Electricity and natural gas joint dispatching method and system for multi-energy interaction

Abstract

The present invention provides a method and system for joint dispatching of electricity and natural gas in the context of multi-energy interaction, comprising: predicting current electricity price data and natural gas price data; using a participant decision model to obtain current electricity quotations and corresponding sales volumes as well as current natural gas quotations and corresponding sales volumes; establishing an energy optimization transaction model to obtain optimal electricity prices and corresponding transaction volumes as well as optimal natural gas prices and corresponding transaction volumes, and obtaining electricity clearing information and natural gas clearing information; verifying the power system and the natural gas system in turn based on the clearing information of electricity and natural gas, respectively, and if the market clearing information does not meet the safety constraint requirements of the power system and the natural gas system, respectively adjusting the clearing information of the power system and the natural gas system using a power system re-dispatching model and a natural gas system re-dispatching model until their respective preset safety constraint requirements are met.

Description

Technical Field

[0001] The present invention relates to the technical field of electric power dispatching automation, and in particular to a method and system for coordinated dispatching of an electric power system and a natural gas system. Background Art

[0002] At present, the research on power and natural gas dispatching generally takes into account the physical property differences between the power system and the natural gas system, and only relies on the natural gas generators participating in the two systems to transmit system information. The power system and the natural gas system are still dispatched independently.

[0003] The coupling relationship between electric energy and natural gas energy is constantly intensifying. However, the existing technology lacks consideration of the interaction between the electricity market and the natural gas market, resulting in the inability to guide the joint dispatch of the two systems with reasonable market price signals. At the same time, energy market participants, energy market operators, and energy system operators lack technical support and cannot cooperate reasonably, which limits the coordinated dispatch of electricity and natural gas in the context of multi-energy interaction. In response to the above problems, the present invention provides a method and system for the joint dispatch of an electric power system and a natural gas system, which can provide a reference for the construction of an electric power-natural gas market and system under a highly coupled relationship.

[0004] Patent document CN107909509A (application number: 201711007017.X) discloses a method for joint dispatching of electricity and natural gas for information collaborative interaction. The power grid control system of the gas power plant is combined with the gas grid control system of the natural gas by using the power grid joint dispatching system for coordinated interaction, and the maximum and minimum output limit values ​​of the gas power plant are used as constraints for the power grid dispatching power generation plan to formulate a real-time dispatching operation plan for the entire network.

[0005] The present invention, on the basis of considering the physical characteristics of the two systems, establishes a coordination method for the electricity market and the natural gas market, guides the joint dispatch of the two systems by obtaining the optimal price signal, and at the same time follows the physical characteristic constraints of the two systems. Specifically, in the market operator module, electricity and natural gas coupling transactions are organized to give full play to the coupling utility of the two energy sources, and the obtained electricity and natural gas clearing information is transmitted to the system operator module. After the system operator module receives the information transmitted by the market operator module, the power system and the natural gas system respectively perform verification and re-dispatch on this basis to meet their respective physical constraint requirements. Summary of the invention

[0006] In view of the defects in the prior art, the object of the present invention is to provide a method and system for joint scheduling of electricity and natural gas in the context of multi-energy interaction.

[0007] According to the present invention, a method for joint dispatching of electricity and natural gas in a multi-energy interaction context includes:

[0008] Step S1: The market participant module predicts current electricity price data and natural gas price data through historical data;

[0009] Step S2: The market participant module uses the participant decision model to obtain the current electricity price and the corresponding sales volume and the current natural gas price and the corresponding sales volume;

[0010] Step S3: The market operator module uses the energy optimization transaction model to obtain the optimal electricity price and corresponding transaction volume and the optimal natural gas price and corresponding transaction volume, thereby realizing the joint clearing of electricity and natural gas transactions in the energy optimization transaction model and obtaining electricity clearing information and natural gas clearing information;

[0011] Step S4: The system operator module verifies the power system and the natural gas system in turn based on the clearing information of electricity and natural gas respectively. If the market clearing information does not meet the security constraint requirements of the power system and the natural gas system, the power system re-dispatch model and the natural gas system re-dispatch model are used to adjust the clearing information of the power system and the natural gas system respectively until the respective preset security constraint requirements are met;

[0012] The participant decision model is based on the predicted electricity price and natural gas price to obtain its own quotation and corresponding sales volume under its own physical constraints;

[0013] The energy optimization transaction model aims at the economic efficiency of market operation, and obtains the optimal electricity energy price and corresponding transaction volume and the optimal natural gas energy price and corresponding transaction volume according to the quotations and corresponding sales volumes in the electricity market and the quotations and corresponding sales volumes in the natural gas market;

[0014] The power system redispatching model and the natural gas system redispatching model both take redispatching economic efficiency as the goal and determine the redispatching electricity and natural gas quantities to meet the safe dispatching requirements of the power system and the natural gas system.

[0015] Preferably, the participant decision model adopts:

[0016]

[0017]

[0018]

[0019]

[0020]

[0021]

[0022]

[0023] Among them, formulas (1) to (4) represent the bidding model of the market participant module that owns the gas turbine; subscript v represents unit v; subscript w represents gas well w; subscripts i, j represent nodes i, j in the power network; subscripts m, n represent nodes m, n in the natural gas pipeline network; subscript t represents time t; subscript b represents stage b in the segmented bidding; formula (1) represents that the market participant module optimizes the bidding strategy with the goal of minimizing its own cost; is the clearing price of electricity commodity in coupled transactions; is the clearing price of natural gas commodity in the coupled transaction; The electricity price generated when the power system is redispatched; The natural gas price generated when the natural gas system is redispatched; The transaction volume of electricity commodities in coupled transactions; The amount of electricity redispatched to the power system; The cost of electricity generation from gas turbines; is the energy conversion rate of the gas turbine; Formula (2) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (3) represents the output constraint of the gas turbine; is the maximum output of the gas turbine; Formula (4) represents the ramp constraint of the gas turbine; are the upper and lower limits of ramping capability, respectively; Formulas (5) to (7) represent the bidding model of market participants with natural gas wells; Formula (5) represents the optimization of bidding strategies by market participants with the goal of minimizing their own costs; is the volume of natural gas commodities in coupled transactions; the amount of natural gas redispatched to the natural gas system; is the operating cost of the natural gas well; Formula (6) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (7) represents the gas supply constraint of the natural gas well; Maximum gas supply capacity for gas turbines; Represents the clearing price of natural gas commodity in coupled transactions.

[0024] Preferably, the energy optimization trading model adopts:

[0025]

[0026]

[0027]

[0028]

[0029] Among them, formula (8) represents the maximization of the total social benefits of the coupled electricity and natural gas markets; formula (9) represents the balance of supply and demand of electricity commodities; It is the forecast value of renewable energy power generation output; is the predicted value of electricity demand in the market; formula (10) represents the supply and demand balance of natural gas commodities; is the predicted value of natural gas demand in the market; formula (11) represents the gas-electricity conversion relationship of the gas turbine; The amount of natural gas required to power the gas turbines in the coupling transaction.

[0030] Preferably, the step S4 adopts: checking whether the power clearing information meets the power security demand constraints of power dispatching, and if so, dispatching the power based on the current power clearing information; if not, adjusting the clearing information of the power system using the power system re-dispatching model to meet the power security dispatching requirements.

[0031] Preferably, the power system redispatching model adopts:

[0032]

[0033]

[0034] -π≤θ i,t ≤π (14)

[0035]

[0036] Wherein, formula (12) represents the dispatch of electricity with the lowest redispatch cost as the objective function; The amount of reduction in power output for renewable energy; is the demand response amount; price penalties for renewable energy cuts; is the cost of demand response; Formula (13) represents the power balance of the power system maintained by appropriate redispatch after considering physical constraints; Formula (14) represents the phase angle constraint of power; θ i,t is the phase angle at a certain node; Formula (15) represents the capacity constraint of the power network line; B i,j is the susceptance matrix of the electric power; is the upper limit of the capacity of the power network line; θ j,trepresents the phase angle at node j.

[0037] Preferably, step S4 adopts: checking whether the natural gas clearing information meets the natural gas safety demand constraint of natural gas scheduling, and if so, scheduling the natural gas based on the current natural gas clearing information; if not, adjusting the clearing information of the natural gas system using the natural gas system rescheduling model to meet the demand for natural gas safety scheduling.

[0038] Preferably, the natural gas system rescheduling model adopts:

[0039]

[0040]

[0041] (q m,n,t / W m,n ) 2 =|r m,t 2 -r n,t 2 | (18)

[0042]

[0043]

[0044] x m,n ={0,1} (21)

[0045]

[0046] Wherein, formula (16) represents the dispatch of natural gas with the lowest redispatch cost as the objective function; is the demand response amount; is the cost of demand response; Formula (17) represents the balance between natural gas supply and demand through appropriate redispatching after considering physical constraints; Formula (18) represents the relationship between the natural gas flow rate and the pressure at both ends of the pipeline network; q m,n,t is the airflow in the pipe mn; r m,t is the air pressure at node m; W m,n is the Weymouth constant; Formula (19) represents the node pressure constraint; is the maximum air pressure constraint of the node; is the minimum gas pressure constraint at the node; Formula (20) represents the capacity constraint of the natural gas pipeline network; natural gas transmission is different from power transmission. The transmission direction cannot be changed arbitrarily and must be transmitted continuously for a certain period of time in a certain transmission direction; x m,n Represents the transmission direction of a pipeline; it is a 0-1 variable; is the upper limit of natural gas transmission in the pipeline network; Formula (22) represents the relationship between the output of the gas turbine adjusted by power redispatching and the natural gas consumption; The amount of natural gas required by the gas turbine after power redispatch; It is expressed as the amount of natural gas required by the gas turbine in the coupled transaction; represents the forecast value of natural gas demand in the market; r n,t Represents the air pressure at node n.

[0047] According to the present invention, a combined dispatching system of electricity and natural gas for use in a multi-energy interaction context includes:

[0048] Market participant module: predicts current electricity price data and natural gas price data through historical data, and uses the participant decision model to obtain the current electricity quotation and corresponding sales volume, as well as the current natural gas quotation and corresponding sales volume;

[0049] Market operator module: using the energy optimization trading model to obtain the optimal electricity price and corresponding transaction volume as well as the optimal natural gas price and corresponding transaction volume, thereby achieving the joint clearing of electricity and natural gas transactions in the energy optimization trading model and obtaining electricity clearing information and natural gas clearing information;

[0050] System operator module: The power system and the natural gas system are verified in turn based on the clearing information of electricity and natural gas respectively. If the market clearing information does not meet the security constraint requirements of the power system and the natural gas system, the clearing information of the power system and the natural gas system is adjusted using the power system redispatch model and the natural gas system redispatch model respectively until the preset security constraint requirements are met;

[0051] The participant decision model is based on the predicted electricity price and natural gas price to obtain its own quotation and corresponding sales volume under its own physical constraints;

[0052] The energy optimization transaction model aims at the economic efficiency of market operation, and obtains the optimal electricity energy price and corresponding transaction volume and the optimal natural gas energy price and corresponding transaction volume according to the quotations and corresponding sales volumes in the electricity market and the quotations and corresponding sales volumes in the natural gas market;

[0053] The power system redispatching model and the natural gas system redispatching model both take redispatching economic efficiency as the goal and determine the redispatching electricity and natural gas quantities to meet the safe dispatching requirements of the power system and the natural gas system.

[0054] Preferably, the participant decision model adopts:

[0055]

[0056]

[0057]

[0058]

[0059]

[0060]

[0061]

[0062] Among them, formulas (1) to (4) represent the bidding model of the market participant module that owns the gas turbine; subscript v represents unit v; subscript w represents gas well w; subscripts i, j represent nodes i, j in the power network; subscripts m, n represent nodes m, n in the natural gas pipeline network; subscript t represents time t; subscript b represents stage b in the segmented bidding; formula (1) represents that the market participant module optimizes the bidding strategy with the goal of minimizing its own cost; is the clearing price of electricity commodity in coupled transactions; is the clearing price of natural gas commodity in the coupled transaction; The electricity price generated when the power system is redispatched; The natural gas price generated when the natural gas system is redispatched; The transaction volume of electricity commodities in coupled transactions; The amount of electricity redispatched to the power system; The cost of electricity generation from gas turbines; is the energy conversion rate of the gas turbine; Formula (2) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (3) represents the output constraint of the gas turbine; is the maximum output of the gas turbine; Formula (4) represents the ramp constraint of the gas turbine; are the upper and lower limits of ramping capability, respectively; Formulas (5) to (7) represent the bidding model of market participants with natural gas wells; Formula (5) represents the optimization of bidding strategies by market participants with the goal of minimizing their own costs; is the volume of natural gas commodities in coupled transactions; the amount of natural gas redispatched to the natural gas system; is the operating cost of the natural gas well; Formula (6) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (7) represents the gas supply constraint of the natural gas well; Maximum gas supply capacity for gas turbines; represents the clearing price of natural gas commodity in coupled transactions;

[0063] The energy optimization trading model adopts:

[0064]

[0065]

[0066]

[0067]

[0068] Among them, formula (8) represents the maximization of the total social benefits of the coupled electricity and natural gas markets; formula (9) represents the balance of supply and demand of electricity commodities; It is the forecast value of renewable energy power generation output; is the predicted value of electricity demand in the market; formula (10) represents the supply and demand balance of natural gas commodities; is the predicted value of natural gas demand in the market; formula (11) represents the gas-electricity conversion relationship of the gas turbine; The amount of natural gas required to power the gas turbines in the coupling transaction.

[0069] Preferably, the system operator module adopts: checking whether the power clearing information meets the power security demand constraint of power dispatching, and if so, dispatching the power based on the current power clearing information; if not, adjusting the clearing information of the power system by using the power system re-dispatching model to meet the demand of power security dispatching;

[0070] The power system redispatch model adopts:

[0071]

[0072]

[0073] -π≤θ i,t ≤π (14)

[0074]

[0075] Wherein, formula (12) represents the dispatch of electricity with the lowest redispatch cost as the objective function; The amount of reduction in power output for renewable energy; is the demand response amount; price penalties for renewable energy cuts; is the cost of demand response; Formula (13) represents the power balance of the power system maintained by appropriate redispatch after considering physical constraints; Formula (14) represents the phase angle constraint of power; θ i,t is the phase angle at a certain node; Formula (15) represents the capacity constraint of the power network line; B i,j is the susceptance matrix of the electric power; is the upper limit of the capacity of the power network line; θ j,t represents the phase angle at node j;

[0076] The system operator module adopts: checking whether the natural gas clearing information meets the natural gas safety demand constraint of natural gas scheduling, and if it does, scheduling the natural gas based on the current natural gas clearing information; if it does not meet the constraints, adjusting the clearing information of the natural gas system by using the natural gas system rescheduling model to meet the demand of natural gas safety scheduling;

[0077] The natural gas system rescheduling model adopts:

[0078]

[0079]

[0080] (q m,n,t / W m,n ) 2 =|r m,t 2 -r n,t 2 | (18)

[0081]

[0082]

[0083] x m,n ={0,1} (21)

[0084]

[0085] Wherein, formula (16) represents the dispatch of natural gas with the lowest redispatch cost as the objective function; is the demand response amount; is the cost of demand response; Formula (17) represents the balance between natural gas supply and demand through appropriate redispatching after considering physical constraints; Formula (18) represents the relationship between the natural gas flow rate and the pressure at both ends of the pipeline network; q m,n,t is the airflow in the pipe mn; r m,t is the air pressure at node m; W m,n is the Weymouth constant; Formula (19) represents the node pressure constraint; is the maximum air pressure constraint of the node; is the minimum gas pressure constraint at the node; Formula (20) represents the capacity constraint of the natural gas pipeline network; natural gas transmission is different from power transmission. The transmission direction cannot be changed arbitrarily and must be transmitted continuously for a certain period of time in a certain transmission direction; x m,n Represents the transmission direction of a pipeline; it is a 0-1 variable; is the upper limit of natural gas transmission in the pipeline network; Formula (22) represents the relationship between the output of the gas turbine adjusted by power redispatching and the natural gas consumption; The amount of natural gas required by the gas turbine after power redispatch; It is expressed as the amount of natural gas required by the gas turbine in the coupled transaction; represents the forecast value of natural gas demand in the market; r n,t Represents the air pressure at node n.

[0086] Compared with the prior art, the present invention has the following beneficial effects:

[0087] 1. The coupling of electricity and natural gas trading can expand the optimization scale of the energy system, obtain the best price signal to guide the joint dispatch of the power system and the natural gas system, and maximize the effectiveness of the coupling relationship between electricity and natural gas energy;

[0088] 2. The power system and the natural gas system operate independently and adjust the unreasonable results obtained in the coupling transaction according to their own physical constraints to ensure safety and stability;

[0089] 3. The combination of coupled trading and independent operation has formed a joint dispatching method for electricity and natural gas systems under the background of multi-energy interaction; it has clarified the technical objectives, technical means, implementation steps, and collaborative relationships of various market participants, market operators, and system operators, and established a joint dispatching system for electricity and natural gas under the background of multi-energy interaction. BRIEF DESCRIPTION OF THE DRAWINGS

[0090] Other features, objects and advantages of the present invention will become more apparent from the detailed description of non-limiting embodiments made with reference to the following drawings:

[0091] Figure 1 Schematic diagram of the joint dispatching system of electricity and natural gas in the context of multi-energy interaction. DETAILED DESCRIPTION

[0092] The present invention is described in detail below in conjunction with specific embodiments. The following embodiments will help those skilled in the art to further understand the present invention, but are not intended to limit the present invention in any form. It should be noted that, for those of ordinary skill in the art, several changes and improvements can also be made without departing from the concept of the present invention. These all belong to the protection scope of the present invention.

[0093] Example 1

[0094] According to the present invention, a method for joint dispatching of electricity and natural gas in a multi-energy interaction context includes:

[0095] Step S1: The market participant module predicts the current electricity price data and natural gas price data through historical data; for example: predicting the current electricity price data through the average value of electricity price in a certain month of the previous n years and the annual rate of change; predicting the current natural gas price data through the average value of natural gas price in a certain month of the previous n years and the annual rate of change; or using historical data (natural gas price or electricity price in a certain month of the previous n years, weather factors and growth factors) to train the power neural network model and the natural gas neural network model respectively, and using the trained power neural network model and the natural gas neural network model to predict the current electricity price and natural gas price respectively;

[0096] Step S2: The market participant module uses the participant decision model to obtain the current electricity price and the corresponding sales volume and the current natural gas price and the corresponding sales volume;

[0097] Step S3: The market operator module establishes an energy optimization transaction model, and uses the energy optimization transaction model to obtain the optimal power system price and corresponding transaction volume and the optimal natural gas system price and corresponding transaction volume, thereby realizing the joint clearing of power and natural gas transactions in the energy optimization transaction model, and obtaining power system clearing information and natural gas system clearing information;

[0098] Step S4: The system operator module verifies the power system and the natural gas system in turn based on the clearing information of electricity and natural gas respectively. If the market clearing information does not meet the security constraint requirements of the power system and the natural gas system, the power system re-dispatch model and the natural gas system re-dispatch model are used to adjust the clearing information of the power system and the natural gas system respectively until the respective preset security constraint requirements are met;

[0099] The participant decision model is based on the predicted electricity price and natural gas price to obtain its own quotation and corresponding sales volume under its own physical constraints;

[0100] The energy optimization transaction model aims at the economic efficiency of market operation, and obtains the optimal electricity energy price and corresponding transaction volume and the optimal natural gas energy price and corresponding transaction volume according to the quotations and corresponding sales volumes in the electricity market and the quotations and corresponding sales volumes in the natural gas market;

[0101] The electric power system redispatching model and the natural gas system redispatching model both aim to optimize the redispatching economic index, the redispatching electricity index and the redispatching cleanliness index, and determine the redispatching electricity to meet the needs of safe power dispatching.

[0102] The electricity-gas market mode with transaction coupling and independent operation is a specific embodiment of the present invention. Transaction coupling means that, at the market transaction level, only the general commodity characteristics of electricity and natural gas are considered, and the influence of their physical characteristics is not considered. At this time, electricity commodities and natural gas commodities are freely traded like general commodities, and the electricity market operator and the natural gas market operator can cooperate with each other to form a unified electricity-gas energy market, and uniformly clear the two energy commodities according to the supply and demand balance of electricity and natural gas commodities. Operation independence means that at the physical operation level, the power system and the natural gas system operate independently, respectively maintaining the safety and stability of the two energy systems in the most economical way, and re-dispatching unreasonable coupling transaction clearing results. In the independent operation part, the power system is operated independently first. The power system operator first verifies whether the market clearing results of the coupling transaction part can meet the safety and stability constraints of the power system. If they can be met, they are dispatched according to the results of the coupling transaction part; if they cannot be met, the transaction volume of each market participant obtained by the coupling transaction part is adjusted in the most economical way. This process is also called the re-dispatching of the power system. The independent operation of the natural gas system is carried out after the independent operation of the power system. The natural gas system operator first verifies whether the market clearing results of the coupling transaction part can meet the safety and stability constraints of the natural gas system, and whether the gas turbine adjusts its output due to the re-dispatch of the power system, thereby changing its natural gas demand. If the system safety and stability constraints can be met and the natural gas demand of the gas turbine has not changed, the dispatch is carried out according to the results of the coupling transaction part; if the system safety and stability constraints cannot be met or the natural gas demand of the gas turbine has changed, the results of the coupling transaction part are adjusted in the most economical way. This process is also called the re-dispatch of the natural gas system.

[0103] The transaction-coupled and independent electricity-natural gas market is a two-layer model. The upper model is the participant decision-making model; the lower model is the energy optimization transaction model, the power system redispatching model and the natural gas system redispatching model.

[0104] Specifically, the market participant module dispatches the upper-level participant decision model. When market participants participate in the electricity-gas coordination market, they bid for prices in the electricity-gas coordination market with the goal of maximizing their own interests. At the same time, market participants need to consider the constraints of their own energy supply and demand capabilities to ensure the rationality of the bid, including unit / gas well capacity constraints and unit ramping constraints.

[0105]

[0106]

[0107]

[0108]

[0109]

[0110]

[0111]

[0112] Among them, formulas (1) to (4) represent the bidding model of the market participant module that owns the gas turbine; formula (1) represents the market participant module optimizing the bidding strategy with the goal of minimizing its own cost; is the clearing price of electricity commodity in coupled transactions; is the clearing price of natural gas commodity in the coupled transaction; The electricity price generated when the power system is redispatched; The natural gas price generated when the natural gas system is redispatched; The transaction volume of electricity commodities in coupled transactions; The amount of electricity redispatched to the power system; The cost of electricity generation from gas turbines; is the energy conversion rate of the gas turbine; Formula (2) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (3) represents the output constraint of the gas turbine; is the maximum output of the gas turbine; Formula (4) represents the ramp constraint of the gas turbine; are the upper and lower limits of ramping capability, respectively; Formulas (5) to (7) represent the bidding model of market participants with natural gas wells; Formula (5) represents the optimization of bidding strategies by market participants with the goal of minimizing their own costs; is the volume of natural gas commodities in coupled transactions; the amount of natural gas redispatched to the natural gas system; is the operating cost of the natural gas well; Formula (6) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (7) represents the gas supply constraint of the natural gas well; Maximum gas supply capacity for gas turbines; Represents the clearing price of natural gas commodity in coupled transactions.

[0113] The lower market clearing model includes three parts: energy optimization trading model, power system re-dispatch model and natural gas system re-dispatch model, which are carried out in chronological order. The market operator module dispatches the energy optimization trading model, and the system operator module dispatches the power system re-dispatch model and the natural gas system re-dispatch model.

[0114] The first part is the energy optimization trading model. Only the general commodity characteristics of electricity and natural gas are considered, and the influence of their physical characteristics is not considered. At this time, electricity and natural gas commodities are traded freely like general commodities. The electricity market operators and natural gas market operators can cooperate with each other to form a unified electricity-natural gas energy market, and the two energy commodities are cleared uniformly according to the supply and demand balance of electricity and natural gas commodities.

[0115]

[0116]

[0117]

[0118]

[0119] Among them, formula (8) represents the maximization of the total social benefits of the coupled electricity and natural gas markets; formula (9) represents the balance of supply and demand of electricity commodities; It is the forecast value of renewable energy power generation output; is the predicted value of electricity demand in the market; formula (10) represents the supply and demand balance of natural gas commodities; is the predicted value of natural gas demand in the market; formula (11) represents the gas-electricity conversion relationship of the gas turbine; The amount of natural gas required to power the gas turbines in the coupling transaction.

[0120] Specifically, the step S4 adopts: checking whether the power clearing information meets the power security demand constraints of power dispatching, and if so, dispatching the power based on the current power clearing information; if not, adjusting the clearing information of the power system using the power system re-dispatching model to meet the power security dispatching requirements.

[0121] Specifically, the power system redispatching model adopts:

[0122]

[0123]

[0124] -π≤θ i,t ≤π (14)

[0125]

[0126] Wherein, formula (12) represents the dispatch of electricity with the lowest redispatch cost as the objective function; The amount of reduction in power output for renewable energy; is the demand response amount; price penalties for renewable energy cuts; is the cost of demand response; Formula (13) represents the power balance of the power system maintained by appropriate redispatch after considering physical constraints; Formula (14) represents the phase angle constraint of power; θ i,t is the phase angle at a certain node; Formula (15) represents the capacity constraint of the power network line; B i,j is the susceptance matrix of the electric power; is the upper limit of the capacity of the power network line; θ j,t represents the phase angle at node j.

[0127] Specifically, step S4 adopts: checking whether the natural gas clearing information meets the natural gas safety demand constraint of natural gas scheduling, and if so, scheduling the natural gas based on the current natural gas clearing information; if not, adjusting the clearing information of the natural gas system using the natural gas system rescheduling model to meet the demand for natural gas safety scheduling.

[0128] Specifically, the natural gas system rescheduling model adopts:

[0129]

[0130]

[0131] (q m,n,t / W m,n ) 2 =|r m,t 2 -r n,t 2 | (18)

[0132]

[0133]

[0134] x m,n ={0,1} (21)

[0135]

[0136] Wherein, formula (16) represents the dispatch of natural gas with the lowest redispatch cost as the objective function; is the demand response amount; is the cost of demand response; Formula (17) represents the balance between natural gas supply and demand through appropriate redispatching after considering physical constraints; Formula (18) represents the relationship between the natural gas flow rate and the pressure at both ends of the pipeline network; q m,n,t is the airflow in the pipe mn; r m,t is the air pressure at node m; W m,n is the Weymouth constant; Formula (19) represents the node pressure constraint; is the maximum air pressure constraint of the node; is the minimum gas pressure constraint at the node; Formula (20) represents the capacity constraint of the natural gas pipeline network; natural gas transmission is different from power transmission. The transmission direction cannot be changed arbitrarily and must be transmitted continuously for a certain period of time in a certain transmission direction; x m,n Represents the transmission direction of a pipeline; it is a 0-1 variable; is the upper limit of natural gas transmission in the pipeline network; Formula (22) represents the relationship between the output of the gas turbine adjusted by power redispatching and the natural gas consumption; The amount of natural gas required by the gas turbine after power redispatch; It is expressed as the amount of natural gas required by the gas turbine in the coupled transaction; represents the forecast value of natural gas demand in the market; r n,t Represents the air pressure at node n.

[0137] According to the present invention, a combined dispatching system of electricity and natural gas for use in a multi-energy interaction context is provided. Figure 1 As shown, including:

[0138] Market participant module: predict current electricity price data and natural gas price data through historical data; for example: predict current electricity price data through the average value of electricity price in a certain month of the previous n years and the annual rate of change; predict current natural gas price data through the average value of natural gas price in a certain month of the previous n years and the annual rate of change; or use historical data (natural gas price or electricity price in a certain month of the previous n years, weather factors and growth factors) to train the power neural network model and the natural gas neural network model respectively, and use the trained power neural network model and natural gas neural network model to predict the current electricity price and natural gas price respectively;

[0139] Market participant module: uses the participant decision model to obtain the current electricity price and corresponding sales volume, as well as the current natural gas price and corresponding sales volume;

[0140] Market operator module: Establish an energy optimization trading model, and use the energy optimization trading model to obtain the optimal power system price and corresponding transaction volume, as well as the optimal natural gas system price and corresponding transaction volume, so as to achieve the joint clearing of power and natural gas transactions in the energy optimization trading model, and obtain power system clearing information and natural gas system clearing information;

[0141] System operator module: The power system and the natural gas system are verified in turn based on the clearing information of electricity and natural gas respectively. If the market clearing information does not meet the security constraints of the power system and the natural gas system, the clearing information of the power system and the natural gas system is adjusted using the power system redispatch model and the natural gas system redispatch model respectively until the preset security constraints of each are met;

[0142] The participant decision model is based on the predicted electricity price and natural gas price to obtain its own quotation and corresponding sales volume under its own physical constraints;

[0143] The energy optimization transaction model aims at the economic efficiency of market operation, and obtains the optimal electricity energy price and the corresponding transaction volume and the optimal natural gas energy price and the corresponding transaction volume according to the quotations and corresponding sales volumes of electricity market operators and the quotations and corresponding sales volumes of natural gas market operators;

[0144] The electric power system redispatching model and the natural gas system redispatching model both aim to optimize the redispatching economic index, the redispatching electricity index and the redispatching cleanliness index, and determine the redispatching electricity to meet the needs of safe power dispatching.

[0145] The electricity-gas market mode with transaction coupling and independent operation is a specific embodiment of the present invention. Transaction coupling means that, at the market transaction level, only the general commodity characteristics of electricity and natural gas are considered, and the influence of their physical characteristics is not considered. At this time, electricity commodities and natural gas commodities are freely traded like general commodities, and the electricity market operator and the natural gas market operator can cooperate with each other to form a unified electricity-gas energy market, and uniformly clear the two energy commodities according to the supply and demand balance of electricity and natural gas commodities. Operation independence means that at the physical operation level, the power system and the natural gas system operate independently, respectively maintaining the safety and stability of the two energy systems in the most economical way, and re-dispatching unreasonable coupling transaction clearing results. In the independent operation part, the power system is operated independently first. The power system operator first verifies whether the market clearing results of the coupling transaction part can meet the safety and stability constraints of the power system. If they can be met, they are dispatched according to the results of the coupling transaction part; if they cannot be met, the transaction volume of each market participant obtained by the coupling transaction part is adjusted in the most economical way. This process is also called the re-dispatching of the power system. The independent operation of the natural gas system is carried out after the independent operation of the power system. The natural gas system operator first verifies whether the market clearing results of the coupling transaction part can meet the safety and stability constraints of the natural gas system, and whether the gas turbine adjusts its output due to the re-dispatch of the power system, thereby changing its natural gas demand. If the system safety and stability constraints can be met and the natural gas demand of the gas turbine has not changed, the dispatch is carried out according to the results of the coupling transaction part; if the system safety and stability constraints cannot be met or the natural gas demand of the gas turbine has changed, the results of the coupling transaction part are adjusted in the most economical way. This process is also called the re-dispatch of the natural gas system.

[0146] The transaction-coupled and independent electricity-natural gas market is a two-layer model. The upper model is the participant decision-making model; the lower model is the energy optimization transaction model, the power system redispatching model and the natural gas system redispatching model.

[0147] Specifically, the market participant module dispatches the upper-level participant decision model. When market participants participate in the electricity-gas coordination market, they bid for prices in the electricity-gas coordination market with the goal of maximizing their own interests. At the same time, market participants need to consider the constraints of their own energy supply and demand capabilities to ensure the rationality of the bid, including unit / gas well capacity constraints and unit ramping constraints.

[0148]

[0149]

[0150]

[0151]

[0152]

[0153]

[0154]

[0155] Among them, formulas (1) to (4) represent the bidding model of the market participant module that owns the gas turbine; formula (1) represents the market participant module optimizing the bidding strategy with the goal of minimizing its own cost; is the clearing price of electricity commodity in coupled transactions; is the clearing price of natural gas commodity in the coupled transaction; The electricity price generated when the power system is redispatched; The natural gas price generated when the natural gas system is redispatched; The transaction volume of electricity commodities in coupled transactions; The amount of electricity redispatched to the power system; The cost of electricity generation from gas turbines; is the energy conversion rate of the gas turbine; Formula (2) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (3) represents the output constraint of the gas turbine; is the maximum output of the gas turbine; Formula (4) represents the ramp constraint of the gas turbine; are the upper and lower limits of ramping capability, respectively; Formulas (5) to (7) represent the bidding model of market participants with natural gas wells; Formula (5) represents the optimization of bidding strategies by market participants with the goal of minimizing their own costs; is the volume of natural gas commodities in coupled transactions; the amount of natural gas redispatched to the natural gas system; is the operating cost of the natural gas well; Formula (6) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (7) represents the gas supply constraint of the natural gas well; Maximum gas supply capacity for gas turbines; Represents the clearing price of natural gas commodity in coupled transactions.

[0156] The lower market clearing model includes three parts: energy optimization trading model, power system re-dispatch model and natural gas system re-dispatch model, which are carried out in chronological order. The market operator module dispatches the energy optimization trading model, and the system operator module dispatches the power system re-dispatch model and the natural gas system re-dispatch model.

[0157] The first part is the energy optimization trading model. Only the general commodity characteristics of electricity and natural gas are considered, and the influence of their physical characteristics is not considered. At this time, electricity and natural gas commodities are traded freely like general commodities. The electricity market operators and natural gas market operators can cooperate with each other to form a unified electricity-natural gas energy market, and the two energy commodities are cleared uniformly according to the supply and demand balance of electricity and natural gas commodities.

[0158]

[0159]

[0160]

[0161]

[0162] Among them, formula (8) represents the maximization of the total social benefits of the coupled electricity and natural gas markets; formula (9) represents the balance of supply and demand of electricity commodities; It is the forecast value of renewable energy power generation output; is the predicted value of electricity demand in the market; formula (10) represents the supply and demand balance of natural gas commodities; is the predicted value of natural gas demand in the market; formula (11) represents the gas-electricity conversion relationship of the gas turbine; The amount of natural gas required to power the gas turbines in the coupling transaction.

[0163] Specifically, the system operator module adopts: checking whether the power clearing information meets the power security demand constraints of power dispatching, and if so, dispatching the power based on the current power clearing information; if not, adjusting the clearing information of the power system using the power system re-dispatching model to meet the power security dispatching requirements.

[0164] Specifically, the power system redispatching model adopts:

[0165]

[0166]

[0167] -π≤θ i,t ≤π (14)

[0168]

[0169] Wherein, formula (12) represents the dispatch of electricity with the lowest redispatch cost as the objective function; The amount of reduction in power output for renewable energy; is the demand response amount; price penalties for renewable energy cuts; is the cost of demand response; Formula (13) represents the power balance of the power system maintained by appropriate redispatch after considering physical constraints; Formula (14) represents the phase angle constraint of power; θ i,t is the phase angle at a certain node; Formula (15) represents the capacity constraint of the power network line; B i,j is the susceptance matrix of the electric power; is the upper capacity limit of the power network line; θ j,t represents the phase angle at node j.

[0170] Specifically, the system operator module adopts: checking whether the natural gas clearing information meets the natural gas safety demand constraints of natural gas scheduling, and if so, scheduling the natural gas based on the current natural gas clearing information; if not, adjusting the clearing information of the natural gas system using the natural gas system rescheduling model to meet the needs of natural gas safety scheduling.

[0171] Specifically, the natural gas system rescheduling model adopts:

[0172]

[0173]

[0174] (q m,n,t / W m,n ) 2 =|r m,t 2 -r n,t 2 | (18)

[0175]

[0176]

[0177] x m,n ={0,1} (21)

[0178]

[0179] Wherein, formula (16) represents the dispatch of natural gas with the lowest redispatch cost as the objective function; is the demand response amount; is the cost of demand response; Formula (17) represents the balance between natural gas supply and demand through appropriate redispatching after considering physical constraints; Formula (18) represents the relationship between the natural gas flow rate and the pressure at both ends of the pipeline network; q m,n,t is the airflow in the pipe mn; r m,t is the air pressure at node m; W m,n is the Weymouth constant; Formula (19) represents the node pressure constraint; is the maximum air pressure constraint of the node; is the minimum gas pressure constraint at the node; Formula (20) represents the capacity constraint of the natural gas pipeline network; natural gas transmission is different from power transmission. The transmission direction cannot be changed arbitrarily and must be transmitted continuously for a certain period of time in a certain transmission direction; x m,n Represents the transmission direction of a pipeline; it is a 0-1 variable; is the upper limit of natural gas transmission in the pipeline network; Formula (22) represents the relationship between the output of the gas turbine adjusted by power redispatching and the natural gas consumption; The amount of natural gas required by the gas turbine after power redispatch; It is expressed as the amount of natural gas required by the gas turbine in the coupled transaction; represents the forecast value of natural gas demand in the market; r n,t Represents the air pressure at node n.

[0180] Example 2

[0181] Embodiment 2 is a preferred embodiment of Embodiment 1

[0182] The present invention provides an electric power and natural gas joint dispatching system for use in a multi-energy interaction context, comprising a market participant module, a market operator module and a system operator module.

[0183] The market participant module includes a market participant decision-making module and a market participant bidding module.

[0184] The market operator module includes the electricity-natural gas coupling clearing module and the market-system interaction module.

[0185] The system operator module includes the power system verification and re-dispatch module and the natural gas system verification and re-dispatch module.

[0186] The power system verification and re-dispatching module includes a power system verification module and a power system re-dispatching module.

[0187] The natural gas system verification and rescheduling module includes a natural gas system verification module and a natural gas system rescheduling module.

[0188] In the market participant decision module, market participants dispatch the participant decision model to optimize the consumption strategy of electricity and natural gas according to their own goals. Market participants need to consider the constraints of their own energy supply and demand capabilities, including unit / gas well capacity constraints and unit ramp constraints, and further determine their own demand for selling / purchasing electricity and natural gas. In the market participant bidding module, market participants bid to the market operator module, and the bid includes the selling / purchasing price and selling / purchasing volume of electricity and natural gas to be sold / purchased.

[0189] In the electricity-gas coupling transaction module, the market operator receives the bidding information of market participants. The market operator considers the conversion relationship between electricity and gas, dispatches the energy optimization transaction model according to the economic and environmental requirements of market dispatch, and selects to accept the best market participant bid. In this module, electricity and natural gas transactions are jointly cleared in the energy optimization transaction model, and the clearing information includes the clearing information of each electricity and the clearing information of natural gas. The electricity clearing information includes: the amount of electricity won by the market participants and the unified electricity price of the market, and the natural gas clearing information includes: the amount of natural gas won by the market participants and the unified natural gas price of the market. The market operator transmits the market clearing information to the system operator through the market-system interaction module.

[0190] In the power system verification module, the system operator verifies whether the power clearing information transmitted by the market operator meets the security demand constraints of the system dispatch, including line capacity constraints and power supply and demand balance constraints of generators and users who do not participate in market transactions. If satisfied, the power system is dispatched accordingly. If not satisfied, the power system redispatching module is entered. In the power system redispatching module, the system operator dispatches the power system redispatching model, with the optimal redispatching economy, redispatching power and redispatching cleanliness as the goals, and determines the redispatching power to meet the needs of safe dispatch of the power system.

[0191] In the natural gas system verification module, the system operator verifies whether the natural gas clearing information transmitted by the market operator meets the safety requirements of the system dispatch, including the pipeline capacity constraints and the natural gas supply and demand balance constraints of gas wells and users that do not participate in market transactions. If satisfied, the natural gas system is dispatched accordingly; if not, the natural gas system re-dispatching module is entered. In the natural gas system re-dispatching module, the system operator dispatches the natural gas system re-dispatching model, with the optimal re-dispatching economy, re-dispatching electricity and re-dispatching cleanliness as the goals, and determines the re-dispatching natural gas volume to meet the needs of safe dispatch of the natural gas system.

[0192] Those skilled in the art know that, in addition to implementing the system, device and its various modules provided by the present invention in a purely computer-readable program code, it is entirely possible to implement the same program in the form of logic gates, switches, application-specific integrated circuits, programmable logic controllers and embedded microcontrollers by logically programming the method steps. Therefore, the system, device and its various modules provided by the present invention can be considered as a hardware component, and the modules included therein for implementing various programs can also be considered as structures within the hardware component; the modules for implementing various functions can also be considered as both software programs for implementing the method and structures within the hardware component.

[0193] The above describes the specific embodiments of the present invention. It should be understood that the present invention is not limited to the above specific embodiments, and those skilled in the art can make various changes or modifications within the scope of the claims, which does not affect the essence of the present invention. In the absence of conflict, the embodiments of the present application and the features in the embodiments can be combined with each other arbitrarily.

Claims

1. A method for joint dispatching of electricity and natural gas in the context of multi-energy interaction, characterized in that: include: Step S1: The market participant module predicts current electricity price data and natural gas price data through historical data; Step S2: The market participant module uses the participant decision model to obtain the current electricity price and the corresponding sales volume and the current natural gas price and the corresponding sales volume; Step S3: The market operator module uses the energy optimization transaction model to obtain the optimal electricity price and corresponding transaction volume and the optimal natural gas price and corresponding transaction volume, thereby realizing the joint clearing of electricity and natural gas transactions in the energy optimization transaction model and obtaining electricity clearing information and natural gas clearing information; Step S4: The system operator module verifies the power system and the natural gas system in turn based on the clearing information of electricity and natural gas respectively. If the market clearing information does not meet the security constraint requirements of the power system and the natural gas system, the power system re-dispatch model and the natural gas system re-dispatch model are used to adjust the clearing information of the power system and the natural gas system respectively until the respective preset security constraint requirements are met; The participant decision model is based on the predicted electricity price and natural gas price to obtain its own quotation and corresponding sales volume under its own physical constraints; The energy optimization transaction model aims at the economic efficiency of market operation, and obtains the optimal electricity energy price and corresponding transaction volume and the optimal natural gas energy price and corresponding transaction volume according to the quotations and corresponding sales volumes in the electricity market and the quotations and corresponding sales volumes in the natural gas market; The power system redispatching model and the natural gas system redispatching model both take redispatching economic efficiency as the goal and determine the redispatching electricity and natural gas quantities to meet the safe dispatching requirements of the power system and the natural gas system.

2. The method for joint dispatching of electricity and natural gas in a multi-energy interactive context according to claim 1, characterized in that: The participant decision model adopts: Among them, formulas (1) to (4) represent the bidding model of the market participant module that owns the gas turbine; subscript v represents unit v; subscript w represents gas well w; subscripts i, j represent nodes i, j in the power network; subscripts m, n represent nodes m, n in the natural gas pipeline network; subscript t represents time t; subscript b represents stage b in the segmented bidding; formula (1) represents that the market participant module optimizes the bidding strategy with the goal of minimizing its own cost; is the clearing price of electricity commodity in coupled transactions; is the clearing price of natural gas commodity in the coupled transaction; The electricity price generated when the power system is redispatched; The natural gas price generated when the natural gas system is redispatched; The transaction volume of electricity commodities in coupled transactions; The amount of electricity redispatched to the power system; The cost of electricity generation from gas turbines; is the energy conversion rate of the gas turbine; Formula (2) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (3) represents the output constraint of the gas turbine; is the maximum output of the gas turbine; Formula (4) represents the ramp constraint of the gas turbine; are the upper and lower limits of ramping capability, respectively; Formulas (5) to (7) represent the bidding model of market participants with natural gas wells; Formula (5) represents the optimization of bidding strategies by market participants with the goal of minimizing their own costs; is the volume of natural gas commodities in coupled transactions; the amount of natural gas redispatched to the natural gas system; is the operating cost of the natural gas well; Formula (6) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (7) represents the gas supply constraint of the natural gas well; Maximum gas supply capacity for gas turbines; Represents the clearing price of natural gas commodity in coupled transactions.

3. The method for joint dispatching of electricity and natural gas in a multi-energy interactive context according to claim 1, characterized in that: The energy optimization trading model adopts: Among them, formula (8) represents the maximization of the total social benefits of the coupled electricity and natural gas markets; formula (9) represents the balance of supply and demand of electricity commodities; It is the forecast value of renewable energy power generation output; is the predicted value of electricity demand in the market; formula (10) represents the supply and demand balance of natural gas commodities; is the predicted value of natural gas demand in the market; formula (11) represents the gas-electricity conversion relationship of the gas turbine; The amount of natural gas required to power the gas turbines in the coupling transaction.

4. The method for joint dispatching of electricity and natural gas in a multi-energy interactive context according to claim 1, characterized in that: The step S4 adopts: checking whether the power clearing information meets the power security demand constraints of power dispatching, and if so, dispatching the power based on the current power clearing information; if not, adjusting the clearing information of the power system using the power system re-dispatching model to meet the power security dispatching requirements.

5. The method for joint dispatching of electricity and natural gas in a multi-energy interactive context according to claim 4, characterized in that: The power system redispatch model adopts: -π≤θ i，t ≤π (14) Wherein, formula (12) represents the dispatch of electricity with the lowest redispatch cost as the objective function; The amount of reduction in power output for renewable energy; is the demand response amount; price penalties for renewable energy cuts; is the cost of demand response; Formula (13) represents the power balance of the power system maintained by appropriate redispatch after considering physical constraints; Formula (14) represents the phase angle constraint of power; θ i，t is the phase angle at a certain node; Formula (15) represents the capacity constraint of the power network line; B i，i is the susceptance matrix of the electric power; is the upper limit of the capacity of the power network line; θ j，t represents the phase angle at node j.

6. The method for joint dispatching of electricity and natural gas in a multi-energy interactive context according to claim 1, characterized in that: The step S4 adopts: checking whether the natural gas clearing information meets the natural gas safety demand constraint of the natural gas scheduling, and if it does, scheduling the natural gas based on the current natural gas clearing information; if it does not, adjusting the clearing information of the natural gas system using the natural gas system rescheduling model to meet the demand for natural gas safety scheduling.

7. The method for joint dispatching of electricity and natural gas in a multi-energy interactive context according to claim 6, characterized in that: The natural gas system rescheduling model adopts: (q m，n，t / W m，n ) 2 =|r m，t 2 -r n，t 2 | (18) x m，n ＝{0，1} (21) Wherein, formula (16) represents the dispatch of natural gas with the lowest redispatch cost as the objective function; is the demand response amount; is the cost of demand response; Formula (17) represents the balance between natural gas supply and demand through appropriate redispatching after considering physical constraints; Formula (18) represents the relationship between the natural gas flow rate and the pressure at both ends of the pipeline network; q m，n，t is the airflow in the pipe mn; r m，t is the air pressure at node m; W m，n is the Weymouth constant; Formula (19) represents the node pressure constraint; is the maximum air pressure constraint of the node; is the minimum gas pressure constraint at the node; Formula (20) represents the capacity constraint of the natural gas pipeline network; natural gas transmission is different from power transmission. The transmission direction cannot be changed arbitrarily and must be transmitted continuously for a certain period of time in a certain transmission direction; x m,n Represents the transmission direction of a pipeline; it is a 0-1 variable; is the upper limit of natural gas transmission in the pipeline network; Formula (22) represents the relationship between the output of the gas turbine adjusted by power redispatching and the natural gas consumption; The amount of natural gas required by the gas turbine after power redispatch; It is expressed as the amount of natural gas required by the gas turbine in the coupled transaction; represents the forecast value of natural gas demand in the market; r n,t Represents the air pressure at node n.

8. A combined dispatching system of electricity and natural gas for use in a multi-energy interactive context, characterized in that: include: Market participant module: predicts current electricity price data and natural gas price data through historical data, and uses the participant decision model to obtain the current electricity quotation and corresponding sales volume, as well as the current natural gas quotation and corresponding sales volume; Market operator module: using the energy optimization trading model to obtain the optimal electricity price and corresponding transaction volume as well as the optimal natural gas price and corresponding transaction volume, thereby achieving the joint clearing of electricity and natural gas transactions in the energy optimization trading model and obtaining electricity clearing information and natural gas clearing information; System operator module: The power system and the natural gas system are verified in turn based on the clearing information of electricity and natural gas respectively. If the market clearing information does not meet the security constraint requirements of the power system and the natural gas system, the clearing information of the power system and the natural gas system is adjusted using the power system redispatch model and the natural gas system redispatch model respectively until the preset security constraint requirements are met; The participant decision model is based on the predicted electricity price and natural gas price to obtain its own quotation and corresponding sales volume under its own physical constraints; The energy optimization transaction model aims at the economic efficiency of market operation, and obtains the optimal electricity energy price and corresponding transaction volume and the optimal natural gas energy price and corresponding transaction volume according to the quotations and corresponding sales volumes in the electricity market and the quotations and corresponding sales volumes in the natural gas market; The power system redispatching model and the natural gas system redispatching model both take redispatching economic efficiency as the goal and determine the redispatching electricity and natural gas quantities to meet the safe dispatching requirements of the power system and the natural gas system.

9. The electric power and natural gas joint dispatching system for multi-energy interaction according to claim 8, characterized in that: The participant decision model adopts: Among them, formulas (1) to (4) represent the bidding model of the market participant module that owns the gas turbine; subscript v represents unit v; subscript w represents gas well w; subscripts i, j represent nodes i, j in the power network; subscripts m, n represent nodes m, n in the natural gas pipeline network; subscript t represents time t; subscript b represents stage b in the segmented bidding; formula (1) represents that the market participant module optimizes the bidding strategy with the goal of minimizing its own cost; is the clearing price of electricity commodity in coupled transactions; is the clearing price of natural gas commodity in the coupled transaction; The electricity price generated when the power system is redispatched; The natural gas price generated when the natural gas system is redispatched; The transaction volume of electricity commodities in coupled transactions; The amount of electricity redispatched to the power system; The cost of electricity generation from gas turbines; is the energy conversion rate of the gas turbine; Formula (2) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (3) represents the output constraint of the gas turbine; is the maximum output of the gas turbine; Formula (4) represents the ramp constraint of the gas turbine; are the upper and lower limits of ramping capability, respectively; Formulas (5) to (7) represent the bidding model of market participants with natural gas wells; Formula (5) represents the optimization of bidding strategies by market participants with the goal of minimizing their own costs; is the volume of natural gas commodities in coupled transactions; the amount of natural gas redispatched to the natural gas system; is the operating cost of the natural gas well; Formula (6) represents the segmented quotation of the market participant module; Quotes for market participants module; is the maximum bid constraint of the market participant module; Formula (7) represents the gas supply constraint of the natural gas well; Maximum gas supply capacity for gas turbines; represents the clearing price of natural gas commodity in coupled transactions; The energy optimization trading model adopts: Among them, formula (8) represents the maximization of the total social benefits of the coupled electricity and natural gas markets; formula (9) represents the balance of supply and demand of electricity commodities; It is the forecast value of renewable energy power generation output; is the predicted value of electricity demand in the market; formula (10) represents the supply and demand balance of natural gas commodities; is the predicted value of natural gas demand in the market; formula (11) represents the gas-electricity conversion relationship of the gas turbine; The amount of natural gas required to power the gas turbines in the coupling transaction.

10. The electric power and natural gas joint dispatching system for multi-energy interaction according to claim 8, characterized in that: The system operator module adopts: checking whether the power clearing information meets the power security demand constraints of power dispatching, and if so, dispatching the power based on the current power clearing information; if not, adjusting the clearing information of the power system by using the power system re-dispatching model to meet the power security dispatching requirements; The power system redispatch model adopts: -π≤θ i，t ≤π (14) Wherein, formula (12) represents the dispatch of electricity with the lowest redispatch cost as the objective function; The amount of reduction in power output for renewable energy; is the demand response amount; price penalties for renewable energy cuts; is the cost of demand response; Formula (13) represents the power balance of the power system maintained by appropriate redispatch after considering physical constraints; Formula (14) represents the phase angle constraint of power; θ i，t is the phase angle at a certain node; Formula (15) represents the capacity constraint of the power network line; B i，j is the susceptance matrix of the electric power; is the upper capacity limit of the power network line; θ j，t represents the phase angle at node j; The system operator module adopts: checking whether the natural gas clearing information meets the natural gas safety demand constraint of natural gas scheduling, and if it does, scheduling the natural gas based on the current natural gas clearing information; if it does not meet the constraints, adjusting the clearing information of the natural gas system by using the natural gas system rescheduling model to meet the demand of natural gas safety scheduling; The natural gas system rescheduling model adopts: (q m，n，t / W m，n ) 2 =|r m，t 2 -r n，t 2 | (18) x m，n ＝{0，1} (21) Wherein, formula (16) represents the dispatch of natural gas with the lowest redispatch cost as the objective function; is the demand response amount; is the cost of demand response; Formula (17) represents the balance between natural gas supply and demand through appropriate redispatching after considering physical constraints; Formula (18) represents the relationship between the natural gas flow rate and the pressure at both ends of the pipeline network; q m，n，t is the airflow in the pipe mn; r m，t is the air pressure at node m; W m，n is the Weymouth constant; Formula (19) represents the node pressure constraint; is the maximum air pressure constraint of the node; is the minimum gas pressure constraint at the node; Formula (20) represents the capacity constraint of the natural gas pipeline network; natural gas transmission is different from power transmission. The transmission direction cannot be changed arbitrarily and must be transmitted continuously for a certain period of time in a certain transmission direction; x m,n Represents the transmission direction of a pipeline; it is a 0-1 variable; is the upper limit of natural gas transmission in the pipeline network; Formula (22) represents the relationship between the output of the gas turbine adjusted by power redispatching and the natural gas consumption; The amount of natural gas required by the gas turbine after power redispatch; It is expressed as the amount of natural gas required by the gas turbine in the coupled transaction; represents the forecast value of natural gas demand in the market; r n,t Represents the air pressure at node n.

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