Joint market clearing method considering cross-regional standby mutual aid

Abstract

The invention discloses a joint market clearing method considering cross-regional standby mutual aid, and the method comprises the following steps: 1), considering a coupling relation between unit energy and standby, taking the minimum total operation cost as a target, and constructing a security constraint unit commitment model; 2) solving the security constraint unit commitment model to obtain a unit commitment scheme; 3) constructing a security constraint economic dispatch model; 4) based on the unit commitment scheme in the step 2), solving the security constraint economic dispatch model to obtain a dual multiplier of a constraint condition of the security constraint economic dispatch model; and 5) based on the dual multiplier, carrying out market subject settlement, including energy settlement and standby auxiliary service settlement. According to the method, the new energy can bear corresponding auxiliary service cost while cross-regional consumption of the new energy can be promoted, and powerful support is provided for optimal scheduling and safe and stable operation of a power system.

Description

Technical Field

[0001] The invention relates to the field of power systems and automation thereof, and in particular to a joint market clearing method taking into account cross-regional reserve mutual assistance. Background Art

[0002] The great differences in resource endowments in various regions of China have led to an increasingly urgent need for cross-provincial and cross-regional consumption of new energy. By the end of 2023, the total installed capacity of new energy power generation in China will reach 1.05 billion kilowatts, accounting for 35.99% of the total installed capacity; 20 ultra-high voltage direct current transmission channels will be built, with a cross-provincial and cross-regional transmission capacity of about 300 million kilowatts. In the future, China will continue to promote the planning and construction of cross-provincial and cross-regional transmission channels and the upgrading and transformation of distribution networks. Considering the large-scale grid connection of new energy, the wide-area configuration of power resources will become the mainstream trend of China's power system in the future.

[0003] At present, the dispatching systems of various countries determine the allowable power transmission range based on the transmission capacity of inter-regional transmission lines, and carry out the inter-regional optimal allocation of power resources accordingly. China's inter-regional dispatching adopts a zoning mode. The National Dispatching Center first coordinates and formulates the inter-regional interconnection line power transmission plan, and each province / region formulates its own dispatching plan based on the inter-regional boundary conditions. Under the framework of the US electricity spot market, each independent system operator (ISOs) needs to release interconnection line information and price signals in advance to promote inter-regional power transmission and market transactions between regions. In the European power market, the European inter-regional power market considers inter-regional transmission capacity before and during the day. The clearing algorithm formulates clearing results and inter-regional power plans according to the maximization of social welfare. Through market means, the power in the load-frequency control (LFC) area flows from the low-price area to the high-price area, realizing the inter-regional optimal allocation of power resources. The coupling of regional markets reduces the impact of a high proportion of new energy on the power balance of the European power grid.

[0004] Under the above-mentioned inter-regional trading methods, inter-regional interconnection line trading only considers electric energy trading, and the real-time balance of inter-regional imported electric energy is considered afterwards. China's inter-regional imported electric energy basically does not bear the obligation of auxiliary services, and the receiving area is responsible for the real-time balance of electric energy. The United States conducts inter-regional electric energy trading based on the net exchange of electric energy between regions to make up for the difference between regional power generation and demand. After the electric energy of the interconnection line is cleared on the day before, some European transmission system operators (TSOs) adopt a data-driven approach to evaluate the adequacy of inter-regional trading resources. However, due to the specific randomness, volatility, and uncertainty of new energy, in the scenario of large-scale grid connection of new energy in the future, the adequacy of standby auxiliary service resources will become the main factor restricting the cross-regional consumption of new energy.

[0005] At present, China has built an energy market that reflects the supply and demand matching on the power generation side and the user side, and has formed an energy scarcity price based on the supply and demand matching relationship, but has not yet built a regional reserve market that can reflect the supply and demand matching of reserve ancillary services, and has not yet formed a reserve scarcity price that can reflect the scarcity of reserve. Therefore, it is necessary to study the market mechanism that takes into account the cross-regional mutual assistance of reserve, build a cross-regional reserve ancillary service market that can accurately reflect the value of ancillary services and guide full competition between supply and demand, and realize the wide-area optimal allocation of resources. Summary of the invention

[0006] The object of the present invention is to provide a joint market clearing method taking into account cross-regional reserve mutual assistance, comprising the following steps:

[0007] 1) Considering the coupling relationship between unit energy and reserve, and taking the minimum total operating cost as the goal, a safety constraint unit combination model is constructed;

[0008] 2) Solve the safety constraint unit combination model and obtain the unit combination plan;

[0009] 3) Construct a safety-constrained economic dispatch model;

[0010] 4) Based on the unit combination scheme in step 2), solve the safety constraint economic dispatch model and obtain the dual multiplier of the constraint conditions of the safety constraint economic dispatch model;

[0011] 5) Based on the dual multiplier, market entity settlement is carried out, including energy settlement and standby ancillary service settlement.

[0012] Furthermore, the objective function of the safety constraint unit commitment model is as follows:

[0013]

[0014] Where: p j,t is the output of traditional generator j at time t; p w,t is the output of the new energy unit w at time t; and are the upper and lower reserve bid quantities of the traditional generator set j at time t respectively; are the power generation cost, upper reserve cost, lower reserve cost, startup cost, and shutdown cost of traditional generator j at time t respectively; is the power generation cost of the new energy unit w at time t; and is a Boolean variable for starting and stopping the unit; T is a time period set; J is a set of traditional generators; W is a set of new energy units.

[0015] Furthermore, the constraints of the safety constraint unit combination model include power balance constraints, line flow constraints, traditional unit climbing constraints, traditional unit start and stop time constraints, traditional unit start and stop logic constraints, backup demand declaration constraints, backup transmission line capacity reservation constraints, unit winning bid constraints, and new energy backup demand adjustment constraints.

[0016] Furthermore, the power balance constraint is as follows:

[0017]

[0018] Where: p n,t is the load demand of node n at time t; N is the node set, λ t is the dual multiplier of the power balance constraint;

[0019] The line flow constraints are as follows:

[0020]

[0021] Where: Γ i,n is the transfer distribution factor of line i to node n; e n,j and e n,w are the labels of the nodes n where the traditional generator j and the new energy generator w are located; and are the upper and lower limits of the transmission capacity of line i at time t; f i,t is the transmission line power distribution of line i at time t; i,t and are the dual multipliers of the lower and upper constraints of the power flow respectively;

[0022] The traditional unit climbing constraints are as follows:

[0023]

[0024] Where: Ru is the Boolean variable of the operating status of the traditional unit j at time t; j and Rd j Su are the up and down climbing rates of the unit respectively; j and Sd j are the maximum ramp rates when the unit is started and stopped; p j,t-1 is the clearing amount of traditional generator j at time t-1; is the Boolean variable of the operating status of the traditional unit j at time t-1;

[0025] The start and stop time constraints of traditional units are as follows:

[0026]

[0027] In the formula, TO and TS are the minimum start-up time and minimum downtime respectively; is the Boolean variable of the operating status of the traditional unit j at time k;

[0028] The traditional unit start and stop logic constraints are as follows:

[0029]

[0030] In the formula, It is the initial operating state of the unit; The unit operating status at time t=1;

[0031] The alternate requirement declaration constraints are as follows:

[0032]

[0033] In the formula, and They are the upper and lower reserve demands reported by the new energy unit w at time t; and are the upper and lower reserve requirements declared by the power user at node n, respectively; and are the upper and lower reserve adjustment variables of the new energy unit w at time t; are the upper and lower spare dual multipliers for the power balance constraint;

[0034] The capacity reservation constraints for the backup transmission lines are as follows:

[0035]

[0036] In the formula, and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively;

[0037] The scalar constraints in the unit are as follows:

[0038]

[0039] In the formula, is the Boolean variable of the standby winning bid status of the traditional unit j at time t, and M is a sufficiently large constant; are the upper and lower limits of the clearing volume of traditional generator j; is the upper limit of the clearing volume of the new energy unit w at time t;

[0040] The adjustment constraints of new energy reserve demand are as follows:

[0041]

[0042] In the formula, and are the upper and lower reserve adjustment coefficients, respectively, and are taken as 1 in this paper; Adjust the state Boolean variable for the new energy reserve demand.

[0043] Furthermore, the objective function of the safety-constrained economic dispatch model is as follows:

[0044]

[0045] In the formula, J * is the set of traditional units that are in the on state at time t.

[0046] Furthermore, the constraints of the safety-constrained economic dispatch model include equations (2), (6), (11)-(24).

[0047] Furthermore, the unit combination scheme includes the operating state variables of the traditional unit j Startup status variables Shutdown status variables

[0048] Furthermore, in step 5), the steps of market entity settlement include:

[0049] 5.1) Calculate the product prices in each market, namely:

[0050]

[0051] Where: and It is divided into the energy, upper backup and lower backup node marginal prices of node n at time t, Γ' i,n =Γ n,i is the power flow transfer distribution factor after the change; I is the line set; σ i,t and They are the dual multipliers of the conventional line power flow and the upper limit constraint respectively; and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively;

[0052] 5.2) Perform energy market settlement and obtain:

[0053]

[0054] Where: is the energy gain of the traditional unit, is the energy gain of the new energy unit, Payments for electricity users’ energy;

[0055] 5.3) Perform the standby market settlement and obtain:

[0056]

[0057] Where: is the reserve income of the traditional unit, Payment for the standby of new energy units, Upper reserve payment for electricity users.

[0058] 5.4) Perform the next standby market settlement and obtain:

[0059]

[0060] Where: is the reserve income of the traditional unit, To provide standby payment for new energy units. Lower reserve payments for electricity users.

[0061] Furthermore, after market entities settle accounts, traditional power generating units obtain lower reserve income according to the product of lower reserve clearing volume and lower reserve node marginal price, and new energy generating units and power users pay lower reserve fees according to the product of lower reserve demand volume and lower reserve node marginal price;

[0062] Traditional power generating units and new energy generating units obtain energy benefits according to the product of energy clearance and marginal price of energy nodes. Power users pay energy fees according to the product of load and marginal price of energy nodes, and transmission lines obtain conventional congestion surplus benefits.

[0063] Traditional power generating units obtain upper reserve income according to the product of upper reserve clearance volume and the marginal price of upper reserve node, while new energy generating units and power users pay upper reserve fee according to the product of upper reserve demand volume and the marginal price of upper reserve node.

[0064] Furthermore, the solution tools for the safety-constrained unit commitment model and the safety-constrained economic dispatch model include a Cplex solver.

[0065] The technical effect of the present invention is unquestionable. The present invention promotes the cross-regional consumption of new energy through the joint clearing and settlement of regional energy and reserve, while allowing the new energy to bear the corresponding ancillary service costs, providing strong support for the optimized scheduling and safe and stable operation of the power system. BRIEF DESCRIPTION OF THE DRAWINGS

[0066] Figure 1The market settlement cash flow of the settlement mechanism proposed in the present invention;

[0067] Figure 2 is a basic model of the power grid in the embodiment;

[0068] Figure 3 It is the new energy output in scenario 1 when the regional reserves are not mutually beneficial;

[0069] Figure 4 This is the new energy output in scenario 1 during regional reserve mutual assistance.

[0070] Figure 5 This is the new energy output in scenario 2 when regional reserves are not mutually beneficial.

[0071] Figure 6 This is the new energy output in scenario 2 when there is regional reserve mutual assistance. DETAILED DESCRIPTION

[0072] The present invention is further described below in conjunction with the embodiments, but it should not be understood that the above subject matter of the present invention is limited to the following embodiments. Without departing from the above technical ideas of the present invention, various substitutions and changes are made according to the common technical knowledge and customary means in the art, which should all be included in the protection scope of the present invention.

[0073] Embodiment 1:

[0074] See also Figure 1 to Figure 2 , a joint market clearing method considering cross-regional reserve mutual assistance, including the following steps:

[0075] 1) Considering the coupling relationship between unit energy and reserve, and taking the minimum total operating cost as the goal, a safety constraint unit combination model is constructed;

[0076] 2) Solve the safety constraint unit combination model and obtain the unit combination plan;

[0077] 3) Construct a safety-constrained economic dispatch model;

[0078] 4) Based on the unit combination scheme in step 2), solve the safety constraint economic dispatch model and obtain the dual multiplier of the constraint conditions of the safety constraint economic dispatch model;

[0079] 5) Based on the dual multiplier, market entity settlement is carried out, including energy settlement and standby ancillary service settlement.

[0080] The objective function of the safety constraint unit combination model is as follows:

[0081]

[0082] Where: p j,t is the output of traditional generator j at time t; pw,t is the output of the new energy unit w at time t; and are the upper and lower reserve bid quantities of the traditional generator set j at time t respectively; are the power generation cost, upper reserve cost, lower reserve cost, startup cost, and shutdown cost of traditional generator j at time t respectively; is the power generation cost of the new energy unit w at time t; and is a Boolean variable for starting and stopping the unit; T is a time period set; J is a set of traditional generators; W is a set of new energy units.

[0083] The constraints of the safety constraint unit combination model include power balance constraints, line flow constraints, traditional unit climbing constraints, traditional unit start and stop time constraints, traditional unit start and stop logic constraints, backup demand declaration constraints, backup transmission line capacity reservation constraints, unit winning bid constraints, and new energy backup demand adjustment constraints.

[0084] The power balance constraints are as follows:

[0085]

[0086] Where: p n,t is the load demand of node n at time t; N is the node set, λ t is the dual multiplier of the power balance constraint (also called shadow price);

[0087] The line flow constraints are as follows:

[0088]

[0089] Where: Γ i,n is the transfer distribution factor of line i to node n; e n,j and e n,w are the labels of the nodes n where the traditional generator j and the new energy generator w are located; and are the upper and lower limits of the transmission capacity of line i at time t; f i,t is the transmission line power distribution of line i at time t; i,t and are the dual multipliers of the lower and upper constraints of the power flow respectively;

[0090] The traditional unit climbing constraints are as follows:

[0091]

[0092] Where: Ru is the Boolean variable of the operating status of the traditional unit j at time t; jand Rd j Su are the up and down climbing rates of the unit respectively; j and Sd j are the maximum ramp rates when the unit is started and stopped; p j,t-1 is the clearing amount of traditional generator j at time t-1; is the Boolean variable of the operating status of the traditional unit j at time t-1;

[0093] The start and stop time constraints of traditional units are as follows:

[0094]

[0095] In the formula, TO and TS are the minimum start-up time and minimum downtime respectively; is the Boolean variable of the operating status of the traditional unit j at time k;

[0096] The traditional unit start and stop logic constraints are as follows:

[0097]

[0098] In the formula, It is the initial operating state of the unit; The unit operating status at time t=1;

[0099] The alternate requirement declaration constraints are as follows:

[0100]

[0101] In the formula, and They are the upper and lower reserve demands reported by the new energy unit w at time t; and are the upper and lower reserve requirements declared by the power user at node n, respectively; and are the upper and lower reserve adjustment variables of the new energy unit w at time t; are the upper and lower spare dual multipliers for the power balance constraint;

[0102] The capacity reservation constraints for the backup transmission lines are as follows:

[0103]

[0104] In the formula, and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively;

[0105] The scalar constraints in the unit are as follows:

[0106]

[0107] In the formula, is the Boolean variable of the standby winning bid status of the traditional unit j at time t, and M is a sufficiently large constant; are the upper and lower limits of the clearing volume of traditional generator j; is the upper limit of the clearing volume of the new energy unit w at time t;

[0108] The adjustment constraints of new energy reserve demand are as follows:

[0109]

[0110] In the formula, and are the upper and lower reserve adjustment coefficients, respectively, and are taken as 1 in this paper; Adjust the state Boolean variable for the new energy reserve demand.

[0111] The objective function of the safety-constrained economic dispatch model is as follows:

[0112]

[0113] In the formula, J * is the set of traditional units that are in the on state at time t.

[0114] The constraints of the safety-constrained economic dispatch model include equations (2), (6), (11)-(24).

[0115] The unit combination scheme includes the operating state variables of the traditional unit j Startup status variables Shutdown status variables

[0116] In step 5), the steps of market entity settlement include:

[0117] 5.1) Calculate the product prices in each market, namely:

[0118]

[0119] Where: and It is divided into the energy, upper backup and lower backup node marginal prices of node n at time t, Γ' i,n =Γ n,i is the power flow transfer distribution factor after the change; I is the line set; σ i,t and They are the dual multipliers of the conventional line power flow and the upper limit constraint respectively; and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively;

[0120] 5.2) Perform energy market settlement and obtain:

[0121]

[0122] Where: is the energy gain of the traditional unit, is the energy gain of the new energy unit, Payments for electricity users’ energy;

[0123] 5.3) Perform the standby market settlement and obtain:

[0124]

[0125] Where: is the reserve income of the traditional unit, Payment for the standby of new energy units, Upper reserve payment for electricity users.

[0126] 5.4) Perform the next standby market settlement and obtain:

[0127]

[0128]

[0129] Where: is the reserve income of the traditional unit, To provide standby payment for new energy units. Lower reserve payments for electricity users.

[0130] After market entities settle accounts, traditional power generating units obtain reserve income according to the product of reserve clearing volume and reserve node marginal price, and new energy generating units and power users pay reserve fees according to the product of reserve demand volume and reserve node marginal price;

[0131] Traditional power generating units and new energy generating units obtain energy benefits according to the product of energy clearance and marginal price of energy nodes. Power users pay energy fees according to the product of load and marginal price of energy nodes, and transmission lines obtain conventional congestion surplus benefits.

[0132] Traditional power generating units obtain upper reserve income according to the product of upper reserve clearance volume and the marginal price of upper reserve node, while new energy generating units and power users pay upper reserve fee according to the product of upper reserve demand volume and the marginal price of upper reserve node.

[0133] The solution tools for the safety-constrained unit commitment model and the safety-constrained economic dispatch model include the Cplex solver.

[0134] Embodiment 2:

[0135] A joint market clearing method considering cross-regional reserve mutual assistance includes the following steps:

[0136] 1) Considering the coupling relationship between unit energy and reserve, and taking the minimum total operating cost as the goal, a safety constraint unit combination model is constructed;

[0137] 2) Solve the safety constraint unit combination model and obtain the unit combination plan;

[0138] 3) Construct a safety-constrained economic dispatch model;

[0139] 4) Based on the unit combination scheme in step 2), solve the safety constraint economic dispatch model and obtain the dual multiplier of the constraint conditions of the safety constraint economic dispatch model;

[0140] 5) Based on the dual multiplier, market entity settlement is carried out, including energy settlement and standby ancillary service settlement.

[0141] Embodiment 3:

[0142] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content is the same as that of Example 2, and further, the objective function of the safety constraint unit commitment model is as follows:

[0143]

[0144] Where: p j,t is the output of traditional generator j at time t; p w,t is the output of the new energy unit w at time t; and are the upper and lower reserve bid quantities of the traditional generator set j at time t respectively; are the power generation cost, upper reserve cost, lower reserve cost, startup cost, and shutdown cost of traditional generator j at time t respectively; is the power generation cost of the new energy unit w at time t; and is a Boolean variable for starting and stopping the unit; T is a time period set; J is a set of traditional generators; W is a set of new energy units.

[0145] Embodiment 4:

[0146] A joint market clearing method that takes into account cross-regional reserve mutual assistance, the technical content is the same as any one of Examples 2-3, and further, the constraints of the safety constraint unit combination model include power balance constraints, line flow constraints, traditional unit climbing constraints, traditional unit start and stop time constraints, traditional unit start and stop logic constraints, reserve demand declaration constraints, reserve transmission line capacity reservation constraints, unit winning bid constraints, and new energy reserve demand adjustment constraints.

[0147] Embodiment 5:

[0148] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content is the same as any one of embodiments 2-4, and further, the power balance constraint is as follows:

[0149]

[0150] Where: p n,t is the load demand of node n at time t; N is the node set, λ t is the dual multiplier of the power balance constraint;

[0151] The line flow constraints are as follows:

[0152]

[0153] Where: Γ i,n is the transfer distribution factor of line i to node n; e n,j and e n,w are the labels of the nodes n where the traditional generator j and the new energy generator w are located; and are the upper and lower limits of the transmission capacity of line i at time t; f i,t is the transmission line power distribution of line i at time t; i,t and are the dual multipliers of the lower and upper constraints of the power flow respectively;

[0154] The traditional unit climbing constraints are as follows:

[0155]

[0156] Where: Ru is the Boolean variable of the operating status of the traditional unit j at time t; j and Rd j Su are the up and down climbing rates of the unit respectively; j and Sd j are the maximum ramp rates when the unit is started and stopped; p j,t-1 is the clearing amount of traditional generator j at time t-1; is the Boolean variable of the operating status of the traditional unit j at time t-1;

[0157] The start and stop time constraints of traditional units are as follows:

[0158]

[0159] In the formula, TO and TS are the minimum start-up time and minimum downtime respectively; is the Boolean variable of the operating status of the traditional unit j at time k;

[0160] The traditional unit start and stop logic constraints are as follows:

[0161]

[0162] In the formula, It is the initial operating state of the unit;

[0163] The alternate requirement declaration constraints are as follows:

[0164]

[0165] In the formula, and They are the upper and lower reserve demands reported by the new energy unit w at time t; and are the upper and lower reserve requirements declared by the power user at node n, respectively; and are the upper and lower reserve adjustment variables of the new energy unit w at time t; are the upper and lower spare dual multipliers for the power balance constraint;

[0166] The capacity reservation constraints for the backup transmission lines are as follows:

[0167]

[0168] In the formula, and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively;

[0169] The scalar constraints in the unit are as follows:

[0170]

[0171]

[0172] In the formula, is the Boolean variable of the standby winning bid status of the traditional unit j at time t, and M is a sufficiently large constant; are the upper and lower limits of the clearing volume of traditional generator j; is the upper limit of the clearing volume of the new energy unit w at time t;

[0173] The adjustment constraints of new energy reserve demand are as follows:

[0174]

[0175] In the formula, and are the upper and lower reserve adjustment coefficients, respectively, and are taken as 1 in this paper; Adjust the state Boolean variable for the new energy reserve demand.

[0176] Embodiment 6:

[0177] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content is the same as any one of embodiments 2-5, further, the objective function of the safety-constrained economic dispatch model is as follows:

[0178]

[0179] In the formula, J * is the set of traditional units that are in the on state at time t.

[0180] Embodiment 7:

[0181] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content of which is the same as any one of Examples 2-6. Furthermore, the constraints of the safety-constrained economic dispatch model include equations (2), (6), (11)-(24).

[0182] Embodiment 8:

[0183] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content is the same as any one of embodiments 2-7, further, the unit combination plan includes the operating state variable of the traditional unit j Startup status variables Shutdown status variables

[0184] Embodiment 9:

[0185] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content is the same as any one of embodiments 2-8, further, in step 5), the step of performing market entity settlement includes:

[0186] 5.1) Calculate the product prices in each market, namely:

[0187]

[0188] Where: and It is divided into the energy, upper backup and lower backup node marginal prices of node n at time t, Γ' i,n =Γ n,i is the power flow transfer distribution factor after the change; I is the line set; σ i,t and They are the dual multipliers of the conventional line power flow and the upper limit constraint respectively; and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively;

[0189] 5.2) Perform energy market settlement and obtain:

[0190]

[0191] Where: is the energy gain of the traditional unit, is the energy gain of the new energy unit, Payments for electricity users’ energy;

[0192] 5.3) Perform the standby market settlement and obtain:

[0193]

[0194] Where: is the reserve income of the traditional unit, Payment for the standby of new energy units, Upper reserve payment for electricity users.

[0195] 5.4) Perform the next standby market settlement and obtain:

[0196]

[0197] Where: is the reserve income of the traditional unit, To provide standby payment for new energy units. Lower reserve payments for electricity users.

[0198] Embodiment 10:

[0199] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content is the same as any one of embodiments 2-9, further, after the market subject settlement, the traditional power generation unit obtains the reserve income according to the product of the reserve clearing amount and the reserve node marginal price, and the new energy unit and the power user pay the reserve fee according to the product of the reserve demand amount and the reserve node marginal price;

[0200] Traditional power generating units and new energy generating units obtain energy benefits according to the product of energy clearance and marginal price of energy nodes. Power users pay energy fees according to the product of load and marginal price of energy nodes, and transmission lines obtain conventional congestion surplus benefits.

[0201] Traditional power generating units obtain upper reserve income according to the product of upper reserve clearance volume and the marginal price of upper reserve node, while new energy generating units and power users pay upper reserve fee according to the product of upper reserve demand volume and the marginal price of upper reserve node.

[0202] Embodiment 11:

[0203] A joint market clearing method considering cross-regional reserve mutual assistance, the technical content of which is the same as any one of Examples 2-10. Furthermore, the solution tools for the safety-constrained unit combination model and the safety-constrained economic dispatch model include a Cplex solver.

[0204] Embodiment 12:

[0205] A joint market clearing method considering cross-regional reserve mutual assistance is as follows:

[0206] First, a unit safety constraint containing the coupling relationship between energy and reserve capacity is constructed to ensure the deliverability of energy and reserve from the unit level; then a system safety constraint containing cross-regional reserve calls is constructed to ensure the deliverability of energy and reserve from the system level; finally, a market settlement and cost sharing mechanism that can achieve "who benefits, who bears" is designed based on the marginal clearing price and the system safety constraint dual multiplier. The case study based on the IEEE30-node system call Cplex solver in Matlab software shows that the present invention can promote the cross-regional consumption of new energy while ensuring the safe and stable operation of the system, reduce the overall operating cost of the regional market, and realize the reasonable sharing of market operating costs, thereby achieving wide-area optimal allocation of resources.

[0207] 1. Safety Constraint Unit Combination Model

[0208] 1) Objective function

[0209] The objective function is to minimize the total operating cost, which is composed of the electricity production cost of traditional generators and new energy sources, the standby cost of traditional generators, and the start-up and shutdown cost of traditional generators.

[0210]

[0211] Where: p j,t is the output of traditional generator j at time t; p w,t is the output of the new energy unit w at time t; and are the upper and lower reserve bid quantities of the traditional generator set j at time t respectively; are the power generation cost, upper reserve cost, lower reserve cost, startup cost, and shutdown cost of traditional generator j at time t respectively; is the power generation cost of the new energy unit w at time t; and is a Boolean variable for starting and stopping the unit; T is a time period set; J is a set of traditional generators; W is a set of new energy units.

[0212] 2) Power balance constraints

[0213]

[0214] Where: p n,t is the load demand of node n at time t; N is the node set, λ t is the dual multiplier of the power balance constraint (assuming λ t >0).

[0215] 3) Line flow constraints

[0216]

[0217] Where: Γ i,n is the transfer distribution factor of line i to node n; e n,j and e n,w are the labels of the nodes n where the traditional generator j and the new energy generator w are located; and are the upper and lower limits of the transmission capacity of line i at time t; f i,t is the transmission line power distribution of line i at time t; i,t and are the dual multipliers of the lower and upper constraints of the power flow respectively.

[0218] 4) Traditional unit climbing constraints

[0219]

[0220] Where: Ru is the Boolean variable of the operating status of the traditional unit j; j and Rd j Su are the up and down climbing rates of the unit respectively; jand Sd j They are the maximum climbing rates when the unit is started and stopped, respectively.

[0221] 5) Traditional unit start and stop time constraints

[0222]

[0223] Where TO and TS are the minimum startup time and minimum shutdown time respectively.

[0224] 6) Traditional unit start-stop logic constraints

[0225]

[0226] In the formula, This is the initial operating status of the unit.

[0227] 7) Alternative demand declaration constraints

[0228]

[0229] In the formula, and They are the upper and lower reserve demands reported by the new energy unit w at time t; and are the upper and lower reserve requirements declared by the power user at node n, respectively; and They are the upper and lower reserve adjustment variables of the new energy unit w at time t.

[0230] 8) Reserved transmission line capacity constraints

[0231]

[0232] In the formula, and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively.

[0233] 9) Unit bid quantity constraints

[0234]

[0235] In the formula, is the Boolean variable of the standby winning bid status of the traditional unit j at time t, and M is a large constant. Constraints (19)-(20) ensure that the standby winning bid of the unit can respond to the demand in time, and constraints (21)-(22) avoid the situation where the same unit wins the bid for upper and lower standby at the same time.

[0236] 10) Adjustment constraints on new energy reserve demand

[0237]

[0238] In the formula, and are the upper and lower reserve adjustment coefficients, respectively, and are taken as 1 in this paper; Adjust the state Boolean variable for the new energy reserve demand.

[0239] Formulas (1)-(24) constitute a regional safety constraint unit combination optimization model that takes into account the reservation of backup transmission channels. This model takes into account the coupling relationship between unit energy and backup. When backup resources are scarce, the overall operating cost of the market can be reduced by adjusting the backup demand. In addition, formulas (13)-(14) ensure that each applicant can obtain sufficient and deliverable backup capacity, and its dual multiplier can also reflect the value difference of backup at different nodes.

[0240] Since the model has integer variables and belongs to a mixed integer linear programming model, it is impossible to obtain the dual multipliers of the constraints. Therefore, after determining the unit combination, it is necessary to solve the economic dispatch model to obtain the dual multipliers of each constraint, so as to calculate the responsibilities of each party and achieve reasonable cost sharing.

[0241] 2. Safety Constrained Economic Dispatch Model

[0242] 1) Objective function

[0243] The objective function is: under a certain unit state, the total market operating cost is minimized. The market cost is composed of the electricity production cost of traditional generators and new energy, and the standby cost of traditional generators.

[0244]

[0245] In the formula, J * is the set of traditional units that are in the on state at time t.

[0246] 2) Constraints

[0247] In the economic dispatch solution, the operating state variables of the traditional unit j are Startup status variables Shutdown status variables All are known, so there is no need for unit start-stop time constraints and unit start-stop logic constraints. The unit start-stop plan is introduced into constraint equations (2)-(6) and (11)-(24) to form a constraint set for economic dispatch, which together with equation (25) constitutes a safety constraint economic dispatch model that takes into account the reservation of backup transmission channels. This model is a linear programming model. By solving the model, the dual multiplier of its constraints can be obtained, which provides a basis for the responsibility sharing of each market member.

[0248] 3. Market settlement mechanism taking into account differentiated reserve requirements

[0249] After solving the above unit combination and economic dispatch model, the transaction information of each market player is obtained. However, due to the differences in the reserve demand of each player, the payment of reserve needs to be shared according to the different sources of reserve demand. Based on this, this section constructs a sharing mechanism for market operation costs based on the basic principle of "whoever generates, whoever bears".

[0250] The final product prices in each market can be expressed as:

[0251]

[0252] Where: and It is divided into the energy, upper backup and lower backup node marginal prices of node n at time t, Γ′ i,n =Γ n,i is the power flow transfer distribution factor after the change; I is the line set.

[0253] Due to the spatial transmission limitation of network congestion, each node n has a conventional line congestion component. and σ i,t In addition, there is also a blocking component with the reserved line for backup transmission and These price components participate in forming the node marginal price. According to this price, the settlement of each market player is divided into energy settlement and reserve ancillary service settlement. The settlement methods of each market are as follows.

[0254] 1) Energy market settlement

[0255]

[0256] Where: is the energy gain of the traditional unit, is the energy gain of the new energy unit, Payments for energy from electricity users.

[0257] Traditional power generating units and new energy generating units obtain energy benefits according to the product of energy clearance and marginal price of energy nodes. Power users pay energy fees according to the product of load and marginal price of energy nodes, and transmission lines obtain conventional congestion surplus benefits.

[0258] 2) Settlement in the backup market

[0259]

[0260]

[0261] Where: is the reserve income of the traditional unit, Payment for the standby of new energy units, Upper reserve payment for electricity users.

[0262] Traditional power generating units obtain upper reserve income according to the product of upper reserve clearance volume and the marginal price of upper reserve node, while new energy generating units and power users pay upper reserve fee according to the product of upper reserve demand volume and the marginal price of upper reserve node.

[0263] 3) Settlement in the reserve market

[0264]

[0265] Where: is the reserve income of the traditional unit, To provide standby payment for new energy units. Lower reserve payments for electricity users.

[0266] Traditional power generating units obtain lower reserve income according to the product of lower reserve clearance volume and the marginal price of lower reserve node, while new energy generating units and power users pay lower reserve fee according to the product of lower reserve demand volume and the marginal price of lower reserve node.

[0267] The advantage of settling the energy market and the reserve market separately is that it can avoid users who have not declared reserve demand, that is, non-beneficiaries of the reserve transmission channel reservation, from paying the reserve transmission channel reservation fee. The joint clearing of the energy and reserve markets achieves the global optimization of market costs, and the separate settlement of the market can clarify the responsibilities of all market entities, so that market entities pay the corresponding fees according to their own income, ensure the balance of income and expenditure, and avoid excessive payment by users, so as to achieve "whoever generates, whoever bears".

[0268] Embodiment 13:

[0269] A verification of the joint market clearing method considering cross-regional reserve mutual assistance described in any one of Examples 1-12 is as follows:

[0270] 1. Scene construction

[0271] The energy-reserve joint optimization model (unit commitment model + economic dispatch model) established by the present invention taking into account the reserved spare transmission channel is used for market clearing, and the market settlement mechanism taking into account the differentiated spare demand constructed by the present invention is used for cross-regional transaction clearing and settlement. The network model used is as follows: Figure 2 shown.

[0272] Area A is an area with abundant coal resources, and all units are traditional units; Area B is an area with abundant wind and solar resources, and the types of units include traditional units, wind turbines, and centralized photovoltaics. Area A can provide backup auxiliary services to Area B. The values ​​in the figure are all per-unit values, and the baseline value is 100. For the convenience of analysis, this article takes the application of backup demand for new energy as an example, and does not consider the application of backup demand by users for the time being. This method does not change the essence of the problem.

[0273] Scenario 1: New energy grid connection rate in region B is 24%

[0274] Scenario 2: New energy grid connection rate in region B is 40%

[0275] 2. Analysis of market clearing results

[0276] 1) Scenario 1

[0277] In order to verify the effectiveness of the proposed method, this section Figure 2 Based on the network model, a 30MW wind turbine is added at node 17 and a 30MW centralized photovoltaic is added at node 30. The new energy grid connection rate in area B reaches 24%. The results of new energy clearing before and after regional reserve mutual assistance are as follows: Figure 3 , Figure 4 The market operation results before and after regional reserve mutual assistance are shown in Table 1.

[0278] Table 1 Scenario 1 - Market Clearing Results

[0279]

[0280] from Figure 4 It can be seen from the figure that when the reserve resources in areas A and B are not mutually beneficial, there is a clear phenomenon of wind and solar power abandonment in new energy units. The essence is that at this moment, reserve resources are scarce, and the marginal price of new energy output is greater than the marginal price of new thermal power output. Figure 5 It can be seen from Table 1 that after the regional reserve mutual assistance, the consumption of new energy units with low marginal costs increased, resulting in a decrease in the income of thermal power units, an increase in the income of new energy units, a decrease in the payment of users, and a decrease in market operating costs.

[0281] 2) Scenario 2

[0282] Based on Section 4.1, this section adds a 30MW wind turbine at node 15 and a 40MW centralized photovoltaic at node 27, and the new energy grid connection rate in region B reaches 40%. The results of new energy clearing before and after regional reserve mutual assistance are as follows Figure 5 , Figure 6 The market operation results before and after regional reserve mutual assistance are shown in Table 2.

[0283] Table 2 Scenario 2 - Market Clearing Results

[0284]

[0285] from Figure 5 and Figure 6 It can be seen from Table 2 that when the reserve in regions A and B is not mutually beneficial, there is a serious phenomenon of wind and solar abandonment in new energy units, especially the abandoned solar power of centralized photovoltaic 2; after the reserve in regions A and B is mutually beneficial, the reserve supply in region B is relatively sufficient, and the consumption of new energy is significantly improved at this time, and the phenomenon of wind and solar abandonment is greatly improved. It can be seen from Table 2 that after the regional reserve is mutually beneficial, due to the increase in the consumption of new energy units with low marginal costs, the income of thermal power units has decreased, the income of new energy units has increased, the payment of users has decreased, and the market operation cost has decreased.

[0286] Compared with Table 1 and Table 2, when the new energy grid-connected rate is higher, carrying out regional reserve sharing and mutual assistance can effectively reduce market operating costs, promote the flow of reserves from low-price areas to high-price areas, promote the consumption of new energy, and achieve cross-regional optimal allocation of resources.

Claims

1. A joint market clearing method considering cross-regional reserve mutual assistance, characterized in that: The following steps are involved: 1) Considering the coupling relationship between unit energy and reserve, a safety-constrained unit combination model is constructed with the goal of minimizing the total operating cost. 2) Solve the safety constraint unit combination model and obtain the unit combination plan; 3) Construct a safety-constrained economic dispatch model; 4) Based on the unit combination scheme in step 2), solve the safety-constrained economic dispatch model and obtain the dual multiplier of the constraint conditions of the safety-constrained economic dispatch model; 5) Based on the dual multiplier, market entity settlement is carried out, including energy settlement and standby ancillary service settlement.

2. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 1, characterized in that: The objective function of the safety constraint unit combination model is as follows: Where: p j,t is the output of traditional generator j at time t; p w,t is the output of the new energy unit w at time t; and are the upper and lower reserve bid values ​​of traditional generator set j at time t respectively; are the power generation cost, upper reserve cost, lower reserve cost, startup cost, and shutdown cost of traditional generator j at time t respectively; is the power generation cost of the new energy unit w at time t; and is a Boolean variable for starting and stopping the unit; T is a time period set; J is a set of traditional generators; W is a set of new energy units.

3. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 1, characterized in that: The constraints of the safety constraint unit combination model include power balance constraints, line flow constraints, traditional unit climbing constraints, traditional unit start and stop time constraints, traditional unit start and stop logic constraints, backup demand declaration constraints, backup transmission line capacity reservation constraints, unit winning bid constraints, and new energy backup demand adjustment constraints.

4. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 3, characterized in that: The power balance constraints are as follows: Where: p n,t is the load demand of node n at time t; N is the node set, λ t is the dual multiplier of the power balance constraint; The line flow constraints are as follows: Where: i,n is the transfer distribution factor of line i to node n; e n,j and e n,w are the labels of the nodes n where the traditional generator j and the new energy generator w are located; and are the upper and lower limits of the transmission capacity of line i at time t; f i,t is the transmission line power distribution of line i at time t; i,t and are the dual multipliers of the lower and upper constraints of the power flow respectively; The traditional unit climbing constraints are as follows: Where: Ru is the Boolean variable of the operating status of the traditional unit j at time t; j and Rd j Su are the up and down climbing rates of the unit respectively; j and Sd j are the maximum ramp rates when the unit is started and stopped; p j,t-1 is the clearing amount of traditional generator j at time t-1; is the Boolean variable of the operating status of the traditional unit j at time t-1; The start and stop time constraints of traditional units are as follows: In the formula, TO and TS are the minimum start-up time and minimum downtime respectively; is the Boolean variable of the operating status of the traditional unit j at time k; The traditional unit start and stop logic constraints are as follows: In the formula, It is the initial operating state of the unit; The unit operating status at time t=1; The alternate requirement declaration constraints are as follows: In the formula, and They are the upper and lower reserve demands reported by the new energy unit w at time t; and are the upper and lower reserve requirements declared by the power user at node n, respectively; and are the upper and lower reserve adjustment variables of the new energy unit w at time t; are the upper and lower spare dual multipliers for the power balance constraint; The capacity reservation constraints for the backup transmission lines are as follows: In the formula, and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively; The scalar constraints in the unit are as follows: In the formula, is the Boolean variable of the standby winning bid status of the traditional unit j at time t, and M is a constant; are the upper and lower limits of the clearing volume of traditional generator j; is the upper limit of the clearing volume of the new energy unit w at time t; The adjustment constraints of new energy reserve demand are as follows: In the formula, and are the upper and lower reserve adjustment coefficients respectively; Adjust the state Boolean variable for the new energy reserve demand.

5. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 1, characterized in that: The objective function of the safety-constrained economic dispatch model is as follows: In the formula, J * is the set of traditional units that are in the on state at time t.

6. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 4, characterized in that: The constraints of the safety-constrained economic dispatch model include equations (2), (6), (11)-(24).

7. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 1, characterized in that: The unit combination scheme includes the operating state variables of the traditional unit j Startup status variables Shutdown status variables 8. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 1, characterized in that: In step 5), the steps of market entity settlement include: 5.1) Calculate the product prices in each market, namely: Where: and It is divided into the energy, upper backup and lower backup node marginal prices of node n at time t, Γ' i,n =Γ n,i is the power flow transfer distribution factor after the change; I is the line set; σ i,t and They are the dual multipliers of the conventional line power flow and the upper limit constraint respectively; and are the dual multipliers of the lower and upper constraints reserved for the spare transmission channel respectively; and are the dual multipliers of the lower and upper constraints reserved for the lower backup transmission channel respectively; 5.2) Perform energy market settlement and obtain: Where: is the energy gain of the traditional unit, is the energy gain of the new energy unit, Payments for electricity users’ energy; 5.3) Perform the standby market settlement and obtain: Where: is the reserve income of the traditional unit, Payment for the standby of new energy units, Upper reserve payment for electricity users. 5.4) Perform the next standby market settlement and obtain: Where: is the reserve income of the traditional unit, To provide standby payment for new energy units. Lower reserve payments for electricity users.

9. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 8, characterized in that: After market entities settle accounts, traditional power generating units obtain reserve income according to the product of reserve clearing volume and reserve node marginal price, and new energy generating units and power users pay reserve fees according to the product of reserve demand volume and reserve node marginal price; Traditional power generating units and new energy generating units obtain energy benefits according to the product of energy clearance and marginal price of energy nodes. Power users pay energy fees according to the product of load and marginal price of energy nodes, and transmission lines obtain conventional congestion surplus benefits. Traditional power generating units obtain upper reserve income according to the product of upper reserve clearance volume and the marginal price of upper reserve node, while new energy generating units and power users pay upper reserve fee according to the product of upper reserve demand volume and the marginal price of upper reserve node.

10. A joint market clearing method considering cross-regional reserve mutual assistance according to claim 1, characterized in that: The solution tools for the safety-constrained unit commitment model and the safety-constrained economic dispatch model include the Cplex solver.

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