A joint clearing method for regional interconnected power grids considering the reserve capacity of generation and utilization resources

Abstract

The present invention relates to a method for joint clearing of main and auxiliary resources of regional interconnected power grids considering the reserve capacity of power generation and consumption resources, which belongs to the technical field of regional power grid management, and includes the following steps: the power generation side and the power consumption side in the sub-region evaluate their own regulation capabilities; enter the day-ahead market declaration link, all power generators, user-side demand response and energy storage determine their own day-ahead bidding information, and determine the load information at the same time; the sub-regional power grid determines the preliminary day-ahead clearing plan and pushes the information to the regional center; the regional center conducts secondary coordination on each region, and returns the winning bid information to the sub-region after adjustment; each sub-region returns the winning bid information to the power generator, user-side demand response and energy storage operator, and each department preliminarily executes according to the day-ahead plan. The regional power grid market can be cleared more efficiently, and the clearing plans of various types of generator resources, user-side demand response resources and energy storage resources in the region in the day-ahead and real-time main and auxiliary markets can be optimized and calculated to promote the consumption of clean energy.

Description

Technical Field

[0001] The present invention belongs to the technical field of regional power grid management, and in particular relates to a main-auxiliary joint clearing method for a regional interconnected power grid taking into account the reserve capacity of generation and use resources. Background Art

[0002] The large-scale grid connection of new energy sources has made the phenomenon of wind and solar power abandonment at the system level increasingly serious, and the gap in the backup resources of the power grid has further increased. However, as the growth rate of system load becomes increasingly stable, blindly increasing the backup capacity of the power grid is not conducive to the economic efficiency of power grid operation. Therefore, in order to solve the gap in backup resources, it is necessary to consider both "opening up" and "saving". From the perspective of "opening up", the main consideration is to motivate existing adjustable resources to provide backup support for the system. In addition to its own fast start-stop units, the power generation side can also provide paid backup support for the system, including adjustable resources such as factory power. The adjustable capabilities of self-owned power plants, energy storage, electric boilers and large industrial users on the user side are also high-quality backup resources. Existing research mainly focuses on the support of resources on both sides of the generation and use for peak load periods, and has not applied them to the daily operation cycle of the entire power grid. In addition, the adjustment capacity of power generation and use is also mainly used to participate in the spot market, and its application in the backup market has not been considered. From the perspective of "saving", the main consideration is to adopt a joint clearing mode of main and auxiliary power, which can improve the utilization efficiency of electric energy and backup resources. The uncertainty of the generation and consumption resource reserve capacity model and the main and auxiliary joint clearing model combined with a high proportion of new energy significantly increases the difficulty of centralized management of large-scale regional interconnected power grids. Although existing studies have preliminarily explored hierarchical and zoned regional power grid management methods, existing studies have failed to solve the problem of how to clear the main and auxiliary markets of regional power grids that take into account the reserve capacity of resources on both sides of the generation and consumption. Therefore, it is necessary to invent a main and auxiliary joint clearing method for regional interconnected power grids that takes into account the reserve capacity of generation and consumption resources, improve the management efficiency of regional power grids, promote the efficient consumption of new energy, and solve the above problems. Summary of the invention

[0003] The purpose of the present invention is to provide a method for joint clearing of the main and auxiliary markets of a regional interconnected power grid taking into account the reserve capacity of power generation and consumption resources, so as to solve the technical problems existing in the above-mentioned prior art, such as: the existing research has preliminarily explored the hierarchical and zoned regional power grid management method, but the existing research has failed to solve the problem of how to clear the main and auxiliary markets of the regional power grid taking into account the reserve capacity of resources on both the power generation and consumption sides.

[0004] To achieve the above object, the technical solution of the present invention is:

[0005] A method for joint clearing of main and auxiliary power in a regional interconnected power grid taking into account the reserve capacity of power generation and utilization resources comprises the following steps:

[0006] S1: The power generation side and the power consumption side in the sub-region evaluate their own regulation capabilities;

[0007] S2: Entering the day-ahead market application phase, all power generators, user-side demand response and energy storage determine their day-ahead bidding information and load information at the same time;

[0008] S3: The sub-regional power grid determines the preliminary day-ahead clearing plan and pushes the information to the regional center; the regional center conducts secondary coordination among the regions and returns the winning bid information to the sub-region after adjustment;

[0009] S4: Each sub-region returns the winning bid information to the power generator, user-side demand response and energy storage operator, and each department preliminarily implements it according to the day-ahead plan;

[0010] S5: Entering the real-time transaction declaration phase, each sub-region collects statistics on the short-term fluctuation forecast within the region and makes a coordinated market response in advance. All power generators, user-side demand response and energy storage determine their respective real-time bidding information;

[0011] S6: Each sub-regional power grid determines a preliminary real-time clearing plan and pushes the real-time preliminary winning plan to the regional center; the regional center performs a safety check on each region. If it is safe, the winning plan will not be adjusted. If it exceeds the limit, the winning information will be adjusted; and then the real-time winning information will be sent to the sub-region;

[0012] S7: Each sub-region returns the real-time winning bid information to the power generator, user-side demand response and energy storage operator, and each department implements the real-time winning bid plan;

[0013] S8: Settle the fees incurred in the day-ahead and real-time markets.

[0014] Furthermore, step S1 is specifically as follows:

[0015] A survey on the reserve demand of the power generation and power consumption sides is published within the sub-region, and the reserve resource information of the power generation and power consumption sides within the sub-region is integrated to clarify the range of reserve power and its reserve price that the power generation and power consumption sides can provide in the process of participating in the market, and the relevant information is compiled and summarized to the regional center.

[0016] Further, step S2 is specifically as follows:

[0017] When entering the day-ahead market declaration phase, the power grid marketing department provides each substation of D-1 and determines the next day's load forecast information for the 110kV substation, with a step length of 1 hour, including 24 time nodes for the next day; all power generators, demand response and energy storage determine their own day-ahead bidding information, among which the power generation side must provide the maximum power, minimum power, unit start and stop time values, and power generation cost function; demand response must provide response capability information, that is, the maximum load that can be increased or reduced, and can continuously provide time constraints and power generation costs; the energy storage side needs to provide initial state of charge information, maximum and minimum charge and discharge power, operable state of charge range and charge and discharge costs.

[0018] Furthermore, the clearing scheme in step S3 is determined by clearing each sub-regional power grid based on the energy and power joint clearing model; the clearing model includes two parts: objective function and operation constraint;

[0019] The objective function is as follows:

[0020] The goal is to minimize the total day-ahead clearing cost of the system. The day-ahead clearing cost includes two parts: energy expenditure cost and standby expenditure cost. It can be specifically written as formula (1). The first line of the objective function is the energy expenditure cost, and the second line is the standby expenditure cost.

[0021]

[0022] In the formula, and are the startup and shutdown costs of the generator, and Respectively represent the start and stop status, N Gen Indicates the number of generator stations in the area; and are the power generation cost and the winning bid power value of the generator respectively, and are the power generation cost and winning bid power value of new energy, N Ren Indicates the number of stations for new energy sources; and are the charging and discharging operating costs of energy storage and its bid power, N Ess Indicates the number of energy storage stations; and They represent the call cost of demand response and its winning bid power, N DR The total number of demand responses; T represents the total time in the operation cycle. In the day-ahead calculation, this value is 24;

[0023] The constraint function is the operation constraints of each system flow and each device; it mainly includes the following aspects:

[0024] 1) System power flow, including power balance constraint as shown in equation (2) and line power flow constraint as shown in equation (3);

[0025]

[0026]

[0027] Among them, d i,t Indicates the predicted load value of 110kV substation, N Load Indicates the total number of 110kV substations; represents the maximum current value allowed to pass through the transmission line, L represents the number of lines, and SF() represents the power transfer distribution factor function, which constrains the line capacity within the safe operation range;

[0028] 2) Operation constraints of each device, including generator, demand response and energy storage;

[0029] (a) The generator part includes the constraints of conventional units and new energy units:

[0030] Formula (4) and Formula (5) are the day-ahead output and reserve power constraints of the generator, Formula (6) and Formula (7) are the ramp constraints of the generator, Formula (8)-(11) are the logical constraints of the start-stop action constraints of the generator, which respectively indicate that the generator cannot start and stop at the same time, the logical relationship between the start-stop operation and the state, and the maximum start-stop time constraints; Formula (12) and Formula (13) respectively represent the positive reserve and negative reserve constraints of the generator; Formula (14) represents the power value of the new energy unit;

[0031]

[0032]

[0033]

[0034]

[0035]

[0036]

[0037]

[0038]

[0039]

[0040]

[0041]

[0042] in, is the operating status of the generator set, Indicates that the generator is shut down. Indicates that the generator is started. and are the maximum and minimum operating power of the generator respectively; and They represent the climbing limits of the start and stop states respectively. and are the positive and negative climbing power limits of the generator set, T i ON and T i OFF Respectively represent the minimum continuous start-up and shutdown time of the generator set; Indicates the predicted power value of the new energy unit;

[0043] (b) Demand response constraints: piecewise function models representing the power constraints and costs of demand response, respectively;

[0044]

[0045]

[0046] in, is the electricity price for demand response, is the maximum power value of demand response;

[0047] (c) Energy storage operation constraints

[0048] Formula (17) is the energy storage power charge and discharge conversion value, Formula (18) and Formula (19) are the energy storage discharge power constraints, Formula (20) is the energy transfer function model, Formula (21) and Formula (22) are the energy storage energy state constraints and charge and discharge state constraints, respectively; Formula (23) and Formula (24) are the energy storage power constraints considering positive and negative backup, respectively; Formula (25) and Formula (26) respectively indicate that the positive and negative backup powers must be positive;

[0049]

[0050]

[0051]

[0052]

[0053]

[0054]

[0055]

[0056]

[0057]

[0058]

[0059] in, and are the discharge and charge power of energy storage respectively, and They represent the maximum and minimum charging power respectively; and are the maximum and minimum values ​​of energy storage discharge power respectively; Indicates the state of charge of the energy storage. and Respectively represent the charging and discharging efficiency of energy storage, and Respectively represent the maximum and minimum allowable operating ranges of the energy storage power state;

[0060] Combine the objective function and constraints, use the solver to solve the problem, calculate the winning bid for the power generation side, demand response resources, and energy storage, and push the information to the regional center;

[0061] The regional center conducts security verification on the information of each sub-region. The verification principles are as follows:

[0062]

[0063] in, is the transmission power limit of the interconnection line between sub-areas;

[0064] If the safety check passes, the information will be directly released to the sub-region as the execution plan for the next day; if the plan fails, the output plan will be reduced and adjusted until the constraints are met, and the winning bid information will be returned to the sub-region after the adjustment.

[0065] Further, step S4 is specifically as follows:

[0066] Each sub-region will return the time-stamped power generation information and clearing price information to the power generator, demand response and energy storage operator, and each department will preliminarily formulate a daily operation plan based on the day-ahead clearing plan.

[0067] Furthermore, step S5 is specifically as follows:

[0068] Entering the real-time transaction declaration stage, each sub-region counts the short-term fluctuation forecasts of the 110kV substation in the area. The short-term here refers to data within 4 hours, and publishes the forecast information back to the trading center to make a coordinated market response in advance. All power generators, demand response and energy storage determine their respective real-time bidding information. The real-time bidding information includes the power clearing plan of the day before, the actual adjustable power and real-time price information.

[0069] Furthermore, step S6 is specifically as follows:

[0070] Each sub-regional power grid determines the real-time clearing adjustment plan based on the clearing model (Equation (1)-Equation (26)) and pushes the real-time preliminary winning plan to the regional center; the regional center conducts a safety check on each region using Equation (27). If it is safe, the winning plan will not be adjusted. If it exceeds the limit, the output plan will be adjusted until the constraints are met. After the adjustment, the winning information will be returned to the sub-region.

[0071] Further, step S7 is specifically as follows:

[0072] Each sub-region will return the real-time winning bid information to power generators, demand response and energy storage operators. Each department will implement power generation plans, demand response plans and energy storage charging and discharging behaviors according to the real-time winning bid plan.

[0073] Further, step S8 is specifically as follows:

[0074] The marginal price method is used to determine the day-ahead and real-time clearing prices, and the costs incurred in the day-ahead and real-time markets are settled, the benefits of power generation, energy storage, and demand response are clarified, and payments are executed.

[0075] Compared with the prior art, the present invention has the following beneficial effects:

[0076] One of the beneficial effects of this scheme is that this method can clear the regional power grid market more efficiently, optimize the calculation of the clearing schemes for various types of generator resources, user-side demand response resources, and energy storage resources in the region in the day-ahead and real-time primary and auxiliary markets, and promote the consumption of clean energy. BRIEF DESCRIPTION OF THE DRAWINGS

[0077] Figure 1 Schematic diagram of the primary and auxiliary joint clearing model of the regional power grid in an embodiment of the present application.

[0078] Figure 2 This is a schematic diagram of the unit combination results of independent clearing of each sub-area in an embodiment of the present application.

[0079] Figure 3 This is a schematic diagram of a corrected scheme for the regional interconnected unit combination according to an embodiment of the present application. DETAILED DESCRIPTION

[0080] In order to make the purpose, technical solutions and advantages of the present invention more clearly understood, the present invention is further described in detail below in conjunction with the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are only used to explain the present invention and are not used to limit the present invention, that is, the embodiments described are only part of the embodiments of the present invention, rather than all of the embodiments. The components of the embodiments of the present invention described and shown in the drawings herein can be arranged and designed in various different configurations.

[0081] Therefore, the following detailed description of the embodiments of the present invention provided in the accompanying drawings is not intended to limit the scope of the claimed invention, but merely represents selected embodiments of the present invention. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without creative work are within the scope of protection of the present invention. It should be noted that relational terms such as the terms "first" and "second" are only used to distinguish one entity or operation from another entity or operation, and do not necessarily require or imply any such actual relationship or order between these entities or operations.

[0082] Moreover, the terms "comprises", "includes" or any other variations thereof are intended to cover non-exclusive inclusion, so that a process, method, article or apparatus that includes a list of elements includes not only those elements, but also includes other elements not explicitly listed, or also includes elements inherent to such process, method, article or apparatus. In the absence of more restrictions, an element defined by the phrase "comprises a ..." does not exclude the presence of additional identical elements in the process, method, article or apparatus that includes the element.

[0083] The features and performance of the present invention are further described in detail below in conjunction with the embodiments.

[0084] Example:

[0085] like Figure 1 As shown, a method for joint clearing of main and auxiliary power in regional interconnected power grid considering the reserve capacity of power generation and consumption resources is proposed, including the following steps:

[0086] S1: The power generation side and the power consumption side in the sub-region evaluate their own regulation capabilities;

[0087] S2: Entering the day-ahead market application phase, all power generators, user-side demand response and energy storage determine their day-ahead bidding information and load information at the same time;

[0088] S3: The sub-regional power grid determines the preliminary day-ahead clearing plan and pushes the information to the regional center; the regional center conducts secondary coordination among the regions and returns the winning bid information to the sub-region after adjustment;

[0089] S4: Each sub-region returns the winning bid information to the power generator, user-side demand response and energy storage operator, and each department preliminarily implements it according to the day-ahead plan;

[0090] S5: Entering the real-time transaction declaration phase, each sub-region collects statistics on the short-term fluctuation forecast within the region and makes a coordinated market response in advance. All power generators, user-side demand response and energy storage determine their respective real-time bidding information;

[0091] S6: Each sub-regional power grid determines a preliminary real-time clearing plan and pushes the real-time preliminary winning plan to the regional center; the regional center performs a safety check on each region. If it is safe, the winning plan will not be adjusted. If it exceeds the limit, the winning information will be adjusted; and then the real-time winning information will be sent to the sub-region;

[0092] S7: Each sub-region returns the real-time winning bid information to the power generator, user-side demand response and energy storage operator, and each department implements the real-time winning bid plan;

[0093] S8: Settle the fees incurred in the day-ahead and real-time markets.

[0094] Furthermore, step S1 is specifically as follows:

[0095] A survey on the reserve demand of the power generation and power consumption sides is published within the sub-region, and the reserve resource information of the power generation and power consumption sides within the sub-region is integrated to clarify the range of reserve power and its reserve price that the power generation and power consumption sides can provide in the process of participating in the market, and the relevant information is compiled and summarized to the regional center.

[0096] Further, step S2 is specifically as follows:

[0097] When entering the day-ahead market declaration phase, the power grid marketing department provides each substation of D-1 and determines the next day's load forecast information for the 110kV substation, with a step length of 1 hour, including 24 time nodes for the next day; all power generators, demand response and energy storage determine their own day-ahead bidding information, among which the power generation side must provide the maximum power, minimum power, unit start and stop time values, and power generation cost function; demand response must provide response capability information, that is, the maximum load that can be increased or reduced, and can continuously provide time constraints and power generation costs; the energy storage side needs to provide initial state of charge information, maximum and minimum charge and discharge power, operable state of charge range and charge and discharge costs.

[0098] Furthermore, the clearing scheme in step S3 is determined by clearing each sub-regional power grid based on the energy and power joint clearing model; the clearing model includes two parts: objective function and operation constraint;

[0099] The objective function is as follows:

[0100] The goal is to minimize the total day-ahead clearing cost of the system. The day-ahead clearing cost includes two parts: energy expenditure cost and standby expenditure cost. It can be specifically written as formula (1). The first line of the objective function is the energy expenditure cost, and the second line is the standby expenditure cost.

[0101]

[0102] In the formula, and are the startup and shutdown costs of the generator, and Respectively represent the start and stop status, N Gen Indicates the number of generator stations in the area; and are the power generation cost and the winning bid power value of the generator respectively, and are the power generation cost and winning bid power value of new energy, N Ren Indicates the number of stations for new energy sources; and are the charging and discharging operating costs of energy storage and its bid power, N Ess Indicates the number of energy storage stations; and They represent the call cost of demand response and its winning bid power, N DR The total number of demand responses; T represents the total time in the operation cycle. In the day-ahead calculation, this value is 24;

[0103] The constraint function is the operation constraints of each system flow and each device; it mainly includes the following aspects:

[0104] 1) System power flow, including power balance constraint as shown in equation (2) and line power flow constraint as shown in equation (3);

[0105]

[0106]

[0107] Among them, d i,t Indicates the predicted load value of 110kV substation, N Load Indicates the total number of 110kV substations; represents the maximum current value allowed to pass through the transmission line, L represents the number of lines, and SF() represents the power transfer distribution factor function, which constrains the line capacity within the safe operation range;

[0108] 2) Operation constraints of each device, including generator, demand response and energy storage;

[0109] (a) The generator part includes the constraints of conventional units and new energy units:

[0110] Formula (4) and Formula (5) are the day-ahead output and reserve power constraints of the generator, Formula (6) and Formula (7) are the ramp constraints of the generator, Formula (8)-(11) are the logical constraints of the start-stop action constraints of the generator, which respectively indicate that the generator cannot start and stop at the same time, the logical relationship between the start-stop operation and the state, and the maximum start-stop time constraints; Formula (12) and Formula (13) respectively represent the positive reserve and negative reserve constraints of the generator; Formula (14) represents the power value of the new energy unit;

[0111]

[0112]

[0113]

[0114]

[0115]

[0116]

[0117]

[0118]

[0119]

[0120]

[0121]

[0122] in, is the operating status of the generator set, Indicates that the generator is shut down. Indicates that the generator is started. and are the maximum and minimum operating power of the generator respectively; and They represent the climbing limits of the start and stop states respectively. and are the positive and negative climbing power limits of the generator set, T i ON and T i OFF Respectively represent the minimum continuous start-up and shutdown time of the generator set; represents the predicted power value of the new energy unit; (b) demand response constraint: a piecewise function model representing the power constraint of demand response and its cost respectively;

[0123]

[0124]

[0125] in, is the electricity price for demand response, is the maximum power value of demand response;

[0126] (c) Energy storage operation constraints

[0127] Formula (17) is the energy storage power charge and discharge conversion value, Formula (18) and Formula (19) are the energy storage discharge power constraints, Formula (20) is the energy transfer function model, Formula (21) and Formula (22) are the energy storage energy state constraints and charge and discharge state constraints, respectively; Formula (23) and Formula (24) are the energy storage power constraints considering positive and negative backup, respectively; Formula (25) and Formula (26) respectively indicate that the positive and negative backup powers must be positive;

[0128]

[0129]

[0130]

[0131]

[0132]

[0133]

[0134]

[0135]

[0136]

[0137]

[0138] in, and are the discharge and charge power of energy storage respectively, and They represent the maximum and minimum charging power respectively; and are the maximum and minimum values ​​of energy storage discharge power respectively; Indicates the state of charge of the energy storage. and Respectively represent the charging and discharging efficiency of energy storage, and Respectively represent the maximum and minimum allowable operating ranges of the energy storage power state;

[0139] Combine the objective function and constraints, use the solver to solve the problem, calculate the winning bid for the power generation side, demand response resources, and energy storage, and push the information to the regional center;

[0140] The regional center conducts security verification on the information of each sub-region. The verification principles are as follows:

[0141]

[0142] in, is the transmission power limit of the interconnection line between sub-areas;

[0143] If the safety check passes, the information will be directly released to the sub-region as the execution plan for the next day; if the plan fails, the output plan will be reduced and adjusted until the constraints are met, and the winning bid information will be returned to the sub-region after the adjustment.

[0144] Further, step S4 is specifically as follows:

[0145] Each sub-region will return the time-stamped power generation information and clearing price information to the power generator, demand response and energy storage operator, and each department will preliminarily formulate a daily operation plan based on the day-ahead clearing plan.

[0146] Furthermore, step S5 is specifically as follows:

[0147] Entering the real-time transaction declaration stage, each sub-region counts the short-term fluctuation forecasts of the 110kV substation in the area. The short-term here refers to data within 4 hours, and publishes the forecast information back to the trading center to make a coordinated market response in advance. All power generators, demand response and energy storage determine their respective real-time bidding information. The real-time bidding information includes the power clearing plan of the day before, the actual adjustable power and real-time price information.

[0148] Furthermore, step S6 is specifically as follows:

[0149] Each sub-regional power grid determines the real-time clearing adjustment plan based on the clearing model (Equation (1)-Equation (26)) and pushes the real-time preliminary winning plan to the regional center; the regional center conducts a safety check on each region using Equation (27). If it is safe, the winning plan will not be adjusted. If it exceeds the limit, the output plan will be adjusted until the constraints are met. After the adjustment, the winning information will be returned to the sub-region.

[0150] Further, step S7 is specifically as follows:

[0151] Each sub-region will return the real-time winning bid information to power generators, demand response and energy storage operators. Each department will implement power generation plans, demand response plans and energy storage charging and discharging behaviors according to the real-time winning bid plan.

[0152] Further, step S8 is specifically as follows:

[0153] The marginal price method is used to determine the day-ahead and real-time clearing prices, and the costs incurred in the day-ahead and real-time markets are settled, the benefits of power generation, energy storage, and demand response are clarified, and payments are executed.

[0154] Specific case analysis:

[0155] In order to verify the effectiveness of the method proposed in the present invention, the partitioned IEEE118 node system was tested. The total number of system nodes is 118, the number of lines is 186, and the number of cross-regional interconnection lines is 9. Among them, partition 1 contains 14 power generation nodes, 53 lines, and 35 load nodes; partition 2 contains 20 power generation nodes, 61 lines, and 43 load nodes; partition 3 contains 20 power generation nodes, 66 lines, and 40 load nodes. The base load of the entire 118 area is 5913.9MW, and the load rates of partitions 1-3 are 25.9%, 35.8%, and 38.3%, respectively. The installed penetration rates of clean energy are 33.2%, 35.3%, and 25.4%, respectively. All mathematical models are compiled in the YALMIP environment of MATLAB, and the commercial solution software GUROBI is selected for optimization and solution.

[0156] Through calculation, we can obtain the unit combination scheme of independent clearing in sub-regions and the unit combination correction scheme under regional interconnection, as shown in Figure 2 and Figure 3 As shown. Figure 2 and Figure 3 It can be seen from the results that the correction of the unit combination by regional interconnection is a subtle adjustment to the unit combination, so that the formulated unit combination plan can pass the safety check of the interconnection line. Taking zone 1 as an example, the difference in its power generation status is mainly in unit 5, and the power generation status is adjusted for 4 hours. This is because when the results of the independent clearing of the sub-regions were checked for regional interconnection, it was found that the inter-regional interconnection line failed to pass the safety constraint, so the status of the generator set was adjusted so that the adjusted result can meet the safety requirements of the power grid.

[0157] After the day-ahead clearing and real-time clearing calculations, the interconnection clearing results of the entire region can be obtained as shown in Table 1. Among them, the start-stop cost is the generator cost cleared on the day-ahead, which needs to be paid to the generator, which is 2531 yuan, 3742 yuan, and 3825 yuan respectively. The dispatching cost is the electricity cost cleared in real time during the day, which needs to be paid to the generator and new energy enterprises according to the supply unit, which is 519422 yuan, 734407 yuan, and 828302 yuan respectively. Energy storage charges the income earned by providing power and energy reserves, which are 44501 yuan, 9162 yuan, and 30786 yuan respectively. The user-side demand response should charge the income from providing its day-ahead reserve and intraday energy supply, which are 64937 yuan, 21978 yuan, and 32164 yuan respectively. The generator reserve income is the income brought by providing positive and negative reserves on the day-ahead, which are 74777 yuan, 248310 yuan, and 225455 yuan respectively. The total amount of abandoned wind and solar power can show the clearing result of regional interconnection, and the total amount of abandoned wind and solar power is lower.

[0158] Table 1. Results of clearing of regional power grid

[0159]

[0160] The above are preferred embodiments of the present invention. Any changes made according to the technical solution of the present invention, as long as the resulting functions do not exceed the scope of the technical solution of the present invention, belong to the protection scope of the present invention.

Claims

1. A method for joint clearing of main and auxiliary power in regional interconnected power grids taking into account the reserve capacity of power generation and utilization resources, characterized in that: The following steps are involved: S1: The power generation side and the power consumption side in the sub-region evaluate their own regulation capabilities; S2: Entering the day-ahead market application phase, all power generators, user-side demand response and energy storage determine their day-ahead bidding information and load information at the same time; S3: The sub-regional power grid determines the preliminary day-ahead clearing plan and pushes the information to the regional center; the regional center conducts secondary coordination among the regions and returns the winning bid information to the sub-region after adjustment; The clearing scheme in step S3 is determined by clearing each sub-regional power grid based on the energy and power joint clearing model; the clearing model includes two parts: objective function and operation constraint; The objective function is as follows: The goal is to minimize the total day-ahead clearing cost of the system. The day-ahead clearing cost includes two parts: energy expenditure cost and standby expenditure cost. It can be specifically written as formula (1). The first line of the objective function is the energy expenditure cost, and the second line is the standby expenditure cost. In the formula, and are the startup and shutdown costs of the generator, and Respectively represent the start and stop status, N Gen Indicates the number of generator stations in the area; and are the power generation cost and the winning bid power value of the generator respectively, and are the power generation cost and winning bid power value of new energy, N Ren Indicates the number of stations for renewable energy; and are the charging and discharging operating costs of energy storage and its bid power, N Ess Indicates the number of energy storage stations; and They represent the call cost of demand response and its winning bid power, N DR The total number of demand responses; T represents the total time in the operation cycle. In the day-ahead calculation, this value is 24; The constraint function is the operation constraints of each system flow and each device; it mainly includes the following aspects: 1) System power flow, including power balance constraint as shown in equation (2) and line power flow constraint as shown in equation (3); Among them, d i,t Indicates the predicted load value of 110kV substation, N Load Indicates the total number of 110kV substations; represents the maximum current value allowed to pass through the transmission line, L represents the number of lines, and SF() represents the power transfer distribution factor function, which constrains the line capacity within the safe operation range; 2) Operation constraints of each device, including generator, demand response and energy storage; (a) The generator part includes the constraints of conventional units and new energy units: Formula (4) and Formula (5) are the day-ahead output and reserve power constraints of the generator, Formula (6) and Formula (7) are the ramp constraints of the generator, Formula (8)-(11) are the logical constraints of the start-stop action constraints of the generator, which respectively indicate that the generator cannot start and stop at the same time, the logical relationship between the start-stop operation and the state, and the maximum start-stop time constraints; Formula (12) and Formula (13) respectively represent the positive reserve and negative reserve constraints of the generator; Formula (14) represents the power value of the new energy unit; in, is the operating status of the generator set, Indicates that the generator is shut down. Indicates that the generator is started. and are the maximum and minimum operating power of the generator respectively; and They represent the climbing limits of the start and stop states respectively. and are the positive and negative climbing power limits of the generator set, T i ON and T i OFF Respectively represent the minimum continuous start-up and shutdown time of the generator set; Indicates the predicted power value of the new energy unit; (b) Demand response constraints: piecewise function models representing the power constraints and costs of demand response, respectively; in, is the electricity price for demand response, is the maximum power value of demand response; (c) Energy storage operation constraints Formula (17) is the energy storage power charge and discharge conversion value, Formula (18) and Formula (19) are the energy storage discharge power constraints, Formula (20) is the energy transfer function model, Formula (21) and Formula (22) are the energy storage energy state constraints and charge and discharge state constraints, respectively; Formula (23) and Formula (24) are the energy storage power constraints considering positive and negative backup, respectively; Formula (25) and Formula (26) respectively indicate that the positive and negative backup powers must be positive; in, and are the discharge and charge power of energy storage respectively, and They represent the maximum and minimum charging power respectively; and are the maximum and minimum values ​​of energy storage discharge power respectively; Indicates the state of charge of the energy storage. and Respectively represent the charging and discharging efficiency of energy storage, and Respectively represent the maximum and minimum allowable operating ranges of the energy storage power state; Combine the objective function and constraints, use the solver to solve the problem, calculate the winning bid for the power generation side, demand response resources, and energy storage, and push the information to the regional center; The regional center conducts security verification on the information of each sub-region. The verification principles are as follows: in, is the transmission power limit of the interconnection line between sub-areas; If the safety check passes, the information will be directly released to the sub-region as the next day's implementation plan; if the plan fails, the output plan will be reduced and adjusted until the constraints are met, and the winning bid information will be returned to the sub-region after the adjustment; S4: Each sub-region returns the winning bid information to the power generator, user-side demand response and energy storage operator, and each department preliminarily implements it according to the day-ahead plan; S5: Entering the real-time transaction declaration phase, each sub-region collects statistics on the short-term fluctuation forecast within the region and makes a coordinated market response in advance. All power generators, user-side demand response and energy storage determine their respective real-time bidding information; S6: Each sub-regional power grid determines a preliminary real-time clearing plan and pushes the real-time preliminary winning plan to the regional center; the regional center performs a safety check on each region. If it is safe, the winning plan will not be adjusted. If it exceeds the limit, the winning information will be adjusted; and then the real-time winning information will be sent to the sub-region; Step S6 is specifically as follows: Each sub-regional power grid determines the real-time clearing adjustment plan based on the clearing model (Equation (1)-Equation (26)), and pushes the real-time preliminary winning plan to the regional center; the regional center performs a safety check on each region, using Equation (27). If it is safe, the winning plan will not be adjusted. If it exceeds the limit, the output plan will be adjusted until the constraints are met. After the adjustment, the winning information will be returned to the sub-region; S7: Each sub-region returns the real-time winning bid information to the power generator, user-side demand response and energy storage operator, and each department implements the real-time winning bid plan; S8: Settle the fees incurred in the day-ahead and real-time markets.

2. A method for joint clearing of main and auxiliary power in regional interconnected power grids taking into account the reserve capacity of power generation and utilization resources as claimed in claim 1, characterized in that: Step S1 is specifically as follows: A survey on the reserve demand of the power generation and power consumption sides is published within the sub-region, and the reserve resource information of the power generation and power consumption sides within the sub-region is integrated to clarify the range of reserve power and its reserve price that the power generation and power consumption sides can provide in the process of participating in the market, and the relevant information is compiled and summarized to the regional center.

3. A method for joint clearing of main and auxiliary power in regional interconnected power grids taking into account the reserve capacity of power generation and utilization resources as claimed in claim 2, characterized in that: Step S2 is specifically as follows: When entering the day-ahead market declaration phase, the power grid marketing department provides each substation of D-1 and determines the next day's load forecast information for the 110kV substation, with a step length of 1 hour, including 24 time nodes for the next day; all power generators, demand response and energy storage determine their own day-ahead bidding information, among which the power generation side must provide the maximum power, minimum power, unit start and stop time values, and power generation cost function; demand response must provide response capability information, that is, the maximum load that can be increased or reduced, and can continuously provide time constraints and power generation costs; the energy storage side needs to provide initial state of charge information, maximum and minimum charge and discharge power, operable state of charge range and charge and discharge costs.

4. A method for joint clearing of main and auxiliary power in regional interconnected power grids taking into account the reserve capacity of power generation and utilization resources as claimed in claim 3, characterized in that: Step S4 is specifically as follows: Each sub-region will return the time-stamped power generation information and clearing price information to the power generator, demand response and energy storage operator, and each department will preliminarily formulate a daily operation plan based on the day-ahead clearing plan.

5. A method for joint clearing of main and auxiliary power in regional interconnected power grids taking into account the reserve capacity of power generation and utilization resources as claimed in claim 4, characterized in that: Step S5 is specifically as follows: Entering the real-time transaction declaration stage, each sub-region counts the short-term fluctuation forecasts of the 110kV substation in the area. The short-term here refers to data within 4 hours, and publishes the forecast information back to the trading center to make a coordinated market response in advance. All power generators, demand response and energy storage determine their respective real-time bidding information. The real-time bidding information includes the power clearing plan of the day before, the actual adjustable power and real-time price information.

6. A method for joint clearing of main and auxiliary power in regional interconnected power grids taking into account the reserve capacity of power generation and utilization resources as claimed in claim 5, characterized in that: Step S7 is specifically as follows: Each sub-region will return the real-time winning bid information to power generators, demand response and energy storage operators. Each department will implement power generation plans, demand response plans and energy storage charging and discharging behaviors according to the real-time winning bid plan.

7. A method for joint clearing of main and auxiliary power in regional interconnected power grids taking into account the reserve capacity of power generation and utilization resources as claimed in claim 6, characterized in that: Step S8 is specifically as follows: The marginal price method is used to determine the day-ahead and real-time clearing prices, and the costs incurred in the day-ahead and real-time markets are settled, the benefits of power generation, energy storage, and demand response are clarified, and payments are executed.

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