Energy Pricing Method, System and Storage Medium for Electrical-Electronic Combined System

Abstract

The present invention discloses an energy pricing method for an electric-gas integrated system. The method establishes a day-ahead market clearing model for the electric-gas integrated system by considering energy contracts and using the power network constraints, natural gas network constraints, and electric-gas integrated network coupling constraints as the constraint conditions, and taking the minimization of the sum of the power purchase costs of the power grid company and the gas purchase costs of the natural gas company as the objective function. Then, through this day-ahead market clearing model, the sum of the power / gas purchase costs of other members is calculated when each member participates and does not participate in the day-ahead market clearing, and the change in the sum of the power / gas purchase costs of other members is used as the value of this member to formulate the energy price. In the above technical solution, the energy operator formulates the energy price mechanism based on the values of each member obtained by the above method, which can prompt market members to report true prices in the bidding in order to achieve their maximum interests, and ensure the effective dispatching and stable operation of the power market.

Description

Technical Field

[0001] The present invention relates to the technical field of power dispatching, and particularly relates to an energy pricing method, system and storage medium for an electric-gas integrated system. Background Art

[0002] Natural gas has the characteristics of low cost, flexibility and environmental protection. In recent years, gas-fired generators have become widely popular due to their higher energy utilization efficiency and less pollution. With the proposal of the "energy integrated network", the interdependence between various energy sectors has increased significantly, and the coupling relationship between the gas network and the power network has become closer. By jointly operating electricity and gas, more economic and environmental benefits can be obtained.

[0003] In existing domestic and foreign power markets, locational marginal pricing (LMP) has been widely used for settlement. However, through theory and practice, it has been proven that the marginal pricing mechanism cannot guarantee incentive compatibility. Power generators will manipulate prices through strategic bidding with the goal of maximizing their own interests, resulting in low market operation efficiency. Summary of the Invention

[0004] Object of the Invention: The object of the present invention is to propose an energy pricing method for an electric-gas integrated system, which considers power supply and gas supply contracts, can make the bids of market members tend to the real prices during the bidding process, and ensure the effective dispatching and stable operation of the power market.

[0005] Another object of the present invention is to propose an energy pricing system for an electric-gas integrated system that can implement the above method and a storage medium storing a computer program instantiating the above energy pricing method, which can assist power operators in formulating the energy prices of each power system member.

[0006] Technical Solution: The energy pricing method for the electric-gas integrated system described in the present invention includes the following steps:

[0007] S1: Obtain the functions of the power purchase cost of the power grid company and the gas purchase cost of the gas company according to the energy contract;

[0008] S2: Taking the power network constraints, gas network constraints and electric-gas integrated network coupling constraints as constraint conditions, and taking the minimization of the sum of the power purchase cost of the power grid company and the gas purchase cost of the gas company as the objective function, establish a day-ahead market clearing model for the electric-gas integrated system;

[0009] S3: According to the day-ahead market clearing model of the electric-gas integrated system, calculate the optimal bidding power of each generator set and the optimal bidding gas production of each gas well under three cases: all members participate in the system day-ahead clearing, generator set i does not participate in the system day-ahead clearing, and gas well j does not participate in the system day-ahead clearing.

[0010] S4: Calculate the sum M of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for other members when generator set i does not participate in the day-ahead clearing of the system -i , the sum (M - f i -f i con ) of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for other members when gas well j does not participate in the day-ahead clearing of the system, and the sum of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for other members when gas well j participates in the day-ahead clearing of the system -j The value of generator set i is: The value of gas well j is: M is the sum of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for all members when all members participate in the day-ahead clearing, f i is the competitive power purchase cost of generator set i when all members participate in the day-ahead clearing, f i con is the contract power purchase cost of generator set i when all members participate in the day-ahead clearing, f j is the competitive gas purchase cost of gas well j when all members participate in the day-ahead clearing, is the contract gas purchase cost of gas well j when all members participate in the day-ahead clearing.

[0011] Furthermore, the power network constraints of the day-ahead market clearing model include:

[0012] 1) The power supply and demand at each node reach balance;

[0013] 2) The generation shift distribution factor of each node for the corresponding transmission line is less than or equal to the transmission capacity of the corresponding transmission line;

[0014] 3) The output of each thermal power unit is within the output range;

[0015] 4) The output of each gas turbine is within the output range.

[0016] Furthermore, the gas network constraints of the day-ahead market clearing model include:

[0017] 1) The gas production of each gas well is within the gas production range;

[0018] 2) The gas pressure at each gas pipeline node is within the gas pressure range;

[0019] 3) The compression ratio of each compressor is within the compression ratio range;

[0020] ​4) The natural gas supply and demand of each node reach balance.

[0021] Furthermore, the electrical-gas integrated network coupling constraints of the day-ahead market clearing model are shown as follows:

[0022]

[0023] Where P i G is the competitive power generation quantity of gas turbine i, P i G,con is the contract power generation quantity of gas turbine i, η is the efficiency coefficient of the gas turbine i at the turning point, is the gas volume supplied by natural gas well j for power generation of gas turbine i, is the set of gas turbines in the electrical-gas integrated system, N g is the set of natural gas wells in the electrical-gas integrated system.

[0024] Furthermore, the day-ahead market clearing model is shown as follows:

[0025] Objective function:

[0026] Constraints:

[0027]

[0028]

[0029]

[0030]

[0031]

[0032] ρ c,min ≤ρ c ≤ρ c,max ;

[0033]

[0034]

[0035] Where F cost is the sum of the power purchase cost of the power grid company and the gas purchase cost of the natural gas company, N e is the set of generating units, is the set of thermal power units, is the set of gas turbine units, N g is the set of natural gas wells, f i (P i) is the competitive bidding price of generator set i, f i con (P i con ) is the contract price of generator set i, P i The competitive bidding power generation of generator set i, P i con is the contract power generation of generator set i, f j (Q j ) is the competitive bidding gas price of natural gas well j, is the contract gas price of natural gas well j, Q j is the competitive bidding gas production of natural gas well j, is the contract gas production of natural gas well j;

[0036] P i C is the competitive bidding power generation of thermal power unit i, P i C,con is the contract power generation of thermal power unit i, P i G is the competitive bidding power generation of gas turbine unit i, P i G,con is the contract power generation of gas turbine unit i, and L e respectively represent the index matrices of thermal power units, gas turbine units and loads in the power network, represents the power load demand of node i;

[0037] ζ li represents the generation shift distribution factor of node i to transmission line l; is the transmission capacity of line l;

[0038] and are respectively the lower and upper limits of the output of thermal power unit i;

[0039] and are respectively the lower and upper limits of the output of gas turbine unit i;

[0040] Q j,min and Q j,max are respectively the lower and upper limits of the gas production of natural gas well j;

[0041] p M,min and p M,max are respectively the lower and upper limits of the gas pressure at natural gas pipeline node M, p M is the gas pressure at natural gas pipeline node M;

[0042] ρ c,min and ρ c,maxare the lower and upper limits of the compression ratio of the compressor c, respectively, and ρ c is the compression ratio of the compressor c;

[0043] S g , W g and L g respectively represent the index matrices of natural gas wells, natural gas pipelines, and natural gas loads in the natural gas network. F MN represents the natural gas flow rate in the pipeline connecting node M and node N, represents the natural gas load demand at node j;

[0044] η represents the gas-to-electricity efficiency coefficient of the gas turbine, represents the gas volume supplied by natural gas well j to gas turbine i for power generation.

[0045] The energy pricing system of the electric-gas integrated system described in the present invention includes: a day-ahead market clearing module, which is used to establish a day-ahead market clearing model of the electric-gas integrated system considering energy contracts, power network constraints, natural gas network constraints, and electric-gas integrated network coupling constraints, and calculates the day-ahead market output and gas production plan of the electric-gas integrated system with the minimum sum of the power purchase cost of the power grid company and the gas purchase cost of the natural gas company as the optimization objective; a VCG energy pricing module, which is used to calculate, according to the VCG mechanism, the sum M -i of the optimal power purchase cost of the power grid company and the gas purchase cost of the natural gas company of other members when generator set i does not participate in the day-ahead clearing of the system, the sum (M - f i - f i con ) of the optimal power purchase cost of the power grid company and the gas purchase cost of the natural gas company of other members when generator set i participates in the day-ahead clearing, the sum M -j of the optimal power purchase cost of the power grid company and the gas purchase cost of the natural gas company of other members when natural gas well j does not participate in the day-ahead clearing of the system, and the sum of the optimal power purchase cost of the power grid company and the gas purchase cost of the natural gas company of other members when natural gas well j participates in the day-ahead clearing The value of generator set i is: The value of natural gas well j is: M is the sum of the optimal power purchase cost of the power grid company and the gas purchase cost of the natural gas company of all members when all members participate in the day-ahead clearing, f i is the competitive power purchase cost of generator set i when all members participate in the day-ahead clearing, f i con is the contract power purchase cost of generator set i when all members participate in the day-ahead clearing, f j is the competitive gas purchase cost of natural gas well j when all members participate in the day-ahead clearing, is the contract gas purchase cost of natural gas well j when all members participate in the day-ahead clearing.

[0046] The storage medium described in the present invention stores a computer program, and the computer program is configured to implement the energy pricing method of the above-mentioned electric-gas combined system when executed.

[0047] Beneficial effects: Compared with the prior art, the present invention has the following advantages: 1. The day-ahead clearing model takes into account energy contracts, and the calculated output and gas production plans in the day-ahead market are more accurate and real. 2. Based on the results calculated by combining the VCG mechanism with the day-ahead clearing model, the value of each member within the system is given, which encourages market members to declare real prices during the bidding process. Description of the Drawings

[0048] Figure 1 It is a flowchart of the energy pricing method of the embodiment of the present invention;

[0049] Figure 2 It is a system structure diagram of a certain electric-gas combined system;

[0050] Figure 3 For Figure 2 The true power purchase costs of the grid company and the gas purchase costs of the gas company declared by the thermal power unit G4 in the system under different coefficients;

[0051] Figure 4 For Figure 2 The true power purchase costs of the grid company and the gas purchase costs of the gas company declared by the gas well Q2 in the system under different coefficients;

[0052] Figure 5 It is the net profit level of the generator set declared under different coefficients calculated by using the energy pricing method of the embodiment of the present invention;

[0053] Figure 6 It is the net profit level of the gas well declared under different coefficients calculated by using the energy pricing method of the embodiment of the present invention. Detailed Embodiments

[0054] The technical solution of the present invention will be further described below with reference to the drawings.

[0055] Referring to Figure 1 , according to the energy pricing method of the electric-gas combined system of the embodiment of the present invention, the following steps are included:

[0056] S1: Obtain the functions of the power purchase cost of the grid company and the gas purchase cost of the gas company according to the energy contract;

[0057] S2: Establish a day-ahead market clearing model for the electric-gas combined system with the power network constraints, natural gas network constraints, and electric-gas combined network coupling constraints as the constraint conditions and the minimization of the sum of the power purchase cost of the grid company and the gas purchase cost of the gas company as the objective function;

[0058] S3: According to the day-ahead market clearing model of the electric-gas integrated system, calculate the optimal bidding power of each generator set and the optimal bidding gas production of each gas well under three cases: all members participate in the system day-ahead clearing, generator set i does not participate in the system day-ahead clearing, and gas well j does not participate in the system day-ahead clearing;

[0059] S4: Calculate the sum M of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for other members when generator set i does not participate in the system day-ahead clearing -i , and the sum (M - f i - f i con ) of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for other members when generator set i participates in the system day-ahead clearing, and the sum M of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for other members when gas well j does not participate in the system day-ahead clearing -j , and the sum of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for other members when gas well j participates in the system day-ahead clearing The value of generator set i is: The value of gas well j is: M is the sum of the optimal power purchase cost of the grid company and the gas purchase cost of the gas company for all members when all members participate in the day-ahead clearing, f i is the competitive power purchase cost of generator set i when all members participate in the day-ahead clearing, f i con is the contract power purchase cost of generator set i when all members participate in the day-ahead clearing, f j is the competitive gas purchase cost of gas well j when all members participate in the day-ahead clearing, and is the contract gas purchase cost of gas well j when all members participate in the day-ahead clearing.

[0060] When a certain member does not participate in the day-ahead market clearing, due to the fixed load, the load borne by this member will be shared by other members. By calculating the change in the electricity purchase cost of the grid company and the gas purchase cost of the gas company when other members participate in the market before and after a certain member in the energy system participates in the day-ahead market, this change can be used as the substitution benefit of this member to other members. This substitution benefit reflects the value of this member and also reflects the contribution of this member to the overall benefit. By calculating the value of each member in the system using the above method and purchasing energy according to the value, and using the substitution benefit of each member as the basis for the energy operation company to pay fees to each member, when a certain member misreports the price, whether it misreports a high price or a low price, it will lead to a reduction in its substitution benefit and damage its own interests. When all market members meet the individual rationality, paying fees based on the value of each member calculated by the above method in the long term will ultimately prompt each member to participate in the bidding according to the true power generation cost and gas production cost, restrain market members from making profits through strategic bidding, and ensure the stable operation and dispatching of the power market.

[0061] The present invention takes the system of the combined operation of the power subsystem and the natural gas subsystem as the research object. In addition to being applicable to the electric-gas combined system, the present invention is also applicable to other energy systems of single energy or multiple energies. Those skilled in the art only need to make adaptive modifications to the objective function and constraint conditions of the day-ahead market clearing model.

[0062] On the premise of the existence of power contracts and natural gas contracts, without considering the start-up and shutdown constraints, with the minimization of the electricity purchase cost of the grid company and the gas purchase cost of the gas company as the objective function, the objective function can be expressed as the following formula:

[0063]

[0064] In the formula, F cost represents the electricity purchase cost of the grid company and the gas purchase cost of the gas company, and N e is the set of generator sets in the system, including the set of thermal power generator sets and the set of gas turbines N g is the set of natural gas wells in the system.

[0065] f i (P i ) represents the cost that needs to be paid for the bidding electricity quantity P i output by the generator set i participating in the bidding. Generally, it can be expressed by a quadratic function:

[0066] f i (P i ) = α i P i 2 + b i Pi +c i (2)

[0067] α i 、β i and c i are their corresponding parameters.

[0068] f i con (P i con ) is the contract power P i con that the generator set i needs to produce according to the power contract, is the contract power price of the generator set i.

[0069]

[0070] g j (Q j ) and are respectively the competitive gas production volume Q j produced by the gas well j and the contract gas production volume that need to pay the cost, β j is its gas production cost coefficient, is its contract gas price.

[0071] g j (Q j ) = β j Q j (4)

[0072]

[0073] The constraint conditions of the day-ahead market clearing model of the electricity-gas integrated system considering energy contracts include three parts: power network constraints, gas network constraints, and electricity-gas integrated network coupling constraints.

[0074] (1) Power network constraints

[0075] 1) Node power supply-demand balance constraint:

[0076]

[0077] In the formula, P i C 、P i C,con are the competitive power and contract power of the i-th thermal power unit, P i G and P i G,con are respectively the competitive power and contract power of the i-th gas turbine, and L e respectively represent the index matrices of thermal power units, gas turbines and loads in the power grid; represents the power load demand of node i.

[0078] 2) Transmission network power flow constraint:

[0079]

[0080] where ζ li is the generation shift distribution factor of node i to transmission line l; is the transmission capacity of line l.

[0081] 3) Thermal power unit output constraint:

[0082]

[0083] where P i,min and P i,max respectively represent the lower and upper limits of the output of thermal power unit i.

[0084] 4) Gas turbine output constraint:

[0085]

[0086] where and respectively represent the lower and upper limits of the output of gas turbine i.

[0087] (2) Natural gas network constraints

[0088] 1) Natural gas well gas production constraint:

[0089]

[0090] where Q j,min and Q j,max respectively represent the lower and upper limits of gas production of natural gas well j.

[0091] 2) Natural gas pipeline node air pressure constraint:

[0092]

[0093] where p M,min and p M,max respectively represent the lower and upper limits of the air pressure of node M.

[0094] 3) Compressor compression ratio constraint:

[0095] ρ c,min ≤ρ c ≤ρ c,max (12)

[0096] where ρ c,min and ρ c,max represent the lower and upper limits of the compression ratio of the compressor c, respectively.

[0097] 4) Natural gas nodal balance constraint:

[0098]

[0099] where S g , W g and L g represent the index matrices of natural gas wells, natural gas pipelines, and natural gas loads in the natural gas network, respectively; F MN represents the natural gas flow rate in the pipeline connecting node M and node N; represents the natural gas load demand at node j.

[0100] (3) Coupling constraints of the integrated power-gas network

[0101] The gas-to-power constraint of the gas turbine is shown in Equation (14):

[0102]

[0103] where η represents the gas-to-power efficiency coefficient of the gas turbine; represents the natural gas consumed when the power generation of the gas turbine is (P i G +P i G,con ).

[0104] Through the above-mentioned day-ahead market clearing model of the integrated power-gas system considering energy contracts, the day-ahead market output and gas production plans of power generation units and natural gas wells can be obtained.

[0105] The VCG (Vickrey-Clarke-Groves) mechanism charges according to the losses caused by bidders to other bidders, and it is a mechanism design method that satisfies the incentive compatibility property, which can encourage market members to actively reveal their true cost information. Through the above-mentioned day-ahead market clearing model, the minimum values of the power purchase costs of the power grid company and the gas purchase costs of the gas company can be calculated when any member participates or does not participate in the day-ahead clearing. By calculating the change in the power purchase costs of other members and the gas purchase costs of the gas company when any member participates in the clearing and does not participate in the clearing respectively, this change represents the substitution benefit of this member to other members. Using this change as the value of this member and as the basis for the energy operation company to pay fees can inhibit each member from making profits through strategic bidding.

[0106] Considering the energy contract, assume that \(c\) and \(\beta\) represent the cost bid vectors declared by all thermal power generation units and natural gas wells to the ISO respectively. Assume that the optimal solution of the day-ahead market clearing optimization of the electric-gas integrated system considering the energy contract is In the case of considering the energy contract, according to the VCG mechanism, the value of the generator set is, that is, the fee paid by the ISO to it is:

[0107]

[0108] In the formula, \(M(P,Q)\) represents the optimal power purchase cost of the grid company and the gas purchase cost of the gas company when all members participate in the day-ahead market clearing optimization; represents the optimal power purchase cost of the grid company and the gas purchase cost of the gas company of the new system when the generator set \(i\) does not participate in the system day-ahead clearing and the declared costs of other generator sets are (equivalent to adding the constraint condition \(P i = 0 in the clearing model); is the power generation cost when the generator set \(i\) declares when all members participate in the day-ahead clearing, is the cost of the contract power of the generator set \(i\).

[0109] The value of the natural gas well \(j\), that is, the fee paid by the ISO to it is:

[0110]

[0111] In the formula: represents the optimal power purchase cost of the grid company and the gas purchase cost of the gas company of the new system when the natural gas well \(j\) does not participate in the system day-ahead clearing and the declared gas purchase costs of other natural gas wells are (equivalent to adding the constraint condition \(Q j = 0 in the clearing model); is the gas production cost when the natural gas well \(j\) declares and is the cost of the contract gas production volume of the natural gas well \(j\).

[0112] Next, the above method is verified with an electric-gas integrated system as Figure 2 shown. The electric-gas integrated system consists of a 14-node power system and a 9-node natural gas system. The relevant bidding parameters and contract parameters of the generator sets and natural gas wells are shown in Table 1 and Table 2 respectively; the parameters of the power load and natural gas load are shown in Table 3 and Table 4 respectively; in addition, a compressor is installed on each of the natural gas wells Q1 and Q4, and their loss ratio coefficients are both 7%. The gas-to-electricity conversion coefficient \(\eta\) of the gas turbine unit is 0.201 MW / kcf.

[0113] Table 1 Generator set parameters of IEEE 14-node power system

[0114]

[0115] Table 2 Natural gas well parameters of IEEE 9-node natural gas system

[0116]

[0117] Table 3 Power load parameters of IEEE 14-node power system

[0118]

[0119] Table 4 Natural gas load parameters of IEEE 9-node natural gas system

[0120]

[0121] (1) LMP mechanism

[0122] Taking G4 and Q2 as examples, under the LMP mechanism considering energy contracts, assuming that other power generation units and natural gas wells declare their true power generation costs and gas production costs. When the thermal power unit G4 and the natural gas well Q2 falsely report their power generation cost coefficients and gas production cost coefficients within a certain range, the changes in the true power purchase costs of the power grid company and the gas purchase costs of the natural gas company in the day-ahead market of the electricity-gas integrated system are as Figure 3 and Figure 4 .

[0123] From Figure 3 and Figure 4 , under the LMP mechanism, regardless of whether the power generation units and natural gas wells falsely report high cost coefficients or low cost coefficients, the true power purchase costs of the power grid company and the gas purchase costs of the natural gas company in the day-ahead market of the electricity-gas integrated system considering energy contracts are not less than the power purchase costs of the power grid company and the gas purchase costs of the natural gas company when all market members declare their true cost coefficients. Obviously, it does not meet the requirement of minimizing the power purchase costs of the power grid company and the gas purchase costs of the natural gas company in the day-ahead market.

[0124] (2) Energy price mechanism using the pricing of the present invention

[0125] When all market members in the above integrated system declare their true power generation / gas production costs, the competitive power generation outputs and gas production plans of each power generation unit and natural gas well, and the VCG fees and net profit calculation results paid by the ISO to them are shown in Tables 5 and 6 respectively.

[0126] Table 5 Competitive outputs, system payments and net profits of power generation units declaring true cost coefficients under the mechanism proposed in the present invention.

[0127]

[0128] Table 6 The bid production gas volume, system payment and net profit of the true cost coefficient of the natural gas wells declared by the mechanism proposed in the present invention

[0129]

[0130] As shown in Table 5 and Table 6, when all market members truthfully quote, the production gas volume of the natural gas well Q3 is 0 because its true gas production cost is the highest among the other three gas wells. At the same time, the net profits of the generator sets and natural gas wells are not less than 0. Therefore, the mechanism proposed in the present invention satisfies individual rationality.

[0131] To verify that the VCG energy price mechanism considering energy contracts proposed in the present invention satisfies incentive compatibility, since the power generation cost of the gas turbine depends on the gas price at the corresponding node and the market clearing gas production value of the natural gas well Q3 is 0, it is assumed that the gas turbines G1 and G3 do not participate in the market quotation, and the situation of the natural gas well Q3 participating in the market quotation is not considered. Figure 5 and Figure 6 give the results when the generator sets G2, G4, G5 and the natural gas wells Q1, Q2, Q4 false quote within a certain proportion range of their true cost coefficients.

[0132] From Figure 5 and Figure 6 , under the VCG energy price mechanism considering energy contracts proposed in the present invention, regardless of whether other market members false quote or not, when a certain generator set / natural gas well false quotes its power generation / gas production cost, whether it false quotes a high cost or a low cost, it will instead reduce its own profit. Therefore, the optimal strategy for the generator sets and natural gas wells is to declare the true power generation cost and the true gas production cost, that is, the mechanism proposed in the present invention satisfies incentive compatibility.

[0133] The energy pricing system of the electric-gas integrated system in the embodiment of the present invention includes a day-ahead market clearing module and a VCG energy pricing module. The day-ahead market clearing module is used to establish a day-ahead market clearing model of the electric-gas integrated system considering energy contracts, power network constraints, natural gas network constraints and electric-gas integrated network coupling constraints, and calculate the day-ahead market output and gas production plan of the electric-gas integrated system with the minimum sum of the power purchase cost of the power grid company and the gas purchase cost of the natural gas company as the optimization target; the VCG energy pricing module is used to calculate the substitution benefits of each member to other members according to the VCG mechanism and obtain the power purchase / gas purchase costs of other members before and after each member participates in the day-ahead market clearing through the market clearing module.

[0134] The storage medium of the embodiment of the present invention stores a computer program instantiated with the above energy pricing method.

Claims

1. An energy pricing method for an electric-gas integrated system, characterized in that, It includes the following steps: S1: Obtain the functions of the electricity purchase cost of the power grid company and the gas purchase cost of the gas company according to the energy contract; S2: Establish a day-ahead market clearing model for the electricity-gas integrated system with the power network constraints, gas network constraints, and electricity-gas integrated network coupling constraints as the constraint conditions and the minimization of the sum of the electricity purchase cost of the power grid company and the gas purchase cost of the gas company as the objective function; S3: According to the day-ahead market clearing model of the electricity-gas integrated system, calculate the optimal bidding electricity quantity of each generator set and the optimal bidding gas production volume of each gas well under three cases where all members participate in the day-ahead clearing of the system, generator set i does not participate in the day-ahead clearing of the system, and gas well j does not participate in the day-ahead clearing of the system; S4: Calculate the sum M of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when generator set i does not participate in the system's day-ahead clearing -i , the sum (M - f i -f i con ) of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when generator set i participates in the day-ahead clearing, the sum M of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when gas well j does not participate in the system's day-ahead clearing -j , the sum of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when gas well j participates in the system's day-ahead clearing The value of generator set i is: The value of gas well j is: M is the sum of the optimal power purchase costs of all members from the grid company and the gas purchase costs of all members from the gas company when all members participate in the day-ahead clearing, f i is the competitive power purchase cost of generator set i when all members participate in the day-ahead clearing, f i con is the contract power purchase cost of generator set i when all members participate in the day-ahead clearing, f j is the competitive gas purchase cost of gas well j when all members participate in the day-ahead clearing, is the contract gas purchase cost of gas well j when all members participate in the day-ahead clearing.

2. The energy pricing method for the electric-gas integrated system according to claim 1, characterized in that The power network constraints of the day-ahead market clearing model include: 1) The power supply and demand at each node reach balance; 2) The generation transfer distribution factor of each node to the corresponding transmission line is less than or equal to the transmission capacity of the corresponding transmission line; 3) The output of each thermal power unit is within the output range; 4) The output of each gas turbine is within the output range.

3. The energy pricing method for the electric-gas integrated system according to claim 1, characterized in that, The gas network constraints of the day-ahead market clearing model include: 1) The gas production of each gas well is within the gas production range; 2) The gas pressure at each gas pipeline node is within the gas pressure range; 3) The compression ratio of each compressor is within the compression ratio range; 4) The gas supply and demand at each node reach balance.

4. The energy pricing method for the electric-gas integrated system according to claim 1, characterized in that The electricity-gas integrated network coupling constraint of the day-ahead market clearing model is shown as the following formula: Among which P i G is the competitive power generation quantity of gas turbine i, P i G,con is the contract power generation quantity of gas turbine i, η is the efficiency coefficient at the turning point of the gas turbine i, is the gas volume of natural gas well j used to supply power generation for gas turbine i, is the set of gas turbines in the electric-gas integrated system, N g is the set of natural gas wells in the electric-gas integrated system.

5. The energy pricing method for the electric-gas integrated system according to claim 1, characterized in that, The day-ahead market clearing model is shown as follows: Objective function: Constraints: ρ c,min ≤ ρ c ≤ ρ c,max ; Among which F cost is the sum of the electricity purchase cost of the power grid company and the gas purchase cost of the gas company, N e is the set of generating units, is the set of thermal power units, is the set of gas turbine units, N g is the set of natural gas wells, f i (P i ) is the competitive bidding electricity price of generating unit i, f i con (P i con ) is the contract electricity price of generating unit i, P i The competitive bidding power generation volume of generating unit i, P i con is the contract power generation volume of generating unit i, f j (Q j ) is the competitive bidding gas price of natural gas well j, is the contract gas price of natural gas well j, Q j is the competitive bidding gas production volume of natural gas well j, is the contract gas production volume of natural gas well j; g j (Q j ) is the competitive bidding gas production volume Q of natural gas well j j The cost to be paid; is the contract gas production volume of natural gas well j The cost to be paid; P i C is the competitive bidding power generation of thermal power unit i, P i C,con is the contract power generation of thermal power unit i, P i G is the competitive bidding power generation of gas turbine i, P i G,con is the contract power generation of gas turbine i, and L e respectively represent the index matrices of thermal power units, gas turbine units and loads in the power network, represents the power load demand of node i; ζ li represents the generation shift distribution factor of node i with respect to transmission line l; is the transmission capacity of line l; and are the lower and upper limits of the output of thermal power and i, respectively; and are the lower limit and upper limit of the output of gas turbine i, respectively; Q j,min and Q j,max are the lower and upper limits of gas production of gas well j, respectively; p M,min and p M,max are respectively the lower limit and the upper limit of the air pressure at the natural gas pipeline node M, and p M is the air pressure at the natural gas pipeline node M; ρ c,min and ρ c,max are respectively the lower limit and the upper limit of the compression ratio of the compressor c, and ρ c is the compression ratio of the compressor c; S g 、W g and L g respectively represent the index matrices of gas wells, gas pipelines, and gas loads in the natural gas network, F MN represents the gas flow rate in the pipeline connecting node M and node N, represents the gas load demand of node j; η represents the gas-to-electricity efficiency coefficient of the gas turbine, represents the gas volume supplied from natural gas well j to gas turbine i for power generation.

6. An energy pricing system for an electric-gas integrated system, characterized in that, It includes: A day-ahead market clearing module, which is used to establish a day-ahead market clearing model for the electricity-gas integrated system considering energy contracts, power network constraints, gas network constraints, and electricity-gas integrated network coupling constraints, and calculate the day-ahead market output and gas production plan of the electricity-gas integrated system with the minimization of the sum of the electricity purchase cost of the power grid company and the gas purchase cost of the gas company as the optimization objective; The VCG energy pricing module is used to calculate, according to the VCG mechanism, the sum M of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when generator set i does not participate in the day-ahead clearing of the system -i , the sum (M - f i -f i con ) of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when generator set i participates in the day-ahead clearing of the system, the sum M of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when gas well j does not participate in the day-ahead clearing of the system -j , the sum of the optimal power purchase costs of other members from the grid company and the gas purchase costs of other members from the gas company when gas well j participates in the day-ahead clearing of the system The value of generator set i is: The value of gas well j is: M is the sum of the optimal power purchase costs of all members from the grid company and the gas purchase costs of all members from the gas company when all members participate in the day-ahead clearing, f i is the competitive power purchase cost of generator set i when all members participate in the day-ahead clearing, f i con is the contract power purchase cost of generator set i when all members participate in the day-ahead clearing, f j is the competitive gas purchase cost of gas well j when all members participate in the day-ahead clearing, is the contract gas purchase cost of gas well j when all members participate in the day-ahead clearing.

7. A storage medium stores a computer program, characterized in that, The computer program is designed to implement the energy pricing method for the electricity-gas integrated system according to any one of claims 1 to 5 when executed.

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