Two-stage resilience enhancement method for integrated energy system considering electricity-gas demand response

Abstract

This invention discloses a two-stage resilience enhancement method for integrated energy systems considering electricity-gas demand response. The method includes: establishing a two-stage resilience enhancement model for the integrated electricity-gas energy system, considering electricity-gas integrated energy dispatch constraints, and inputting operational cost data, unit output cost data, and unit call cost data; using a column and constraint generation algorithm to output the day-ahead state variables of the integrated electricity-gas energy system and the real-time unit output data and unit call load data; controlling the operation of the integrated electricity-gas energy system during the day-ahead phase, and performing optimal dispatching of the integrated electricity-gas energy system's resilience during the real-time phase. This invention can fully consider the adverse effects of extreme weather in the optimized dispatching of integrated electricity-gas energy systems, optimize traditional system dispatchable resources and demand response resources for multi-energy load forms of electricity-gas, and improve the overall ability and resilience of the integrated electricity-gas energy system to withstand extreme weather.

Description

Technical Field

[0001] This invention relates to a method for enhancing the resilience of integrated energy systems, specifically a two-stage method for enhancing the resilience of integrated energy systems that considers electricity and gas demand response. Background Technology

[0002] Currently, with the continuous increase in the installed capacity of new energy units in the power grid, the demand for gas turbine units as a flexible resource is also gradually increasing, thereby strengthening the coupling between the power grid and the natural gas grid. On the other hand, in recent years, extreme weather events have occurred frequently, threatening the reliable operation of both the power grid and the natural gas grid to varying degrees. Improving the resilience of the power grid and the natural gas grid under the adverse effects of extreme weather has become one of the most important goals of the dispatching of integrated power-gas energy systems.

[0003] However, existing research only focuses on regulating resources on the generation and grid sides, which limits the scope of regulation. The potential of demand-side multi-energy complementarity of electricity and gas to enhance system resilience has not been fully explored. Summary of the Invention

[0004] To address the problems existing in the background art, the present invention provides a two-stage integrated energy system resilience enhancement method that considers electricity demand response.

[0005] The technical solution adopted in this invention is:

[0006] The two-stage integrated energy distribution network resilience enhancement method of the present invention includes the following steps:

[0007] 1) Establish an integrated electric-gas energy system. Considering the constraints of integrated electric-gas energy dispatch, establish a two-stage resilience enhancement model for the integrated electric-gas energy system. Obtain the day-ahead operational cost data of the integrated electric-gas energy system one day before encountering an extreme event. At the same time, obtain the real-time unit output cost data and unit call cost data of the integrated electric-gas energy system when encountering an extreme event. Input the operational cost data, unit output cost data, and unit call cost data into the two-stage resilience enhancement model.

[0008] 2) The two-stage resilience enhancement model uses a column and constraint generation algorithm to output the state variables of the integrated electric-gas energy system in the day-ahead stage, and at the same time outputs the unit output data and unit call load data of the integrated electric-gas energy system in the real-time stage.

[0009] 3) Control the operation of the integrated electric-gas energy system in the day-ahead phase based on the output state variables, and perform optimal scheduling of the resilience of the integrated electric-gas energy system in the real-time phase based on the output unit output data and unit call load data, so as to ultimately achieve the two-stage integrated energy distribution network resilience improvement of the integrated electric-gas energy system.

[0010] In step 1), the integrated electric-gas energy system includes a power network and a natural gas network. The power network includes several electrical nodes, generator sets, substations, and electrical load equipment. The electrical nodes are connected to each other through various transmission lines. Each generator set, substation, and electrical load equipment is located at its respective electrical node. Each generator set includes gas turbine units and non-gas turbine units. Each non-gas turbine unit includes coal-fired units, nuclear power units, and hydroelectric units, etc. Each electrical load equipment includes electrical load equipment that consumes conventional electrical load and electrical load equipment that consumes gas load. Conventional electrical load is used for the normal operation of electrical load equipment that is not related to the natural gas network.

[0011] The natural gas network includes several gas nodes, gas source equipment, and gas load equipment. The gas nodes are connected by various gas transmission pipelines. Each gas source equipment and gas load equipment is located on its respective gas node. Each gas source equipment includes conventional gas sources and power-to-gas conversion equipment. Each gas load equipment includes gas load equipment that consumes conventional gas load and gas load equipment that consumes power-to-gas load. Conventional gas load is used for the normal operation of gas load equipment that is independent of the power network.

[0012] The electrical nodes of each gas turbine unit in the power grid are connected to the gas nodes of each gas load device in the natural gas network that consumes the converted load; the gas nodes of each electric-to-gas device in the natural gas network are connected to the electrical nodes of the electric load devices in the power grid that consume the converted load.

[0013] In an integrated electricity-gas energy system, the interdependence between electricity and natural gas includes the gas turbine dependency link and the power-to-gas (EPG) equipment dependency link. The gas turbine dependency link refers to the connection between the electrical node of the gas turbine in the power grid and the gas node in the natural gas network. The EPG dependency link refers to the connection between the electrical node of the EPG equipment in the power grid and the gas node in the natural gas network. The natural gas fuel consumed by the gas turbine for power generation depends on the gas node in the natural gas network; the electrical load required for the EPG to maintain normal operation depends on the electrical node in the power grid. The power grid and the natural gas network are coupled through the gas turbine. On the one hand, the gas turbine is an important power source for the power grid. On the other hand, the gas turbine requires natural gas supplied by the natural gas network as a primary energy source for power generation.

[0014] Based on the characteristics of load-side resources in an integrated electricity-gas energy system, the demand response resources for integrated electricity-gas energy loads are divided into four categories: 1) transferable electrical load; 2) reducible electrical load; 3) transferable gas load; and 4) transferable gas load. Transferable electrical load refers to electrical load that can be shifted to other times of the day, but the total daily electrical load must be met. Reducible electrical load refers to electrical load that can be directly reduced as needed without needing to be replenished in other times. Similarly, transferable gas load refers to gas load that can be shifted to other times of the day, but the total daily gas load must be met. Reducible gas load refers to gas load that can be directly reduced as needed without needing to be replenished in other times. The demand response of electrical load in a given time period equals the sum of transferable and reducible electrical loads; the demand response of gas load in a given time period equals the sum of transferable and reducible gas loads.

[0015] In step 1), considering the constraints of integrated electricity-gas energy dispatch, the two-stage resilience enhancement model of the integrated electricity-gas energy system is established as follows:

[0016]

[0017] in, and These represent the operating cost, startup cost, and shutdown cost of coal-fired unit c in the power grid, respectively. and Let x represent the operating cost, start-up cost, and shutdown cost of the gas turbine unit g in the power grid, respectively; c,t and x g,t Let x represent the operating state variables of coal-fired unit c and gas-fired unit g in the power network during time period t. c,t =1 and x g,t =1 indicates that coal-fired unit c and gas-fired unit g are operating during time period t, respectively, x c,t =0 and x g,t =0 indicates that coal-fired unit c and gas-fired unit g were not operating during time period t; y c,t and y g,t Let y represent the startup state variables of coal-fired unit c and gas-fired unit g in the power grid during time period t. c,t =1 and y g,t =1 indicates that coal-fired unit c and gas-fired unit g are started at time t, that is, coal-fired unit c and gas-fired unit g are not running in time period t-1, but are started and scheduled to run at time t. c,t =0 indicates that the coal-fired unit c and the gas-fired unit g were not started at time t; z c,t and z g,tLet z represent the stationary state variables of coal-fired unit c and gas-fired unit g in the power grid at time t, respectively. c,t =1 and z g,t =1 indicates that coal-fired unit c and gas-fired unit g were stopped at time t, meaning that coal-fired unit c and gas-fired unit g were operating during time period t-1, but stopped and not scheduled to operate at time t. c,t =0 and z g,t =0 indicates that coal-fired unit c and gas-fired unit g were not shut down during time period t; Ψ represents the set of dispatchable variables in the day-ahead phase of the integrated electricity-gas energy system. Let C represent the objective function for scheduling in the day-ahead phase, specifically minimizing the running cost of the day-ahead phase; c and C g Let C represent the unit power output cost of coal-fired unit c and gas-fired unit g in the power network, respectively. gs This represents the cost per unit output gas flow rate of a gas source gs in a natural gas network. and These represent the unit cost of electricity load reduction and the unit cost of electricity load transfer in an integrated electricity-gas energy system, respectively. and These represent the unit cost of reducing gas load and the cost of transferring gas load within an integrated electric-gas energy system, respectively; p c,t and p g,t Let q represent the active power output of coal-fired unit c and gas-fired unit g in the power network during time period t. gs,t This represents the unit output gas flow rate of gas source gs in the natural gas network; and These respectively represent the unit-based reduction and transfer of electrical load within the integrated electric-gas energy system. and Let represent the unit-based gas load reduction and transferable gas load of the integrated electric-gas energy system, respectively; Φ represents the set of variables representing the uncertain impact of extreme events on the integrated electric-gas energy system during the real-time phase. This represents the search for the worst-case impact of extreme events on the integrated electric-gas energy system during the real-time phase; Ξ represents the set of dispatchable variables in the integrated electric-gas energy system during the real-time phase, which includes the active power output p of coal-fired units c and gas-fired units g in the power grid during time period t. c,t and p g,t The unit output gas flow rate q of the gas source gs in the natural gas network gs,t The unit dispatch of the integrated electric-gas energy system can reduce and transfer electrical load. and And the unit dispatch of the integrated electric-gas energy system can reduce gas load and transfer gas load. and This refers to finding the optimal resilience enhancement strategy under the worst-case scenario of extreme events on the integrated electric-gas energy system.

[0018] The aforementioned integrated electricity-gas energy dispatch constraints include day-ahead stage dispatch constraints and real-time stage dispatch constraints of the integrated electricity-gas energy system.

[0019] The operational cost data input to the two-stage resilience enhancement model includes the operating cost, start-up cost, and shutdown cost of coal-fired unit c in the power grid. and And the operating costs, start-up costs, and shutdown costs of gas turbine units g in the power grid. and The unit output cost data mentioned includes the unit power output cost C of coal-fired unit c and gas-fired unit g in the power network. c and C g And the unit output gas flow cost C of gas source gs in the natural gas network. gs The unit call cost data includes the unit call cost of electricity load reduction and the unit call cost of electricity load transfer for the integrated electricity-gas energy system. and Furthermore, the unit dispatch of the integrated electric-gas energy system can reduce gas load costs and transfer gas load costs. and The cost is specifically the amount of electricity or natural gas consumed.

[0020] In step 2), the state variables output by the two-stage resilience enhancement model include the operating state variables x of the coal-fired unit c and the gas-fired unit g in the power grid during time period t. c,t and x g,t The starting state variable y of coal-fired unit c and gas-fired unit g in the power grid during time period t. c,t and y g,t And the stationary state variable z of coal-fired unit c and gas-fired unit g in the power grid at time t. c,t and z g,t The unit output data includes the active power output p of coal-fired units c and gas-fired units g in the power network during time period t. c,t and p g,t and the unit output gas flow rate q of the gas source gs in the natural gas network. gs,t Unit load data includes unit load reduction and transferable loads from the integrated electricity-gas energy system. and And the unit dispatch of the integrated electric-gas energy system can reduce gas load and transfer gas load. and

[0021] The specific day-ahead scheduling constraints are as follows:

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[0040] in, This represents the sum of electrical load demand response resources at electrical node ed, where the electrical load equipment is located in the power network during time period t; and D represents the transferable and reducible electrical loads at electrical nodes ed where the electrical load equipment is located in the power network during time period t; ed,t This represents the total electrical load at electrical node ed, where the electrical load equipment is located in the power network during time period t; This represents the reducible electrical load at the electrical node ed where the electrical load equipment in the power network is located during time period t. D of the total electrical load ed,t The preset maximum ratio; This represents the sum of gas load demand response resources on gas node gd, where the gas load equipment is located in the natural gas network during time period t. and D represents the transferable gas load and the reduceable gas load at the gas node gd where the gas load equipment in the natural gas network is located during time period t; gd,t This represents the total gas load on gas node gd, where the gas load equipment in the natural gas network is located during time period t. This represents the proportion of the total gas load D at the gas node gd where the gas load equipment in the natural gas network is located during time period t. gd,t The maximum proportion; x c,t-1 and x g,t-1 Let x represent the operating state variables of coal-fired unit c and gas-fired unit g in the power grid during time period t-1. c,t-1 =1 and x g,t-1 =1 indicates that coal-fired unit c and gas-fired unit g are operating in time period t-1, respectively. c,t-1 =0 and x g,t-1 =0 indicates that coal-fired unit c and gas-fired unit g were not operating during time period t-1; y c,i and y g,i Let y represent the startup state variables of coal-fired unit c and gas-fired unit g in the power network during time period i, respectively. c,i =1 and y g,i =1 indicates that coal-fired unit c and gas-fired unit g are started at time i, respectively. c,i =0 and y g,i =0 indicates that the coal-fired unit c and the gas-fired unit g were not started at time i; z c,i and z g,i Let z represent the stopping state variables of coal-fired unit c and gas-fired unit g in the power network at time i, respectively. c,i =1 and z g,i =1 indicates that the coal-fired unit c and the gas-fired unit g are stopped at time i, respectively, and z c,i =0 and z g,i =0 indicates that coal-fired unit c and gas-fired unit g were not stopped during time period i; formula x c,t ,y c,t ,z c,t ∈{0,1} and x g,t ,y g,t ,z g,t ∈{0,1} They represent x respectively c,t ,y c,t ,z c,t and x g,t ,yg,t ,z g,t A variable whose value can only be 0 or 1. TU c and TU g Let represent the minimum time interval between the start-up time of coal-fired unit c and the next shutdown time of gas-fired unit g in the power grid, respectively; NT represents the total number of time periods in the day-ahead phase, divided into several time periods; TD c and TD g These represent the minimum time interval between the shutdown time of coal-fired unit c and the next startup time of gas-fired unit g in the power grid, respectively.

[0041] The specific real-time stage scheduling constraints are as follows:

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[0061] Among them, EJ l,t EJ represents the availability of transmission line l in the power network during time period t under extreme events in the real-time phase. l,t =0 indicates that transmission line l in the power network is unavailable during time period t under extreme events in the real-time phase. l,t =1 indicates that transmission line l in the power network is available during time period t under extreme events in the real-time phase; Γ L This represents the maximum number of unavailable transmission lines in the power grid under extreme events during the real-time phase; formula EJ l,t ≥EJ l,t+1 This indicates that if transmission line l is unavailable during time period t, it will remain unavailable during subsequent time periods. (GJ) p,t GJ represents the availability of a gas pipeline p in a natural gas network during time period t under extreme events in the real-time phase. p,t =0 indicates that the gas pipeline p in the natural gas network is unavailable during time period t under extreme events in the real-time phase. p,t =1 indicates that the gas pipeline p in the natural gas network is available in time period t under extreme events during the real-time phase; Γ P This represents the maximum number of unavailable gas pipelines in the natural gas network under extreme events during the real-time phase; formula GJ p,t ≥GJ p,t+1 This indicates that if gas pipeline p is unavailable in time period t, it will remain unavailable in subsequent time periods. NC(m) represents the set of coal-fired power units connected to node m in the power network, NG(m) represents the set of gas-fired power units connected to node m in the power network, and L... fnode (m) represents the set of transmission lines with node m in the power network as the head node, L tnode (m) represents the set of transmission lines with node m in the power network as the tail node, and ED(m) represents the set of gas load devices connected to node m in the power network; p l,t This represents the active power flowing through transmission line l in the power network during time period t; P represents the total electrical load participating in demand response at the electrical node ed where the electrical load equipment is located in the power network; c min and P c max P represents the minimum and maximum active power output of coal-fired unit c in the power network during time period t, respectively. g min and P g max Let p represent the minimum and maximum active power output of the gas turbine unit g in the power network during time period t, respectively;c,t-1 and p g,t-1 These represent the active power outputs of coal-fired unit c and gas-fired unit g in the power network during time period t-1, respectively; RU c and RD c RU represents the maximum uphill ramp rate and the maximum downhill ramp rate of coal-fired unit c in the power network, respectively. g and RD g SU represents the maximum uphill ramp rate and the maximum downhill ramp rate of the gas turbine unit g in the power grid, respectively. c and SU g SD represents the maximum uphill ramp rate of coal-fired unit c and gas-fired unit g in the power grid during the startup phase, respectively. c and SD g θ represents the maximum downhill ramp rate of coal-fired unit c and gas-fired unit g in the power grid during the shutdown phase, respectively; m,t and θ n,t X represents the voltage phase angles of electrical nodes m and n connected to both ends of transmission line l in the power network during time period t, respectively. l θ represents the reactance of transmission line l in a power network. ref,t f represents the voltage at the pre-selected reference node in the power network during time period t; l max Let P represent the maximum active power flowing through transmission line l in the power grid; NGS(n) represents the set of gas sources connected to gas node n in the natural gas network; NG(n) represents the set of gas turbine units connected to gas node n in the natural gas network; P fnode (n) represents the set of gas pipelines with gas node n as the head node in the natural gas network, P tnode GD(n) represents the set of gas pipelines with gas node n as the tail node in the natural gas network, and GD(n) represents the set of gas load equipment connected to gas node n in the natural gas network; q g,t q represents the natural gas gas demand of gas turbine unit g in the power grid during time period t; p,t Q represents the magnitude of the gas flow through a gas pipeline p in a natural gas network during time period t; gd,t This represents the total gas load on the gas node gd where the gas load equipment in the natural gas network is located; This represents the total gas load participating in demand response at the gas node gd where the gas load equipment is located in the natural gas network; the gas flow rate from the gas node n in the natural gas network during time period t is equal to the gas flow rate from the outflow node. η represents the maximum gas flow through pipeline p in a natural gas network; g This represents the conversion coefficient between natural gas and electricity generated by gas turbine unit g in the power grid.

[0062] The set of variables Φ representing the uncertain impact of the extreme event on the integrated electric-gas energy system includes the availability of transmission lines l in the power network during time period t under the extreme event in the real-time phase. l,t The availability of gas pipeline p in the natural gas network during time period t under extreme events in the real-time phase. p,t .

[0063] In step 3), the operation of the integrated electric-gas energy system is controlled according to the output state variables during the day-ahead phase. Specifically, the operation, start-up, and shutdown states of the coal-fired unit c and gas-fired unit g of the integrated electric-gas energy system are controlled according to the state variables during the day-ahead phase. In the real-time phase, the resilience of the integrated electric-gas energy system is optimally scheduled according to the output unit output data and unit call load data. Specifically, the active power output of the coal-fired unit c and gas-fired unit g of the integrated electric-gas energy system, the unit output gas flow rate of the gas source gs, and the unit call load that can be reduced, transferred, reduced, and transferred are determined according to the unit output data and unit call load data in the real-time phase. The resilience of the integrated electric-gas energy system is optimally scheduled, and the two-stage integrated energy distribution network resilience improvement of the integrated electric-gas energy system is finally achieved.

[0064] The beneficial effects of this invention are:

[0065] This invention, taking into full account the deep coupling between power and natural gas networks and the impact of extreme weather on these two networks, seeks an optimal scheduling strategy that enhances the overall resilience of both networks. This method can fully utilize integrated power-gas demand response resources to expand the scheduling space of the integrated power-gas energy system in both day-ahead and real-time phases, thereby better improving the system's ability to withstand extreme conditions and enhancing its overall resilience. Attached Figure Description

[0066] Figure 1 This is a flowchart illustrating the present invention;

[0067] Figure 2 This is a schematic diagram of an embodiment of the electric-gas integrated energy system of the present invention. Detailed Implementation

[0068] The present invention will be further described in detail below with reference to the accompanying drawings and specific embodiments.

[0069] like Figure 1 As shown, the two-stage integrated energy distribution network resilience enhancement method of the present invention includes the following steps:

[0070] 1) Establish an integrated electric-gas energy system. Considering the constraints of integrated electric-gas energy dispatch, establish a two-stage resilience enhancement model for the integrated electric-gas energy system. Obtain the day-ahead operational cost data of the integrated electric-gas energy system one day before encountering an extreme event. At the same time, obtain the real-time unit output cost data and unit call cost data of the integrated electric-gas energy system when encountering an extreme event. Input the operational cost data, unit output cost data, and unit call cost data into the two-stage resilience enhancement model.

[0071] In step 1), the integrated electric-gas energy system includes a power network and a natural gas network. The power network includes several electrical nodes, generator sets, substations, and electrical load equipment. The electrical nodes are connected to each other through various transmission lines. Each generator set, substation, and electrical load equipment is located at its respective electrical node. Each generator set includes gas turbine units and non-gas turbine units. Each non-gas turbine unit includes coal-fired units, nuclear power units, and hydroelectric units, etc. Each electrical load equipment includes electrical load equipment that consumes conventional electrical load and electrical load equipment that consumes gas load. Conventional electrical load is used for the normal operation of electrical load equipment that is not related to the natural gas network.

[0072] The natural gas network includes several gas nodes, gas source equipment, and gas load equipment. The gas nodes are connected by various gas transmission pipelines. Each gas source equipment and gas load equipment is located on its respective gas node. Each gas source equipment includes conventional gas sources and power-to-gas conversion equipment. Each gas load equipment includes gas load equipment that consumes conventional gas load and gas load equipment that consumes power-to-gas load. Conventional gas load is used for the normal operation of gas load equipment that is independent of the power network.

[0073] The electrical nodes of each gas turbine unit in the power grid are connected to the gas nodes of each gas load device in the natural gas network that consumes the converted load; the gas nodes of each electric-to-gas device in the natural gas network are connected to the electrical nodes of the electric load devices in the power grid that consume the converted load.

[0074] In an integrated electricity-gas energy system, the interdependence between electricity and natural gas includes the gas turbine dependency link and the power-to-gas (EPG) equipment dependency link. The gas turbine dependency link refers to the connection between the electrical node of the gas turbine in the power grid and the gas node in the natural gas network. The EPG dependency link refers to the connection between the electrical node of the EPG equipment in the power grid and the gas node in the natural gas network. The natural gas fuel consumed by the gas turbine for power generation depends on the gas node in the natural gas network; the electrical load required for the EPG to maintain normal operation depends on the electrical node in the power grid. The power grid and the natural gas network are coupled through the gas turbine. On the one hand, the gas turbine is an important power source for the power grid. On the other hand, the gas turbine requires natural gas supplied by the natural gas network as a primary energy source for power generation.

[0075] Based on the characteristics of load-side resources in an integrated electricity-gas energy system, the demand response resources for integrated electricity-gas energy loads are divided into four categories: 1) transferable electrical load; 2) reducible electrical load; 3) transferable gas load; and 4) transferable gas load. Transferable electrical load refers to electrical load that can be shifted to other times of the day, but the total daily electrical load must be met. Reducible electrical load refers to electrical load that can be directly reduced as needed without needing to be replenished in other times. Similarly, transferable gas load refers to gas load that can be shifted to other times of the day, but the total daily gas load must be met. Reducible gas load refers to gas load that can be directly reduced as needed without needing to be replenished in other times. The demand response of electrical load in a given time period equals the sum of transferable and reducible electrical loads; the demand response of gas load in a given time period equals the sum of transferable and reducible gas loads.

[0076] In step 1), considering the constraints of integrated electricity-gas energy dispatch, the two-stage resilience enhancement model of the integrated electricity-gas energy system is established as follows:

[0077]

[0078] in, and These represent the operating cost, startup cost, and shutdown cost of coal-fired unit c in the power grid, respectively. and Let x represent the operating cost, start-up cost, and shutdown cost of the gas turbine unit g in the power grid, respectively; c,t and x g,t Let x represent the operating state variables of coal-fired unit c and gas-fired unit g in the power network during time period t. c,t =1 and x g,t =1 indicates that coal-fired unit c and gas-fired unit g are operating during time period t, respectively, x c,t =0 and x g,t =0 indicates that coal-fired unit c and gas-fired unit g were not operating during time period t; y c,t and y g,t Let y represent the startup state variables of coal-fired unit c and gas-fired unit g in the power grid during time period t. c,t =1 and y g,t =1 indicates that coal-fired unit c and gas-fired unit g are started at time t, that is, coal-fired unit c and gas-fired unit g are not running in time period t-1, but are started and scheduled to run at time t. c,t =0 indicates that the coal-fired unit c and the gas-fired unit g were not started at time t; z c,t and zg,t Let z represent the stationary state variables of coal-fired unit c and gas-fired unit g in the power grid at time t, respectively. c,t =1 and z g,t =1 indicates that coal-fired unit c and gas-fired unit g were stopped at time t, meaning that coal-fired unit c and gas-fired unit g were operating during time period t-1, but stopped and not scheduled to operate at time t. c,t =0 and z g,t =0 indicates that coal-fired unit c and gas-fired unit g were not shut down during time period t; Ψ represents the set of dispatchable variables in the day-ahead phase of the integrated electricity-gas energy system. Let C represent the objective function for scheduling in the day-ahead phase, specifically minimizing the running cost of the day-ahead phase; c and C g Let C represent the unit power output cost of coal-fired unit c and gas-fired unit g in the power network, respectively. gs This represents the cost per unit output gas flow rate of a gas source gs in a natural gas network. and These represent the unit cost of electricity load reduction and the unit cost of electricity load transfer in an integrated electricity-gas energy system, respectively. and These represent the unit cost of reducing gas load and the cost of transferring gas load within an integrated electric-gas energy system, respectively; p c,t and p g,t Let q represent the active power output of coal-fired unit c and gas-fired unit g in the power network during time period t. gs,t This represents the unit output gas flow rate of gas source gs in the natural gas network; and These respectively represent the unit-based reduction and transfer of electrical load within the integrated electric-gas energy system. and Let represent the unit-based gas load reduction and transferable gas load of the integrated electric-gas energy system, respectively; Φ represents the set of variables representing the uncertain impact of extreme events on the integrated electric-gas energy system during the real-time phase. This represents the search for the worst-case impact of extreme events on the integrated electric-gas energy system during the real-time phase; Ξ represents the set of dispatchable variables in the integrated electric-gas energy system during the real-time phase, which includes the active power output p of coal-fired units c and gas-fired units g in the power grid during time period t. c,t and p g,t The unit output gas flow rate q of the gas source gs in the natural gas network gs,t The unit dispatch of the integrated electric-gas energy system can reduce and transfer electrical load. and And the unit dispatch of the integrated electric-gas energy system can reduce gas load and transfer gas load. and This refers to finding the optimal resilience enhancement strategy under the worst-case scenario of extreme events on the integrated electric-gas energy system.

[0079] The constraints of integrated power-gas energy dispatch include day-ahead stage dispatch constraints and real-time stage dispatch constraints of integrated power-gas energy systems.

[0080] The operational cost data input to the two-stage resilience enhancement model includes the operating cost, start-up cost, and shutdown cost of coal-fired unit c in the power grid. and And the operating costs, start-up costs, and shutdown costs of gas turbine units g in the power grid. and Unit output cost data includes the unit power output cost C of coal-fired unit c and gas-fired unit g in the power network. c and C g And the unit output gas flow cost C of gas source gs in the natural gas network. gs The unit call cost data includes the unit call cost of electricity load reduction and the unit call cost of electricity load transfer for the integrated electricity-gas energy system. and Furthermore, the unit dispatch of the integrated electric-gas energy system can reduce gas load costs and transfer gas load costs. and The cost is specifically the amount of electricity or natural gas consumed.

[0081] 2) The two-stage resilience enhancement model uses a column and constraint generation algorithm to output the state variables of the integrated electric-gas energy system in the day-ahead stage, and at the same time outputs the unit output data and unit call load data of the integrated electric-gas energy system in the real-time stage.

[0082] In step 2), the state variables output by the two-stage resilience enhancement model include the operating state variables x of coal-fired unit c and gas-fired unit g in the power grid during time period t. c,t and x g,t The starting state variable y of coal-fired unit c and gas-fired unit g in the power grid during time period t. c,t and y g,t And the stationary state variable z of coal-fired unit c and gas-fired unit g in the power grid at time t. c,t and z g,t The unit output data includes the active power output p of coal-fired units c and gas-fired units g in the power network during time period t. c,t and p g,t and the unit output gas flow rate q of the gas source gs in the natural gas network. gs,tUnit load data includes unit load reduction and transferable loads from the integrated electricity-gas energy system. and And the unit dispatch of the integrated electric-gas energy system can reduce gas load and transfer gas load. and

[0083] The specific scheduling constraints for the current phase are as follows:

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[0102] in, This represents the sum of electrical load demand response resources at electrical node ed, where the electrical load equipment is located in the power network during time period t; and D represents the transferable and reducible electrical loads at electrical nodes ed where the electrical load equipment is located in the power network during time period t; ed,t This represents the total electrical load at electrical node ed, where the electrical load equipment is located in the power network during time period t; This represents the reducible electrical load at the electrical node ed where the electrical load equipment in the power network is located during time period t. D of the total electrical load ed,t The preset maximum ratio; This represents the sum of gas load demand response resources on gas node gd, where the gas load equipment is located in the natural gas network during time period t. and D represents the transferable gas load and the reduceable gas load at the gas node gd where the gas load equipment in the natural gas network is located during time period t; gd,t This represents the total gas load on gas node gd, where the gas load equipment in the natural gas network is located during time period t. This represents the proportion of the total gas load D at the gas node gd where the gas load equipment in the natural gas network is located during time period t. gd,t The maximum proportion; x c,t-1 and x g,t-1 Let x represent the operating state variables of coal-fired unit c and gas-fired unit g in the power grid during time period t-1. c,t-1 =1 and x g,t-1 =1 indicates that coal-fired unit c and gas-fired unit g are operating in time period t-1, respectively. c,t-1 =0 and x g,t-1 =0 indicates that coal-fired unit c and gas-fired unit g were not operating during time period t-1; y c,i and y g,i Let y represent the startup state variables of coal-fired unit c and gas-fired unit g in the power network during time period i, respectively. c,i =1 and y g,i =1 indicates that coal-fired unit c and gas-fired unit g are started at time i, respectively. c,i =0 and y g,i =0 indicates that the coal-fired unit c and the gas-fired unit g were not started at time i; z c,i and z g,i Let z represent the stopping state variables of coal-fired unit c and gas-fired unit g in the power network at time i, respectively. c,i =1 and z g,i =1 indicates that the coal-fired unit c and the gas-fired unit g are stopped at time i, respectively, and z c,i =0 and z g,i =0 indicates that coal-fired unit c and gas-fired unit g were not stopped during time period i; formula x c,t ,y c,t ,z c,t∈{0,1} and x g,t ,y g,t ,z g,t ∈{0,1} They represent x respectively c,t ,y c,t ,z c,t and x g,t ,y g,t ,z g,t A variable whose value can only be 0 or 1. TU c and TU g Let represent the minimum time interval between the start-up time of coal-fired unit c and the next shutdown time of gas-fired unit g in the power grid, respectively; NT represents the total number of time periods in the day-ahead phase, divided into several time periods; TD c and TD g These represent the minimum time interval between the shutdown time of coal-fired unit c and the next startup time of gas-fired unit g in the power grid, respectively.

[0103] The specific real-time stage scheduling constraints are as follows:

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[0123] Among them, EJ l,t EJ represents the availability of transmission line l in the power network during time period t under extreme events in the real-time phase. l,t =0 indicates that transmission line l in the power network is unavailable during time period t under extreme events in the real-time phase. l,t =1 indicates that transmission line l in the power network is available during time period t under extreme events in the real-time phase; Γ L This represents the maximum number of unavailable transmission lines in the power grid under extreme events during the real-time phase; formula EJ l,t ≥EJ l,t+1 This indicates that if transmission line l is unavailable during time period t, it will remain unavailable during subsequent time periods. (GJ) p,t GJ represents the availability of a gas pipeline p in a natural gas network during time period t under extreme events in the real-time phase. p,t =0 indicates that the gas pipeline p in the natural gas network is unavailable during time period t under extreme events in the real-time phase. p,t =1 indicates that the gas pipeline p in the natural gas network is available in time period t under extreme events during the real-time phase; Γ P This represents the maximum number of unavailable gas pipelines in the natural gas network under extreme events during the real-time phase; formula GJ p,t ≥GJ p,t+1 This indicates that if gas pipeline p is unavailable in time period t, it will remain unavailable in subsequent time periods. NC(m) represents the set of coal-fired power units connected to node m in the power network, NG(m) represents the set of gas-fired power units connected to node m in the power network, and L... fnode (m) represents the set of transmission lines with node m in the power network as the head node, L tnode (m) represents the set of transmission lines with node m in the power network as the tail node, and ED(m) represents the set of gas load devices connected to node m in the power network; p l,t This represents the active power flowing through transmission line l in the power network during time period t; P represents the total electrical load participating in demand response at the electrical node ed where the electrical load equipment is located in the power network; c min and P cmax P represents the minimum and maximum active power output of coal-fired unit c in the power network during time period t, respectively. g min and P g max Let p represent the minimum and maximum active power output of the gas turbine unit g in the power network during time period t, respectively; c,t-1 and p g,t-1 These represent the active power outputs of coal-fired unit c and gas-fired unit g in the power network during time period t-1, respectively; RU c and RD c RU represents the maximum uphill ramp rate and the maximum downhill ramp rate of coal-fired unit c in the power network, respectively. g and RD g SU represents the maximum uphill ramp rate and the maximum downhill ramp rate of the gas turbine unit g in the power grid, respectively. c and SU g SD represents the maximum uphill ramp rate of coal-fired unit c and gas-fired unit g in the power grid during the startup phase, respectively. c and SD g θ represents the maximum downhill ramp rate of coal-fired unit c and gas-fired unit g in the power grid during the shutdown phase, respectively; m,t and θ n,t X represents the voltage phase angles of electrical nodes m and n connected to both ends of transmission line l in the power network during time period t, respectively. l θ represents the reactance of transmission line l in a power network. ref,t f represents the voltage at the pre-selected reference node in the power network during time period t; l max Let P represent the maximum active power flowing through transmission line l in the power grid; NGS(n) represents the set of gas sources connected to gas node n in the natural gas network; NG(n) represents the set of gas turbine units connected to gas node n in the natural gas network; P fnode (n) represents the set of gas pipelines with gas node n as the head node in the natural gas network, P tnode GD(n) represents the set of gas pipelines with gas node n as the tail node in the natural gas network, and GD(n) represents the set of gas load equipment connected to gas node n in the natural gas network; q g,t q represents the natural gas gas demand of gas turbine unit g in the power grid during time period t; p,t Q represents the magnitude of the gas flow through a gas pipeline p in a natural gas network during time period t; gd,t This represents the total gas load on the gas node gd where the gas load equipment in the natural gas network is located; This represents the total gas load participating in demand response at the gas node gd where the gas load equipment is located in the natural gas network; the gas flow rate from the gas node n in the natural gas network during time period t is equal to the gas flow rate from the outflow node. η represents the maximum gas flow through pipeline p in a natural gas network; g This represents the conversion coefficient between natural gas and electricity generated by gas turbine unit g in the power grid.

[0124] The set of variables Φ representing the uncertain impact of extreme events on the integrated power-electricity energy system includes the availability of transmission lines l in the power grid during time period t under extreme events in the real-time phase (EJ). l,t The availability of gas pipeline p in the natural gas network during time period t under extreme events in the real-time phase. p,t .

[0125] 3) Control the operation of the integrated electric-gas energy system in the day-ahead phase based on the output state variables, and perform optimal scheduling of the resilience of the integrated electric-gas energy system in the real-time phase based on the output unit output data and unit call load data, so as to ultimately achieve the two-stage integrated energy distribution network resilience improvement of the integrated electric-gas energy system.

[0126] In step 3), the operation of the integrated electric-gas energy system is controlled according to the output state variables during the day-ahead phase. Specifically, the operation, start-up, and shutdown states of the coal-fired unit c and gas-fired unit g of the integrated electric-gas energy system are controlled according to the state variables during the day-ahead phase. In the real-time phase, the resilience of the integrated electric-gas energy system is optimally scheduled according to the output unit output data and unit call load data. Specifically, the active power output of the coal-fired unit c and gas-fired unit g, the unit output gas flow rate of the gas source gs, and the unit call load that can be reduced, transferred, reduced, and transferred are determined according to the unit output data and unit call load data in the real-time phase. The optimal scheduling of the resilience of the integrated electric-gas energy system is then performed, ultimately achieving a two-stage integrated energy distribution network resilience improvement for the integrated electric-gas energy system.

[0127] Specific embodiments of the present invention are as follows:

[0128] like Figure 2 As shown, taking the integrated electric-gas energy system consisting of an IEEE 30-node power network and a Belgian 20-node natural gas network as an example, the specific implementation of the present invention is described in detail with reference to the technical solution and accompanying drawings.

[0129] The two-stage integrated energy system resilience enhancement method considering electricity-gas demand response proposed in this invention is compared with the traditional two-stage scheduling method for integrated electricity-gas energy systems. The total cost can be quantitatively reflected to reflect the magnitude of system resilience. The results are shown in the table below.

[0130] method Total cost Current stage costs Real-time stage cost Method of the present invention <![CDATA[1.367×10 9 ]]> <![CDATA[0.349×10 9 ]]> <![CDATA[1.018×10 9 ]]> Traditional methods <![CDATA[2.289×10 9 ]]> <![CDATA[0.687×10 9 ]]> <![CDATA[1.602×10 9 ]]>

[0131] Therefore, this invention improves the overall resilience of the integrated electric-gas energy system by considering the worst-case impact of extreme weather on the system and by introducing demand response resources in the form of multi-energy loads, thus achieving its technical effect.

Claims

1. A two-stage integrated energy distribution network resilience enhancement method considering electricity demand response, characterized in that: Includes the following steps: 1) Establish an integrated electric-gas energy system. Considering the constraints of integrated electric-gas energy dispatch, establish a two-stage resilience improvement model for the integrated electric-gas energy system. Obtain the day-ahead operational cost data of the integrated electric-gas energy system one day before encountering an extreme event. At the same time, obtain the real-time unit output cost data and unit call cost data of the integrated electric-gas energy system when encountering an extreme event. Input the operational cost data, unit output cost data, and unit call cost data into the two-stage resilience improvement model. 2) The two-stage resilience enhancement model uses a column and constraint generation algorithm to output the state variables of the integrated electric-gas energy system in the day-ahead stage, and simultaneously outputs the unit output data and unit call load data of the integrated electric-gas energy system in the real-time stage; 3) Control the operation of the integrated power-gas energy system in the day-ahead phase based on the output state variables, and perform optimal scheduling of the resilience of the integrated power-gas energy system in the real-time phase based on the output unit output data and unit call load data, so as to ultimately achieve the two-stage integrated energy distribution network resilience improvement of the integrated power-gas energy system. In step 1), considering the constraints of integrated electricity-gas energy dispatch, the two-stage resilience enhancement model of the integrated electricity-gas energy system is established as follows: in, , and These represent coal-fired power units in the power grid. The operating costs, startup costs, and shutdown costs; , and These represent gas turbine units in the power grid. The operating costs, startup costs, and shutdown costs; and These represent coal-fired power units in the power grid. and gas turbine units The running state variables in time period t, and They represent coal-fired power units and gas turbine units Run during time period t and They represent coal-fired power units and gas turbine units It was not run during time period t; and These represent coal-fired power units in the power grid. and gas turbine units The startup state variable in time period t and They represent coal-fired power units and gas turbine units It is started at time t. and They represent coal-fired power units and gas turbine units It was not started at time t; and These represent coal-fired power units in the power grid. and gas turbine units The stopping state variable at time t, and They represent coal-fired power units and gas turbine units The process is stopped at time t. and They represent coal-fired power units and gas turbine units It was not stopped during time period t; This represents the set of dispatchable variables in the day-ahead phase of the integrated electric-gas energy system; and These represent coal-fired power units in the power grid. and gas turbine units The cost per unit power output, Indicates the gas source in the natural gas network Cost per unit output gas flow rate; and These represent the unit cost of electricity load reduction and the unit cost of electricity load transfer in an integrated electricity-gas energy system, respectively. and These represent the unit gas load reduction cost and the gas load transfer cost of the integrated electric-gas energy system, respectively. and These represent coal-fired power units in the power grid. and gas turbine units During the period Active power output, Indicates the gas source in the natural gas network Unit output gas flow rate; and These respectively represent the unit-based reduction and transfer of electrical load within the integrated electric-gas energy system. and These respectively represent the unit gas load reduction and the gas load transfer capability of the integrated electric-gas energy system; The set of variables representing the uncertain impact of extreme events on the integrated electric-gas energy system in the real-time stage; This represents the set of dispatchable variables in a real-time integrated electricity-gas energy system, which includes coal-fired power units in the power grid. and gas turbine units Time period active power output and Gas sources in natural gas networks Unit output gas flow rate The unit dispatch of the integrated electric-gas energy system can reduce and transfer electrical load. and And the unit dispatch of the integrated electric-gas energy system can reduce gas load and transfer gas load. and .

2. The two-stage integrated energy distribution network resilience enhancement method considering electricity demand response as described in claim 1, characterized in that: In step 1), the integrated electric-gas energy system includes a power network and a natural gas network. The power network includes several power nodes, generator sets, substations, and electrical load equipment. The power nodes are connected to each other through various transmission lines. Each generator set, substation, and electrical load equipment is located at its respective power node. Each generator set includes gas turbine units and non-gas turbine units. Each non-gas turbine unit includes coal-fired units, nuclear power units, and hydroelectric units. Each electrical load equipment includes electrical load equipment that consumes electrical load and electrical load equipment that consumes gas load. The natural gas network includes several gas nodes, gas source equipment and gas load equipment. The gas nodes are connected by various gas transmission pipelines. Each gas source equipment and gas load equipment is located on its respective gas node. Each gas source equipment includes gas source and power-to-gas equipment. Each gas load equipment includes gas load equipment that consumes gas load and gas load equipment that consumes power load. The electrical nodes of each gas turbine unit in the power grid are connected to the gas nodes of each gas load device in the natural gas network that consumes the converted load; the gas nodes of each electric-to-gas device in the natural gas network are connected to the electrical nodes of the electric load devices in the power grid that consume the converted load.

3. The two-stage integrated energy distribution network resilience enhancement method considering electricity demand response as described in claim 2, characterized in that: In step 1), the integrated power-gas energy dispatch constraints include day-ahead stage dispatch constraints and real-time stage dispatch constraints of the integrated power-gas energy system. The operational cost data input to the two-stage resilience enhancement model includes coal-fired power units in the power grid. Operating costs, startup costs, and shutdown costs , and And gas turbine units in the power grid Operating costs, startup costs, and shutdown costs , and The unit output cost data mentioned includes coal-fired power units in the power grid. and gas turbine units unit power output cost and and gas sources in the natural gas network Cost per unit output gas flow The unit call cost data includes the unit call cost of electricity load reduction and the unit call cost of electricity load transfer for the integrated electricity-gas energy system. and Furthermore, the unit dispatch of the integrated electric-gas energy system can reduce gas load costs and transfer gas load costs. and ; In step 2), the state variables output by the two-stage resilience enhancement model include coal-fired power units in the power grid. and gas turbine units Running state variables in time period t and Coal-fired power units in the power grid and gas turbine units Startup state variables in time period t and And coal-fired power units in the power grid and gas turbine units The stopping state variable at time t and The unit output data includes coal-fired power units in the power network. and gas turbine units Time period active power output and and gas sources in the natural gas network Unit output gas flow rate Unit load data includes unit load reduction and transferable loads from the integrated electricity-gas energy system. and And the unit dispatch of the integrated electric-gas energy system can reduce gas load and transfer gas load. and .

4. The two-stage integrated energy distribution network resilience enhancement method considering electricity demand response as described in claim 3, characterized in that: The specific day-ahead scheduling constraints are as follows: in, This represents the sum of electrical load demand response resources at electrical node ed, where the electrical load equipment is located in the power network during time period t; and These represent the transferable electrical load and the reducible electrical load at the electrical node ed where the electrical load equipment is located in the power network during time period t, respectively. Indicates time period The total electrical load at the electrical node ed where the electrical load equipment is located in the power network; Indicates time period Reduceable electrical load at electrical node ed where electrical load equipment is located in the power network Total electrical load The preset maximum ratio; This represents the sum of gas load demand response resources on gas node gd, where the gas load equipment is located in the natural gas network during time period t. and These represent the transferable gas load and the reducible gas load on the gas node gd where the gas load equipment is located in the natural gas network during time period t, respectively. This represents the total gas load on gas node gd, where the gas load equipment in the natural gas network is located during time period t. This indicates that the reducible gas load at gas node gd, where the gas load equipment is located in the natural gas network during time period t, represents the proportion of the total gas load. The maximum proportion; and These represent coal-fired power units in the power grid. and gas turbine units The running state variables in time period t-1 and They represent coal-fired power units and gas turbine units Running during time period t-1, and They represent coal-fired power units and gas turbine units It was not run during time period t-1; and These represent coal-fired power units in the power grid. and gas turbine units The startup state variable in time period i and They represent coal-fired power units and gas turbine units At time i, it is started. and They represent coal-fired power units and gas turbine units It was not started at time i; and These represent coal-fired power units in the power grid. and gas turbine units The stopping state variable at time i, and They represent coal-fired power units and gas turbine units At time i, the process is stopped. and They represent coal-fired power units and gas turbine units It was not stopped during time period i; and These represent coal-fired power units in the power grid. and gas turbine units The minimum time interval between the start time and the next shutdown time. This indicates the division of the day-ahead period into several time periods, and the total number of time periods within the day-ahead period; and These represent coal-fired power units in the power grid. and gas turbine units The minimum time interval between the shutdown time and the next startup time.

5. The two-stage integrated energy distribution network resilience enhancement method considering electricity demand response as described in claim 3, characterized in that: The specific real-time stage scheduling constraints are as follows: in, This refers to the transmission lines in the power network under extreme events during the real-time phase. During the period Availability, This refers to the transmission lines in the power network under extreme events during the real-time phase. During the period Unavailable This refers to the transmission lines in the power network under extreme events during the real-time phase. During the period Available; This represents the maximum number of unavailable transmission lines in the power grid under extreme events during the real-time phase. This refers to gas pipelines in a natural gas network under extreme events during the real-time phase. During the period Availability, This refers to gas pipelines in a natural gas network under extreme events during the real-time phase. During the period Unavailable This refers to gas pipelines in a natural gas network under extreme events during the real-time phase. During the period Available; This represents the maximum number of unavailable gas pipelines in the natural gas network under extreme events during the real-time phase. Represents nodes in the power network A collection of interconnected coal-fired power units. Represents nodes in the power network A collection of interconnected gas turbine units. Representing nodes in a power network The collection of transmission lines that serve as head nodes. Representing nodes in a power network The collection of transmission lines that serve as tail nodes. Represents nodes in the power network A collection of connected air load devices; Represents transmission lines in a power network superior The active power flowing through a given time period; This represents the total electrical load participating in demand response at the electrical node ed where the electrical load equipment is located in the power network; and These represent coal-fired power units in the power grid. During the period The minimum and maximum active power output; and These represent gas turbine units in the power grid. During the period The minimum and maximum active power output; and These represent coal-fired power units in the power grid. and gas turbine units During the period The active power output; and These represent coal-fired power units in the power grid. Maximum operating uphill rate and maximum operating downhill rate, and These represent gas turbine units in the power grid. Maximum operating uphill rate and maximum operating downhill rate, and These represent coal-fired power units in the power grid. and gas turbine units Maximum uphill rate during the startup phase and These represent coal-fired power units in the power grid. and gas turbine units Maximum downhill rate during shutdown; and They represent time periods respectively. Transmission lines in the power grid The voltage phase angle between electrical nodes m and n connected at both ends, Represents transmission lines in a power network Reactance, Indicates time period Voltage at a pre-selected reference node in a power network; Represents transmission lines in a power network The maximum active power flowing upstream; Indicates gas nodes in the natural gas network A collection of interconnected gas sources. Indicates gas nodes in the natural gas network A collection of interconnected gas turbine units. Represents gas nodes in a natural gas network The collection of gas pipelines that serve as head nodes. Represents gas nodes in a natural gas network A collection of gas pipelines serving as tail nodes. Indicates gas nodes in the natural gas network A collection of connected air load devices; Indicates gas turbine units in the power grid exist The size of natural gas flow demand during a given time period; Indicates gas pipelines in a natural gas network superior The magnitude of the airflow during a given period; This represents the total gas load on the gas node gd where the gas load equipment in the natural gas network is located; This represents the total gas load participating in demand response at the gas node gd where the gas load equipment is located in the natural gas network. Indicates gas pipelines in a natural gas network The maximum airflow passing through the middle; Indicates gas turbine units in the power grid The conversion factor between natural gas and electricity generation; The set of variables describing the uncertain impact of the extreme events on the integrated electric-gas energy system Including transmission lines in the power grid under real-time extreme events. During the period Availability Gas pipelines in natural gas networks under real-time extreme events During the period Availability .

6. The two-stage integrated energy distribution network resilience enhancement method considering electricity demand response as described in claim 3, characterized in that: In step 3), the operation of the integrated electric-gas energy system during the day-ahead phase is controlled based on the output state variables. Specifically, this involves controlling the coal-fired units of the integrated electric-gas energy system based on the state variables. and gas turbine units The system monitors the operating, startup, and shutdown statuses during the daytime phase. Based on the unit output data and unit load data, optimal scheduling of the integrated power-gas energy system's resilience is performed in the real-time phase. Specifically, this involves determining the coal-fired power units of the integrated power-gas energy system based on the unit output data and unit load data in the real-time phase. and gas turbine units Active power output, gas source The system optimizes the resilience of the integrated energy distribution network by calculating the unit output gas flow rate and the unit callable electrical load reduction, electrical load transfer, gas load reduction, and gas load transfer of the integrated energy system, ultimately achieving a two-stage improvement in the resilience of the integrated energy distribution network.

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