A market clearing method and system for alternative multi-variety electricity services

Abstract

The present invention provides a method for clearing a market of multiple types of power services that can be replaced, including solving a joint clearing model of electric energy and operating reserve to obtain a power generation plan and an operating reserve plan with the lowest comprehensive cost of purchasing electricity; using the ramp rate of each conventional power generator set, dividing the operating reserve plan to obtain load reserve and accident reserve; solving the power frequency regulation clearing model based on the equivalent substitution relationship between load reserve and power frequency regulation, and further obtaining the units that only win the bid for power frequency regulation with the lowest total cost of power frequency regulation; if the number of units that only win the bid for power frequency regulation in each time period is lower than a predetermined value, it is determined that the power frequency regulation service can be cleared, and the lowest total cost of power frequency regulation solved is recorded as the final power purchase cost. The implementation of the present invention makes full use of the available substitutability between the two types of services, power frequency regulation and operating reserve, solves the problem of low overall operating efficiency of the system, and reduces the overall power purchase cost of the system.

Description

Technical Field

[0001] The present invention relates to the technical field of smart grids and the cross-technical field of power market and dispatching operation, and in particular to a market clearing method and system for substitutable multi-variety power services. Background Art

[0002] With the acceleration of the construction of my country's electricity spot market, the construction of multiple auxiliary service markets such as operating reserve and power frequency regulation under the spot trading of electricity energy has become more urgent, making the clearing of the multi-variety electricity service market an important content of research in this field.

[0003] Judging from the actual construction experience of the pilot areas for the construction of my country's electricity spot market, the main method of step-by-step clearing is to solve the problem of clearing the multiple types of electricity services such as electric energy, power frequency regulation, and operation standby. The advantage is that it reduces the complexity of the market transaction clearing model for each type of electricity service and the probability of difficulty in solving it. However, there is a clear equivalent substitution relationship between the three types of electricity services provided by conventional power generators, namely electric energy, power frequency regulation, and operation standby, which makes the step-by-step clearing method likely to cause certain opportunity cost losses to some market players and lead to an increase in overall operating costs. For this reason, current research and applications often recommend the use of a joint clearing method to uniformly clear the electric energy, power frequency regulation, and operation standby required by the system.

[0004] Although the joint clearing method of electric energy, operating reserve and power frequency regulation can solve the opportunity cost loss of market members caused by the step-by-step clearing method and is more suitable for solving the clearing problem of multiple types of power services, it must be pointed out that the existing joint clearing method of electric energy, operating reserve and power frequency regulation does not fully study the substitution effect between different types of power services, resulting in insufficient utilization of power generation capacity, which can easily cause the problem of low overall operating efficiency of the system and bring a greater power purchase burden to the power grid. Summary of the invention

[0005] The technical problem to be solved by the embodiments of the present invention is to provide a method and system for clearing the market of multi-variety electricity services with interchangeable functions, which fully utilizes the interchangeable functions between the two types of services, namely, power frequency regulation and operation standby, solves the problem of low overall operating efficiency of the system, and reduces the overall electricity purchase cost of the system.

[0006] In order to solve the above technical problems, an embodiment of the present invention provides a method for clearing a market for multiple types of electricity services that can be replaced, the method comprising the following steps:

[0007] Obtain the number of conventional power generating units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid, and solve the pre-defined joint clearing model of electric energy and operating reserve to obtain the power generation plan and operating reserve plan of each conventional power generating unit in each time period under the condition of the lowest comprehensive cost of purchasing electricity, and further obtain the operating reserve winning units and operating reserve unwinning units in each time period;

[0008] By using the pre-defined ramp rates of each conventional power generator set when providing operating standby, the operating standby plan of each period is divided to obtain the load standby and accident standby in each period, and the operating standby winning units of each period are further divided to obtain the load standby units and accident standby units in each period;

[0009] Combined with the load reserve and accident reserve in each time period, as well as the capacity of the operating reserve units that did not win the bid, the capacity plan of each conventional power generator set that won the bid for power frequency regulation in each time period, the maximum frequency regulation response rate of each conventional power generator set, the power frequency regulation capacity limit required by the system and the frequency regulation response time specified by the system operation control, the power frequency regulation clearing model pre-defined based on the equivalent substitution relationship between load reserve and power frequency regulation is solved to obtain the conventional power generator set that won the bid for power frequency regulation auxiliary services in each time period under the condition of the lowest total power frequency regulation cost, and determine the conventional power generator set that only won the bid for power frequency regulation in each time period;

[0010] If the number of conventional power generating units that have won the bid for power frequency regulation in each time period is lower than the predetermined value, it is deemed that the load standby units in each time period can achieve power frequency regulation service clearing, and the minimum total power frequency regulation cost obtained by solving the power frequency regulation clearing model is recorded as the final power purchase cost.

[0011] Wherein, the method further comprises:

[0012] If the number of conventional power generating units that have only won the bid for power frequency regulation in a certain period of time is higher than the predetermined value, it is deemed that the load standby units in this period of time have failed to achieve the clearing of power frequency regulation services due to insufficient capacity, and the operating standby units that have not won the bid in this period of time are called to meet the capacity plan of the conventional power generating units that have only won the bid for power frequency regulation in this period of time, and further combined with the accident reserve in each period of time and the load reserve in other periods except this period, the minimum solution of the pre-defined operating reserve clearing secondary optimization model is sought, and the minimum solution obtained is the final electricity purchase cost.

[0013] Among them, the electric energy and operating reserve joint clearing model is a function constructed with power balance constraints, network transmission capacity constraints, conventional power generator unit power generation capacity constraints, conventional power generator unit climbing capacity constraints, operating reserve capacity constraints, and electric energy and operating reserve coupling constraints as constraints, and with the lowest electricity purchase cost as the optimization goal.

[0014] The electric energy and operating reserve joint clearing model is expressed by the following formulas (1) to (7):

[0015]

[0016]

[0017]

[0018]

[0019]

[0020]

[0021]

[0022] Wherein, formula (1) is the optimization objective; formulas (2) to (7) are respectively the power balance constraint, network transmission capacity constraint, conventional power generator unit power generation capacity constraint, conventional power generator unit climbing capacity constraint, operating reserve capacity constraint and electric energy and operating reserve coupling constraint; N G 、N N 、N B 、N T They correspond to the number of conventional power generating units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid respectively; ΔT is the interval of the optimized time period; They are respectively the power generation plan and the operation standby plan of the conventional power generation unit in period g and t; The price declaration functions for the conventional power generator g electricity spot market and the operating reserve market are respectively; It is the power generation prediction of the new energy power station in period n and t; is the load demand forecast for load node b during period t; G os,g , G os,n , G os,b are the power transfer distribution factors of conventional power generation unit g, new energy power station n, load node b and operating section os respectively; They are the upper and lower limits of the transmission capacity of the operating section os respectively; are the upper and lower limits of the power generation capacity of the conventional power generation unit g respectively; are the upper and lower limits of the climbing capability of the conventional power generator set g; R set Reserve capacity requirements for grid operation.

[0023] Among them, through formulas (8) to (9), the operation reserve plan of each time period is divided to obtain the load reserve and accident reserve in each time period;

[0024]

[0025]

[0026] Among them, R RAAset The accident reserve in the operating reserve required for system operation should not be less than the maximum power loss due to a single simple fault; The number of conventional power generating units that have won the bid for the running standby during period t and are sorted according to the pre-defined ramp rate of each conventional power generating unit when providing running standby can just meet the requirements of the emergency standby part; if the emergency standby units during period t are lower than When the operating reserve of the period t is lower than the required emergency reserve; on the contrary, if the emergency reserve of the period t is higher than or equal to When , the operating reserve in time period t can meet the emergency reserve needs.

[0027] Among them, the power frequency regulation clearing model is a function constructed with power frequency regulation capacity constraints, accident standby unit supply capacity constraints, load standby unit supply capacity constraints, operating standby non-bid unit supply capacity constraints and price constraints as constraints, and with the lowest total power frequency regulation cost as the optimization goal.

[0028] The power frequency regulation clearing model is expressed by the following formulas (10) to (15):

[0029]

[0030]

[0031]

[0032]

[0033]

[0034]

[0035] Among them, formula (10) is the optimization objective; formulas (11) to (15) are respectively the power frequency regulation capacity constraint, the accident standby unit supply capacity constraint, the load standby unit supply capacity constraint, the operating standby unit supply capacity constraint and the price constraint; are the price and capacity plan of the winning bid for power frequency regulation of conventional power generator g in period t; R FAset The power frequency regulation capacity limit required by the system; is the maximum frequency modulation response rate of the conventional power generator set g; ΔT FFrequency modulation response time specified for system operation control; The price function declared for the one-time clearing of the power frequency regulation market of the conventional power generator g; They are the accident standby units and load standby units divided from the operating standby winning units in time period t; It refers to the non-bid-winning units operating as standby in period t.

[0036] The operating reserve clearing secondary optimization model is a function constructed with operating reserve capacity constraints, operating reserve capacity limit constraints and operating reserve capacity price constraints as constraints, and with the lowest operating reserve power purchase cost as the optimization goal.

[0037] The operating reserve clearing secondary optimization model is expressed by the following formulas (17) to (20):

[0038]

[0039]

[0040]

[0041]

[0042] Among them, formula (17) is the optimization objective; formulas (18) to (20) are the operating reserve capacity constraint, the operating reserve capacity limit constraint, and the operating reserve capacity price constraint respectively; are the operating reserve capacity clearing price and secondary clearing capacity of the conventional power generation unit g in period t, respectively; represents a non-set; ∪ represents a union; is the one-time clearing capacity of the conventional power generator set g in period t; The price function declared for the secondary clearing of the power frequency regulation market of the conventional power generator g; It is the conventional power generating set that only won the bid for power frequency regulation during time period t.

[0043] The embodiment of the present invention also provides a market clearing system for multiple types of electricity services that can be replaced, including:

[0044] The electric energy and operating reserve joint clearing unit is used to obtain the number of conventional power generation units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid, and solve the pre-defined electric energy and operating reserve joint clearing model to obtain the power generation plan and operating reserve plan of each conventional power generation unit in each time period under the condition of the lowest comprehensive cost of purchased electricity, and further obtain the operating reserve winning units and operating reserve unwinning units in each time period;

[0045] The operation standby division unit is used to divide the operation standby plan of each time period by using the pre-defined ramp rate of each conventional power generator set when providing operation standby, so as to obtain the load standby and accident standby in each time period, and further divide the operation standby winning units in each time period, so as to obtain the load standby units and accident standby units in each time period;

[0046] The power frequency regulation clearing unit with alternative operating standby is used to solve the power frequency regulation clearing model predefined based on the equivalent substitution relationship between load standby and power frequency regulation by combining the load standby and accident standby in each time period, the capacity of the operating standby units that did not win the bid, the capacity plan of each conventional power generating unit that won the bid for power frequency regulation in each time period, the maximum frequency regulation response rate of each conventional power generating unit, the power frequency regulation capacity limit required by the system and the frequency regulation response time stipulated by the system operation control, so as to obtain the conventional power generating unit that won the bid for power frequency regulation auxiliary service in each time period under the condition of the lowest total power frequency regulation cost, and determine the conventional power generating unit that only won the bid for power frequency regulation in each time period;

[0047] The one-time clearing electricity purchase cost acquisition unit is used to determine that the load standby units in each time period can achieve the clearing of the power frequency regulation service if the number of conventional power generation units that only win the bid for power frequency regulation in each time period is lower than a predetermined value, and record the minimum total power frequency regulation cost obtained by solving the power frequency regulation clearing model as the final electricity purchase cost.

[0048] The implementation of the embodiments of the present invention has the following beneficial effects:

[0049] Compared with the joint clearing mode in the prior art, the present invention fully considers the difference between load reserve and accident reserve in operating reserve, and realizes the available substitution of load reserve and power frequency regulation according to their substitutability, thereby solving the problem of low overall operating efficiency of the system, reducing the overall electricity purchase cost of the system and improving operating efficiency. BRIEF DESCRIPTION OF THE DRAWINGS

[0050] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, without paying creative labor, other drawings obtained based on these drawings still belong to the scope of the present invention.

[0051] Figure 1 A flowchart of a method for clearing a market for multiple types of electricity services that can be replaced provided by an embodiment of the present invention;

[0052] Figure 2A schematic diagram of the structure of an alternative multi-variety electricity service market clearing system provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0053] In order to make the objectives, technical solutions and advantages of the present invention more clear, the present invention will be further described in detail below with reference to the accompanying drawings.

[0054] like Figure 1 As shown in the figure, a multi-variety electricity service market clearing system that can be replaced is proposed in an embodiment of the present invention, and the method includes the following steps:

[0055] Step S1, obtaining the number of conventional power generation units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid, solving the pre-defined electric energy and operating reserve joint clearing model, so as to obtain the power generation plan and operating reserve plan of each conventional power generation unit in each time period under the condition of the lowest comprehensive cost of purchased electricity, and further obtain the operating reserve winning units and the operating reserve unwinning units in each time period;

[0056] Step S2: using the predefined ramp rates of each conventional power generator set when providing operating standby, the operating standby plan of each time period is divided to obtain the load standby and accident standby in each time period, and further dividing the operating standby winning units in each time period to obtain the load standby units and accident standby units in each time period;

[0057] Step S3, combining the load reserve and accident reserve in each time period, as well as the capacity of the operating reserve units that did not win the bid, the capacity plan of each conventional power generator set that won the bid for power frequency regulation in each time period, the maximum frequency regulation response rate of each conventional power generator set, the power frequency regulation capacity limit required by the system and the frequency regulation response time specified by the system operation control, solve the power frequency regulation clearing model predefined based on the equivalent substitution relationship between load reserve and power frequency regulation, so as to obtain the conventional power generator set that won the bid for power frequency regulation auxiliary service in each time period under the condition of the lowest total power frequency regulation cost, and determine the conventional power generator set that only won the bid for power frequency regulation in each time period;

[0058] Step S4: If the number of conventional power generating units that have won the bid for power frequency regulation in each time period is lower than a predetermined value, it is determined that the load standby units in each time period can achieve power frequency regulation service clearance, and the minimum total power frequency regulation cost obtained by solving the power frequency regulation clearing model is recorded as the final power purchase cost;

[0059] Step S5: If the number of conventional power generating sets that have only won the bid for power frequency regulation in a certain period of time is higher than the predetermined value, it is determined that the load standby sets in the period of time have failed to achieve power frequency regulation service clearance due to insufficient capacity, and the operating standby sets that have not won the bid in the period of time are called to meet the capacity plan of the conventional power generating sets that have only won the bid for power frequency regulation in the period of time, and further combined with the accident standby of each period of time and the load standby of other periods except the period of time, the minimum solution of the pre-defined operating standby clearing secondary optimization model is obtained, and the minimum solution obtained is the final power purchase cost.

[0060] The specific process is that before step S1, a joint clearing model of electric energy and operating reserve is pre-defined, and the model is a function constructed with power balance constraints, network transmission capacity constraints, conventional power generation unit generation capacity constraints, conventional power generation unit climbing capacity constraints, operating reserve capacity constraints, and electric energy and operating reserve coupling constraints as constraints, and the optimization goal is to minimize the power purchase cost.

[0061] The joint clearing model of electric energy and operating reserve is expressed by the following formulas (1) to (7):

[0062]

[0063]

[0064]

[0065]

[0066]

[0067]

[0068]

[0069] Among them, formula (1) is the optimization goal, which aims to give priority to the joint clearing of electric energy and operating reserve, so as to determine the electric energy generation plan and operating reserve plan of the market entity under the conditions of meeting the operation needs and minimizing the power purchase cost; formulas (2) to (7) are respectively the power balance constraint, the network transmission capacity constraint, the conventional power generation unit generation capacity constraint, the conventional power generation unit climbing capacity constraint, the operating reserve capacity constraint and the electric energy and operating reserve coupling constraint; N G 、N N 、N B 、N T They correspond to the number of conventional power generating units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid respectively; ΔT is the interval of the optimized time period; They are respectively the power generation plan and operation reserve plan of the conventional power generation unit g in period t, i.e., the power generation power and operation reserve forecast; The price declaration functions for the conventional power generator g electricity spot market and the operating reserve market are respectively; It is the power generation prediction of the new energy power station in period n and t; is the load demand forecast for load node b during period t; G os,g , G os,n , G os,b are the power transfer distribution factors of conventional power generation unit g, new energy power station n, load node b and operating section os respectively; They are the upper and lower limits of the transmission capacity of the operating section os respectively; are the upper and lower limits of the power generation capacity of the conventional power generation unit g respectively; are the upper and lower limits of the climbing capability of the conventional power generator set g; R set Reserve capacity requirements for grid operation.

[0070] Before step S1, it is also necessary to pre-define a power frequency regulation clearing model based on the equivalent substitution relationship between load reserve and power frequency regulation, and the model is a function constructed with power frequency regulation capacity constraints, accident reserve unit supply capacity constraints, load reserve unit supply capacity constraints, operating reserve non-bid unit supply capacity constraints and price constraints as constraints, and with the minimum total power frequency regulation cost as the optimization goal.

[0071] The power frequency regulation clearing model is expressed by the following formulas (10) to (15):

[0072]

[0073]

[0074]

[0075]

[0076]

[0077]

[0078] Among them, formula (10) is the optimization target, which aims to fully consider the equivalent substitution relationship between load reserve and power frequency regulation and realize the clearing of power frequency regulation service; formulas (11) to (15) are respectively the power frequency regulation capacity constraint, the supply capacity constraint of the accident reserve unit, the supply capacity constraint of the load reserve unit, the supply capacity constraint of the operating reserve unit that did not win the bid, and the price constraint; are the price and capacity plan of the winning bid for power frequency regulation of conventional power generator g in period t; R FAset The power frequency regulation capacity limit required by the system; is the maximum frequency modulation response rate of the conventional power generator set g; ΔT F Frequency modulation response time specified for system operation control; The price function declared for the one-time clearing of the power frequency regulation market of the conventional power generator g; They are the accident standby units and load standby units divided from the operating standby winning units in time period t; It refers to the non-bid-winning units operating as standby in period t.

[0079] Before step S1, it is also necessary to pre-define an operating reserve clearing secondary optimization model, and the model is a function constructed with operating reserve capacity constraints, operating reserve capacity limit constraints and operating reserve capacity price constraints as constraints, and with the lowest operating reserve power purchase cost as the optimization goal.

[0080] The operating reserve clearing secondary optimization model is expressed by the following formulas (17) to (20):

[0081]

[0082]

[0083]

[0084]

[0085] Among them, formula (17) is the optimization target, which aims to consider that when the available substitution of operating reserve is insufficient in the power frequency regulation clearing result, additional frequency regulation resources are needed, and additional frequency regulation resources are supplemented by conventional power generation units that have not won the bid for operating reserve auxiliary services, and the available substitution of load reserve in operating reserve is used to realize the clearing of power frequency regulation services, so as to reduce the power purchase cost of operating reserve; formulas (18) to (20) are respectively the operating reserve capacity constraint, the operating reserve capacity limit constraint and the operating reserve capacity price constraint; are the operating reserve capacity clearing price and secondary clearing capacity of the conventional power generation unit g in period t, respectively; represents a non-set; ∪ represents a union; is the one-time clearing capacity of the conventional power generator set g in period t; The price function declared for the secondary clearing of the power frequency regulation market of the conventional power generator g; It is the conventional power generating set that only won the bid for power frequency regulation during time period t.

[0086] It should be noted that the accident reserve in the operating reserve obtained by the joint clearing model of electric energy and operating reserve does not participate in the clearing, and its operating reserve plan follows the clearing result of the model. The conventional power generation units that only participate in the power frequency regulation market obtained by the power frequency regulation clearing model participate in the clearing as the winning bid of the operating reserve, but its operating reserve price is set to 0. The operating reserve clearing secondary optimization model replaces the winning bid of the load reserve in the operating reserve with the winning bid of the conventional power frequency regulation service that only wins the bid in the power frequency regulation auxiliary service market, so as to further reduce the overall power purchase cost.

[0087] In step S1, the number of conventional power generation units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid are obtained, and the joint clearing model of electric energy and operating reserve is solved to obtain the power generation plan of each conventional power generation unit in each time period under the condition of the lowest comprehensive cost of electricity purchase. and running backup plans It should be noted that solving the joint clearing model of electric energy and operating reserve is essentially a mixed integer programming problem, which can be solved directly by using the branch and bound method or calling commercial planning solvers such as Cplex. It belongs to the conventional technical means in this technical field, and its specific solution process will not be repeated here.

[0088] Furthermore, according to whether each conventional power generation unit in each time period wins the bid for operation standby, each conventional power generation unit in each time period is divided into corresponding operation standby winning units. and operate the spare units that did not win the bid

[0089] In step S2, considering that the operation reserve plan required for the operation of the power grid can be divided into load reserve and accident reserve; among them, load reserve is used to smooth the load forecast deviation and fluctuation, and accident reserve is used to pre-control the power shortage after the accident occurs. At this time, it is generally required that the accident reserve in the operation reserve is not less than the maximum power loss caused by a single simple fault, and the load reserve in the operation reserve is configured in a certain proportion according to the unified load level.

[0090] Given that power frequency regulation is essentially a regulatory capability reserved to respond to load fluctuation deviations, in order to achieve a viable alternative between operating standby and power frequency regulation, it is necessary to refine the operating standby and clarify whether the operating standby undertaken by conventional power generators in each period is load standby or accident standby.

[0091] The conventional power generating sets that have won the bid for operating standby are sorted in ascending order according to their maximum ramp rate. Then, according to this order, the emergency standby in each period will be undertaken by the conventional power generating sets that have won the bid and can just meet the emergency standby requirements.

[0092] Therefore, the operation reserve plan of each time period can be divided by the following formulas (8) to (9) to obtain the load reserve and accident reserve in each time period.

[0093]

[0094]

[0095] Among them, R RAAset The accident reserve in the operating reserve required for system operation should not be less than the maximum power loss due to a single simple fault; The number of conventional power generating units that have won the bid for the running standby during period t and are sorted according to the pre-defined ramp rate of each conventional power generating unit when providing running standby can just meet the requirements of the emergency standby part; if the emergency standby units during period t are lower than When the operating reserve of the period t is lower than the required emergency reserve; on the contrary, if the emergency reserve of the period t is higher than or equal to When , the operating reserve in time period t can meet the emergency reserve needs.

[0096] Furthermore, based on formulas (8) to (9), the number of operating standby winning units in each period is All are divided into emergency standby units and load standby units

[0097] In step S3, the load reserve in each time period is and emergency standby R RAAset , and operate the spare units that did not win the bid The capacity of each conventional power generator set and the capacity plan of the power frequency regulation in each period Maximum frequency response rate of each conventional power generator set The power frequency regulation capacity limit R required by the system FAset And the frequency modulation response time ΔT specified by the system operation control F According to the power frequency regulation clearing model considering the available alternative of operating reserve as shown in equations (10) to (15), it is determined that the conventional power generation units that win the bid for the operating reserve accident reserve part in any period are restricted and cannot win the bid for the power frequency regulation auxiliary service to ensure sufficient accident reserve.

[0098] At this time, the clearing price limit of the power frequency regulation service of the conventional power generator set that has won the bid for the standby load is 0, so as to give priority to the power frequency regulation service. When its capacity cannot meet the requirements, the standby units that have not won the bid will continue to be called. To ensure sufficient power frequency regulation capacity.

[0099] At the same time, it is stipulated that the set of conventional power generation units that win the bid for power frequency regulation auxiliary services is According to whether they have won the bid for operation standby, they can be divided into conventional power generation units that have won the bid for power frequency regulation and operation standby at the same time. and conventional power generators that only won the bid for power frequency regulation

[0100] In step S4, it is necessary to consider whether the operating reserve available alternatives in the power frequency regulation clearing results of the operating reserve available alternatives are sufficient, and whether additional frequency regulation resources are needed.

[0101] Once the number of conventional power generating units that have won the bid for power frequency regulation in each time period is lower than a predetermined value (such as 0), it is determined that the load standby units in each time period can achieve power frequency regulation service clearance, and the minimum total power frequency regulation cost obtained by solving the power frequency regulation clearing model in step S3 is recorded as the final power purchase cost.

[0102] For example, formula (16) can be used to determine whether the available alternatives for operating reserves are sufficient:

[0103]

[0104] in, is an empty set symbol. If the judgment condition of formula (16) is met, it means that the load reserve of the conventional power generator set that won the bid for the operating standby auxiliary service can meet the requirements of the power frequency regulation auxiliary service, and the power frequency regulation clearing does not require additional frequency regulation resources, and the process ends; otherwise, it means that the conventional power generator set that did not win the bid for the operating standby auxiliary service needs to supplement additional frequency regulation resources, and step S5 will continue to be executed.

[0105] In step S5, if the number of conventional power generating units that only win the bid for power frequency regulation in a certain period is higher than a predetermined value (such as 0), it is determined that the load standby units in the period cannot achieve power frequency regulation service clearance due to insufficient capacity, and the operating standby units that did not win the bid in the period are called to meet the capacity plan of the conventional power generating units that only win the bid for power frequency regulation in the period, and further combined with the accident reserve in each period and the load reserve in other periods except the period, the minimum solution is obtained according to the operating reserve clearing quadratic optimization model shown in equations (17) to (20), and the minimum solution obtained is the final power purchase cost.

[0106] like Figure 2 As shown in the figure, a multi-variety electricity service market clearing system that can be replaced is provided in an embodiment of the present invention, including:

[0107] The electric energy and operating reserve joint clearing unit 110 is used to obtain the number of conventional power generation units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid, and solve the pre-defined electric energy and operating reserve joint clearing model to obtain the power generation plan and operating reserve plan of each conventional power generation unit in each time period under the condition of the lowest comprehensive cost of purchased electricity, and further obtain the operating reserve winning units and the operating reserve unwinning units in each time period;

[0108] The operation standby division unit 120 is used to divide the operation standby plan of each time period by using the pre-defined ramp rate of each conventional power generator set when providing operation standby, so as to obtain the load standby and accident standby in each time period, and further divide the operation standby winning units in each time period, so as to obtain the load standby units and accident standby units in each time period;

[0109] The power frequency regulation clearing unit 130 that can be replaced by the operating standby is used to solve the power frequency regulation clearing model predefined based on the equivalent substitution relationship between the load standby and the power frequency regulation, in combination with the load standby and the accident standby in each time period, as well as the capacity of the operating standby units that did not win the bid, the capacity plan of each conventional power generator unit that won the bid for power frequency regulation in each time period, the maximum frequency regulation response rate of each conventional power generator unit, the power frequency regulation capacity limit required by the system, and the frequency regulation response time specified by the system operation control, so as to obtain the conventional power generator unit that won the bid for power frequency regulation auxiliary services in each time period under the condition of the lowest total power frequency regulation cost, and determine the conventional power generator unit that only won the bid for power frequency regulation in each time period;

[0110] The one-time clearing electricity purchase cost acquisition unit 140 is used to determine that the load standby units in each time period can achieve the clearing of the power frequency regulation service if the number of conventional power generation units that only win the bid for power frequency regulation in each time period is lower than a predetermined value, and record the minimum total power frequency regulation cost obtained by solving the power frequency regulation clearing model as the final electricity purchase cost.

[0111] The system further includes: a secondary clearing electricity purchase cost acquisition unit 140, which is used to determine that the load standby units in a certain period of time have failed to achieve the clearing of the power frequency regulation service due to insufficient capacity if the number of conventional power generation units that have only won the bid for power frequency regulation in a certain period of time is higher than the predetermined value, and call the operating standby units that have not won the bid in the period of time to meet the capacity plan of the conventional power generation units that have only won the bid for power frequency regulation in the period of time, and further combine the accident standby in each period of time and the load standby in other periods except the period of time to find the minimum solution of the pre-defined operating standby clearing secondary optimization model, and the minimum solution obtained is the final electricity purchase cost.

[0112] The implementation of the embodiments of the present invention has the following beneficial effects:

[0113] Compared with the joint clearing mode in the prior art, the present invention fully considers the difference between load reserve and accident reserve in operating reserve, and realizes the available substitution of load reserve and power frequency regulation according to their substitutability, thereby solving the problem of low overall operating efficiency of the system, reducing the overall electricity purchase cost of the system and improving operating efficiency.

[0114] It is worth noting that in the above system embodiment, the various units included are only divided according to functional logic, but are not limited to the above division, as long as the corresponding functions can be achieved; in addition, the specific names of the functional units are only for the convenience of distinguishing each other, and are not used to limit the scope of protection of the present invention.

[0115] A person skilled in the art can understand that all or part of the steps in the above-mentioned embodiment method can be completed by instructing related hardware through a program, and the program can be stored in a computer-readable storage medium, such as ROM / RAM, disk, CD-ROM, etc.

[0116] The above disclosure is only the preferred embodiment of the present invention, which certainly cannot be used to limit the scope of the present invention. Therefore, equivalent changes made according to the claims of the present invention are still within the scope of the present invention.

Claims

1. A method for clearing a market for multi-variety electricity services with substitutable features, characterized in that: The method comprises the following steps: Obtain the number of conventional power generating units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid, and solve the pre-defined joint clearing model of electric energy and operating reserve to obtain the power generation plan and operating reserve plan of each conventional power generating unit in each time period under the condition of the lowest comprehensive cost of purchasing electricity, and further obtain the operating reserve winning units and operating reserve unwinning units in each time period; By using the pre-defined ramp rates of each conventional power generator set when providing operating standby, the operating standby plan of each period is divided to obtain the load standby and accident standby in each period, and the operating standby winning units of each period are further divided to obtain the load standby units and accident standby units in each period; Combined with the load reserve and accident reserve in each time period, as well as the capacity of the operating reserve units that did not win the bid, the capacity plan of each conventional power generator set that won the bid for power frequency regulation in each time period, the maximum frequency regulation response rate of each conventional power generator set, the power frequency regulation capacity limit required by the system and the frequency regulation response time specified by the system operation control, the power frequency regulation clearing model pre-defined based on the equivalent substitution relationship between load reserve and power frequency regulation is solved to obtain the conventional power generator set that won the bid for power frequency regulation auxiliary services in each time period under the condition of the lowest total power frequency regulation cost, and determine the conventional power generator set that only won the bid for power frequency regulation in each time period; If the number of conventional power generating units that have won the bid for power frequency regulation in each period is lower than the predetermined value, it is deemed that the load standby units in each period can achieve power frequency regulation service clearance, and the minimum total power frequency regulation cost obtained by solving the power frequency regulation clearing model is recorded as the final power purchase cost; The electric energy and operating reserve joint clearing model is a function constructed with power balance constraints, network transmission capacity constraints, conventional power generation unit power generation capacity constraints, conventional power generation unit ramping capacity constraints, operating reserve capacity constraints, and electric energy and operating reserve coupling constraints as constraints, and with the lowest electricity purchase cost as the optimization goal; The electric energy and operating reserve joint clearing model is expressed by the following formulas (1) to (7): Wherein, formula (1) is the optimization objective; formulas (2) to (7) are respectively the power balance constraint, network transmission capacity constraint, conventional power generator unit power generation capacity constraint, conventional power generator unit climbing capacity constraint, operating reserve capacity constraint and electric energy and operating reserve coupling constraint; N G 、N N 、N B 、N T They correspond to the number of conventional power generating units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid respectively; ΔT is the interval of the optimized time period; They are respectively the power generation plan and the operation standby plan of the conventional power generation unit in period g and t; The price declaration functions for the conventional power generator g electricity spot market and the operating reserve market are respectively; It is the power generation prediction of the new energy power station in period n and t; is the load demand forecast for load node b during period t; G os,g , G os,n , G os,b are the power transfer distribution factors of conventional power generation unit g, new energy power station n, load node b and operating section os respectively; They are the upper and lower limits of the transmission capacity of the operating section os respectively; are the upper and lower limits of the power generation capacity of the conventional power generation unit g respectively; are the upper and lower limits of the climbing capability of the conventional power generator set g; R set reserve capacity requirements for grid operation; Among them, through formulas (8) to (9), the operation reserve plan of each time period is divided to obtain the load reserve and accident reserve in each time period; Among them, R RAAset The accident reserve in the operating reserve required for system operation should not be less than the maximum power loss due to a single simple fault; The number of conventional power generating units that have won the bid for the running standby during period t and are sorted according to the pre-defined ramp rate of each conventional power generating unit when providing running standby can just meet the requirements of the emergency standby part; if the emergency standby units during period t are lower than When the operating reserve of the period t is lower than the required emergency reserve; on the contrary, if the emergency reserve of the period t is higher than or equal to When , the operation reserve in time period t can meet the emergency reserve needs; The power frequency regulation clearing model is a function constructed with power frequency regulation capacity constraints, accident standby unit supply capacity constraints, load standby unit supply capacity constraints, operating standby unit supply capacity constraints and price constraints as constraints, and with the lowest total power frequency regulation cost as the optimization goal; The power frequency regulation clearing model is expressed by the following formulas (10) to (15): Among them, formula (10) is the optimization objective; formulas (11) to (15) are respectively the power frequency regulation capacity constraint, the accident standby unit supply capacity constraint, the load standby unit supply capacity constraint, the operating standby unit supply capacity constraint and the price constraint; are the price and capacity plan of the winning bid for power frequency regulation of conventional power generator g in period t; R FAset The power frequency regulation capacity limit required by the system; is the maximum frequency modulation response rate of the conventional power generator set g; ΔT F Frequency modulation response time specified for system operation control; The price function declared for the one-time clearing of the power frequency regulation market of the conventional power generator g; They are the accident standby units and load standby units divided from the operating standby winning units in time period t; It refers to the non-bid-winning units operating as standby in period t.

2. The method for clearing a market for substitutable multiple-variety electricity services as claimed in claim 1, characterized in that: The method further comprises: If the number of conventional power generating units that have only won the bid for power frequency regulation in a certain period of time is higher than the predetermined value, it is deemed that the load standby units in this period of time have failed to achieve the clearing of power frequency regulation services due to insufficient capacity, and the operating standby units that have not won the bid in this period of time are called to meet the capacity plan of the conventional power generating units that have only won the bid for power frequency regulation in this period of time, and further combined with the accident reserve in each period of time and the load reserve in other periods except this period, the minimum solution of the pre-defined operating reserve clearing secondary optimization model is sought, and the minimum solution obtained is the final electricity purchase cost.

3. The method for clearing a market for substitutable multiple-variety electricity services as claimed in claim 2, characterized in that: The operating reserve clearing secondary optimization model is a function constructed with operating reserve capacity constraint, operating reserve capacity limit constraint and operating reserve capacity price constraint as constraint conditions and with the lowest operating reserve power purchase cost as the optimization goal.

4. The method for clearing a market for substitutable multiple-variety electricity services as claimed in claim 3, characterized in that: The operating reserve clearing secondary optimization model is expressed by the following formulas (17) to (20): Among them, formula (17) is the optimization objective; formulas (18) to (20) are the operating reserve capacity constraint, the operating reserve capacity limit constraint, and the operating reserve capacity price constraint respectively; are the operating reserve capacity clearing price and secondary clearing capacity of the conventional power generation unit g in period t, respectively; represents a non-set; ∪ represents a union; is the one-time clearing capacity of the conventional power generator set g in period t; The price function declared for the secondary clearing of the power frequency regulation market of the conventional power generator g; It is the conventional power generating set that only won the bid for power frequency regulation during time period t.

5. A market clearing system for multiple types of electricity services that can be replaced, characterized in that: include: The electric energy and operating reserve joint clearing unit is used to obtain the number of conventional power generation units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid, and solve the pre-defined electric energy and operating reserve joint clearing model to obtain the power generation plan and operating reserve plan of each conventional power generation unit in each time period under the condition of the lowest comprehensive cost of purchased electricity, and further obtain the operating reserve winning units and the operating reserve unwinning units in each time period; The operation standby division unit is used to divide the operation standby plan of each time period by using the pre-defined ramp rate of each conventional power generator set when providing operation standby, so as to obtain the load standby and accident standby in each time period, and further divide the operation standby winning units in each time period, so as to obtain the load standby units and accident standby units in each time period; The power frequency regulation clearing unit with alternative operating standby is used to solve the power frequency regulation clearing model predefined based on the equivalent substitution relationship between load standby and power frequency regulation by combining the load standby and accident standby in each time period, the capacity of the operating standby units that did not win the bid, the capacity plan of each conventional power generating unit that won the bid for power frequency regulation in each time period, the maximum frequency regulation response rate of each conventional power generating unit, the power frequency regulation capacity limit required by the system and the frequency regulation response time stipulated by the system operation control, so as to obtain the conventional power generating unit that won the bid for power frequency regulation auxiliary service in each time period under the condition of the lowest total power frequency regulation cost, and determine the conventional power generating unit that only won the bid for power frequency regulation in each time period; A one-time clearing power purchase cost acquisition unit is used to determine that all load standby units in each time period can achieve power frequency regulation service clearing if the number of conventional power generation units that only win the bid for power frequency regulation in each time period is lower than a predetermined value, and record the minimum total power frequency regulation cost obtained by solving the power frequency regulation clearing model as the final power purchase cost; The electric energy and operating reserve joint clearing model is a function constructed with power balance constraints, network transmission capacity constraints, conventional power generation unit power generation capacity constraints, conventional power generation unit ramping capacity constraints, operating reserve capacity constraints, and electric energy and operating reserve coupling constraints as constraints, and with the lowest electricity purchase cost as the optimization goal; The electric energy and operating reserve joint clearing model is expressed by the following formulas (1) to (7): Wherein, formula (1) is the optimization objective; formulas (2) to (7) are respectively the power balance constraint, network transmission capacity constraint, conventional power generator unit power generation capacity constraint, conventional power generator unit climbing capacity constraint, operating reserve capacity constraint and electric energy and operating reserve coupling constraint; N G 、N N 、N B 、N T They correspond to the number of conventional power generating units, the number of new energy power stations, the number of load nodes and the number of optimized time periods in the power grid respectively; ΔT is the interval of the optimized time period; They are respectively the power generation plan and the operation standby plan of the conventional power generation unit in period g and t; The price declaration functions for the conventional power generator g electricity spot market and the operating reserve market are respectively; It is the power generation prediction of the new energy power station in period n and t; is the load demand forecast for load node b during period t; G os,g , G os,n , G os,b are the power transfer distribution factors of conventional power generation unit g, new energy power station n, load node b and operating section os respectively; They are the upper and lower limits of the transmission capacity of the operating section os respectively; are the upper and lower limits of the power generation capacity of the conventional power generation unit g respectively; are the upper and lower limits of the climbing capability of the conventional power generator set g; R set reserve capacity requirements for grid operation; Among them, through formulas (8) to (9), the operation reserve plan of each time period is divided to obtain the load reserve and accident reserve in each time period; Among them, R RAAset The accident reserve in the operating reserve required for system operation should not be less than the maximum power loss due to a single simple fault; The number of conventional power generating units that have won the bid for the running standby during period t and are sorted according to the pre-defined ramp rate of each conventional power generating unit when providing running standby can just meet the requirements of the emergency standby part; if the emergency standby units during period t are lower than When the operating reserve of the period t is lower than the required emergency reserve; on the contrary, if the emergency reserve of the period t is higher than or equal to When , the operation reserve in time period t can meet the emergency reserve needs; The power frequency regulation clearing model is a function constructed with power frequency regulation capacity constraints, accident standby unit supply capacity constraints, load standby unit supply capacity constraints, operating standby unit supply capacity constraints and price constraints as constraints, and with the lowest total power frequency regulation cost as the optimization goal; The power frequency regulation clearing model is expressed by the following formulas (10) to (15): Among them, formula (10) is the optimization objective; formulas (11) to (15) are respectively the power frequency regulation capacity constraint, the accident standby unit supply capacity constraint, the load standby unit supply capacity constraint, the operating standby unit supply capacity constraint and the price constraint; are the price and capacity plan of the winning bid for power frequency regulation of conventional power generator g in period t; R FAset The power frequency regulation capacity limit required by the system; is the maximum frequency modulation response rate of the conventional power generator set g; ΔT F Frequency modulation response time specified for system operation control; The price function declared for the one-time clearing of the power frequency regulation market of the conventional power generator g; They are the accident standby units and load standby units divided from the operating standby winning units in time period t; It refers to the non-bid-winning units operating as standby in period t.

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