Inertia, primary frequency modulation and secondary frequency modulation pricing method considering frequency modulation capability of hydrogen refueling station

Abstract

The invention discloses an inertia, primary frequency modulation and secondary frequency modulation pricing method considering the frequency modulation capability of a hydrogen refueling station. The method comprises the following steps: 1) establishing a frequency safety constraint considering the frequency response capability of the hydrogen refueling station; 2) constructing a frequency modulation auxiliary service pricing model considering the frequency response capability of the hydrogen refueling station; and 3) solving the frequency modulation auxiliary service pricing model considering the frequency response capability of the hydrogen refueling station to obtain a power system frequency modulation auxiliary service pricing scheme. When primary frequency modulation and secondary frequency modulation pricing are carried out, the frequency modulation capability of the hydrogen refueling station is considered, and primary frequency modulation and secondary frequency modulation prices provided by the hydrogen refueling station and the synchronous generator are formulated. The method fully considers the operation characteristics of the hydrogen refueling station, and is suitable for a high-proportion new energy power grid.

Description

Technical Field

[0001] The present invention relates to the technical field of new energy power systems, and specifically to a pricing method for inertia, primary frequency modulation, and secondary frequency modulation considering the frequency modulation capacity of hydrogen refueling stations. Background Art

[0002] The high penetration of renewable energy has significantly reduced the number of online synchronous generators in the power system. The inertia, primary frequency modulation, and secondary frequency modulation response capabilities provided by synchronous generators show scarcity characteristics and cannot ensure the frequency stability of the new power system. When there is a sudden imbalance between power generation and demand in the power system, extreme events such as system frequency over-limit will occur, posing a huge challenge to system security. Therefore, it is necessary to deeply explore and utilize various grid-connected resources to provide frequency modulation auxiliary services to the power grid and enhance the power grid frequency regulation ability.

[0003] In recent years, the scale of hydrogen refueling stations has been continuously expanding to meet the growing hydrogen demand. Hydrogen refueling stations use renewable energy to generate electricity to produce hydrogen, inject green hydrogen into the hydrogen pipeline network or hydrogen storage tanks to meet the hydrogen demand for transportation and industry. In addition, hydrogen refueling stations can use the fast response characteristics of on-site electrolyzers and fuel cells to provide frequency modulation auxiliary services to the power system, including inertia response, primary frequency modulation, and secondary frequency modulation services.

[0004] Therefore, it is necessary to provide a pricing method for inertia, primary frequency modulation, and secondary frequency modulation considering the frequency modulation capacity of hydrogen refueling stations. Summary of the Invention

[0005] The purpose of the present invention is to provide a pricing method for inertia, primary frequency modulation, and secondary frequency modulation considering the frequency modulation capacity of hydrogen refueling stations, including the following steps:

[0006] 1) Establish a frequency security constraint considering the frequency response capacity of hydrogen refueling stations;

[0007] 2) Construct a pricing model for frequency modulation auxiliary services considering the frequency response capacity of hydrogen refueling stations;

[0008] 3) Solve the pricing model for frequency modulation auxiliary services considering the frequency response capacity of hydrogen refueling stations to obtain a pricing scheme for frequency modulation auxiliary services in the power system.

[0009] Further, in step 1), the steps of establishing a frequency security constraint considering the frequency response capacity of hydrogen refueling stations are as follows:

[0010] 1.1) Calculate the virtual inertia response power of the hydrogen refueling station, that is:

[0011]

[0012] Wherein, is the virtual inertia response power of the hydrogen refueling station; H Eis the virtual inertia time constant of the electrolyzer in the hydrogen refueling station; H F is the virtual inertia time constant of the hydrogen fuel cell in the hydrogen refueling station; P s E,max represents the maximum operating power of the electrolyzer in hydrogen refueling station s; P s F,max represents the maximum operating power of the hydrogen fuel cell in hydrogen refueling station s; u s,t represents the operating state of hydrogen refueling station s at time t, 1 means operating, 0 means shutdown; f 0 is the rated frequency of the power grid; Δf(t) is the system frequency deviation;

[0013] 1.2) Build the primary frequency regulation response models of the hydrogen refueling station and the synchronous generator respectively, that is:

[0014]

[0015] In the formula, t r represents the frequency fluctuation time after the power deficit event occurs; represents the frequency disturbance at time t r seconds later, the primary frequency regulation power output of hydrogen refueling station s; represents the frequency disturbance at time t r seconds later, the primary frequency regulation power output of synchronous generator g; represents the primary frequency regulation reserve capacity of synchronous generator g at time t; represents the primary frequency regulation reserve capacity of the electrolyzer in hydrogen refueling station s at time t; represents the primary frequency regulation reserve capacity of the fuel cell in hydrogen refueling station s at time t; t DB,h represents the time when the frequency deviation reaches the frequency regulation dead zone during the frequency response process of the hydrogen refueling station; t DB,g represents the time when the frequency deviation reaches the frequency regulation dead zone during the frequency response process of the synchronous generator; represents the primary frequency regulation response time of the synchronous generator; represents the primary frequency regulation response time of the hydrogen refueling station;

[0016] 1.3) Calculate the frequency regulation power of the hydrogen refueling station in the secondary frequency regulation stage, that is:

[0017]

[0018] In the formula, t ss represents the time when the frequency reaches the quasi-steady state; represents the frequency disturbance at time t r seconds later, the secondary frequency regulation power output of hydrogen refueling station s; represents the frequency disturbance at time t r seconds later, the secondary frequency regulation power output of synchronous generator g; represents the secondary frequency regulation reserve capacity of synchronous generator g at time t; Denote the secondary frequency regulation reserve capacity of the electrolyzer at hydrogen refueling station s during period t; Denote the secondary frequency regulation reserve capacity of the fuel cell at hydrogen refueling station s during period t; Denote the secondary frequency regulation response time of the synchronous generator; Denote the secondary frequency regulation response time of the hydrogen refueling station;

[0019] 1.4) Construct the power system swing equation, i.e.:

[0020]

[0021] In the formula, N G Denote the set of synchronous generators; N S Denote the set of hydrogen refueling stations; H G,t Is the moment of inertia of the synchronous generator; Is the virtual inertia of the hydrogen refueling station during period t; ΔP d Is the system power deficit; PFR(t) is the system frequency regulation output power;

[0022] 1.5) Construct the frequency security constraint considering the frequency response ability of the hydrogen refueling station through the system swing equation.

[0023] Furthermore, the frequency security constraint considering the frequency response ability of the hydrogen refueling station includes RoCoF, frequency nadir constraint, frequency quasi-steady state constraint, and frequency steady state constraint.

[0024] Furthermore, the RoCoF constraint is as follows:

[0025]

[0026] In the formula, Is the rated power of synchronous generator g; H g Is the inertia time constant of synchronous generator g; u g,t Is the operating state of synchronous generator g during period t, 1 represents the operating state, and 0 represents the shutdown state; RoCoF max Is the upper limit of the frequency change rate; RoCoF is the frequency change rate;

[0027] The frequency nadir constraint is as follows:

[0028]

[0029] In the formula, Δf max Is the maximum frequency deviation; H t Is the total system inertia, H t =H G,t +H VIS,t ; Is the total primary frequency regulation output of the synchronous generator, is the total primary frequency regulation output of the hydrogen refueling station;

[0030]

[0031] The frequency quasi-steady state constraints are as follows:

[0032]

[0033] The frequency steady state constraints are as follows:

[0034]

[0035] In the formula, K is the unit regulation power of the power system; Δf ss is the steady state frequency deviation of the system; is the total secondary frequency regulation output of the synchronous generator, is the total secondary frequency regulation output of the hydrogen refueling station; Δf lim is the upper limit of the steady state frequency deviation of the system;

[0036] Among them, the total secondary frequency regulation output of the synchronous generator The total secondary frequency regulation output of the hydrogen refueling station is as follows

[0037]

[0038] Furthermore, in step 2), the steps to establish a frequency regulation ancillary service pricing model considering the frequency response ability of the hydrogen refueling station include:

[0039] 2.1) Convert the frequency lowest point constraint into the standard second-order cone formula form, that is:

[0040]

[0041] 2.2) Simplify the standard second-order cone formula form to obtain:

[0042]

[0043] In the formula, μ is the dual variable; λ 1 and λ 2 are dual variables;

[0044] 2.3) Construct the Lagrangian function L of the pricing model including RoCoF constraints, frequency quasi-steady state constraints, frequency lowest point constraints and frequency steady state constraints FR , that is:

[0045]

[0046] In the formula, λ RoCoF is the dual variable of the RoCoF constraint; λ qssis the dual variable of the frequency quasi-steady-state constraint; λ ss is the dual variable of the frequency steady-state constraint;

[0047] 2.4) According to the KKT conditions of the gradient of the Lagrangian function, the shadow prices of different frequency regulation ancillary services are derived, including the virtual inertia H provided by the hydrogen refueling station VIS,t and the inertia H provided by the synchronous generator G,t price, the primary frequency regulation P provided by the hydrogen refueling station PFRS,t price, the primary frequency regulation P provided by the synchronous generator PFRG,t price, the secondary frequency regulation P provided by the hydrogen refueling station and the synchronous generator SFRS,t price;

[0048] 2.5) Calculate the output of renewable energy and the output of synchronous generators;

[0049] Among them, the output of renewable energy is as follows:

[0050]

[0051] In the formula, r represents the renewable energy power station; N R represents the set of renewable energy power stations; N T represents the set of day-ahead scheduling periods; represents the error of the output of renewable energy; represents the predicted value of renewable energy generation; represents the output of renewable energy;

[0052] The output of synchronous generators is as follows:

[0053]

[0054] In the formula, P g,t represents the standard power output of synchronous generator g at time t; α g,t represents the regulation factor of synchronous generator g at time t; is the total error of the output of renewable energy; represents the predicted value of the power generation of synchronous generator g at time t;

[0055] The regulation factor α g,t and the total error of the output of renewable energy are as follows:

[0056]

[0057] In the formula, I T represents the coefficient vector with elements all being 1; is the output error vector of the renewable energy power station, R represents the number of renewable energy power stations;

[0058] 2.6) Based on the shadow prices of different frequency regulation ancillary services, the output of renewable energy, and the output of synchronous generators, a pricing model for frequency regulation ancillary services considering the frequency response capability of hydrogen refueling stations is constructed.

[0059] Furthermore, the virtual inertia H provided by the hydrogen refueling station VIS,t and the inertia H provided by the synchronous generator G,t have the following prices:

[0060]

[0061] The primary frequency regulation P provided by the hydrogen refueling station PFRS,t has the following price:

[0062]

[0063] The primary frequency regulation P provided by the synchronous generator PFRG,t has the following price:

[0064]

[0065] The secondary frequency regulation P provided by the hydrogen refueling station and the synchronous generator SFRS,t has the following price:

[0066]

[0067] Furthermore, the objective function of the pricing model for frequency regulation ancillary services considering the frequency response capability of hydrogen refueling stations is as follows:

[0068] min C = C G + C st + C re + C cur + C shed + C ad (31)

[0069]

[0070] In the formula, N D represents the set of buses; and respectively represent the upward regulation reserve capacity and downward regulation reserve capacity of unit g at time t; a g , b g and c g are respectively the operating cost coefficients of the synchronous generator; and are respectively the start-up cost and shutdown cost of the synchronous generator; represents the start-up state of unit g at time t, 1 means start-up, 0 means no start-up; Indicates the outage status of unit g during period t. 1 indicates outage, and 0 indicates non-outage; and respectively represent the cost of the upper regulation reserve capacity and the cost of the lower regulation reserve capacity of synchronous generator g; represents the regulation cost of synchronous generator g; represents the primary frequency regulation cost coefficient of unit g; represents the secondary frequency regulation cost coefficient of unit g; represents the virtual inertia cost coefficient of hydrogen refueling station s; represents the primary frequency regulation cost coefficient of hydrogen refueling station s; represents the secondary frequency regulation cost coefficient of hydrogen refueling station s; C is the total cost of system operation; C G 、C st 、C re 、C PFRg 、C SFRg 、C ad 、C VIs 、C PFRs 、C SFRg are the power generation cost of synchronous generator, the start-stop cost of synchronous generator, the reserve capacity cost of synchronous generator, the primary frequency regulation cost of synchronous generator, the secondary frequency regulation cost of synchronous generator, the adjustment cost of the uncertainty of renewable energy output, the virtual inertia response cost of hydrogen refueling station, the primary frequency regulation cost of hydrogen refueling station, and the secondary frequency regulation cost of hydrogen refueling station.

[0071] Furthermore, the constraint conditions of the frequency regulation ancillary service pricing model considering the frequency response ability of hydrogen refueling stations include the primary frequency regulation reserve capacity constraints of electrolyzers and fuel cells in the hydrogen refueling station, the hydrogen flow equation, the secondary frequency regulation reserve capacity constraints of electrolyzers and fuel cells in the hydrogen refueling station, the operating power constraints of electrolyzers, the operating power constraints of fuel cells, the power generation power equation of fuel cells, the operating power constraints of fuel cells, the hydrogen storage capacity constraints of hydrogen storage tanks in the hydrogen refueling station, the hydrogen production constraints of the hydrogen refueling station, the operating constraints of synchronous generators, the minimum start-stop time constraints of synchronous generators, the ramp constraints of synchronous generators, the reserve capacity constraints of synchronous generators, the regulation reserve capacity constraints of synchronous generators, the primary and secondary frequency regulation reserve capacity constraints of synchronous generators, the power balance constraints of the power system, the power constraints of transmission lines, and the frequency safety constraint content considering the frequency response ability of hydrogen refueling stations.

[0072] Furthermore, the primary frequency regulation reserve capacity constraints of electrolyzers and fuel cells in the hydrogen refueling station are as follows:

[0073]

[0074] In the formula, is the maximum proportion of the primary frequency regulation capacity provided by hydrogen refueling station s;

[0075] The secondary frequency regulation reserve capacity constraints of the electrolyzer and fuel cell in the hydrogen refueling station are as follows:

[0076]

[0077] Wherein, is the maximum proportion of secondary frequency regulation capacity provided by hydrogen refueling station s;

[0078] The hydrogen flow equation generated by the electrolyzer in the hydrogen refueling station is as follows:

[0079]

[0080] Wherein, N Es,t is the hydrogen production of the electrolyzer in hydrogen refueling station s at time period t; P Es,t represents the operating power of the electrolyzer in hydrogen refueling station s at time period t; η E is the electro-hydrogen energy conversion efficiency of the electrolyzer in hydrogen refueling station s; HHV H is the high heating value coefficient of hydrogen;

[0081] The operating power constraint of the electrolyzer is as follows:

[0082]

[0083] Wherein, P E,mins represents the minimum operating power of the electrolyzer in hydrogen refueling station s at time period t; P E,maxs represents the maximum operating power of the electrolyzer in hydrogen refueling station s at time period t;

[0084] The power generation equation of the fuel cell is as follows:

[0085]

[0086] Wherein, N Fs,t is the hydrogen consumption of the fuel cell in hydrogen refueling station s at time period t; P Fs,t represents the power generation power of the fuel cell in hydrogen refueling station s at time period t; η F is the power generation efficiency of the fuel cell in hydrogen refueling station s;

[0087] The operating power constraint of the fuel cell is as follows:

[0088]

[0089] Wherein, P F,mins represents the minimum operating power of the fuel cell in hydrogen refueling station s at time period t; P F,maxs represents the maximum operating power of the fuel cell in hydrogen refueling station s at time period t;

[0090] The hydrogen storage capacity constraint of the hydrogen storage tank in the hydrogen refueling station is as follows:

[0091]

[0092] Wherein, SoH s,t-1 represents the hydrogen storage of the hydrogen storage tank at time t-1; η in and η out are the efficiencies of hydrogen input and output of the hydrogen storage tank respectively; Δt represents the system scheduling time granularity; represents the minimum hydrogen storage of the hydrogen storage tank; SoH maxs represents the maximum hydrogen storage of the hydrogen storage tank;

[0093] The hydrogen production constraint of the hydrogen refueling station is as follows:

[0094]

[0095] Wherein, N Ht is the hydrogen demand at time t;

[0096] The operation constraint of the synchronous generator is as follows:

[0097]

[0098] The minimum start-stop time constraint of the synchronous generator is as follows:

[0099]

[0100] Wherein, T onfg represents the minimum on-time of unit g; T offg represents the minimum off-time of unit g;

[0101] The ramp constraint of the synchronous generator is as follows:

[0102]

[0103] Wherein, RU g and RD g represent the upward and downward ramp limits of synchronous generator g respectively;

[0104] The reserve capacity constraint of the synchronous generator is as follows:

[0105]

[0106] Wherein, P maxg and P ming represent the maximum power limit and minimum power limit of synchronous generator g respectively.

[0107] The regulation reserve capacity constraint of the synchronous generator is as follows:

[0108]

[0109] The primary frequency regulation and secondary frequency regulation reserve capacity constraints of the synchronous generator are as follows:

[0110]

[0111] Wherein, δ PFRg is the maximum proportion of the primary frequency regulation capacity provided by the synchronous generator g; δ SFRg is the maximum proportion of the secondary frequency regulation capacity provided by the synchronous generator g.

[0112] The power balance constraint of the power system is as follows:

[0113]

[0114] Wherein, P d,t represents the grid-connected load of bus d at time t.

[0115] The power constraint of the transmission line is as follows:

[0116]

[0117] Wherein, N l represents the set of lines; κ l,g represents the power flow transfer factor of the synchronous generator g on line l; κ l,s represents the power flow transfer factor on line l; κ l,d represents the power flow transfer factor of the load d on line l; F maxl represents the power constraint on the transmission line l.

[0118] Furthermore, in step 3), the steps of solving the frequency modulation auxiliary service pricing model considering the frequency response ability of the hydrogen refueling station include:

[0119] 3.1) Define the CVaR-Wasserstein metric That is:

[0120]

[0121] Wherein, ∏ is the joint distribution composed of the random variable ζ 1 belonging to the probability distribution and ζ 2 belonging to the probability distribution ; d(ζ 1 -ζ 2 ) = ||ζ 1 -ζ 2 || is the distance between the random variables ζ 1 and ζ 2 defined by the vector norm, represents the set of all probability distributions with the support set Ξ; the support set of the random variable ζ and are the sample mean and sample covariance, and σ max is the sample coefficient; represents the minimum cost required to move the probability mass from to ;

[0122] 3.2) Determine the empirical distribution of the renewable energy output error based on the historical data of N samples of the uncertainty variable ; is the Dirac distribution of the random variable ;

[0123] 3.3) Construct a fuzzy set using the CVaR-Wasserstein ball, that is:

[0124]

[0125] where ε is the radius of the CVaR-Wasserstein ball;

[0126] 3.4) Calculate the worst-case expected cost that is:

[0127]

[0128] where ||·|| * is the dual norm of ||·||; and ||e|| 1 = 1; is the fuzzy set constructed by the type-∞ Wasserstein metric; is the classical type-1 Wasserstein fuzzy set; is the loss function; 1-α is the scaling ratio of the radius ε of the fuzzy set;

[0129] 3.5) Reconstruct the worst-case expected cost to obtain the reconstructed worst-case expected cost model, that is:

[0130] min C = C de + z

[0131]

[0132] where: z is the auxiliary variable; C de is the sum of the costs other than the expected cost in the worst distribution case.

[0133] 3.6) Solve the reconstructed worst-case expected cost model to obtain the pricing scheme for the frequency regulation ancillary services of the power system.

[0134] The technical effects of the present invention are beyond doubt. When pricing primary frequency regulation and secondary frequency regulation, the present invention takes into account the frequency regulation capacity of hydrogen refueling stations and formulates the primary frequency regulation and secondary frequency regulation prices provided by hydrogen refueling stations and synchronous generators. The present invention fully considers the operating characteristics of hydrogen refueling stations and is applicable to high-proportion new energy power grids. Description of the Drawings

[0135] Figure 1 is a schematic flow chart of a method for pricing inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation capacity of hydrogen refueling stations;

[0136] Figure 2 (a)-(d) are diagrams comparing the frequency regulation ancillary service prices under different scenarios;

[0137] Figure 3 (a)-(b) are diagrams comparing the clearing capacities of primary frequency regulation and secondary frequency regulation under different scenarios. Detailed Embodiments

[0138] The present invention will be further described below in conjunction with embodiments, but it should not be understood that the above-mentioned subject matter scope of the present invention is limited to the following embodiments. Without departing from the above technical ideas of the present invention, various substitutions and changes made according to ordinary technical knowledge and customary means in the art shall be included within the protection scope of the present invention.

[0139] Embodiment 1:

[0140] Refer to Figures 1 to 3 , a method for pricing inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation capacity of hydrogen refueling stations, includes the following steps:

[0141] 1) Establish a frequency security constraint considering the frequency response capacity of hydrogen refueling stations;

[0142] 2) Construct a pricing model for frequency regulation ancillary services considering the frequency response capacity of hydrogen refueling stations;

[0143] 3) Solve the pricing model for frequency regulation ancillary services considering the frequency response capacity of hydrogen refueling stations to obtain the pricing scheme for the frequency regulation ancillary services of the power system.

[0144] Embodiment 2:

[0145] A method for pricing inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation capacity of hydrogen refueling stations, the technical content is the same as that of Embodiment 1. Further, in step 1), the steps for establishing a frequency security constraint considering the frequency response capacity of hydrogen refueling stations are as follows:

[0146] 1.1) Calculate the virtual inertia response power of the hydrogen refueling station, that is:

[0147]

[0148] Wherein, is the virtual inertia response power of the hydrogen refueling station; H E is the virtual inertia time constant of the electrolyzer in the hydrogen refueling station; H F is the virtual inertia time constant of the hydrogen fuel cell in the hydrogen refueling station; P s E,max represents the maximum operating power of the electrolyzer of the hydrogen refueling station s; P s F,max represents the maximum operating power of the hydrogen fuel cell of the hydrogen refueling station s; u s,t represents the operating state of the hydrogen refueling station s at time t, 1 represents operating, and 0 represents shutdown; f 0 is the rated frequency of the power grid; Δf(t) is the system frequency deviation;

[0149] 1.2) Construct the primary frequency regulation response models of the hydrogen refueling station and the synchronous generator respectively, that is:

[0150]

[0151] Wherein, t r represents the frequency fluctuation time after the power deficit event occurs; represents the frequency disturbance at time t r seconds later, the primary frequency regulation power output of the hydrogen refueling station s; represents the frequency disturbance at time t r seconds later, the primary frequency regulation power output of the synchronous generator g; represents the primary frequency regulation reserve capacity of the synchronous generator g at time t; represents the primary frequency regulation reserve capacity of the electrolyzer of the hydrogen refueling station s at time t; represents the primary frequency regulation reserve capacity of the fuel cell of the hydrogen refueling station s at time t; t DB,h represents the time when the frequency deviation reaches the frequency regulation dead zone during the frequency response process of the hydrogen refueling station; t DB,g represents the time when the frequency deviation reaches the frequency regulation dead zone during the frequency response process of the synchronous generator; represents the primary frequency regulation response time of the synchronous generator; represents the primary frequency regulation response time of the hydrogen refueling station;

[0152] 1.3) Calculate the frequency regulation power of the hydrogen refueling station in the secondary frequency regulation stage, that is:

[0153]

[0154] Wherein, t ss represents the time when the frequency reaches the quasi-steady state; represents the frequency disturbance at time t rHydrogen refueling station s secondary frequency regulation power output after Indicates the frequency disturbance during period t r Synchronous generator g secondary frequency regulation power output after Indicates the secondary frequency regulation reserve capacity of synchronous generator g during period t Indicates the secondary frequency regulation reserve capacity of the electrolyzer at hydrogen refueling station s during period t Indicates the secondary frequency regulation reserve capacity of the fuel cell at hydrogen refueling station s during period t Indicates the secondary frequency regulation response time of the synchronous generator Indicates the secondary frequency regulation response time of the hydrogen refueling station

[0155] 1.4) Construct the power system swing equation, i.e.:

[0156]

[0157] In the formula, N G Indicates the set of synchronous generators; N S Indicates the set of hydrogen refueling stations; H G,t Is the moment of inertia of the synchronous generator; Is the virtual inertia of the hydrogen refueling station during period t; ΔP d Is the system power deficit; PFR(t) is the system frequency regulation output power;

[0158] 1.5) Construct frequency security constraints considering the frequency response ability of hydrogen refueling stations through the system swing equation.

[0159] Example 3:

[0160] A method for pricing inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation ability of hydrogen refueling stations. The technical content is the same as any one of Examples 1-2. Further, the frequency security constraints considering the frequency response ability of hydrogen refueling stations include RoCoF, frequency minimum point constraint, frequency quasi-steady state constraint, and frequency steady state constraint.

[0161] Example 4:

[0162] A method for pricing inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation ability of hydrogen refueling stations. The technical content is the same as any one of Examples 1-3. Further, the RoCoF constraint is as follows:

[0163]

[0164] In the formula, Is the rated power of synchronous generator g; H g Is the inertia time constant of synchronous generator g; u g,t Is the operating state of synchronous generator g during period t, 1 indicates the operating state, and 0 indicates the shutdown state; RoCoF maxis the upper limit of the rate of change of frequency; RoCoF is the rate of change of frequency;

[0165] The frequency minimum point constraint is as follows:

[0166]

[0167] In the formula, Δf max is the maximum frequency deviation; H t is the total system inertia, H t = H G,t + H VIS,t ; is the total primary frequency regulation output of the synchronous generator, is the total primary frequency regulation output of the hydrogen refueling station;

[0168]

[0169] The frequency quasi-steady state constraint is as follows:

[0170]

[0171] The frequency steady state constraint is as follows:

[0172]

[0173]

[0174] In the formula, K is the unit regulation power of the power system; Δf ss is the steady state frequency deviation of the system; is the total secondary frequency regulation output of the synchronous generator, is the total secondary frequency regulation output of the hydrogen refueling station; Δf lim is the upper limit of the steady state frequency deviation of the system;

[0175] Among them, the total secondary frequency regulation output of the synchronous generator The total secondary frequency regulation output of the hydrogen refueling station is as follows

[0176]

[0177] Example 5:

[0178] An inertia, primary frequency regulation, and secondary frequency regulation pricing method considering the frequency regulation ability of a hydrogen refueling station, the technical content is the same as any one of Examples 1-4. Further, in step 2), the steps of establishing a frequency regulation ancillary service pricing model considering the frequency response ability of the hydrogen refueling station include:

[0179] 2.1) Convert the frequency minimum point constraint into the standard second-order cone formula form, that is:

[0180]

[0181] 2.2) Simplify the standard second-order cone formula form to obtain:

[0182]

[0183] where μ is the dual variable; λ 1 and λ 2 are dual variables;

[0184] 2.3) Construct the Lagrangian function L of the pricing model that includes RoCoF constraints, frequency quasi-steady-state constraints, frequency lowest point constraints, and frequency steady-state constraints FR , that is:

[0185]

[0186] where λ RoCoF is the dual variable of the RoCoF constraint; λ qss is the dual variable of the frequency quasi-steady-state constraint; λ ss is the dual variable of the frequency steady-state constraint;

[0187] 2.4) According to the KKT conditions of the gradient of the Lagrangian function, derive the shadow prices of different frequency regulation ancillary services, including the virtual inertia H VIS,t provided by the hydrogen refueling station and the inertia H G,t price provided by the synchronous generator, the primary frequency regulation P PFRS,t price provided by the hydrogen refueling station, the primary frequency regulation P PFRG,t price provided by the synchronous generator, and the secondary frequency regulation P SFRS,t price provided by the hydrogen refueling station and the synchronous generator;

[0188] 2.5) Calculate the output of renewable energy and the output of synchronous generators;

[0189] Among them, the output of renewable energy is as follows:

[0190]

[0191] where r represents the renewable energy power station; N R represents the set of renewable energy power stations; N T represents the set of day-ahead scheduling periods; represents the output error of renewable energy; represents the predicted value of renewable energy generation; represents the output of renewable energy;

[0192] The output of synchronous generators is as follows:

[0193]

[0194] In the formula, P g,t represents the standard power output of the synchronous generator g at time t; α g,t represents the regulation factor of the synchronous generator g at time t; is the total error of the renewable energy output; represents the power generation prediction value of the synchronous generator g at time t;

[0195] The regulation factor α g,t and the total error of the renewable energy output are as follows:

[0196]

[0197] In the formula, I T represents a coefficient vector with elements all being 1; is the output error vector of the renewable energy power station, R represents the number of renewable energy power stations;

[0198] 2.6) Based on the shadow prices of different frequency regulation ancillary services, the renewable energy output, and the synchronous generator output, construct a frequency regulation ancillary service pricing model considering the frequency response ability of the hydrogen refueling station.

[0199] Example 6:

[0200] A method for pricing inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation ability of the hydrogen refueling station, the technical content is the same as any one of Examples 1 - 5. Further, the virtual inertia H VIS,t provided by the hydrogen refueling station and the inertia H G,t provided by the synchronous generator are as follows:

[0201]

[0202] The primary frequency regulation P PFRS,t provided by the hydrogen refueling station is as follows:

[0203]

[0204] The primary frequency regulation P PFRG,t provided by the synchronous generator is as follows:

[0205]

[0206] The secondary frequency regulation P SFRS,t provided by the hydrogen refueling station and the synchronous generator is as follows:

[0207]

[0208] Example 7:

[0209] A method for pricing inertia, primary frequency regulation, and secondary frequency regulation considering the frequency modulation capacity of hydrogen refueling stations. The technical content is the same as any one of Embodiments 1-6. Further, the objective function of the frequency modulation auxiliary service pricing model considering the frequency response capacity of hydrogen refueling stations is as follows:

[0210] min C=C G +C st +C re +C cur +C shed +C ad (31)

[0211]

[0212] In the formula, N D represents the set of buses; and respectively represent the upward regulation reserve capacity and downward regulation reserve capacity of unit g at time t; a g , b g and c g are respectively the operating cost coefficients of synchronous generators; and are respectively the start-up cost and shut-down cost of synchronous generators; represents the start-up state of unit g at time t, 1 means start-up, 0 means no start-up; represents the outage state of unit g at time t, 1 means outage, 0 means no outage; and respectively represent the upward regulation reserve capacity cost and downward regulation reserve capacity cost of synchronous generator g; represents the regulation cost of synchronous generator g; represents the primary frequency regulation cost coefficient of unit g; represents the secondary frequency regulation cost coefficient of unit g; represents the virtual inertia cost coefficient of hydrogen refueling station s; represents the primary frequency regulation cost coefficient of hydrogen refueling station s; represents the secondary frequency regulation cost coefficient of hydrogen refueling station s; C is the total cost of system operation; C G 、C st 、C re 、C PFRg 、C SFRg 、C ad 、C VIs 、C PFRs 、C SFRgFor the power generation cost of a synchronous generator, the start-stop cost of a synchronous generator, the reserve capacity cost of a synchronous generator, the primary frequency regulation cost of a synchronous generator, the secondary frequency regulation cost of a synchronous generator, the adjustment cost for the uncertainty of renewable energy output, the virtual inertia response cost of a hydrogen refueling station, the primary frequency regulation cost of a hydrogen refueling station, and the secondary frequency regulation cost of a hydrogen refueling station.

[0213] Example 8:

[0214] A pricing method for inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation ability of a hydrogen refueling station. The technical content is the same as any one of Examples 1-7. Further, the constraint conditions of the frequency regulation ancillary service pricing model considering the frequency response ability of a hydrogen refueling station include the primary frequency regulation reserve capacity constraints of electrolyzers and fuel cells in the hydrogen refueling station, the hydrogen flow equation, the secondary frequency regulation reserve capacity constraints of electrolyzers and fuel cells in the hydrogen refueling station, the operating power constraints of electrolyzers, the operating power constraints of fuel cells, the power generation power equation of fuel cells, the operating power constraints of fuel cells, the hydrogen storage capacity constraints of hydrogen storage tanks in the hydrogen refueling station, the hydrogen production constraints of the hydrogen refueling station, the operating constraints of synchronous generators, the minimum start-stop time constraints of synchronous generators, the ramp constraints of synchronous generators, the reserve capacity constraints of synchronous generators, the regulation reserve capacity constraints of synchronous generators, the primary and secondary frequency regulation reserve capacity constraints of synchronous generators, the power balance constraints of the power system, the power constraints of transmission lines, and the frequency security constraint content considering the frequency response ability of the hydrogen refueling station.

[0215] Example 9:

[0216] A pricing method for inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation ability of a hydrogen refueling station. The technical content is the same as any one of Examples 1-8. Further, the primary frequency regulation reserve capacity constraints of electrolyzers and fuel cells in the hydrogen refueling station are as follows:

[0217]

[0218] In the formula, is the maximum proportion of primary frequency regulation capacity provided by hydrogen refueling station s;

[0219] The secondary frequency regulation reserve capacity constraints of electrolyzers and fuel cells in the hydrogen refueling station are as follows:

[0220]

[0221] In the formula, is the maximum proportion of secondary frequency regulation capacity provided by hydrogen refueling station s;

[0222] The hydrogen flow equation generated by electrolyzers in the hydrogen refueling station is as follows:

[0223]

[0224] In the formula, N Es,tis the hydrogen production of the electrolyzer at the hydrogen refueling station s during period t; P Es,t represents the operating power of the electrolyzer at the hydrogen refueling station s during period t; η E is the electro-hydrogen energy conversion efficiency of the electrolyzer at the hydrogen refueling station s; HHV H is the high heating value coefficient of hydrogen;

[0225] The operating power constraint of the electrolyzer is as follows:

[0226]

[0227] In the formula, P E,mins represents the minimum operating power of the electrolyzer at the hydrogen refueling station s during period t; P E,maxs represents the maximum operating power of the electrolyzer at the hydrogen refueling station s during period t;

[0228] The power generation equation of the fuel cell is as follows:

[0229]

[0230] In the formula, N Fs,t is the hydrogen consumption of the fuel cell at the hydrogen refueling station s during period t; P Fs,t represents the power generation of the fuel cell at the hydrogen refueling station s during period t; η F is the power generation efficiency of the fuel cell at the hydrogen refueling station s;

[0231] The operating power constraint of the fuel cell is as follows:

[0232]

[0233] In the formula, P F,mins represents the minimum operating power of the fuel cell at the hydrogen refueling station s during period t; P F,maxs represents the maximum operating power of the fuel cell at the hydrogen refueling station s during period t;

[0234] The hydrogen storage constraint in the hydrogen refueling station is as follows:

[0235]

[0236] In the formula, SoH s,t-1 represents the hydrogen storage of the hydrogen storage tank during period t-1; η in and η out are the input and output efficiencies of hydrogen in the hydrogen storage tank respectively; Δt represents the system scheduling time granularity; represents the minimum hydrogen storage of the hydrogen storage tank; SoH maxs represents the maximum hydrogen storage of the hydrogen storage tank;

[0237] The hydrogen production constraint of the hydrogen refueling station is as follows:

[0238]

[0239] Wherein, N Ht is the hydrogen demand during period t;

[0240] The operating constraints of the synchronous generator are as follows:

[0241]

[0242] The minimum start-stop time constraint of the synchronous generator is as follows:

[0243]

[0244] Wherein, T onfg represents the minimum on-time of unit g; T offg represents the minimum off-time of unit g;

[0245] The ramping constraint of the synchronous generator is as follows:

[0246]

[0247] Wherein, RU g and RD g respectively represent the upward and downward ramp limits of synchronous generator g;

[0248] The reserve capacity constraint of the synchronous generator is as follows:

[0249]

[0250] Wherein, P maxg and P ming respectively represent the maximum power limit and the minimum power limit of synchronous generator g.

[0251] The regulation reserve capacity constraint of the synchronous generator is as follows:

[0252]

[0253] The primary frequency regulation and secondary frequency regulation reserve capacity constraints of the synchronous generator are as follows:

[0254]

[0255] Wherein, δ PFRg is the maximum proportion of the primary frequency regulation capacity provided by synchronous generator g; δ SFRg is the maximum proportion of the secondary frequency regulation capacity provided by synchronous generator g.

[0256] The power balance constraint of the power system is as follows:

[0257]

[0258] Wherein, Pd,t Indicates the grid-connected load of bus d during time period t.

[0259] The power constraints of the transmission line are as follows:

[0260]

[0261] In the formula, N l Indicates the set of lines; κ l,g Indicates the power flow transfer factor of synchronous generator g on line l; κ l,s Indicates the power flow transfer factor on line l; κ l,d Indicates the power flow transfer factor of load d on line l; F maxl Indicates the power constraint on transmission line l.

[0262] Example 10:

[0263] A method for pricing inertia, primary frequency modulation, and secondary frequency modulation considering the frequency modulation capacity of hydrogen refueling stations. The technical content is the same as any one of Examples 1-9. Further, in step 3), the steps for solving the frequency modulation ancillary service pricing model considering the frequency response capacity of hydrogen refueling stations include:

[0264] 3.1) Define the CVaR-Wasserstein metric That is:

[0265]

[0266] In the formula, ∏ is the joint distribution composed of the random variable ζ 1 belonging to the probability distribution and ζ 2 belonging to the probability distribution ; d(ζ 1 -ζ 2 ) = ||ζ 1 -ζ 2 || is the distance between the random variables ζ 1 and ζ 2 defined by the vector norm, represents the set of all probability distributions with the support set Ξ; the support set of the random variable ζ and are the sample mean and sample covariance, σ max is the sample coefficient; represents the minimum cost required to transfer the probability mass from to ;

[0267] 3.2) Determine the empirical distribution of the renewable energy output error based on the N-sample historical data of the uncertainty variable ​ is a random variable Dirac distribution of;

[0268] 3.3) Construct a fuzzy set using the CVaR-Wasserstein ball, i.e.:

[0269]

[0270] In the formula, ε is the radius of the CVaR-Wasserstein ball;

[0271] 3.4) Calculate the worst-case expected cost That is:

[0272]

[0273]

[0274] In the formula, ||·|| * is the dual norm of ||·||; and ||e|| 1 = 1; is the fuzzy set constructed by the type-∞ Wasserstein metric; is the classical type-1 Wasserstein fuzzy set; is the loss function; 1-α is the scaling ratio of the radius ε of the fuzzy set;

[0275] 3.5) Reconstruct the worst-case expected cost to obtain the reconstructed worst-case expected cost model, i.e.:

[0276] min C = C de + z

[0277]

[0278] In the formula: z is the auxiliary variable; C de is the sum of the costs other than the expected cost in the worst distribution case.

[0279] 3.6) Solve the reconstructed worst-case expected cost model to obtain the pricing scheme for the frequency regulation ancillary services of the power system.

[0280] Example 11:

[0281] A pricing method for inertia, primary frequency regulation, and secondary frequency regulation considering the frequency regulation capacity of hydrogen refueling stations, including the following steps:

[0282] 1) Study the frequency security constraints considering the frequency response capacity of hydrogen refueling stations;

[0283] 2) Study the pricing model of frequency regulation ancillary services considering the frequency response ability of hydrogen refueling stations;

[0284] 3) Study the solution algorithm for the pricing method of frequency regulation ancillary services in power systems.

[0285] The main steps to establish the frequency security constraints considering the frequency response ability of hydrogen refueling stations are as follows:

[0286] In the virtual inertia response stage, the hydrogen refueling station quickly changes the operating power of the electrolyzer and the hydrogen fuel cell according to the system frequency change rate dΔf(t) / dt signal to provide inertia support to the system, as shown in the following formula:

[0287]

[0288] In the formula, is the virtual inertia response power (MW) of the hydrogen refueling station; H E is the virtual inertia time constant (s) of the electrolyzer in the hydrogen refueling station; H F is the virtual inertia time constant (s) of the hydrogen fuel cell in the hydrogen refueling station; P E,maxs represents the maximum operating power (MW) of the electrolyzer of hydrogen refueling station s; P F,maxs represents the maximum operating power (MW) of the hydrogen fuel cell of hydrogen refueling station s; u s,t represents the operating state of hydrogen refueling station s at time t (1 means operating, 0 means shutdown); f 0 is the rated grid frequency of 50 Hz; Δf(t) is the system frequency deviation (Hz).

[0289] In the primary frequency regulation stage, the frequency regulation power output of the hydrogen refueling station increases linearly with time. Different from the primary frequency regulation response of synchronous generators, the primary frequency regulation response time of the hydrogen refueling station is extremely short and can quickly adjust the power within 1 second. Considering the difference in the frequency response speed between the hydrogen refueling station and the synchronous generator, the primary frequency regulation response models of the hydrogen refueling station and the synchronous generator are shown in the following formulas respectively

[0290]

[0291]

[0292] In the formula, t r represents the frequency fluctuation time after the power deficit event occurs; ΔP PFRs,t,tr represents the primary frequency regulation power output of hydrogen refueling station s at time t after the frequency disturbance at time t r seconds; ΔP PFRg,t,tr represents the primary frequency regulation power output of synchronous generator g at time t after the frequency disturbance at time t r seconds; R PFRg,t represents the primary frequency regulation reserve capacity of synchronous generator g at time t; RE,PFRs,t Denote the primary frequency regulation reserve capacity of the electrolyzer at hydrogen refueling station s during period t; R F,PFRs,t Denote the primary frequency regulation reserve capacity of the fuel cell at hydrogen refueling station s during period t; t DB,h Denote the time when the frequency deviation reaches the frequency regulation dead zone during the frequency response process of the hydrogen refueling station; t DB,g Denote the time when the frequency deviation reaches the frequency regulation dead zone during the frequency response process of the synchronous generator; T PFRg Denote the primary frequency regulation response time of the synchronous generator; T PFRh Denote the primary frequency regulation response time of the hydrogen refueling station.

[0293] During the secondary frequency regulation stage, the frequency regulation power output of the hydrogen refueling station increases linearly with time, as follows:

[0294]

[0295] In the formula, t ss Denote the time when the frequency reaches the quasi-steady state; ΔP SFRs,t,tr Denote the frequency disturbance during period t r Seconds later, the secondary frequency regulation power output of hydrogen refueling station s; ΔP SFRg,t,tr Denote the frequency disturbance during period t r Seconds later, the secondary frequency regulation power output of synchronous generator g; R SFRg,t Denote the secondary frequency regulation reserve capacity of synchronous generator g during period t; R E,SFRs,t Denote the secondary frequency regulation reserve capacity of the electrolyzer at hydrogen refueling station s during period t; R F,SFRs,t Denote the secondary frequency regulation reserve capacity of the fuel cell at hydrogen refueling station s during period t; T SFRg Denote the secondary frequency regulation response time of the synchronous generator; T SFRh Denote the secondary frequency regulation response time of the hydrogen refueling station.

[0296] After the system power deficit disturbance occurs, the system frequency security constraint can be derived and determined from the swing equation describing the dynamic change of the power system frequency. The swing equation of the power system can be expressed as:

[0297]

[0298] In the formula, N G Denote the set of synchronous generators; N S Denote the set of hydrogen refueling stations; H G,t Is the moment of inertia of the synchronous generator; H VIS,t Is the virtual inertia of the hydrogen refueling station during period t; ΔP d Is the system power deficit (MW). Neglect the load damping response of the system.

[0299] Construct the RoCoF, frequency lowest point constraint, frequency quasi-steady state constraint, and frequency steady state constraint through the system swing equation, and map the above constraints into the system scheduling model to meet the frequency security requirements of the power system. The derivation process of the above system frequency security constraints is as follows.

[0300] 1) RoCoF constraint: At the moment when the power deficit occurs, that is, at time t r = 0, Δf(t r ) = 0, and the RoCoF is the largest. From the above formula, the RoCoF constraint can be derived as:

[0301]

[0302]

[0303] In the formula, is the rated power of synchronous generator g; H g is the inertia time constant of synchronous generator g; u g,t is the operating state of synchronous generator g in time period t, (1 represents the operating state, 0 represents the shutdown state).

[0304] 2) Frequency lowest point constraint: The frequency modulation power response speed of the hydrogen refueling station is much faster than that of the synchronous generator. When the synchronous generator enters the primary frequency modulation stage, the hydrogen refueling station has completed the frequency modulation power adjustment. At this time, the system frequency modulation output power can be expressed as:

[0305]

[0306] Based on the capacity limit of the hydrogen refueling station, after the frequency response of the hydrogen refueling station ends, the frequency continues to decrease until the frequency reaches the lowest point at time t r = t*, dΔf(t * ) / dt = 0. By solving the above formula, the expression of the frequency lowest point can be obtained. To meet the frequency security requirements of the system, the frequency lowest point shall not exceed the maximum frequency deviation Δf max , so the frequency lowest point constraint is expressed as:

[0307]

[0308] In the formula, H t is the total system inertia, H t = H G,t + H VIS,t ; P PFRG,t is the total primary frequency modulation output of synchronous generators, and P PFRS,t is the total primary frequency modulation output of the hydrogen refueling station, which can be calculated by the following formulas respectively:

[0309]

[0310] Rearranging the above equation, the lowest frequency point constraint can be reformulated in the following second-order cone formula form:

[0311]

[0312] 3) Frequency quasi-steady state constraint: To ensure that the system frequency does not continue to drop, the primary frequency regulation response power of the hydrogen refueling station and the synchronous generator should be able to stabilize the frequency at a level relative to the normal operating level. At this time, the frequency quasi-steady state constraint can be expressed as:

[0313]

[0314] 4) Frequency steady state constraint: After the system frequency reaches the quasi-steady state, secondary frequency regulation starts to act, and the hydrogen refueling station and the synchronous generator jointly provide secondary frequency regulation services. At the end of secondary frequency regulation, the following power balance relationship is satisfied between the system frequency regulation response power and the frequency deviation:

[0315]

[0316] In the formula, K is the unit regulation power of the power system; Δf ss is the steady-state frequency deviation of the system; P SFRG,t is the total output of secondary frequency regulation of the synchronous generator, and P SFRS,t is the total output of secondary frequency regulation of the hydrogen refueling station, which can be calculated by the following formulas respectively:

[0317]

[0318] To ensure that the system frequency returns to the standard operating state, at the end of secondary frequency regulation, the system frequency steady state constraint can be expressed as:

[0319]

[0320] In the formula, Δf lim is the allowable deviation of the system frequency during normal operation.

[0321] The main steps to establish a pricing model for frequency regulation ancillary services considering the frequency response ability of hydrogen refueling stations are as follows:

[0322] The shadow price of frequency regulation ancillary services is determined by the Karush-Kuhn-Tucker (KKT) conditions of the frequency security constraint model. The dual variable of the RoCoF constraint is λ RoCoF , the dual variable of the frequency quasi-steady state constraint is λ qss , and the dual variable of the frequency steady state constraint is λ ss . The lowest frequency point constraint is non-linear, and it is converted into the standard second-order cone formula form:

[0323]

[0324] The dual variables of the first and second rows on the left side of the second-order cone formula are λ 1 and λ 2 , and the dual variable on the right side is μ, which should satisfy the following constraints:

[0325]

[0326] The Lagrangian function of the pricing model including RoCoF constraints, frequency quasi-steady-state constraints, frequency nadir constraints, and frequency steady-state constraints should include the following options:

[0327]

[0328] According to the KKT conditions of the gradient of the Lagrangian function, the shadow prices of different frequency regulation ancillary services can be derived. The frequency regulation ancillary service prices considering the frequency support of hydrogen refueling stations are as follows:

[0329] 1) The virtual inertia H provided by the hydrogen refueling station VIS,t and the inertia H provided by the synchronous generator G,t Price:

[0330]

[0331] 2) The primary frequency regulation P provided by the hydrogen refueling station PFRS,t Price:

[0332]

[0333] 3) The primary frequency regulation P provided by the synchronous generator PFRG,t Price:

[0334]

[0335] 4) The secondary frequency regulation P provided by the hydrogen refueling station and the synchronous generator SFRS,t Price:

[0336]

[0337] Renewable energy: The output of renewable energy is a random variable determined jointly by the predicted value P fr,t of renewable energy power generation and the output error of renewable energy

[0338]

[0339] where r represents the renewable energy power station; N R represents the set of renewable energy power stations; N T represents the set of day-ahead scheduling periods.

[0340] ​Total error of renewable energy output in the power system It is the sum of the output errors of each renewable energy power station and is expressed by the following formula

[0341]

[0342] In the formula, I T represents a coefficient vector with elements of 1; is the output error vector of the renewable energy power station,

[0343] R represents the number of renewable energy power stations.

[0344] Synchronous generator: The synchronous generator adopts an affine strategy to adjust its output to make up for the error caused by the uncertainty of renewable energy output. The actual output of the synchronous generator is an affine function of the renewable energy output error and can be expressed as:

[0345]

[0346] In the formula, P g,t represents the standard power output of synchronous generator g at time t; α g,t represents the regulation factor of synchronous generator g at time t, which is affected by the operating state of the synchronous generator:

[0347]

[0348] The objective function of the pricing model is to minimize the total cost C of system operation, including the power generation cost C G of the synchronous generator, the start-stop cost C st of the synchronous generator, the reserve capacity cost C re of the synchronous generator, the primary frequency regulation cost C PFRg of the synchronous generator, the secondary frequency regulation cost C SFRg of the synchronous generator, the adjustment cost C ad for the uncertainty of renewable energy output, the virtual inertia response cost C VIs of the hydrogen refueling station, the primary frequency regulation cost C PFRs of the hydrogen refueling station, and the secondary frequency regulation cost C SFRg of the hydrogen refueling station are respectively as follows:

[0349] min C = C G + C st + C re + C cur + C shed + C ad (33)

[0350]

[0351]

[0352] In the formula, N D represents the set of busbars; r upg,t and r dng,t respectively represent the upper regulation reserve capacity and the lower regulation reserve capacity of unit g in period t; a g , b g and c g are respectively the operating cost coefficients of the synchronous generator; λ sug and λ sdg are respectively the start-up cost and the shut-down cost of the synchronous generator; z sug,t represents the start-up state of unit g in period t (1 means start-up, 0 means no start-up); z sdg,t represents the outage state of unit g in period t (1 means outage, 0 means no outage); d upg and d dng respectively represent the upper regulation reserve capacity cost and the lower regulation reserve capacity cost of synchronous generator g; d adg represents the regulation cost of synchronous generator g; c PFRg represents the primary frequency regulation cost coefficient of unit g; c SFRg represents the secondary frequency regulation cost coefficient of unit g; c VIs represents the virtual inertia cost coefficient of hydrogen refueling station s; c PFRs represents the primary frequency regulation cost coefficient of hydrogen refueling station s; c SFRs represents the secondary frequency regulation cost coefficient of hydrogen refueling station s.

[0353] (1) Hydrogen refueling station operation model: The hydrogen refueling station provides primary and secondary frequency regulation services to the power system by changing the operating power of the electrolyzers and fuel cells in the station. The primary frequency regulation reserve capacity limits of the electrolyzers and fuel cells in the hydrogen refueling station are as follows:

[0354]

[0355] In the formula, δ PFRs is the maximum proportion of the primary frequency regulation capacity provided by hydrogen refueling station s.

[0356] The secondary frequency regulation reserve capacity limits of the electrolyzers and fuel cells in the hydrogen refueling station are as follows:

[0357]

[0358] In the formula, δ SFRs is the maximum proportion of the secondary frequency regulation capacity provided by hydrogen refueling station s.

[0359] The electrolyzers in the hydrogen refueling station use renewable energy to generate hydrogen, and the hydrogen flow rate is as follows:

[0360]

[0361] In the formula, N Es,t is the hydrogen production of the electrolyzer in hydrogen refueling station s during period t (kg / h); P Es,t represents the operating power of the electrolyzer in hydrogen refueling station s during period t (MW); η E is the electro-hydrogen energy conversion efficiency of the electrolyzer in hydrogen refueling station s; HHV H is the high heating value coefficient of hydrogen (39.4 kWh / kg, equivalent to 0.0035 kWh / L).

[0362] The operating power of the electrolyzer is limited by its operating range:

[0363]

[0364] In the formula, P E,mins represents the minimum operating power of the electrolyzer in hydrogen refueling station s during period t (MW); P E,maxs represents the maximum operating power of the electrolyzer in hydrogen refueling station s during period t (MW).

[0365] In the hydrogen refueling station, the fuel cell consumes hydrogen to generate electricity, and the operation model is as follows:

[0366]

[0367] In the formula, N Fs,t is the hydrogen consumption of the fuel cell in hydrogen refueling station s during period t (kg / h); P Fs,t represents the power generation power of the fuel cell in hydrogen refueling station s during period t (MW); η F is the power generation efficiency of the fuel cell in hydrogen refueling station s.

[0368] The operating power of the fuel cell is limited by its operating range:

[0369]

[0370] In the formula, P F,mins represents the minimum operating power of the fuel cell in hydrogen refueling station s during period t (MW); P F,maxs represents the maximum operating power of the fuel cell in hydrogen refueling station s during period t (MW).

[0371] The hydrogen storage tank in the hydrogen refueling station is a physical device for hydrogen storage and does not involve the process of energy form conversion. The hydrogen storage volume SoH of the hydrogen storage tank during period t s,t should satisfy the following constraints:

[0372]

[0373] In the formula, SoH s,t-1 represents the hydrogen storage volume of the hydrogen storage tank during period t-1 (kg); η in, η out The efficiency of hydrogen input and output of the hydrogen storage tank respectively; Δt represents the system scheduling time granularity (h); represents the minimum hydrogen storage of the hydrogen storage tank (kg); SoH maxs represents the maximum hydrogen storage of the hydrogen storage tank (kg).

[0374] The hydrogen produced by the hydrogen refueling station should meet the hydrogen demand of the hydrogen fuel cell vehicle:

[0375]

[0376] In the formula, N Ht is the hydrogen demand at time period t (kg / h).

[0377] (2) Synchronous generator operation constraints: The relationship between the operating state and start-stop state of the synchronous generator:

[0378]

[0379] Minimum start-stop time limit of the synchronous generator:

[0380]

[0381] In the formula, T onfg represents the minimum start-up time of unit g; T offg represents the minimum shutdown time of unit g.

[0382] Synchronous generator ramp constraint:

[0383]

[0384] In the formula, RU g and RD g represent the upward and downward ramp limits of synchronous generator g respectively.

[0385] Synchronous generator reserve capacity constraint:

[0386]

[0387] In the formula, P maxg and P ming represent the maximum power limit and minimum power limit of synchronous generator g respectively.

[0388] Synchronous generator regulation reserve capacity constraint:

[0389]

[0390] Primary frequency regulation and secondary frequency regulation reserve capacity constraints of the synchronous generator:

[0391]

[0392] In the formula, δ PFRg is the maximum proportion of primary frequency regulation capacity provided by the synchronous generator g; δ SFRg is the maximum proportion of secondary frequency regulation capacity provided by the synchronous generator g.

[0393] (3) Power balance and network constraints:

[0394] Power balance constraint of the power system:

[0395]

[0396] In the formula, P d,t represents the grid-connected load of bus d at time period t.

[0397] Power constraint of the transmission line:

[0398]

[0399] In the formula, N l represents the set of lines; κ l,g represents the power flow transfer factor of the synchronous generator g on line l; κ l,s represents the power flow transfer factor on line l; κ l,d represents the power flow transfer factor of load d on line l; F maxl represents the power constraint on transmission line l.

[0400] (4) Frequency security constraint

[0401] Combined with the frequency security constraint content considering the frequency response ability of the hydrogen refueling station, the RoCoF constraint, the minimum frequency point constraint, the quasi-steady state constraint of the system frequency, and the steady state constraint of the system frequency are incorporated into the pricing model.

[0402] The main steps of the solution algorithm for the pricing method of frequency modulation ancillary services in the power system are as follows:

[0403] CVaR-Wasserstein metric is defined as:

[0404]

[0405] In the formula, CVaR α is a consistent risk measurement method based on conditional value at risk; Π is the joint distribution composed of the random variable ζ 1 belonging to the probability distribution and ζ 2 belonging to the probability distribution ; d(ζ 1 -ζ 2 ) = ||ζ 1 -ζ2 || is a random variable ζ defined by the vector norm 1 and ζ 2 the distance between denotes the set of all probability distributions with support set Ξ; the support set of the random variable ζ where and are the sample mean and sample covariance, σ max is the sample coefficient; denotes the minimum cost required to move the probability mass from to

[0406] Considering the data-driven characteristics of the CVaR-Wasserstein metric, based on the N-sample historical data of the uncertainty variable (here the sample historical data is a vector denotes starting from the time dimension, is a 1*24 vector, 24 represents 24 hours a day. If the time dimension is not considered, the sample historical data is a scalar at a single moment) can determine the empirical distribution of the renewable energy output error where is the Dirac distribution of the random variable The CVaR-Wasserstein ball is used to construct a fuzzy set, that is, the empirical distribution of the random variable and the true distribution the distance between is less than the ball radius ε:

[0407]

[0408] The maximum value of the expected cost in the worst-case distribution is reconstructed into a tractable form, and the loss function satisfies the worst-case expected cost is equivalent to the following formula:

[0409]

[0410] where

[0411]

[0412] where ||·|| * is the dual norm of ||·||; and ||e|| 1 = 1; is the fuzzy set constructed by the type-∞ Wasserstein metric; ​is a classical type-1 Wasserstein fuzzy set, and the radius ε of the fuzzy set is scaled in proportion to (1-α).

[0413] Reconstruct and transform the above formula into

[0414] min C = C de +z

[0415]

[0416] In the formula: z is an auxiliary variable; C de is the sum of the costs other than the expected cost in the worst distribution case.

[0417] Example 12:

[0418] Verification of a pricing method for inertia, primary frequency modulation, and secondary frequency modulation considering the frequency modulation ability of hydrogen refueling stations, the main steps are as follows:

[0419] To verify the correctness of the pricing method for inertia, primary frequency modulation, and secondary frequency modulation considering the frequency modulation ability of hydrogen refueling stations proposed in the present invention, an improved IEEE-118 test system is used for simulation analysis. The relevant parameters of the simulation model are shown in Table 1.

[0420] Table 1 Simulation parameters

[0421]

[0422] To verify the effectiveness of the pricing method for inertia, primary frequency modulation, and secondary frequency modulation considering the frequency modulation ability of hydrogen refueling stations proposed in the present invention, the following comparison scenarios are set:

[0423] Scenario 1: A pricing method for inertia, primary frequency modulation, and secondary frequency modulation where only synchronous generators provide frequency modulation auxiliary services;

[0424] Scenario 2: A pricing method for inertia, primary frequency modulation, and secondary frequency modulation where both synchronous generators and hydrogen refueling stations provide frequency modulation auxiliary services;

[0425] Scenario 3: A distributionally robust pricing method based on Type1-Wasserstein fuzzy sets where both synchronous generators and hydrogen refueling stations provide frequency modulation auxiliary services.

[0426] Figure 2(a)-(d) show the inertia, primary frequency regulation of hydrogen refueling stations, primary frequency regulation of synchronous generators, and secondary frequency regulation prices. Since the frequency response capabilities of electrolyzers and fuel cells in hydrogen refueling stations reduce the marginal cost of ancillary services, the inertia price, primary frequency regulation service price, and secondary frequency regulation service price in Scenario 2 are all lower than those in Scenario 1. Although the hydrogen refueling station in Scenario 1 does not provide primary frequency regulation, the primary frequency regulation service price of the hydrogen refueling station can be determined by Equation (20), and this price is higher than that in Scenario 2. This indicates that hydrogen refueling stations have great motivation to provide frequency regulation ancillary services. Due to the faster frequency response speed of hydrogen refueling stations and the greater contribution of frequency response capabilities to frequency regulation, the primary frequency regulation service price provided by hydrogen refueling stations in Scenario 2 is higher than the primary frequency regulation service price of synchronous generators.

[0427] Figure 3 (a)-(b) show the cleared capacities of primary frequency regulation and secondary frequency regulation of hydrogen refueling stations and synchronous generators. Figure 3 As can be seen from (a), the cleared capacity of primary frequency regulation of synchronous generators in Scenario 1 is greater than the sum of the cleared capacities of primary frequency regulation of hydrogen refueling stations and synchronous generators in Scenario 2. Since the primary frequency regulation response time of hydrogen refueling stations is faster and the suppression effect on system frequency fluctuations is better, Scenario 2 can meet the system frequency minimum point and quasi-steady state frequency safety requirements with a smaller cleared capacity of primary frequency regulation. Figure 3 As can be seen from (b), the cleared capacity of secondary frequency regulation of synchronous generators in Scenario 1 is equal to the sum of the cleared capacities of secondary frequency regulation of hydrogen refueling stations and synchronous generators in Scenario 2. The grid AGC dispatching center can dispatch hydrogen refueling stations or synchronous generators without discrimination to meet the secondary frequency regulation requirements. During the period from 10 to 24, since the hydrogen refueling stations in Scenario 2 provide all the cleared capacities of secondary frequency regulation, it leads to Figure 2 the cleared price of secondary frequency regulation response in Scenario 2 in (d) is lower than that in Scenario 1.

[0428] Table 2 Comparative analysis of frequency regulation benefits (10 3 $)

[0429]

[0430] Table 2 compares the frequency regulation ancillary service revenues, costs, and profits of synchronous generators and hydrogen refueling stations under two scenarios, including inertia response, primary frequency regulation, and secondary frequency regulation response services. Compared with S1, the total frequency regulation ancillary service cost of synchronous generators and hydrogen refueling stations in S2 is reduced by 71.61%. The hydrogen refueling station obtains an economic benefit of $20,140 by providing frequency regulation ancillary services to the power system, and the profit rate reaches 15.51%. This indicates that hydrogen refueling stations can obtain economic profits by providing frequency regulation ancillary services to the power system, improve their own operating revenues, and are conducive to the large-scale promotion of hydrogen energy.

[0431] Table 3 Frequency regulation benefit analysis of different distributionally robust pricing methods (10 3 $)

[0432]

[0433] To demonstrate the effectiveness of the distributionally robust optimization method proposed in the present invention, Table 3 compares the frequency regulation revenues of different types of distributionally robust pricing methods. The total frequency regulation ancillary service cost of synchronous generators and hydrogen refueling stations in Scenario 3 is higher than that in Scenario 2. On the other hand, the frequency regulation ancillary service profits of synchronous generators and hydrogen refueling stations in Scenario 2 are both higher than those in Scenario 3. This shows that the fuzzy set based on the CVaR-Wasserstein metric reduces the conservatism of the frequency regulation scheme and improves the frequency regulation ancillary service revenue.

Claims

1. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capacity of a hydrogen refueling station, characterized in that: The following steps are involved: 1) Establish frequency safety constraints that take into account the frequency response capability of hydrogen refueling stations; 2) Construct a frequency regulation ancillary service pricing model that takes into account the frequency response capability of hydrogen refueling stations; 3) Solve the frequency regulation ancillary service pricing model taking into account the frequency response capability of hydrogen refueling stations, and obtain the pricing scheme for frequency regulation ancillary services of the power system.

2. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capacity of a hydrogen refueling station according to claim 1, characterized in that: In step 1), the steps for establishing frequency security constraints considering the frequency response capability of the hydrogen refueling station are as follows: 1.1) Calculate the virtual inertia response power of the hydrogen refueling station, that is: In the formula, is the virtual inertia response power of the hydrogen refueling station; H E is the virtual inertia time constant of the electrolyzer in the hydrogen refueling station; H F is the virtual inertia time constant of the hydrogen fuel cell in the hydrogen refueling station; Indicates the maximum operating power of the electrolyzer at hydrogen refueling station s; represents the maximum operating power of the hydrogen fuel cell at the hydrogen refueling station s; u s,t represents the operating status of hydrogen refueling station s during period t, 1 represents operation, and 0 represents shutdown; f0 is the rated frequency of the power grid; Δf(t) is the system frequency deviation; 1.2) Construct the primary frequency modulation response model of the hydrogen refueling station and synchronous generator respectively, namely: Where, t r Indicates the frequency fluctuation time after the power shortage event occurs; represents the frequency disturbance t in period t r Seconds later, the hydrogen station s once modulates the power output; represents the frequency disturbance t in period t r Seconds later, the synchronous generator g outputs the primary frequency modulation power; represents the primary frequency regulation reserve capacity of synchronous generator g during period t; It represents the primary frequency regulation reserve capacity of the electrolyzer of hydrogen station s during period t; represents the primary frequency regulation reserve capacity of the fuel cell of hydrogen station s during period t; t DB,h Indicates the time when the frequency deviation reaches the frequency modulation dead zone during the frequency response process of the hydrogen station; t DB,g It indicates the time when the frequency deviation reaches the frequency regulation dead zone during the frequency response of the synchronous generator; Indicates the primary frequency modulation response time of the synchronous generator; Indicates the frequency modulation response time of a hydrogen refueling station; 1.3) Calculate the frequency modulation power of the hydrogenation station in the secondary frequency modulation stage, that is: Where, t ss Indicates the time when the frequency reaches the quasi-steady state; represents the frequency disturbance t in period t r Seconds later, the secondary frequency modulation power output of the hydrogen refueling station s; represents the frequency disturbance t in period t r Seconds later, the synchronous generator g secondary frequency modulation power output; represents the secondary frequency regulation reserve capacity of synchronous generator g during period t; It represents the secondary frequency regulation reserve capacity of the electrolyzer of hydrogen station s during period t; represents the secondary frequency regulation reserve capacity of the fuel cell of hydrogen station s during period t; Indicates the secondary frequency regulation response time of the synchronous generator; Indicates the secondary frequency modulation response time of the hydrogen refueling station; 1.4) Construct the power system swing equation, namely: Where N G represents the set of synchronous generators; N S Indicates a collection of hydrogen refueling stations; H G,t is the moment of inertia of the synchronous generator; is the virtual inertia of the hydrogen refueling station during period t; ΔP d is the system power shortage; PFR(t) is the system frequency modulation output power; 1.5) The frequency safety constraint considering the frequency response capability of the hydrogen refueling station is constructed through the system swing equation.

3. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capacity of a hydrogen refueling station according to claim 1, characterized in that: The frequency security constraints considering the frequency response capability of hydrogen refueling stations include RoCoF, frequency minimum point constraint, frequency quasi-steady-state constraint and frequency steady-state constraint.

4. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capability of a hydrogen refueling station according to claim 3, characterized in that: The RoCoF constraints are as follows: In the formula, is the rated power of the synchronous generator g; H g is the inertia time constant of the synchronous generator g; u g,t is the operating state of the synchronous generator g during period t, 1 indicates the operating state, and 0 indicates the shutdown state; RoCoF max is the upper limit of the frequency change rate; RoCoF is the frequency change rate; The frequency minimum point constraint is as follows: Where Δf max is the maximum frequency deviation; H t is the total inertia of the system, is the total primary frequency modulation output of the synchronous generator, is the total primary frequency modulation output of the hydrogen refueling station; The frequency quasi-steady-state constraints are as follows: The frequency steady-state constraints are as follows: Where K is the unit regulation power of the power system; Δf ss is the system steady-state frequency deviation; is the total output of the synchronous generator secondary frequency regulation, is the total secondary frequency modulation output of the hydrogen refueling station; Δf lim is the upper limit of the system steady-state frequency deviation; Among them, the total output of the synchronous generator secondary frequency regulation Total output of secondary frequency regulation at hydrogen refueling station As shown below 5. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capacity of a hydrogen refueling station according to claim 1, characterized in that: In step 2), the steps of establishing a frequency regulation auxiliary service pricing model taking into account the frequency response capability of the hydrogen refueling station include: 2.1) Convert the frequency minimum point constraint into the standard second-order cone formula form, that is: 2.2) Simplify the standard second-order cone formula to obtain: Where μ is the dual variable; λ1 and λ2 are the dual variables; 2.3) Construct the Lagrangian function L of the pricing model including RoCoF constraint, frequency quasi-steady-state constraint, frequency minimum point constraint and frequency steady-state constraint FR ,Right now: In the formula, λ RoCoF is the dual variable of the RoCoF constraint; qss is the dual variable of the frequency quasi-steady-state constraint; ss is the dual variable of the frequency steady-state constraint; 2.4) Based on the KKT condition of the gradient of the Lagrangian function, the shadow prices of different frequency regulation auxiliary services are derived, including the virtual inertia H provided by the hydrogen station. VIS,t and the inertia H provided by the synchronous generator G,t Price, primary frequency modulation P provided by hydrogen refueling station PFRS,t Price, primary frequency regulation provided by synchronous generator P PFRG,t Price, hydrogen refueling station and synchronous generator provide secondary frequency regulation P SFRS,t price; 2.5) Calculate the output of renewable energy and synchronous generators; The renewable energy output is as follows: Where r represents the renewable energy station; N R Represents the set of renewable energy sites; N T Represents the day-ahead scheduling period set; Represents the renewable energy output error; represents the predicted value of renewable energy power generation; Represents renewable energy output; The output of synchronous generator is as follows: Where P g,t represents the standard power output of synchronous generator g during period t; α g,t represents the regulation factor of the synchronous generator g during period t; is the total error of renewable energy output; It represents the predicted value of power generation of synchronous generator g during period t; Regulatory factor α g,t , Total error of renewable energy output As shown below: In the formula, I T represents a coefficient vector whose elements are 1; is the output error vector of renewable energy station, R represents the number of renewable energy sites; 2.6) Based on the shadow prices of different frequency regulation ancillary services and the output of renewable energy and synchronous generators, a frequency regulation ancillary service pricing model that takes into account the frequency response capability of hydrogen refueling stations is constructed.

6. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capability of a hydrogen refueling station according to claim 5, characterized in that: The virtual inertia H provided by the hydrogen refueling station VIS,t and the inertia H provided by the synchronous generator G,t The prices are as follows: The primary frequency modulation P provided by the hydrogen refueling station PFRS,t The prices are as follows: The synchronous generator provides a frequency modulation P PFRG,t The prices are as follows: Secondary frequency regulation P provided by hydrogen refueling station and synchronous generator SFRS,t The prices are as follows:

7. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capacity of a hydrogen refueling station according to claim 1, characterized in that: The objective function of the frequency regulation ancillary service pricing model taking into account the frequency response capability of hydrogen refueling stations is as follows: Where N D represents a busbar set; and They represent the upper regulation reserve capacity and lower regulation reserve capacity of unit g in period t respectively; a g ,b g and c g are the synchronous generator operation cost coefficients respectively; and are the startup cost and shutdown cost of synchronous generators, respectively; Indicates the startup status of unit g in period t, 1 indicates startup, 0 indicates non-startup; Indicates the shutdown status of unit g in time period t, 1 means shutdown, 0 means non-operation; and denote the upward regulation reserve capacity cost and downward regulation reserve capacity cost of the synchronous generator g, respectively; represents the regulation cost of the synchronous generator g; represents the primary frequency regulation cost coefficient of unit g; The secondary frequency regulation cost coefficient of unit g is shown; represents the virtual inertia cost coefficient of hydrogen refueling station s; represents the primary frequency regulation cost coefficient of hydrogen refueling station s; represents the secondary frequency regulation cost coefficient of hydrogen refueling station s; C is the total cost of system operation; C G , C st , C re , C PFRg , C SFRg , C ad , C VIs , C PFRs , C SFRg It is the power generation cost of synchronous generator, the start-up and shutdown cost of synchronous generator, the standby capacity cost of synchronous generator, the primary frequency regulation cost of synchronous generator, the secondary frequency regulation cost of synchronous generator, the adjustment cost of renewable energy output uncertainty, the virtual inertia response cost of hydrogen refueling station, the primary frequency regulation cost of hydrogen refueling station, and the secondary frequency regulation cost of hydrogen refueling station.

8. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capability of a hydrogen refueling station according to claim 1, characterized in that: The constraints of the frequency regulation auxiliary service pricing model taking into account the frequency response capability of the hydrogen refueling station include the primary frequency regulation reserve capacity constraint of the electrolyzer and fuel cell in the hydrogen refueling station, the hydrogen flow equation, the secondary frequency regulation reserve capacity constraint of the electrolyzer and fuel cell in the hydrogen refueling station, the electrolyzer operating power constraint, the fuel cell operating power constraint, the fuel cell power generation power equation, the fuel cell operating power constraint, the hydrogen storage capacity constraint of the hydrogen storage tank in the hydrogen refueling station, the hydrogen production constraint of the hydrogen refueling station, the synchronous generator operation constraint, the synchronous generator minimum start and stop time constraint, the synchronous generator climbing constraint, the synchronous generator reserve capacity constraint, the synchronous generator regulation reserve capacity constraint, the synchronous generator primary and secondary frequency regulation reserve capacity constraint, the power system power balance constraint, the transmission line power constraint, and the frequency security constraint taking into account the frequency response capability of the hydrogen refueling station.

9. A method for pricing inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capability of a hydrogen refueling station according to claim 8, characterized in that: The primary frequency regulation reserve capacity constraints of the electrolyzer and fuel cell in the hydrogen station are as follows: In the formula, Provide the maximum proportion of primary frequency regulation capacity for hydrogen refueling station s; The secondary frequency regulation reserve capacity constraints of the electrolyzer and fuel cell in the hydrogen station are as follows: In the formula, Provide the maximum proportion of secondary frequency regulation capacity for hydrogen refueling station s; The equation for the hydrogen flow rate generated by the electrolyzer in the hydrogen refueling station is as follows: Where N Es,t is the hydrogen production of the electrolyzer at hydrogen refueling station s during period t; P Es,t represents the operating power of the electrolyzer at hydrogenation station s during period t; η E The electricity-hydrogen energy conversion efficiency of the electrolyzer in the hydrogen refueling station; HHV H is the high heating value coefficient of hydrogen; The electrolyzer operating power constraints are as follows: Where P E,mins represents the minimum operating power of the electrolyzer of hydrogen station s during period t; P E,maxs represents the maximum operating power of the electrolyzer at hydrogen station s during period t; The power equation for fuel cell generation is shown below: Where N Fs,t is the hydrogen consumption of the fuel cell at hydrogen refueling station s during period t; P Fs,t represents the power generation of the fuel cell at hydrogen refueling station s during period t; η F The power generation efficiency of the fuel cell of the hydrogen refueling station; The fuel cell operating power constraints are as follows: Where P F,mins represents the minimum operating power of the fuel cell of hydrogen refueling station s during period t; P F,maxs represents the maximum operating power of the fuel cell at hydrogen station s during period t; The hydrogen storage capacity constraints of the hydrogen storage tanks in the hydrogen refueling station are as follows: In the formula, SoH s,t-1 represents the hydrogen storage capacity of the hydrogen storage tank during period t-1; η in , η out The efficiency of hydrogen input and output of the hydrogen storage tank respectively; Δt represents the granularity of system scheduling time; Indicates the minimum hydrogen storage capacity of the hydrogen storage tank; SoH maxs Indicates the maximum hydrogen storage capacity of the hydrogen storage tank; The constraints on hydrogen production at a hydrogen refueling station are as follows: Where N Ht is the hydrogen demand in period t; The synchronous generator operation constraints are as follows: The minimum start and stop time constraints of synchronous generators are as follows: Where, T onfg Indicates the minimum startup time of unit g; T offg Indicates the minimum downtime of unit g; The synchronous generator ramp constraints are as follows: In the formula, RU g and RD g They represent the rising and falling ramp limits of the synchronous generator g respectively; The synchronous generator reserve capacity constraint is as follows: Where P maxg and P ming They represent the maximum power limit and minimum power limit of the synchronous generator g respectively. The synchronous generator regulation reserve capacity constraint is as follows: The primary and secondary frequency regulation reserve capacity constraints of synchronous generators are as follows: In the formula, δ PFRg Provide the maximum proportion of primary frequency regulation capacity for synchronous generator g; δ SFRg Provide the maximum proportion of secondary frequency regulation capacity for synchronous generator g. The power balance constraints of the power system are as follows: Where P d,t Represents the grid-connected load of bus d in time period t. The transmission line power constraints are as follows: Where N l represents the set of lines; κ l,g represents the power flow transfer factor of synchronous generator g on line l; κ l,s The power flow transfer factor on line l is shown; κ l,d represents the power flow transfer factor of load d on line l; F maxl represents the power constraint on transmission line l.

10. A pricing method for inertia, primary frequency regulation and secondary frequency regulation taking into account the frequency regulation capability of a hydrogen refueling station according to claim 1, characterized in that: In step 3), the step of solving the frequency regulation auxiliary service pricing model taking into account the frequency response capability of the hydrogen refueling station includes: 3.1) Define the CVaR-Wasserstein metric Right now: In the formula, Π is the probability distribution of the random variable ζ1. and ζ2 belong to the probability distribution The joint distribution of ζ1 and ζ2; d(ζ1-ζ2) = ||ζ1-ζ2|| is the distance between the random variables ζ1 and ζ2 defined by the vector norm, represents the set of all probability distributions with support Ξ; the support set of the random variable ζ and is the sample mean and sample covariance, σ max is the sample coefficient; represents the probability mass from Move to Minimum cost required; 3.2) N sample historical data based on uncertain variables Determining the empirical distribution of renewable energy output errors is a random variable The Dirac distribution of 3.3) Use the CVaR-Wasserstein ball to construct fuzzy sets, namely: Where ε is the radius of the CVaR-Wasserstein sphere; 3.4) Calculate the worst-case expected cost Right now: In the formula, ||·|| * is the dual norm of ||·||; And ||e||1=1; is a fuzzy set constructed by type-∞Wassersteinmetric; It is a classic type-1 Wasserstein fuzzy set; is the loss function; 1-α is the scaling ratio of the fuzzy set radius ε; 3.5) Reconstruct the worst-case expected cost to obtain the reconstructed worst-case expected cost model, namely: min C=C de +with Where: z is an auxiliary variable; C de It is the sum of all costs except the expected cost in the worst distribution case. 3.6) Solve the reconstructed worst-case expected cost model and obtain the pricing scheme for power system frequency regulation ancillary services.

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