∑ d∈DR′ u d c d )

[0012] Among them, Ctotal represents the total annual cost of construction and operation of the power system during the preset expansion planning period, C Ope and C Inv are the annualized operating cost and annualized construction cost of the power system within the preset expansion planning period; S represents the scenario set of the power system, each scenario includes the typical daily load curve of each season of spring, summer, autumn and winter, π s represents the probability of occurrence of scenario s in the scenario set S of the power system; T represents the number of dispatching times, Δt represents the time interval between two adjacent dispatching times; c g represents the unit power generation cost of thermal power unit g in the power system, P s,t,g represents the output of thermal power unit g of the power system at dispatching time t under scenario s; represents the demand response input cost of the segmented incentive demand response device d of the power system at the dispatching time t under the scenario s. The segmented incentive demand response device includes a load response device and a cost calculation device. The load response device is used to dynamically adjust the user's load demand, and the cost calculation device is used to calculate the cost required for the user's load demand adjustment; c cur It represents the unit wind and solar curtailment cost of renewable energy unit n in the power system, represents the maximum output of renewable energy unit n in the power system at dispatch time t under scenario s, P s,t,n represents the actual output of renewable energy unit n in the power system at the dispatching time t under scenario s; c ls represents the unit operating cost of transmission line l, represents the load shedding power of load node i of the power system at dispatching time t under scenario s; c bb represents the unit operating cost of the energy storage device b in the power system, and They represent the charging and discharging power of the energy storage device b of the power system at the dispatching time t under scenario s; A represents the annualized cost coefficient; L′, B′ and DR′ represent the set of transmission lines to be expanded, the set of energy storage facilities to be expanded, and the set of segmented incentive demand response devices to be installed in the power system, respectively; u l 、u b and u d They represent the expansion status of the power transmission line l, energy storage device b and segmented incentive demand response device d of the power system. When the expansion status is 1, it means expansion, and when the expansion status is 0, it means no expansion. l 、u b and u d All are Boolean variables; c l 、c b and c d They respectively represent the construction costs of the power system’s transmission line l, energy storage equipment b and segmented incentive demand response device d.

[0013] The equipment cost parameters of the power system include the unit power generation cost c of the thermal power unit g of the power system g 、The unit wind and solar curtailment cost c of renewable energy unit n cur , the unit operating cost c of the transmission line l ls and construction cost c l 、Unit operating cost c of energy storage device b bb and construction cost c b and the construction cost c of the segmented incentive demand response device d d .

[0014] The number of transmission lines and energy storage devices in the power system to be expanded depends on the expansion status u of the transmission line l of the power system. l and the expansion status u of the energy storage device b b Sure.

[0015] In step S1, the transport and storage constraints are as follows:

[0016] a) Node power balance constraint:

[0017]

[0018] Where D(i), G(i), L(i), N(i) and B(i) represent the set of segmented incentive demand response device d, thermal power unit g, transmission line l, renewable energy unit n and energy storage device b at load node i of the power system respectively; P s,t,i represents the load demand of load node i of the power system at dispatching time t under scenario s; represents the load shedding power of load node i of the power system at the dispatching time t under scenario s; represents the load change of load node i in the power system at the dispatching time t after the demand response in scenario s; P s,t,g represents the output of thermal power unit g in the power system at dispatching time t under scenario s; P s,t,l represents the transmission power of the power transmission line l of the power system at the scheduling time t under scenario s; P s,t,n represents the actual output of renewable energy unit n of the power system at dispatch time t under scenario s; and They respectively represent the charging and discharging power of the energy storage device b of the power system at the scheduling time t under scenario s.

[0019] b) System power flow balance constraints:

[0020] P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / xl =0,l∈L

[0021] -M(1-u l )≤P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l ,l∈L′

[0022] P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l ≤M(1-u l ),l∈L′

[0023] Among them, θ s,t,l,1 and θ s,t,l,2 They represent the voltage phase angles at both ends of the transmission line l of the power system at the dispatching time t under scenario s; x l represents the impedance matrix of the transmission line l; M represents a large preset positive integer; L′ represents the set of transmission lines to be expanded in the power system; u l Indicates the expansion status of the transmission line l of the power system.

[0024] c) Constraints on thermal power units:

[0025]

[0026] in, and They represent the minimum and maximum outputs of the thermal power generation unit g in the power system respectively; and They represent the minimum and maximum landslide climbing rates of the thermal power unit g in the power system; Δt represents the time interval between two adjacent dispatching times; P s,t-1,g It represents the output of thermal power unit g in the power system at the dispatching time t-1 under scenario s.

[0027] d) Energy storage equipment operation constraints:

[0028]

[0029] E b,T-1 =E b,0

[0030] in, Indicates the charging state of the energy storage device b in the power system. When the energy storage device b is charged, the charging state When the energy storage device b is not charged; is the discharge state of the energy storage device b in the power system, and the discharge state When the energy storage device b discharges, the discharge state When the energy storage device b does not discharge, and All are Boolean variables; and They represent the maximum charging power and maximum discharging power of the energy storage device b in the power system respectively; u b Indicates the expansion status of the energy storage device b of the power system; E b,t 、E b,t-1 and E b,T-1 are the charge states of the energy storage device b of the power system at the dispatching times t, t-1 and T-1, respectively, and T represents the number of dispatching times; and They represent the maximum and minimum charge states of the energy storage device b in the power system, E b,0 represents the initial charge state of the energy storage device b of the power system; and They respectively represent the charging and discharging efficiency of the energy storage device b of the power system.

[0031] e) Renewable energy output constraints:

[0032]

[0033] in, It represents the maximum output of renewable energy unit n in the power system at the dispatching time t under scenario s.

[0034] f) Load shedding constraints:

[0035]

[0036] The demand response input cost of the segmented incentive demand response device d of the power system at the dispatch time t under the scenario s is The details are as follows:

[0037]

[0038] w1+w2+w3+w4+w5=1

[0039] 0≤w1,w2,w3,w4,w5≤1

[0040] w1≤z1

[0041] w2≤z1+z2

[0042] w3≤z2+z3

[0043] w4≤z3+z4

[0044] w5≤z4

[0045] z1+z2+z3+z4=1

[0046] Wherein, w1, w2, w3, w4 and w5 represent the first, second, third, fourth and fifth continuous auxiliary variables respectively, and z1, z2, z3 and z4 represent the first, second, third and fourth preset Boolean auxiliary variables respectively; and They represent the preset first, second, third and fourth demand response steps of the segmented incentive demand response device d of the power system at the dispatching time t under scenario s, respectively. and They respectively represent the unit input cost of the segmented incentive type demand response device d participating in the demand response under the preset first, second, third and fourth demand response steps of the segmented incentive type demand response device d of the power system under scenario s at the dispatch time t; represents the original load demand of the segmented incentive demand response device d of the power system at the dispatching time t under scenario s; b + and b - denote the first and second constants respectively.

[0047] The transmission and storage coordinated expansion system applicable to the above-mentioned method of the present invention comprises:

[0048] The collaborative planning model construction module is used to construct a segmented incentive transmission and storage collaborative expansion model for power systems that meet transmission and storage constraints.

[0049] The model solving module is used to input the equipment cost parameters of the power system into the segmented incentive transmission and storage collaborative expansion model for processing, and use a commercial solver to solve it to obtain the number of transmission lines and energy storage equipment in the power system to be expanded.

[0050] The transmission and storage coordinated expansion system also includes a demand response model construction module and a demand response model linearization module. The demand response model construction module is used to construct a segmented incentive demand response model, and the demand response model linearization module is used to linearize the segmented incentive demand response model.

[0051] The electronic device of the present invention comprises: a memory and a processor coupled to each other, wherein the memory stores program data, and the processor calls the program data to execute the method as described above.

[0052] The computer-readable storage medium of the present invention stores program data thereon, and when the program data is executed by a processor, the method described above is implemented.

[0053] Compared with the traditional transmission network planning method, the present invention proposes a segmented incentive demand response model to explore the flexible response capability of the demand side, and on this basis considers the flexible adjustment capability of the power system itself, and proposes a segmented incentive transmission and storage collaborative expansion model of transmission lines and energy storage equipment. The proposed model is converted into a mixed integer linear programming model using a mathematical optimization method, which can be efficiently solved by a commercial solver and is scalable and replicable.

[0054] The beneficial effects of the present invention are:

[0055] Compared with traditional transmission network planning methods, the present invention is a transmission network planning technology that improves the flexibility of the transmission network, can reduce the risk of transmission congestion, improve the safety and stability margin of power grid operation, and promote the consumption of renewable energy. BRIEF DESCRIPTION OF THE DRAWINGS

[0056] Figure 1 is an overall flow chart of the method of the present invention;

[0057] Figure 2 is a schematic block diagram of the device of the present invention;

[0058] Figure 3 It is a schematic diagram of the segmented incentive demand response of the method of the present invention. DETAILED DESCRIPTION

[0059] The exemplary embodiments will be described in detail below, examples of which are shown in the accompanying drawings. When the following description refers to the drawings, unless otherwise indicated, the same numbers in different drawings represent the same or similar elements. The implementations described in the following exemplary embodiments do not represent all implementations consistent with the present application. Instead, they are only examples of devices and methods consistent with some aspects of the present application as detailed in the attached claims.

[0060] The terms used in this application are for the purpose of describing specific embodiments only and are not intended to limit this application. The singular forms of "a", "said" and "the" used in this application and the appended claims are also intended to include plural forms unless the context clearly indicates other meanings. It should also be understood that the term "and / or" used herein refers to and includes any or all possible combinations of one or more associated listed items.

[0061] like Figure 1 As shown, the transmission and storage coordinated expansion method of the power system of the present invention is specifically as follows:

[0062] First, a segmented incentive transmission and storage collaborative expansion model for the power system that meets the transmission and storage constraints is constructed as follows:

[0063] min C total =C Ope+C Inv

[0064]

[0065] C Inv =A(∑ l∈L′ u l c l +∑ b∈B′ u b c b +∑ d∈DR′ u d c d )

[0066] Among them, C total represents the total annual cost of construction and operation of the power system during the preset expansion planning period, C Ope and C Inv are the annualized operating cost and annualized construction cost of the power system within the preset expansion planning period; S represents the scenario set of the power system, each scenario includes the typical daily load curve of each season of spring, summer, autumn and winter, π s represents the probability of occurrence of scenario s in the scenario set S of the power system; T represents the number of dispatching times, Δt represents the time interval between two adjacent dispatching times; c g represents the unit power generation cost of thermal power unit g in the power system, P s,t,g represents the output of thermal power unit g of the power system at dispatching time t under scenario s; represents the demand response input cost of the segmented incentive demand response device d of the power system at the dispatching time t under the scenario s. The segmented incentive demand response device includes a load response device and a cost calculation device. The load response device is used to dynamically adjust the user's load demand, and the cost calculation device is used to calculate the cost required for the user's load demand adjustment; c cur It represents the unit wind and solar curtailment cost of renewable energy unit n in the power system, represents the maximum output of renewable energy unit n in the power system at dispatch time t under scenario s, P s,t,n represents the actual output of renewable energy unit n in the power system at the dispatching time t under scenario s; c ls represents the unit operating cost of transmission line l, represents the load shedding power of load node i of the power system at dispatching time t under scenario s; c bb represents the unit operating cost of the energy storage device b in the power system, and They represent the charging and discharging power of the energy storage device b of the power system at the dispatching time t under scenario s; A represents the annualized cost coefficient; L′, B′ and DR′ represent the set of transmission lines to be expanded, the set of energy storage facilities to be expanded, and the set of segmented incentive demand response devices to be installed in the power system, respectively; u l 、u b and u d They represent the expansion status of the power transmission line l, energy storage device b and segmented incentive demand response device d of the power system. When the expansion status is 1, it means expansion, and when the expansion status is 0, it means no expansion. l 、u b and u d All are Boolean variables; c l 、c b and c d They respectively represent the construction costs of the power system’s transmission line l, energy storage equipment b and segmented incentive demand response device d.

[0067] The annualized cost coefficient A is as follows:

[0068]

[0069] Among them, k represents the cost-return ratio, T k Represents the planning period. The cost can be measured in terms of power generation.

[0070] The equipment cost parameters of the power system include the unit power generation cost c of the thermal power unit g of the power system g 、The unit wind and solar curtailment cost c of renewable energy unit n cur , the unit operating cost c of the transmission line l ls and construction cost c l 、Unit operating cost c of energy storage device b bb and construction cost c b and the construction cost c of the segmented incentive demand response device d d .

[0071] The number of transmission lines and energy storage devices in the power system to be expanded depends on the expansion status u of the transmission line l of the power system. l and the expansion status u of the energy storage device b b Sure.

[0072] The specific constraints on transportation and storage are as follows:

[0073] a) Node power balance constraint:

[0074]

[0075] Where D(i), G(i), L(i), N(i) and B(i) represent the set of segmented incentive demand response device d, thermal power unit g, transmission line l, renewable energy unit n and energy storage device b at load node i of the power system respectively; P s,t,i represents the load demand of load node i of the power system at dispatching time t under scenario s; represents the load shedding power of load node i of the power system at the dispatching time t under scenario s; represents the load change of load node i in the power system at the dispatching time t after the demand response in scenario s; P s,t,g represents the output of thermal power unit g in the power system at dispatching time t under scenario s; P s,t,l represents the transmission power of the power transmission line l of the power system at the scheduling time t under scenario s; P s,t,n represents the actual output of renewable energy unit n of the power system at dispatch time t under scenario s; and They respectively represent the charging and discharging power of the energy storage device b of the power system at the scheduling time t under scenario s.

[0076] b) System power flow balance constraints:

[0077] P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l =0,l∈L

[0078] -M(1-u l )≤P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l ,l∈L′

[0079] P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l ≤M(1-u l ),l∈L′

[0080] Among them, θ s,t,l,1 and θ s,t,l,2 They represent the voltage phase angles at both ends of the transmission line l of the power system at the dispatching time t under scenario s; x l represents the impedance matrix of the transmission line l; M represents a large preset positive integer; L′ represents the set of transmission lines to be expanded in the power system; u l Indicates the expansion status of the transmission line l of the power system.

[0081] c) Constraints on thermal power units:

[0082]

[0083] in, and They represent the minimum and maximum outputs of the thermal power generation unit g in the power system respectively;

[0084] and They represent the minimum and maximum landslide climbing rates of the thermal power unit g in the power system; Δt represents the time interval between two adjacent dispatching times; P s,t-1,g It represents the output of thermal power unit g in the power system at the dispatching time t-1 under scenario s.

[0085] d) Energy storage equipment operation constraints:

[0086]

[0087] E b,T-1 =E b,0

[0088] in, Indicates the charging state of the energy storage device b in the power system. When the energy storage device b is charged, the charging state When the energy storage device b is not charged; is the discharge state of the energy storage device b in the power system, and the discharge state When the energy storage device b discharges, the discharge state When the energy storage device b does not discharge, and All are Boolean variables; and They represent the maximum charging power and maximum discharging power of the energy storage device b in the power system respectively; u b Indicates the expansion status of the energy storage device b of the power system; E b,t 、E b,t-1 and E b,T-1 are the charge states of the energy storage device b of the power system at the dispatching times t, t-1 and T-1, respectively, and T represents the number of dispatching times; and They represent the maximum and minimum charge states of the energy storage device b in the power system, E b,0 represents the initial charge state of the energy storage device b of the power system; and They respectively represent the charging and discharging efficiency of the energy storage device b of the power system.

[0089] e) Renewable energy output constraints:

[0090]

[0091] in, It represents the maximum output of renewable energy unit n in the power system at the dispatching time t under scenario s.

[0092] f) Load shedding constraints:

[0093]

[0094] The demand response input cost of the segmented incentive demand response device d of the power system at the dispatch time t under scenario s The details are as follows:

[0095]

[0096] w1+w2+w3+w4+w5=1

[0097] 0≤w1,w2,w3,w4,w5≤1

[0098] w1≤z1

[0099] w2≤z1+z2

[0100] w3≤z2+z3

[0101] w4≤z3+z4

[0102] w5≤z4

[0103] z1+z2+z3+z4=1

[0104] Wherein, w1, w2, w3, w4 and w5 represent the first, second, third, fourth and fifth continuous auxiliary variables respectively, and z1, z2, z3 and z4 represent the first, second, third and fourth preset Boolean auxiliary variables respectively; and They represent the preset first, second, third and fourth demand response steps of the segmented incentive demand response device d of the power system at the dispatching time t under scenario s, respectively. and They respectively represent the unit input cost of the segmented incentive type demand response device d participating in the demand response under the preset first, second, third and fourth demand response steps of the segmented incentive type demand response device d of the power system under scenario s at the dispatch time t; represents the original load demand of the segmented incentive demand response device d of the power system at the dispatching time t under scenario s; b + and b - denote the first and second constants respectively.

[0105] like Figure 3 As shown in the figure, a segmented incentive demand response model is constructed, as follows:

[0106] For load node i, its demand response input cost under scenario s can be expressed as:

[0107]

[0108] in, represents the load demand of load node i after participating in demand response under scenario s Ratio to original load demand

[0109] The segmented incentive demand response model meets the demand response scale constraints as follows:

[0110]

[0111] in, and λ i They respectively represent the maximum and minimum response ratios of load node i when responding to demand.

[0112] The nonlinear segmented incentive demand response model is transformed into a linear model using mathematical optimization methods to obtain the demand response input cost of the power system.

[0113] Then, the equipment cost parameters of the power system are input into the segmented incentive transmission and storage collaborative expansion model for processing, and the commercial solver is used to solve it, and the number of transmission lines and energy storage equipment of the power system to be expanded is obtained to realize the transmission and storage collaborative expansion of the power system. In the specific implementation, the segmented incentive transmission and storage collaborative expansion model is converted into a mathematical optimization model, and then solved using a commercial solver to obtain the final planning result.

[0114] like Figure 2 As shown, the transmission and storage collaborative expansion system of the present invention includes a collaborative planning model construction module, a model solving module, a demand response model construction module and a demand response model linearization module. The collaborative planning model construction module constructs a segmented incentive transmission and storage collaborative expansion model of the power system that meets the transmission and storage constraints; the model solving module inputs the equipment cost parameters of the power system into the segmented incentive transmission and storage collaborative expansion model for processing, and uses a commercial solver to solve it to obtain the number of transmission lines and energy storage equipment of the power system to be expanded; the demand response model construction module is used to construct a segmented incentive demand response model, and the demand response model linearization module is used for linearization of the segmented incentive demand response model.

[0115] The present invention provides a method and device for coordinated expansion of transmission and storage in an electric power system. Compared with the traditional transmission network planning method, a segmented incentive demand response model is proposed to explore the flexible response capability of the demand side, and on this basis, the flexible adjustment capability of the electric power system itself is considered, and a segmented incentive transmission and storage coordinated expansion model of transmission lines and energy storage equipment is proposed. The proposed model is converted into a mixed integer linear programming model by using a mathematical optimization method, which can be efficiently solved by a commercial solver and is scalable and replicable.

[0116] Regarding the device in the above embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method, and will not be elaborated here.

[0117] For the device embodiment, since it basically corresponds to the method embodiment, the relevant parts can refer to the partial description of the method embodiment. The device embodiment described above is only schematic, wherein the units described as separate components may or may not be physically separated, and the components displayed as units may or may not be physical units, that is, they may be located in one place, or they may be distributed on multiple network units. Some or all of the modules may be selected according to actual needs to achieve the purpose of the present application scheme. A person of ordinary skill in the art can understand and implement it without paying any creative work.

[0118] Those skilled in the art will readily appreciate other embodiments of the present application after considering the specification and practicing the disclosure disclosed herein. The present application is intended to cover any modification, use or adaptation of the present application, which follows the general principles of the present application and includes common knowledge or customary techniques in the art that are not disclosed in the present application. The specification and examples are intended to be exemplary only, and the true scope and spirit of the present application are indicated by the following claims.

[0119] It should be understood that the present application is not limited to the precise structures that have been described above and shown in the drawings, and that various modifications and changes may be made without departing from the scope thereof. The scope of the present application is limited only by the appended claims.

Claims

1. A transmission and storage coordinated expansion method for a power system, characterized in that: include: Step S1: construct a segmented incentive transmission and storage collaborative expansion model for the power system that meets the transmission and storage constraints; Step S2: Input the equipment cost parameters of the power system into the segmented incentive transmission and storage coordinated expansion model for processing, and use a commercial solver to solve it to obtain the number of transmission lines and energy storage equipment of the power system to be expanded, so as to realize the transmission and storage coordinated expansion of the power system.

2. The transmission and storage coordinated expansion method of the power system according to claim 1, characterized in that: In step S1, the segmented incentive transmission and storage collaborative expansion model of the power system is specifically as follows: my C total =C Ope +C Inv C Inv =A(∑ l∈L′ u l c l +Σ b∈B′ u b c b +Σ d∈DR′ u d c d ) Among them, C total represents the total annual cost of construction and operation of the power system during the preset expansion planning period, C Ope and C I nv are the annualized operating cost and annualized construction cost of the power system within the preset expansion planning period; S represents the scenario set of the power system, π s represents the probability of occurrence of scenario s in the scenario set S of the power system; T represents the number of dispatching times, Δt represents the time interval between two adjacent dispatching times; c g represents the unit power generation cost of thermal power unit g in the power system, P s,t,g represents the output of thermal power unit g of the power system at dispatching time t under scenario s; represents the demand response input cost of the segmented incentive demand response device d of the power system at the dispatch time t under scenario s; c cur It represents the unit wind and solar curtailment cost of renewable energy unit n in the power system, represents the maximum output of renewable energy unit n in the power system at dispatch time t under scenario s, P s,t,n represents the actual output of renewable energy unit n in the power system at the dispatching time t under scenario s; c ls represents the unit operating cost of transmission line l, represents the load shedding power of load node i of the power system at dispatching time t under scenario s; c bb represents the unit operating cost of the energy storage device b in the power system, and They represent the charging and discharging power of the energy storage device b of the power system at the dispatching time t under scenario s; A represents the annualized cost coefficient; L′, B′ and DR′ represent the set of transmission lines to be expanded, the set of energy storage facilities to be expanded, and the set of segmented incentive demand response devices to be installed in the power system, respectively; u l 、u b and u d They represent the expansion status of the power transmission line l, energy storage device b and segmented incentive demand response device d of the power system respectively. When the expansion status is 1, it means expansion, and when the expansion status is 0, it means no expansion; c l 、c b and c d They represent the construction costs of the power transmission line l, energy storage equipment b and segmented incentive demand response device d of the power system respectively; The equipment cost parameters of the power system include the unit power generation cost c of the thermal power unit g of the power system g 、The unit wind and solar curtailment cost c of renewable energy unit n cur , the unit operating cost c of the transmission line l ls and construction cost c l 、Unit operating cost c of energy storage device b bb and construction cost c b and the construction cost c of the segmented incentive demand response device d d ; The number of transmission lines and energy storage devices in the power system to be expanded depends on the expansion status u of the transmission line l of the power system. l and the expansion status u of the energy storage device b b Sure.

3. The transmission and storage coordinated expansion method of the power system according to claim 1, characterized in that: In step S1, the transport and storage constraints are as follows: a) Node power balance constraint: Where D(i), G(i), L(i), N(i) and B(i) represent the set of segmented incentive demand response device d, thermal power unit g, transmission line l, renewable energy unit n and energy storage device b at load node i of the power system respectively; P s,t,i represents the load demand of load node i of the power system at dispatching time t under scenario s; represents the load shedding power of load node i of the power system at the dispatching time t under scenario s; represents the load change of load node i in the power system at the dispatching time t after the demand response in scenario s; P s,t,g represents the output of thermal power unit g in the power system at dispatching time t under scenario s; P s,t,l represents the transmission power of the power transmission line l of the power system at the scheduling time t under scenario s; P s,t,n represents the actual output of renewable energy unit n in the power system at the dispatching time t under scenario s; and They represent the charging and discharging power of the energy storage device b of the power system at the scheduling time t under scenario s respectively; b) System power flow balance constraints: P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l =0,l∈L -M(1-u l )≤P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l ,l∈L ′ P s,t,l -(θ s,t,l,1 -θ s,t,l,2 ) / x l ≤M(1-u l ),l∈L ′ Among them, θ s,t,l,1 and θ s,t,l,2 They represent the voltage phase angles at both ends of the transmission line l of the power system at the dispatching time t under scenario s; x l represents the impedance matrix of the transmission line l; M represents a preset positive integer; L ′ represents the set of transmission lines to be expanded in the power system; u l Indicates the expansion status of the transmission line l of the power system; c) Constraints on thermal power units: in, and They represent the minimum and maximum outputs of the thermal power generation unit g in the power system respectively; and They represent the minimum and maximum landslide climbing rates of the thermal power unit g in the power system respectively; Δt represents the time interval between two adjacent dispatching times; P s,t-1,g represents the output of thermal power unit g of the power system at the dispatching time t-1 under scenario s; d) Energy storage equipment operation constraints: AND b,T-1 =And b,0 in, Indicates the charging state of the energy storage device b in the power system. When the energy storage device b is charged, the charging state When the energy storage device b is not charged; is the discharge state of the energy storage device b in the power system, and the discharge state When the energy storage device b discharges, the discharge state When the energy storage device b does not discharge; and They represent the maximum charging power and maximum discharging power of the energy storage device b in the power system respectively; u b Indicates the expansion status of the energy storage device b of the power system; E b,t 、E b,t-1 and E b,T-1 are the charge states of the energy storage device b of the power system at the dispatching times t, t-1 and T-1, respectively, and T represents the number of dispatching times; and They represent the maximum and minimum charge states of the energy storage device b in the power system, E b,0 represents the initial charge state of the energy storage device b of the power system; and They represent the charging and discharging efficiency of the energy storage device b of the power system respectively; e) Renewable energy output constraints: in, represents the maximum output of renewable energy unit n in the power system at dispatch time t under scenario s; f) Load shedding constraints:

4. The transmission and storage coordinated expansion method of the power system according to claim 2, characterized in that: The demand response input cost of the segmented incentive demand response device d of the power system at the dispatch time t under the scenario s is The details are as follows: w1+w2+w3+w4+w5=1 0≤w1,w2,w3,w4,w5≤1 w1≤z1 w2≤z1+z2 w3≤z2+z3 w4≤z3+z4 w5≤z4 z1+z2+z3+z4=1 Wherein, w1, w2, w3, w4 and w5 represent the first, second, third, fourth and fifth continuous auxiliary variables respectively, and z1, z2, z3 and z4 represent the first, second, third and fourth preset Boolean auxiliary variables respectively; and They represent the preset first, second, third and fourth demand response steps of the segmented incentive demand response device d of the power system at the dispatching time t under scenario s, respectively. and They respectively represent the unit input cost of the segmented incentive type demand response device d participating in the demand response under the preset first, second, third and fourth demand response steps of the segmented incentive type demand response device d of the power system under scenario s at the dispatch time t; represents the original load demand of the segmented incentive demand response device d of the power system at the dispatching time t under scenario s; b + and b - denote the first and second constants respectively.

5. A transmission and storage coordinated expansion system applicable to the method according to any one of claims 1 to 4, characterized in that: include: The collaborative planning model building module is used to build a segmented incentive transmission and storage collaborative expansion model for power systems that meet transmission and storage constraints; The model solving module is used to input the equipment cost parameters of the power system into the segmented incentive transmission and storage collaborative expansion model for processing, and use a commercial solver to solve it to obtain the number of transmission lines and energy storage equipment in the power system to be expanded.

6. An electronic device, characterized in that: include: A memory and a processor coupled to each other, wherein the memory stores program data, and the processor calls the program data to execute the method according to any one of claims 1 to 4.

7. A computer-readable storage medium having program data stored thereon, characterized in that: When the program data is executed by a processor, the method according to any one of claims 1 to 4 is implemented.

Images