Day-ahead electric energy and active auxiliary service combined clearing modeling method and related device

Abstract

The invention belongs to the technical field of power system model construction, and discloses a day-ahead electric energy and active auxiliary service combined clearing modeling method and a related device. The day-ahead electric energy and active auxiliary service combined clearing modeling method comprises the following steps: establishing an operation target of a novel power system; establishing constraint conditions of power system scheduling, and completing construction of a day-ahead electric energy and active auxiliary service combined clearing model; the operation target is the sum of the minimum thermal power resource operation cost and the active auxiliary service transaction cost; in the active auxiliary service transaction, a main body participating in the transaction comprises a coal-fired thermal power generating unit and an electricity-hydrogen coupling energy storage system. According to the technical scheme disclosed by the invention, the short-term flexibility of the power system is improved by adding novel auxiliary services and flexible resources, and the construction and development of an auxiliary service market can be promoted.

Description

Technical Field

[0001] The present invention belongs to the technical field of electric power system model building, and in particular relates to a modeling method for joint clearing of day-ahead electric energy and active auxiliary services and a related device. Background Art

[0002] The "Management Measures for Ancillary Services of Electric Power Systems" focuses on enriching and expanding the trading entities, trading products and other contents in the active auxiliary services market, adding market entities such as energy storage systems and virtual power plants to participate in market transactions, and puts forward strict qualification review and management requirements for market entities; among them, newly added active auxiliary services such as rotational inertia and climbing are intended to reduce the impact of new energy uncertainties on the safe operation of the system.

[0003] With the development of the power system and the reform of the power market, the existing clearing modeling methods have gradually exposed some problems, so it is necessary to develop new modeling methods to adapt to the new market environment and needs. Specifically, the existing clearing modeling methods mainly include the following steps:

[0004] 1) Data collection and processing: Collect various types of data from the power market, including load forecasts, power generation plans, unit characteristics, etc., and perform pre-processing.

[0005] 2) Model construction: According to market rules and demands, a clearing model is constructed, including objective functions and constraints. The objective function usually involves minimizing market costs or maximizing social welfare, while the constraints include power balance, unit output limitations, network transmission limitations, etc.

[0006] 3) Solving and optimization: Use appropriate mathematical methods (such as linear programming, mixed integer linear programming, etc.) to solve the model and obtain the optimal clearing result.

[0007] Although the above existing clearing modeling methods meet the market needs to a certain extent, they still have some defects, including:

[0008] 1) Insufficient flexibility: With the large-scale grid connection of renewable energy and the gradual liberalization of the power market, the operating environment of the power system has become more complex and changeable. The existing clearing modeling methods cannot fully cope with such changes, resulting in inflexible and inaccurate market clearing results.

[0009] 2) The characteristics of energy storage systems are not fully considered: Energy storage systems play an increasingly important role in power systems, and their charging and discharging characteristics have a significant impact on market clearing results; however, existing clearing modeling methods do not fully consider the characteristics of energy storage systems, resulting in the failure to fully tap the potential of energy storage systems.

[0010] 3) Failure to fully consider demand-side response: Demand-side response is an important part of the electricity market. Effective regulation of the electricity market can be achieved by adjusting users' electricity consumption behavior. However, the existing clearing modeling methods do not fully consider the impact of demand-side response, resulting in suboptimal market clearing results.

[0011] In summary, the problem of insufficient short-term flexibility resources in the new power system has brought certain challenges to the economic operation and efficient dispatch of the system. The joint clearing of the electric energy market and the active ancillary service market can further give play to the advantages of multiple types of market mechanisms and resource endowments and promote the low-carbon transformation of the power system. Therefore, a new modeling method for the joint clearing of day-ahead electric energy and active ancillary services is urgently needed to promote the construction and development of the ancillary service market. Summary of the invention

[0012] The purpose of the present invention is to provide a joint clearing modeling method and related devices for day-ahead electric energy and active auxiliary services to solve one or more of the above-mentioned technical problems. The technical solution disclosed in the present invention is a highly flexible joint clearing modeling solution for day-ahead electric energy and active auxiliary services, which improves the short-term flexibility of the power system by adding new auxiliary services and flexibility resources, and can promote the construction and development of the auxiliary service market.

[0013] In order to achieve the above object, the present invention adopts the following technical solutions:

[0014] In a first aspect, the present invention provides a joint clearing modeling method for day-ahead electric energy and active auxiliary services, comprising the following steps:

[0015] Establishing the operation target of the new power system; wherein the operation target is to minimize the sum of the operation cost of thermal power resources and the transaction cost of active auxiliary services; in the active auxiliary service transaction, the main participants include coal-fired thermal power units and electric-hydrogen coupled energy storage systems;

[0016] Establish constraints for power system dispatch and complete the construction of a joint clearing model for day-ahead electric energy and active ancillary services; the constraints are coal-fired power units and electric-hydrogen coupled energy storage systems; the constraints include operation constraints, ramp constraints, and active ancillary service provision constraints, as well as supply and demand balance and transaction constraints in the day-ahead electric energy market and active ancillary service market.

[0017] A further improvement of the present invention is that in the step of establishing the operation target of the new power system, the objective function of the operation target is expressed as:

[0018] min F=F G +F A ;

[0019] Where F is the sum of the operating cost of thermal power resources and the transaction cost of active auxiliary services; F G F is the operating cost of thermal power resources; A transaction costs for active ancillary services;

[0020]

[0021] In the formula, e g,t and Z g,t They represent the actual power generation plan and power generation cost of unit g in period t respectively; l g,t d g,t They respectively indicate whether the unit g is in the start-stop state transition stage during the t period, n g,t Indicates whether the unit g is higher than the minimum output during period t; and They represent the start-up and shutdown costs of unit g during period t, represents the no-load operation cost of unit g in period t; T represents all periods; G represents all coal-fired thermal power units;

[0022]

[0023] Where A represents the set of active auxiliary service types; and They are respectively the electricity plan and cost of the coal-fired power unit g providing active auxiliary service a during period t.

[0024] A further improvement of the present invention is that in the calculation process of the thermal power resource operation cost, during the non-start-stop period, the power generation plan of the thermal power unit is represented by the instantaneous power generation plan at the end of each time period; wherein,

[0025]

[0026] In the formula, is the minimum operating output of unit g; p g,t-1 、p g,t is the power generation plan that is instantaneously higher than the minimum output at the end of the period t-1 and t when unit g is operating normally; Δt is the difference between the instantaneous times at the end of the period t-1 and t;

[0027] Among them, in calculating p g,t-1 、p g,t When the coal-fired power unit is scheduled to generate electricity at the end of period t, It is divided into three parts, specifically expressed as follows:

[0028]

[0029] In the formula, and They represent the output of unit g in period i during the start-stop state transition phase; and They respectively represent the duration of the start-stop state conversion phase of unit g.

[0030] A further improvement of the present invention is that, in the constraint conditions,

[0031] The start and stop state constraints of coal-fired power units are expressed as:

[0032] n g,t -n g,t-1 = l g,t -d g,t t∈T,g∈G;

[0033] Where n g,t 、n g,t-1 Respectively indicate whether the unit g is higher than the minimum output at time t and t-1; l g,t d g,t They respectively indicate whether the unit g is in the start-stop state transition stage during the period t; T represents all periods; G represents all coal-fired thermal power units;

[0034] The minimum duration constraint of the startup and shutdown state of coal-fired power units is expressed as:

[0035]

[0036] In the formula, i represents the i-th period; and They respectively represent the duration of the start-stop state conversion phase of unit g.

[0037] A further improvement of the present invention is that, in the constraint conditions,

[0038] The constraints on the coal-fired power units providing spinning reserve auxiliary services are expressed as:

[0039]

[0040] In the formula, p g,t-1 、p g,t It is the power generation plan that is instantaneously higher than the minimum output at the end of the period t-1 and t when the unit g is working normally; and are the plans for unit g to provide upward and downward spinning reserve auxiliary services in period t, respectively; Δt is the difference between the instantaneous time at the end of period t-1 and t; are the maximum up and down ramp rates of unit g within 30 minutes, respectively; T represents all time periods; G represents all coal-fired power units;

[0041] The constraints on coal-fired power units that provide secondary frequency regulation and ramp auxiliary services are expressed as follows:

[0042]

[0043] In the formula, They represent the maximum upward and downward climbing rates of unit g within 15 minutes respectively; They represent the plans of unit g to provide upward and downward secondary frequency regulation auxiliary services during period t respectively; They represent the plans of unit g to provide upward and downward climbing auxiliary services during period t respectively;

[0044] The capacity constraints of the units are specifically expressed as follows:

[0045]

[0046] In the formula, and are the plans for unit g to provide upward and downward active auxiliary services a during period t respectively.

[0047] A further improvement of the present invention is that, in the constraint conditions,

[0048] The operation constraint of the electric-hydrogen coupled energy storage system is the working mode constraint of RSOC. At a certain moment, RSOC can only be in one working mode, which is expressed as:

[0049]

[0050] In the formula, S represents the set of electric-hydrogen coupled energy storage systems; and They respectively indicate whether the energy storage s is in the SOFC and SOEC working modes during period t;

[0051] The climbing constraints of different RSOC working modes are expressed as follows:

[0052]

[0053] In the formula, R UF and R DF Respectively represent the upper and lower maximum ramp rates of SOFC working mode; R UE and R DE Respectively represent the upper and lower maximum ramp rates of the SOEC working mode; and They represent the actual output of energy storage s in SOFC and SOEC working modes respectively;

[0054] The scheduling constraints of RSOC include: when SOFC is in working mode, RSOC converts hydrogen energy in the hydrogen storage tank into electric energy and provides it to the power-consuming load; when in SOEC working mode, RSOC, as the power-consuming load, converts electric energy into hydrogen energy and stores it in the hydrogen storage tank;

[0055] RSOC operating capacity boundaries and related output rate constraints are as follows:

[0056]

[0057] Where N R,max 、N R,min are the RSOC capacity of energy storage s The upper and lower boundaries of They represent the upper and lower limits of the discharge power of the SOFC working mode of energy storage s, η PF,max and η PF,min They are and The correlation coefficient of They represent the upper and lower limits of the charging power of the SOEC working mode of the energy storage s, η PE,max and η PE,min They are and The correlation coefficient of

[0058] The following constraints exist for the operating capacity boundary of the hydrogen storage reservoir and the related storage / desorption rates:

[0059]

[0060] Where N H,max 、N H,min Respectively represent the hydrogen storage capacity of energy storage s The upper and lower boundaries of (kg); Respectively represent the upper and lower limits of the hydrogen storage rate of energy storage s, η HE,max and η HE,min They are and The correlation coefficient of Respectively represent the upper and lower limits of the hydrogen release rate of energy storage s, η HF,max and η HF,min They are and The correlation coefficient of

[0061] In the process of scheduling optimization, when RSOC is in SOFC or SOEC mode, the corresponding relationship between RSOC output and hydrogen storage / desorption capacity of hydrogen storage tank is expressed as:

[0062]

[0063] In the formula, and They represent the hydrogen storage and desorption rates of energy storage s in time period t respectively; η E and η FThey represent the energy conversion efficiency when RSOC is in different working modes; H h Indicates the high calorific value of hydrogen;

[0064] The energy storage system does not participate in the electricity energy transaction. Considering the hydrogen energy supply and demand balance of the hydrogen storage reservoir, the following constraints exist:

[0065]

[0066] In the formula, represents the hydrogen storage capacity of the hydrogen storage reservoir with energy storage s in time period t; represents the change in hydrogen energy capacity of the hydrogen storage reservoir during period t, The right side shows the hydrogen storage and consumption in the hydrogen storage reservoir during period t;

[0067] The constraint between the RSOC output in the energy storage system and the storage / dehydration rate of the hydrogen storage reservoir is expressed as:

[0068]

[0069] The expression for constraining the charging and discharging capacity of RSOC under different working modes at different time intervals is:

[0070]

[0071] A further improvement of the present invention is that, in the constraint conditions,

[0072] The day-ahead electric energy market constraints include the bidding constraints of market players in the electric energy market and the power balance constraints of the power system, which can be expressed as follows:

[0073] 0≤e g,t ≤E g,t t∈T,g∈G;

[0074]

[0075] In the formula, E g,t represents the power generation plan for period t submitted by unit g in the electric energy market; J represents the set of new energy units in the power system; P j,t represents the output of new energy unit j in period t;

[0076] The bidding quantity constraint of coal-fired power units and electric-hydrogen coupled energy storage systems in the active auxiliary service market is expressed as:

[0077]

[0078] In the formula, represents the bidding amount of unit g for active auxiliary service a; represents the bidding amount of energy storage s for active ancillary service a;

[0079] The power system's demand constraints for secondary frequency regulation ancillary services are as follows:

[0080]

[0081] In the formula, and They represent the demand for upward and downward frequency regulation ancillary services of the power system during period t respectively;

[0082] The demand constraints of the power system for ramp assistance services are as follows:

[0083]

[0084] In the formula, and They represent the demand for upward and downward climbing auxiliary services of the system in period t respectively;

[0085] The power system's demand constraints for spinning reserve ancillary services are as follows:

[0086]

[0087] In the formula, and They represent the system's upward and downward rotation reserve ancillary service requirements during period t, respectively.

[0088] In a second aspect, the present invention provides a modeling system for joint clearing of day-ahead electric energy and active auxiliary services, comprising:

[0089] The first building block is used to establish the operation target of the new power system; wherein the operation target is to minimize the sum of the operation cost of thermal power resources and the transaction cost of active auxiliary services; in the active auxiliary service transaction, the main participants in the transaction include coal-fired thermal power units and electric-hydrogen coupled energy storage systems;

[0090] The second construction module is used to establish the constraints for power system dispatch and complete the construction of the joint clearing model of day-ahead electric energy and active auxiliary services; wherein the constraints are coal-fired power units and electric-hydrogen coupled energy storage systems; the constraints include operation constraints, ramp constraints and active auxiliary service provision constraints, as well as supply and demand balance and transaction constraints in the day-ahead electric energy market and active auxiliary service market.

[0091] According to a third aspect of the present invention, an electronic device is provided, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the program, a method for modeling the joint clearing of day-ahead electric energy and active auxiliary services as described in any one of the first aspects of the present invention is implemented.

[0092] According to a fourth aspect of the present invention, a non-transitory computer-readable storage medium is provided, on which a computer program is stored. When the computer program is executed by a processor, the method for modeling the joint clearing of day-ahead electric energy and active auxiliary services as described in any one of the first aspects of the present invention is implemented.

[0093] Compared with the prior art, the present invention has the following beneficial effects:

[0094] The modeling method for the joint clearing of day-ahead electric energy and active auxiliary services provided by the present invention is an innovative solution with high flexibility, which aims to enhance the short-term flexibility of the power system by adding new auxiliary services and flexibility resources, and promote the construction and development of the auxiliary service market. Specifically and explanatoryally, the present invention introduces an electric-hydrogen coupled energy storage system based on reversible solid oxide batteries and hydrogen storage reservoirs as a new type of flexibility resource. This electric-hydrogen coupled energy storage system not only has efficient electric energy storage and conversion capabilities, but also can further increase the flexibility and stability of the power system through the storage and release of hydrogen. The equipment involved in the modeling method of the present invention includes various types such as new energy units, coal-fired thermal power units, and electric-hydrogen coupled energy storage systems based on RSOC (reversible solid oxide batteries) and hydrogen storage reservoirs. This wide range of equipment coverage enables the model to more comprehensively consider the role and mutual influence of different resources in the power system.

[0095] The modeling method of the present invention starts from the optimization of unit power generation plan and improves the day-ahead unit combination model. Through more refined unit output plan and more flexible resource scheduling strategy, the short-term operation flexibility of the power system is improved. BRIEF DESCRIPTION OF THE DRAWINGS

[0096] In order to more clearly illustrate the technical solutions in the present invention or 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 some embodiments of the present invention, and for ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0097] Figure 1 It is a flow chart of a joint clearing modeling method of day-ahead electric energy and active auxiliary service in an embodiment of the present invention;

[0098] Figure 2 is a schematic diagram of intraday load and active auxiliary service demand in an embodiment of the present invention;

[0099] Figure 3 Schematic diagram of two wind power output prediction scenarios, scenario 1 and scenario 2, in an embodiment of the present invention;

[0100] Figure 4This is a schematic diagram of the clearing results of the electric energy market in scenario 1 in an embodiment of the present invention;

[0101] Figure 5 This is a schematic diagram of the clearing results of the electric energy market in scenario 2 in an embodiment of the present invention;

[0102] Figure 6 It is a schematic diagram of a modeling system for joint clearing of day-ahead electric energy and active auxiliary services in an embodiment of the present invention. DETAILED DESCRIPTION

[0103] In order to make the purpose, technical solutions and advantages of the present invention clearer, the technical solutions in the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention; it is obvious that the described embodiments and technical solutions are only part of the embodiments of the present invention, not all of the embodiments.

[0104] All other embodiments obtained by those of ordinary skill in the art without creative work based on the technical solutions disclosed in the embodiments of the present invention belong to the scope of protection of the present invention. In addition, the terms "include" and "have" and any variations thereof are intended to cover non-exclusive inclusions. For example, a process, method, system, product or device including a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0105] See also Figure 1 The embodiment of the present invention discloses a joint clearing modeling method of day-ahead electric energy and active auxiliary services, comprising the following steps:

[0106] Step 1: Establishing the operation target of the new power system; the operation target is to minimize the sum of the operation cost of thermal power resources and the transaction cost of active auxiliary services;

[0107] In the exemplary optional technical solution, in the calculation process of the thermal power resource operation cost, during the non-start-stop period, the power generation plan of the thermal power unit is represented by the instantaneous power generation plan at the end of each time period;

[0108] In the exemplary optional technical solution, in the active auxiliary service transaction, the entities participating in the transaction include coal-fired thermal power units and electric-hydrogen coupled energy storage systems, and the active auxiliary service transaction cost includes the cost of various active auxiliary services provided by the coal-fired thermal power units;

[0109] Step 2: Establish the constraints for power system dispatch and complete the construction of the joint clearing model of day-ahead electric energy and active auxiliary services; wherein the constraints are coal-fired power units and electric-hydrogen coupled energy storage systems; the constraints include operation constraints, ramp constraints, and active auxiliary service provision constraints, as well as supply and demand balance and transaction constraints in the day-ahead electric energy market and active auxiliary service market.

[0110] In the technical solution provided by the embodiment of the present invention, the short-term flexibility of the power system is significantly improved by adding new auxiliary services and flexibility resources, which is of great significance for coping with challenges such as uncertainty in renewable energy output and load fluctuations. In addition, since various types of auxiliary services and flexibility resources are taken into account, the modeling method of the embodiment of the present invention can better adapt to the uncertainty and volatility of new energy output, which helps to promote the consumption and utilization of new energy and promote the transformation and upgrading of the energy structure. In summary, the modeling method for the joint clearing of day-ahead electric energy and active auxiliary services provided by the embodiment of the present invention is an innovative solution with high flexibility. By adding new auxiliary services and flexibility resources, etc., the short-term flexibility of the power system is significantly improved, and the advantages of multiple types of market mechanisms and resource endowments can be further exerted to promote the low-carbon transformation of the power system.

[0111] In one embodiment of the present invention, the operation goal is to minimize the sum of the thermal power resource operation cost and the active auxiliary service transaction cost, and further explained as follows:

[0112] In the operation and dispatch of the new power system, the power generation cost of new energy units and the regulation cost of energy storage systems are ignored; therefore, in the joint clearing model of the day-ahead electricity energy market and the active auxiliary service market, the system operation cost is mainly composed of the operation cost of thermal power resources and the cost of providing active auxiliary services. The objective function of minimizing the sum of the operation cost of thermal power resources and the transaction cost of active auxiliary services is expressed as:

[0113] min F=F G +F A (1)

[0114] Where F is the sum of the operating cost of thermal power resources and the transaction cost of active auxiliary services (yuan); F G is the operating cost of thermal power resources (yuan); F A It is the transaction cost of active auxiliary services (Yuan).

[0115] About the operation cost of thermal power resources GThe further explanation is as follows: With the increase in the proportion of new energy units connected to the grid, the importance of thermal power units participating in the ancillary service market to provide ancillary services has also increased; in order to meet the flexibility requirements of the system and achieve economical operation, coal-fired thermal power units need to provide basic active auxiliary services when participating in the optimization of power system dispatch. Its operating costs mainly include three aspects: unit coal cost, start-up and shutdown cost, and no-load operation cost. The specific formula is as follows:

[0116]

[0117] In the formula, e g,t and Z g,t They represent the actual power generation plan (MWh) and power generation cost (yuan / MWh) of unit g in period t respectively; g,t d g,t 、n g,t All are 0-1 variables, l g,t d g,t They respectively indicate whether the unit g is in the start-stop state transition stage during the t period, n g,t Indicates whether the unit g is higher than the minimum output during period t; and represents the start-up and shutdown cost of unit g during period t (yuan), It represents the no-load operation cost of unit g during period t (yuan).

[0118] In the model, it is assumed that the ramp rate of the coal-fired power unit is constant and its output changes uniformly between two time periods. In the non-start-stop period, the unit power generation plan can be expressed by the instantaneous power generation plan at the end of each time period, which is specifically expressed as:

[0119]

[0120] In the formula, is the minimum operating output of unit g (MW), p g,t-1 、p g,t is the power generation plan (MWh) that is higher than the minimum output at the end of the period t-1 and t when the unit g is working normally; Δt is the difference between the instantaneous time at the end of the period t-1 and t; T represents all periods; G represents all coal-fired thermal power units;

[0121] The power generation plan of coal-fired power units at the end of period t (MWh) can be divided into three parts, specifically expressed as:

[0122]

[0123] In the formula, the first and second parts correspond to the power generation plan when the unit is started and shut down, respectively, and the third part is the power generation plan that is higher than the minimum operating output of the unit; and They represent the output (MW) of unit g during the i-th period of the start-stop state transition phase, and They respectively represent the duration (in hours) of the start / stop state conversion phase of unit g.

[0124] In the embodiment of the present invention, regarding the active auxiliary service transaction cost F A The further explanation is as follows: In the active auxiliary service market transaction, the main participants include coal-fired thermal power units and electric-hydrogen coupled energy storage systems; among them, the regulation cost of the energy storage system is low and can be ignored, so the active auxiliary service transaction cost is mainly composed of the cost of various active auxiliary services provided by coal-fired thermal power units; specifically, the active auxiliary service transaction cost F A It is expressed as:

[0125]

[0126] Where A represents the set of active auxiliary service types; and They are respectively the electricity plan (MWh) and cost (yuan / MWh) of the coal-fired power unit g providing active auxiliary service a during period t.

[0127] The technical solution of the embodiment of the present invention is very flexible. After modeling different active auxiliary services, the type of service to be calculated can be selected as needed, which can improve the applicability and solution speed of the model and give priority to clearing high-performance active auxiliary services.

[0128] In one embodiment of the present invention, the constraints for power system dispatch established in step 2 include the following:

[0129] The constraints involved in power system dispatch are mainly coal-fired power units and electric-hydrogen coupled energy storage systems, including operation constraints, ramp constraints and constraints on providing active auxiliary services. At the same time, it is also necessary to consider the supply and demand balance and transaction constraints of the day-ahead electricity energy market and the auxiliary service market.

[0130] In the embodiment of the present invention, further explanations on the scheduling constraints of coal-fired thermal power units are as follows, including:

[0131] The start and stop state constraints of coal-fired power units are expressed as:

[0132] n g,t -n g,t-1 = l g,t -d g,t t∈T,g∈G(6)

[0133] Explanatory, formula (6) can ensure that the unit can only be in one state in the same period through three 0-1 variables representing the unit state;

[0134] The minimum duration constraint of the startup and shutdown state of coal-fired power units is expressed as:

[0135]

[0136] Explanatory, the above formulas (6) to (8) describe the transitions between different states of the unit; i is an iteration count, indicating the i-th time period.

[0137] At present, the ramp constraints of traditional thermal power units are as follows:

[0138]

[0139] In the formula, and They are respectively the upper and lower maximum ramp rates of unit g within 1 hour (MWh).

[0140] Among the auxiliary services considered in the technical solution of the embodiment of the present invention, the spinning reserve requires the unit to respond within 30 minutes, and the secondary frequency regulation and ramp auxiliary services require responses within 15 minutes, both of which require the unit to have a fast ramp capability; therefore, the ramp constraints of the coal-fired thermal power unit in the model are refined, each time period is in hours, and the correlation coefficient is used to represent the 30-minute and 15-minute time intervals in the active auxiliary service, so that the constraints on the coal-fired thermal power unit providing spinning reserve auxiliary services are expressed as follows:

[0141]

[0142] In the formula, and They are respectively the maximum upward and downward climbing rates of unit g within 30 minutes.

[0143] In addition, since secondary frequency regulation and ramp auxiliary services have high requirements on the regulating ability of the units, when the coal-fired thermal power units have a regulating margin and are more economical, they can also participate in the optimization clearing as rotating reserves; therefore, the constraints on the coal-fired thermal power units that provide secondary frequency regulation and ramp auxiliary services are expressed by the formula:

[0144]

[0145] In the formula, They represent the upper and lower maximum ramp rates of unit g within 15 minutes respectively; it is worth noting that the higher the response time requirement of the auxiliary service for the unit and the shorter the response time interval of the unit, the higher the short-term ramp rate of the unit is required, that is,

[0146] In order to ensure that the output of coal-fired thermal power units does not exceed their output range when providing corresponding active auxiliary services, it is necessary to adjust the capacity constraints of traditional units and make corrections at time intervals of hours, 30 minutes, and 15 minutes, as shown below:

[0147]

[0148] In the formula, and are the plans for unit g to provide upward and downward active auxiliary services a during period t respectively.

[0149] In the embodiment of the present invention, further explanations on the dispatch constraints of the electric-hydrogen coupled energy storage system are as follows, including:

[0150] The operating constraints of the electric-hydrogen coupled energy storage system are mainly the RSOC (reversible solid oxide fuel cell) working mode constraints, that is, at a certain moment, RSOC can only be in one working mode, expressed as:

[0151]

[0152] In the formula, S represents the set of electric-hydrogen coupled energy storage systems; and Both are 0-1 variables, indicating whether the energy storage s is in the SOFC (solid oxide fuel cell) and SOEC (solid oxide electrolyzer) working modes during period t; when both are 0, the RSOC of the energy storage s is not working.

[0153] Unlike coal-fired power units, the average up and down ramp capabilities of RSOC in different working modes can meet the dispatching requirements of the power system; therefore, there is no need to differentiate the ramp constraints of RSOC providing active auxiliary services based on time, but only the time interval of active auxiliary services needs to be considered. The ramp constraints of different working modes are expressed as:

[0154]

[0155] In the formula, R UF and R DF Respectively represent the upper and lower maximum ramp rates of SOFC working mode (MWh); R UE and R DE Respectively represent the upper and lower maximum ramp rates of SOEC working mode (MWh); and They represent the actual output (MW) of the energy storage in SOFC and SOEC working modes respectively.

[0156] The scheduling constraints of RSOC also need to consider the impact of hydrogen storage. Specifically: when SOFC is in working mode, RSOC converts hydrogen energy in the hydrogen storage into electrical energy and provides it to the power-consuming load; when in SOEC working mode, RSOC, as a power-consuming load, converts electrical energy into hydrogen energy and stores it in the hydrogen storage. The profit of RSOC in producing hydrogen is not considered here.

[0157] RSOC operating capacity boundaries and related output rate constraints are as follows:

[0158]

[0159] Where N R,max and N R,min are the RSOC capacity of energy storage s In addition, the upper and lower boundaries of RSOC power are related; and They represent the upper and lower limits of the discharge power of the SOFC working mode of the energy storage s (MW), η PF,max and η PF,min They are and The correlation coefficient of and They represent the upper and lower limits of the charging power of the SOEC working mode of the energy storage s (MW), η PE,max and η PE,min They are and The correlation coefficient of

[0160] The following constraints exist for the operating capacity boundary of the hydrogen storage reservoir and the related storage / desorption rates:

[0161]

[0162]

[0163] Where N H,max and N H,min Respectively represent the hydrogen storage capacity of energy storage s The upper and lower boundaries of the hydrogen storage / dehydrogenation rate are related; and They represent the upper and lower limits of the hydrogen storage rate of energy storage s (kg / h), and the correlation coefficients are η HE,max and η HE,min ; and They represent the upper and lower limits of the hydrogen release rate of energy storage s (kg / h), and the correlation coefficients are η HF,max and ηHF,min ;

[0164] RSOC is related to the capacity and operating status of the hydrogen storage tank. During the scheduling optimization process, when RSOC is in SOFC or SOEC mode, the corresponding relationship between RSOC output and the storage / release capacity of the hydrogen storage tank is expressed as:

[0165]

[0166] In the formula, and They represent the hydrogen storage and release rates of energy storage s in time period t (kg / h); η E and η F They represent the energy conversion efficiency when RSOC is in different working modes, and H h Indicates the high calorific value of hydrogen (MWh / kg);

[0167] The energy storage system does not participate in electric energy trading, so the RSOC charge and discharge capacity of the energy storage system is the same in each scheduling cycle, and the corresponding hydrogen storage reservoir should also store the same amount. At the same time, considering the balance of hydrogen energy supply and demand in the hydrogen storage reservoir, there are the following constraints:

[0168]

[0169] In the formula, represents the hydrogen storage capacity (kg) of the hydrogen storage reservoir with energy storage s in period t. The left side of formula (27) represents the change of hydrogen energy capacity of the hydrogen storage reservoir in period t, and the right side represents the hydrogen storage capacity and hydrogen consumption of the hydrogen storage reservoir in period t. This formula expresses the dynamic balance requirement of hydrogen energy;

[0170] In addition, there are constraints between the RSOC output of the energy storage system and the storage / dehydration rate of the hydrogen storage tank:

[0171]

[0172] In order to ensure that the output of RSOC does not exceed the limit when providing active auxiliary services in different working modes, it is necessary to constrain the charging and discharging capacity of RSOC in different working modes at different time intervals. The formula is as follows:

[0173]

[0174] In the embodiment of the present invention, further explanations on the dispatch constraints of the electric energy market are as follows, including:

[0175] The day-ahead electric energy market constraints include the bidding constraints of market players in the electric energy market and the power balance constraints of the power system, which can be expressed as follows:

[0176] 0≤e g,t ≤Eg,t t∈T,g∈G(32)

[0177]

[0178] In the formula, E g,t represents the power generation plan (MWh) submitted by unit g in the electricity market for period t, J represents the set of new energy units in the power system, P j,t It represents the output of renewable energy unit j in period t (MW).

[0179] In the embodiment of the present invention, further explanations on the active auxiliary service market dispatch constraints are as follows, including:

[0180] The bidding constraints for coal-fired power units and electric-hydrogen coupled energy storage systems in the active auxiliary service market are as follows:

[0181]

[0182] In the formula, represents the bid amount of active auxiliary service a by unit g (MWh), represents the bid amount of energy storage s for active ancillary service a (MWh);

[0183] The power system's demand constraints for secondary frequency regulation ancillary services are as follows:

[0184]

[0185] In the formula, and They represent the system's demand for upward and downward frequency regulation ancillary services during period t (in MWh).

[0186] The demand constraints of the power system for ramp assistance services are as follows:

[0187]

[0188] In the formula, and They represent the demand for upward and downward ramping auxiliary services of the system during period t (MWh).

[0189] Some market flexibility resources with better economic performance and margin in providing secondary frequency regulation and ramping auxiliary services can also use the dispatch margin to meet the demand for spinning reserve auxiliary services; therefore, the demand constraints for spinning reserve auxiliary services in the power system are as follows:

[0190]

[0191] In the formula, and They represent the system's upward and downward rotation reserve ancillary service demand (MWh) during period t.

[0192] See also Figures 2 to 5 , the embodiments of the present invention are specifically and exemplarily: Figure 2 It shows the load and active auxiliary service demand of the regional power system during the day. Figure 3 The wind power output forecast for two scenarios is shown. Figure 4 and Figure 5 The clearing results of the electricity energy market in scenario 1 and scenario 2 are shown respectively. Table 1 shows the clearing results of the active power ancillary service market in scenario 1, and Table 2 shows the clearing results of the active power ancillary service market in scenario 2. Table 3 shows the scheduling results of three different models: a joint clearing model including an electric-hydrogen coupled energy storage system, a joint clearing model without an energy storage system, and a separate clearing model.

[0193] Table 1. Clearing results of active ancillary service market in scenario 1

[0194]

[0195]

[0196] Table 2. Clearing results of active ancillary service market in scenario 2

[0197]

[0198]

[0199] Table 3. Scheduling results of three different models

[0200]

[0201] In the embodiment of the present invention, a regional power system integrating wind power generation and coal-fired power generation resources is considered. By analyzing the power load and active auxiliary service demand of the system within a day, reference is made to Figure 2 , the rationality and advantages of a joint clearing model of day-ahead electric energy and active auxiliary services can be evaluated; the total power generation capacity of the system is 5050 MW, of which wind power generation accounts for 23.8% of the total power generation capacity; the larger the scale of the system's coal-fired thermal power units, the more economical its power generation cost and the stronger its climbing ability. In addition, in order to improve the stability of the model, the initial state of the unit participating in the dispatch is also explicitly provided.

[0202] In the regional power system, the wind power output forecast is set to two possible situations, such as Figure 3As shown; the first case predicts a lower wind power output level, while the second case predicts a higher output. This distinction helps to evaluate the effect of the joint clearing model under different operating conditions. At the same time, by comparing the simulation results of the joint clearing model that only includes coal-fired thermal power units and the separate clearing model, the superiority of the joint clearing model and the value of the new energy storage system can be demonstrated. In addition, two types of electric-hydrogen coupled energy storage systems are integrated in the system. These energy storage systems do not participate in direct transactions in the electric energy market, but participate in the bidding for active auxiliary services as price takers. Coal-fired thermal power units choose to participate in the electric energy market and the active auxiliary service market according to actual conditions.

[0203] For scenario 1, the clearing results of the day-ahead electricity energy market and the clearing results of the active power ancillary service market are shown in Figure 4 and Table 1. Explanatory, in scenario 1, coal-fired thermal power unit 1 has an advantage in the day-ahead electricity market due to its large installed capacity, with a low on-grid electricity price, a high bid price for active auxiliary services, and a relatively stable output change; in contrast, units 6 and 7 with smaller installed capacity focus more on the active auxiliary service market, with higher bid capacities, indicating that they need greater output adjustment space in system dispatch; other units bid in both markets according to actual conditions, and units with larger installed capacity have higher bids in the electricity market. Due to the high technical requirements for ramping and secondary frequency regulation auxiliary services, only some units and energy storage systems can provide them, resulting in higher market quotations. During dispatch, the winning bids for active auxiliary services are closely related to resource generation characteristics, system requirements, and operating conditions. Energy storage systems, especially those with larger rated capacity, mainly provide ramping auxiliary services and some secondary frequency regulation auxiliary services; while thermal power units mainly provide secondary frequency regulation and spinning reserve auxiliary services, including a small amount of ramping auxiliary services.

[0204] In scenario 2, due to the increase in wind power output, the clearing results of the electricity market are as follows: Figure 5 As shown in Table 2, the winning bids of coal-fired thermal power units have dropped significantly; in order to promote the consumption of new energy, the output adjustment range and scope of thermal power units have increased, and the clearing results of the active auxiliary service market in scenario 2 are shown in Table 2. Explanatory, compared with scenario 1, although the specific clearing situation is different, the characteristics are similar. The cost of new energy generation is low, but it is intermittent and uncertain, and flexible resources are needed to provide auxiliary services. In the context of joint clearing, the high proportion of new energy grid connection has led to a decrease in the power generation share of traditional thermal power units. Therefore, thermal power units should optimize scheduling performance and adjust bidding strategies to increase their profits in the active auxiliary service market.

[0205] In summary, by comparing the market clearing results under two different wind power output scenarios, the effectiveness of the joint clearing model is verified. The results show that large-capacity units are more competitive in the electric energy market, while small-capacity units perform better in the active auxiliary service market. In addition, the high proportion of new energy grid connection has put forward new requirements for the dispatching strategy of thermal power units, emphasizing the importance of thermal power units in improving dispatching revenue in the active auxiliary service market. The results of the graphical experiment emphasize the key role of flexible resources in the grid connection of new energy, and the necessity of thermal power units to adjust their strategies in adapting to the trend of new energy grid connection.

[0206] After comparing the dispatch results of the joint clearing model (model 1) including the electric hydrogen coupled energy storage system, the joint clearing model (model 2) without the energy storage system, and the separate clearing model (model 3), as shown in Table 3. It can be found that when the wind power output is low, Model 3 shows lower system operating costs and no wind abandonment, which is better than Model 2. However, when the wind power output increases, although the wind abandonment capacity of Model 3 decreases, its dispatch cost increases significantly. Therefore, in the power system with a high proportion of new energy grid connection, Model 2 improves the economy of the system by optimizing resource allocation, showing superiority over Model 3. Further, by comparing Model 1 and Model 2, it can be found that although the electric-hydrogen coupled energy storage system only accounts for 1.0% of the coal-fired thermal power units, it can significantly reduce the transaction costs of the electric energy market and the active auxiliary service market when participating in the active auxiliary service market transactions, and greatly reduce the wind curtailment capacity. This shows that the electric-hydrogen coupled energy storage system has significant effects in reducing overall operating costs, improving economic efficiency, and promoting the consumption of new energy. It is of great value for improving the short-term flexibility of the new power system and ensuring the system stability when new energy is consumed. In the embodiment of the present invention, by comparing the dispatch results of the joint clearing model including the electric-hydrogen coupled energy storage system, the joint clearing model not including the energy storage system, and the separate clearing model, it not only verifies the advantages of the economy and resource optimization allocation of the joint clearing model in the context of high proportion of new energy grid connection, but also highlights the important role of the electric-hydrogen coupled energy storage system in reducing costs, reducing wind curtailment and improving system flexibility, which provides a valuable reference for the design and operation of the new power system.

[0207] In summary, the embodiments of the present invention enhance the short-term flexibility of the new power system by optimizing the active auxiliary service market clearing mode and introducing the electric-hydrogen coupled energy storage system. The clearing results given by the above experiments show that the improved joint clearing model is more economical when the output of new energy is high, and the electric-hydrogen coupled energy storage system can effectively reduce costs and promote the consumption of new energy; at the same time, with the increase in the proportion of new energy installed capacity, traditional resources need to improve flexibility to adapt to market changes and increase revenue. The technical solution of the embodiments of the present invention provides important guidance for the optimized operation of the new power system.

[0208] The following are device embodiments of the present invention, which can be used to implement the method embodiments of the present invention. For details not disclosed in the device embodiments, please refer to the method embodiments of the present invention.

[0209] See also Figure 6 In an embodiment of the present invention, a modeling system for joint clearing of day-ahead electric energy and active auxiliary services is provided, comprising:

[0210] The first building block is used to establish the operation target of the new power system; wherein the operation target is to minimize the sum of the operation cost of thermal power resources and the transaction cost of active auxiliary services; in the active auxiliary service transaction, the main participants in the transaction include coal-fired thermal power units and electric-hydrogen coupled energy storage systems;

[0211] The second construction module is used to establish the constraints for power system dispatch and complete the construction of the joint clearing model of day-ahead electric energy and active auxiliary services; wherein the constraints are coal-fired power units and electric-hydrogen coupled energy storage systems; the constraints include operation constraints, ramp constraints and active auxiliary service provision constraints, as well as supply and demand balance and transaction constraints in the day-ahead electric energy market and active auxiliary service market.

[0212] In one embodiment of the present invention, a computer device is provided, the computer device comprising a processor and a memory, the memory being used to store a computer program, the computer program comprising program instructions, and the processor being used to execute the program instructions stored in the computer storage medium. The processor may be a central processing unit (CPU), or may be other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components, etc. It is the computing core and control core of the terminal, which is suitable for implementing one or more instructions, and is specifically suitable for loading and executing one or more instructions in the computer storage medium to implement the corresponding method flow or corresponding function; the processor described in the embodiment of the present invention can be used to perform the operation of the joint clearing modeling method of day-ahead electric energy and active auxiliary services.

[0213] In one embodiment of the present invention, a storage medium is provided, specifically a computer-readable storage medium (Memory), which is a memory device in a computer device for storing programs and data. It is understandable that the computer-readable storage medium here can include both built-in storage media in the computer device and, of course, extended storage media supported by the computer device. The computer-readable storage medium provides a storage space, which stores the operating system of the terminal. In addition, one or more instructions suitable for being loaded and executed by the processor are also stored in the storage space, and these instructions can be one or more computer programs (including program codes). It should be noted that the computer-readable storage medium here can be a high-speed RAM (Random Access Memory) memory, or a non-volatile memory (non-volatile memory), such as at least one disk memory. The processor can load and execute one or more instructions stored in the computer-readable storage medium to implement the corresponding steps of the joint clearing modeling method of day-ahead electric energy and active auxiliary services in the above embodiment.

[0214] Those skilled in the art will appreciate that the embodiments of the present application may be provided as methods, systems, or computer program products. Therefore, the present application may adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the present application may adopt the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, optical storage, etc.) that contain computer-usable program code.

[0215] The present application is described with reference to the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products according to the embodiments of the present application. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of the processes and / or boxes in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to generate a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0216] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0217] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0218] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention rather than to limit it. Although the present invention has been described in detail with reference to the above embodiments, ordinary technicians in the relevant field should understand that the specific implementation methods of the present invention can still be modified or replaced by equivalents. Any modification or equivalent replacement that does not depart from the spirit and scope of the present invention should be covered within the scope of protection of the claims of the present invention.

Claims

1. A joint clearing modeling method for day-ahead electric energy and active auxiliary services, characterized in that: The following steps are involved: Establishing the operation target of the new power system; wherein the operation target is to minimize the sum of the operation cost of thermal power resources and the transaction cost of active auxiliary services; in the active auxiliary service transaction, the main participants include coal-fired thermal power units and electric-hydrogen coupled energy storage systems; Establish constraints for power system dispatch and complete the construction of a joint clearing model for day-ahead electric energy and active ancillary services; the constraints are coal-fired power units and electric-hydrogen coupled energy storage systems; the constraints include operation constraints, ramp constraints, and active ancillary service provision constraints, as well as supply and demand balance and transaction constraints in the day-ahead electric energy market and active ancillary service market.

2. A joint clearing modeling method for day-ahead electric energy and active auxiliary services according to claim 1, characterized in that: In the step of establishing the operation target of the new power system, the objective function of the operation target is expressed as: min F=F G +F A ; Where F is the sum of the operating cost of thermal power resources and the transaction cost of active auxiliary services; F G F is the operating cost of thermal power resources; A transaction costs for active ancillary services; In the formula, e g,t and Z g,t They represent the actual power generation plan and power generation cost of unit g in period t respectively; l g,t ,d g,t They respectively indicate whether the unit g is in the start-stop state transition stage during the t period, n g,t Indicates whether the unit g is higher than the minimum output during period t; and They represent the start-up and shutdown costs of unit g during period t, represents the no-load operation cost of unit g in period t; T represents all periods; G represents all coal-fired thermal power units; Where A represents the set of active auxiliary service types; and They are respectively the electricity plan and cost of the coal-fired power unit g providing active auxiliary service a during period t.

3. A joint clearing modeling method for day-ahead electric energy and active auxiliary services according to claim 2, characterized in that: In the calculation process of the thermal power resource operation cost, during the non-start-up and shutdown period, the power generation plan of the thermal power unit is represented by the instantaneous power generation plan at the end of each time period; wherein, In the formula, is the minimum operating output of unit g; p g,t-1 、p g,t is the power generation plan that is instantaneously higher than the minimum output at the end of the period t-1 and t when unit g is operating normally; Δt is the difference between the instantaneous times at the end of the period t-1 and t; Among them, in calculating p g,t-1 、p g,t When the coal-fired power unit is scheduled to generate electricity at the end of period t, It is divided into three parts, specifically expressed as follows: In the formula, and They represent the output of unit g in period i during the start-stop state transition phase; and They respectively represent the duration of the start-stop state conversion phase of unit g.

4. A joint clearing modeling method for day-ahead electric energy and active auxiliary services according to claim 1, characterized in that: Among the constraints, The start and stop state constraints of coal-fired power units are expressed as: n g,t -n g,t-1 l g,t -d g,t t∈T,g∈G; Where n g,t 、n g,t -1 Respectively indicate whether the unit g is higher than the minimum output at time t and t-1; l g,t ,d g,t They respectively indicate whether the unit g is in the start-stop state transition stage during the period t; T represents all periods; G represents all coal-fired thermal power units; The minimum duration constraint of the startup and shutdown state of coal-fired power units is expressed as: In the formula, i represents the i-th period; and They respectively represent the duration of the start-stop state conversion phase of unit g.

5. The method for joint clearing of day-ahead electric energy and active auxiliary services according to claim 1 is characterized in that: Among the constraints, The constraints on the coal-fired power units providing spinning reserve auxiliary services are expressed as: In the formula, p g,t-1 、p g,t It is the power generation plan that is instantaneously higher than the minimum output at the end of the period t-1 and t when the unit g is working normally; and are the plans for unit g to provide upward and downward spinning reserve auxiliary services in period t, respectively; Δt is the difference between the instantaneous time at the end of period t-1 and t; are the maximum up and down ramp rates of unit g within 30 minutes, respectively; T represents all time periods; G represents all coal-fired thermal power units; The constraints on coal-fired power units that provide secondary frequency regulation and ramp auxiliary services are expressed as follows: In the formula, They represent the maximum upward and downward climbing rates of unit g within 15 minutes respectively; They represent the plans of unit g to provide upward and downward secondary frequency regulation auxiliary services during period t respectively; They represent the plans of unit g to provide upward and downward climbing auxiliary services during period t respectively; The capacity constraints of the units are specifically expressed as follows: In the formula, and are the plans for unit g to provide upward and downward active auxiliary services a during period t respectively.

6. A joint clearing modeling method for day-ahead electric energy and active auxiliary services according to claim 1, characterized in that: Among the constraints, The operation constraint of the electric-hydrogen coupled energy storage system is the working mode constraint of RSOC. At a certain moment, RSOC can only be in one working mode, which is expressed as: In the formula, S represents the set of electric-hydrogen coupled energy storage systems; and They respectively indicate whether the energy storage s is in the SOFC and SOEC working modes during period t; The climbing constraints of different RSOC working modes are expressed as follows: In the formula, R UF and R DF Respectively represent the upper and lower maximum ramp rates of SOFC working mode; R UE and R DE Respectively represent the upper and lower maximum ramp rates of the SOEC working mode; and They represent the actual output of energy storage s in SOFC and SOEC working modes respectively; The scheduling constraints of RSOC include: when SOFC is in working mode, RSOC converts hydrogen energy in the hydrogen storage tank into electric energy and provides it to the power-consuming load; when in SOEC working mode, RSOC, as the power-consuming load, converts electric energy into hydrogen energy and stores it in the hydrogen storage tank; RSOC operating capacity boundaries and related output rate constraints are as follows: Where N R,max 、N R,min are the RSOC capacity of energy storage s The upper and lower boundaries of P s F,max , P s F,min They represent the upper and lower limits of the discharge power of the SOFC working mode of energy storage s, η PF,max and η PF,min P s F,max and P s F,min The correlation coefficient of s E ,max , P s E,min They represent the upper and lower limits of the charging power of the SOEC working mode of the energy storage s, η PE,max and η PE,min P s E,max and P s E,min The correlation coefficient of The following constraints exist for the operating capacity boundary of the hydrogen storage reservoir and the related storage / desorption rates: Where N H,max 、N H,min Respectively represent the hydrogen storage capacity of energy storage s The upper and lower boundaries of (kg); Respectively represent the upper and lower limits of the hydrogen storage rate of energy storage s, η HE,max and η HE,min They are and The correlation coefficient of Respectively represent the upper and lower limits of the hydrogen release rate of energy storage s, η HF,max and η HF,min They are and The correlation coefficient of In the process of scheduling optimization, when RSOC is in SOFC or SOEC mode, the corresponding relationship between RSOC output and hydrogen storage / desorption capacity of hydrogen storage tank is expressed as: In the formula, and They represent the hydrogen storage and desorption rates of energy storage s in time period t respectively; η E and η F They represent the energy conversion efficiency when RSOC is in different working modes; H h Indicates the high calorific value of hydrogen; The energy storage system does not participate in the electricity energy transaction. Considering the hydrogen energy supply and demand balance of the hydrogen storage reservoir, the following constraints exist: In the formula, represents the hydrogen storage capacity of the hydrogen storage reservoir with energy storage s in time period t; represents the change in hydrogen energy capacity of the hydrogen storage reservoir during period t, The right side shows the hydrogen storage and consumption in the hydrogen storage reservoir during period t; The constraint between the RSOC output in the energy storage system and the storage / dehydration rate of the hydrogen storage reservoir is expressed as: The expression for constraining the charging and discharging capacity of RSOC under different working modes at different time intervals is:

7. A joint clearing modeling method for day-ahead electric energy and active auxiliary services according to claim 1, characterized in that: Among the constraints, The day-ahead electric energy market constraints include the bidding constraints of market players in the electric energy market and the power balance constraints of the power system, which can be expressed as follows: 0≤e g,t ≤E g,t t∈T,g∈G; In the formula, E g,t represents the power generation plan for period t submitted by unit g in the electric energy market; J represents the set of new energy units in the power system; P j,t represents the output of new energy unit j in period t; The bidding quantity constraint of coal-fired power units and electric-hydrogen coupled energy storage systems in the active auxiliary service market is expressed as: In the formula, represents the bidding amount of unit g for active auxiliary service a; represents the bidding amount of energy storage s for active ancillary service a; The power system's demand constraints for secondary frequency regulation ancillary services are as follows: In the formula, and They represent the demand for upward and downward frequency regulation ancillary services of the power system during period t respectively; The demand constraints of the power system for ramp assistance services are as follows: In the formula, and They represent the demand for upward and downward climbing auxiliary services of the system in period t respectively; The power system's demand constraints for spinning reserve ancillary services are as follows: In the formula, and They represent the system's upward and downward rotation reserve ancillary service requirements during period t, respectively.

8. A joint clearing modeling system for day-ahead electric energy and active auxiliary services, characterized in that: include: The first building block is used to establish the operation target of the new power system; wherein the operation target is to minimize the sum of the operation cost of thermal power resources and the transaction cost of active auxiliary services; in the active auxiliary service transaction, the main participants in the transaction include coal-fired thermal power units and electric-hydrogen coupled energy storage systems; The second construction module is used to establish the constraints for power system dispatch and complete the construction of the joint clearing model of day-ahead electric energy and active auxiliary services; wherein the constraints are coal-fired power units and electric-hydrogen coupled energy storage systems; the constraints include operation constraints, ramp constraints and active auxiliary service provision constraints, as well as supply and demand balance and transaction constraints in the day-ahead electric energy market and active auxiliary service market.

9. An electronic device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the program, the day-ahead electric energy and active auxiliary service joint clearing modeling method according to any one of claims 1 to 7 is implemented.

10. A non-transitory computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the method for modeling the joint clearing of day-ahead electric energy and active auxiliary services according to any one of claims 1 to 7 is implemented.

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