Electric energy and climbing demand capacity combined clearing method and related device

Abstract

The invention belongs to the field of electric power automation, and discloses an electric energy and climbing demand capacity combined clearing method and a related device, and the method comprises the steps: obtaining the climbing demand capacity of a power system based on the distribution of historical net load prediction errors of the power system; obtaining the climbing demand vacancy cost of the power system according to the climbing demand capacity of the power system; performing day-ahead clearing according to the day-ahead load prediction value and the day-ahead new energy output prediction value of the power system to obtain a day-ahead clearing result; and performing intra-day rolling clearing according to the day-ahead clearing result in combination with the intra-day load prediction value and the intra-day new energy output prediction value of the power system to obtain an intra-day rolling clearing result. According to the method, the possible climbing demand of the power system in the future can be reflected more accurately, the energy storage station and the flexible load are fully utilized to reduce the net load fluctuation in the day-ahead market, the flexible climbing ability with the finer time scale is provided in the day-ahead market wind and light uncertain environment, and the uncertainty fluctuation risk resistance ability is enhanced.

Description

Technical Field

[0001] The invention belongs to the field of electric power automation and relates to a method for jointly clearing electric energy and ramp demand capacity and a related device. Background Art

[0002] With the continuous increase in the proportion of renewable energy power generation, the sharp increase or decrease in the net load of the power system has become more and more serious, and the "duck curve" trend of the net load of the power system has become more and more obvious. Therefore, the power system needs to reserve a certain amount of flexible ramping capacity (Flexible Ramping Product, FRP) during operation, including two types of upward regulation products (Flexible Ramping Up, FRU) and downward regulation products (Flexible Ramping Down, FRD), to ensure that the power system can achieve the grid connection and consumption of large-scale distributed renewable energy power stations under the premise of safe and stable operation.

[0003] At present, the flexibility of the power system is mainly provided by traditional generators on the supply side. In the future, as the penetration rate of renewable energy continues to increase, the frequency of short-term power generation shortage events may increase due to insufficient flexible ramping resources. Simply relying on generators to provide flexible ramping regulation capabilities will not be able to meet the increasing demand for system flexible regulation capabilities. At the same time, the net load fluctuation of the power system will cause inaccurate determination of the ramping auxiliary demand capacity, which will lead to an increase in the operating cost of the power system. It may also lead to insufficient ramping capacity of the power system, making it difficult to resist the risk of uncertainty fluctuations, affecting the safe operation of the power system. Summary of the invention

[0004] The purpose of the present invention is to overcome the shortcomings of the above-mentioned prior art and provide a method for jointly clearing electric energy and ramp demand capacity and related devices.

[0005] In order to achieve the above object, the present invention adopts the following technical solutions:

[0006] In a first aspect, the present invention provides a method for jointly clearing electric energy and ramp demand capacity, comprising:

[0007] The ramp demand capacity of the power system is obtained based on the distribution of the historical net load forecast error of the power system, and the ramp demand shortfall cost of the power system is obtained according to the ramp demand capacity of the power system;

[0008] According to the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, the day-ahead clearing is performed with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost as the optimization goal, and the day-ahead clearing result is obtained;

[0009] According to the day-ahead clearing results combined with the daily load forecast value and the daily renewable energy output forecast value of the power system, the intraday rolling clearing is carried out with the minimum sum of the power system's power generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost as the optimization goal to obtain the intraday rolling clearing results.

[0010] Optionally, the distribution of historical net load forecast errors of the power system is obtained in the following manner:

[0011] Several historical net load forecast error rates of the power system on the same typical day and in the same time period are obtained, and the historical net load forecast error rates are arranged from small to large into an error rate set as the distribution of the historical net load forecast error of the power system.

[0012] Optionally, obtaining the ramp demand capacity of the power system based on the distribution of historical net load forecast errors of the power system includes:

[0013] The upper limit of the net load forecast error rate r under the preset confidence level in each period is obtained by the following formula: u,t and the lower limit of the net load forecast error rate r l,t :

[0014] r u，t =r n，t and

[0015] r l，t =r n，t and

[0016] Where C is the preset confidence level; r n,t is the historical net load forecast error rate corresponding to the nth element in the distribution of historical net load forecast errors in time period t; r t is the distribution of historical net load forecast error in period t; K t is the number of elements in the distribution of historical net load forecast errors for period t; and They are respectively the rounding up operator and the rounding down operator;

[0017] The ramp-up demand capacity of the power system is obtained by the following formula and downhill demand capacity

[0018]

[0019]

[0020]

[0021]

[0022]

[0023]

[0024]

[0025]

[0026] in, is the positive net load forecast error caused by inaccurate net load forecast in time period t, is the negative error of net load forecast caused by inaccurate net load forecast in period t, P t net，p is the net load forecast value for period t, is the net load forecast value for period t+1, P t net,r is the actual value of daily net load in period t, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in period t respectively; and They are the uncertainty demand capacities of the up and down ramp demand capacities that meet the preset confidence level.

[0027] Optionally, obtaining the ramp demand shortfall cost of the power system according to the ramp demand capacity of the power system includes:

[0028] The climbing demand shortage price under the upper and lower climbing demand shortage capacity interval d is obtained by the following formula:

[0029]

[0030]

[0031]

[0032]

[0033] in, and are the upper and lower climbing price limits, α d and β d are the expected loss probabilities of the system under the upper and lower ramp demand shortage capacity intervals d, respectively; and They are the up-ramp and down-ramp demand shortage capacities in time period t respectively; and They are the upward and downward ramp demand deficit price curves in period t respectively;

[0034] The up and down ramp demand shortfall costs are obtained by the following formula:

[0035]

[0036]

[0037] in, and They are the shortfall costs of uphill and downhill climbing respectively.

[0038] Optionally, the day-ahead clearing is performed based on the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost of the power system as the optimization target, and the day-ahead clearing results include:

[0039] Construct the day-ahead optimization objective function minf:

[0040]

[0041] Among them, T, Ω G ,Ω B ,Ω SL and Ω IL They are the day-ahead optimized time period set, thermal power unit set, energy storage set, new energy station set, transferable load set and curtailable load set; and are the thermal power fuel cost and start-up and shutdown cost of the i-th thermal power unit in time period t; C SL and C IL They are the unit call price of the load that can be transferred and the unit call price of the load that can be curtailed; and are the discharge price and charging price of the b-th energy storage power station in time period t respectively; P i,t is the output of the i-th thermal power unit in time period t, and are the discharge power and charging power of the b-th energy storage power station in time period t respectively; and P x,t are the call amount of the kth transferable load and the call amount of the xth curtailable load in time period t, respectively; and They are the uphill and downhill demand shortfall costs respectively;

[0042] According to the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, based on the day-ahead optimization objective function, combined with the system load balance constraints, line safety constraints, climbing demand capacity constraints, thermal power unit constraints, electrochemical energy storage constraints, new energy station constraints, transferable load constraints and reducible load constraints, the day-ahead clearing is carried out to obtain the day-ahead clearing result.

[0043] Optionally, the day-ahead clearing result is combined with the daily load forecast value and the daily new energy output forecast value of the power system, and the daily rolling clearing is performed with the minimum sum of the power system generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost as the optimization goal, and the daily rolling clearing result includes:

[0044] Constructing intraday optimization objective function

[0045]

[0046] Among them, T' is the intraday optimization period set, Ω N is the set of new energy stations, λ n,t and λ loss,t are the power abandonment price of the nth renewable energy station in time period t and the system unit load shedding penalty price, P loss,t is the load shedding power in time period t; is the actual output of the nth renewable energy station in period t; is the predicted maximum output of the nth renewable energy station in period t;

[0047] The deterministic demand capacity of the ramp demand capacity of the power system is updated by the following formula:

[0048]

[0049]

[0050] in, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in the updated time period t, respectively; P rn,t is the intraday net load forecast value of time period t; P m，t+1 is the intraday net load forecast value for period t+1;

[0051] Update the system load balancing constraints as follows:

[0052]

[0053]

[0054]

[0055]

[0056]

[0057] in, and They are the up-ramp and down-ramp capacities called by the i-th thermal power unit in the intraday period t and the up-ramp and down-ramp capacities called by the b-th energy storage power station;

[0058] Update the electrochemical energy storage constraint by:

[0059]

[0060] Among them, SOC b,t is the state of charge of the b-th energy storage station in time period t, SOC b,t－1 is the charge state of the b-th energy storage power station in time period t-1; and are the charging and discharging efficiencies of the b-th energy storage power station respectively; and are the minimum state of charge and maximum state of charge of the b-th energy storage power station respectively; is the rated capacity of the b-th energy storage power station; Δt is the length of a time period;

[0061] According to the intraday load forecast value and the intraday new energy output forecast value of the power system, the day-ahead clearing results and the updated deterministic demand capacity of the ramp demand capacity of the power system, based on the intraday optimization objective function, combined with the updated system load balance constraints, line safety constraints, ramp demand capacity constraints, thermal power unit constraints, updated electrochemical energy storage constraints, new energy station constraints, transferable load constraints and reducible load constraints, rolling clearing is performed in each period of the day to obtain the intraday rolling clearing results.

[0062] In a second aspect, the present invention provides a system for jointly clearing electric energy and ramp demand capacity, comprising:

[0063] A ramp demand shortfall cost determination module is used to obtain the ramp demand capacity of the power system based on the distribution of the historical net load forecast error of the power system, and to obtain the ramp demand shortfall cost of the power system according to the ramp demand capacity of the power system;

[0064] The day-ahead clearing module is used to perform day-ahead clearing based on the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost as the optimization target, and obtain the day-ahead clearing result;

[0065] The intraday clearing module is used to perform intraday rolling clearing based on the day-ahead clearing results, combined with the intraday load forecast value and the intraday new energy output forecast value of the power system, with the minimum sum of the power system's system power generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost as the optimization goal, to obtain the intraday rolling clearing results.

[0066] Optionally, obtaining the ramp demand capacity of the power system based on the distribution of historical net load forecast errors of the power system includes:

[0067] The upper limit of the net load forecast error rate r under the preset confidence level in each period is obtained by the following formula: u,t and the lower limit of the net load forecast error rate r l,t :

[0068] r u，t =r n，t and

[0069] r l，t =r n，t and

[0070] Where C is the preset confidence level; r n,t is the historical net load forecast error rate corresponding to the nth element in the distribution of historical net load forecast errors in time period t; r t is the distribution of historical net load forecast error in period t; K t is the number of elements in the distribution of historical net load forecast errors for period t; and They are respectively the rounding up operator and the rounding down operator;

[0071] The ramp-up demand capacity of the power system is obtained by the following formula and downhill demand capacity

[0072]

[0073]

[0074]

[0075]

[0076]

[0077]

[0078]

[0079]

[0080] in, is the positive net load forecast error caused by inaccurate net load forecast in time period t, is the negative error of net load forecast caused by inaccurate net load forecast in period t, P t net，p is the net load forecast value for period t, is the net load forecast value for period t+1, P t net,r is the actual value of daily net load in period t, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in period t respectively; and They are the uncertainty demand capacities of the up and down ramp demand capacities that meet the preset confidence level.

[0081] According to a third aspect of the present invention, a computer device is provided, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the steps of the above-mentioned method for jointly clearing electric energy and ramp demand capacity when executing the computer program.

[0082] According to a fourth aspect of the present invention, a computer-readable storage medium is provided, wherein the computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the steps of the above-mentioned method for jointly clearing electric energy and ramp demand capacity are implemented.

[0083] Compared with the prior art, the present invention has the following beneficial effects:

[0084] The electric energy and ramp demand capacity joint clearing method of the present invention obtains the ramp demand capacity based on the distribution of the historical net load forecast error of the power system, which can more accurately reflect the ramp demand that the power system may face in the future. At the same time, the ramp demand shortage cost of the power system is obtained according to the ramp demand capacity of the power system, and the ramp demand shortage cost related to the ramp demand capacity is introduced to participate in the clearing, which can effectively reflect the scarcity of the ramp capacity of the power system, thereby effectively playing the regulatory role of the ramp auxiliary market. In the clearing process, firstly, based on the day-ahead load forecast and the day-ahead renewable energy output forecast of the power system, the sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and climbing demand shortfall cost is minimized as the optimization target for day-ahead clearing, and energy storage sites and flexible loads are fully utilized to reduce net load fluctuations in the day-ahead market. Then, based on the day-ahead clearing results combined with the intraday load forecast and the intraday renewable energy output forecast of the power system, intraday rolling clearing is performed with the sum of the power system power generation cost, power abandonment cost, load shedding cost and climbing demand shortfall cost minimized as the optimization target, so as to provide a more refined time scale of flexible climbing capability in the uncertain environment of wind and solar power in the intraday market, so as to improve the real-time flexibility of the power system, enhance the ability to resist uncertainty fluctuation risks and ensure safe operation. BRIEF DESCRIPTION OF THE DRAWINGS

[0085] Figure 1 This is a flow chart of a method for jointly clearing electric energy and ramp demand capacity according to an embodiment of the present invention.

[0086] Figure 2 It is a schematic diagram of simulating the clearing process of an embodiment of the present invention.

[0087] Figure 3 This is a structural block diagram of the electric energy and ramp demand capacity joint clearing system according to an embodiment of the present invention. DETAILED DESCRIPTION

[0088] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0089] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0090] The present invention is further described in detail below in conjunction with the accompanying drawings:

[0091] See also Figure 1 In one embodiment of the present invention, a method for jointly clearing electric energy and ramp demand capacity is provided, specifically, a method for jointly clearing electric energy and ramp demand capacity that couples the day-ahead market and the intraday market taking into account the elasticity of the ramp demand, which can effectively solve the problem of inaccurate determination of the ramp auxiliary demand capacity caused by the net load fluctuation of the current power system, resulting in increased power system costs and insufficient power system climbing capacity.

[0092] Specifically, the method for jointly clearing electric energy and ramp demand capacity of the present invention comprises the following steps:

[0093] S1: The ramp demand capacity of the power system is obtained based on the distribution of the historical net load forecast error of the power system, and the ramp demand shortfall cost of the power system is obtained according to the ramp demand capacity of the power system.

[0094] S2: Based on the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, the day-ahead clearing is performed with the minimum sum of the power system's system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost as the optimization goal to obtain the day-ahead clearing result.

[0095] S3: Based on the day-ahead clearing results combined with the daily load forecast value and the daily renewable energy output forecast value of the power system, the intraday rolling clearing is performed with the minimum sum of the power system's power generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost as the optimization goal to obtain the intraday rolling clearing results.

[0096] The electric energy and ramp demand capacity joint clearing method of the present invention obtains the ramp demand capacity based on the distribution of the historical net load forecast error of the power system, which can more accurately reflect the ramp demand that the power system may face in the future. At the same time, the ramp demand shortage cost of the power system is obtained according to the ramp demand capacity of the power system, and the ramp demand shortage cost related to the ramp demand capacity is introduced to participate in the clearing, which can effectively reflect the scarcity of the ramp capacity of the power system, thereby effectively playing the regulatory role of the ramp auxiliary market. In the clearing process, firstly, based on the day-ahead load forecast and the day-ahead renewable energy output forecast of the power system, the sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and climbing demand shortfall cost is minimized as the optimization target for day-ahead clearing, and energy storage sites and flexible loads are fully utilized to reduce net load fluctuations in the day-ahead market. Then, based on the day-ahead clearing results combined with the intraday load forecast and the intraday renewable energy output forecast of the power system, intraday rolling clearing is performed with the sum of the power system power generation cost, power abandonment cost, load shedding cost and climbing demand shortfall cost minimized as the optimization target, so as to provide a more refined time scale of flexible climbing capability in the uncertain environment of wind and solar power in the intraday market, so as to improve the real-time flexibility of the power system, enhance the ability to resist uncertainty fluctuation risks and ensure safe operation.

[0097] In one possible implementation, the distribution of the historical net load forecast error of the power system is obtained in the following manner: obtaining several historical net load forecast error rates of the power system on the same typical day and the same time period, and arranging the historical net load forecast error rates in ascending order into an error rate set as the distribution of the historical net load forecast error of the power system.

[0098] Specifically, based on the historical operation data of the power system, the load and wind and solar data of different operation days are extracted, and the historical net load forecast values ​​and actual values ​​of multiple typical days (such as weekdays, Saturdays, weekends and holidays, etc.) and the same period are counted, and then the error rates of multiple historical net load forecasts in the period are calculated. ht :

[0099]

[0100] Among them, P t net，p and P t net,r are the historical net load forecast value and actual value of the power system in period t respectively.

[0101] Then, the historical net load forecast error rates of all the same typical days and the same period are arranged from small to large and from negative to positive into an error rate set as the distribution of the historical net load forecast error of the power system. The number of error samples is the number of elements in the set.

[0102] In a possible implementation manner, obtaining the ramp demand capacity of the power system based on the distribution of the historical net load forecast error of the power system includes: obtaining the upper limit r of the net load forecast error rate at the preset confidence level in each time period by the following formula: u,t and the lower limit of the net load forecast error rate r l,t :

[0103] r u，t =r n，t and

[0104] r l，t =r n，t and

[0105] Where C is the preset confidence level; r n,t is the historical net load forecast error rate corresponding to the nth element in the distribution of historical net load forecast errors in time period t; r t is the distribution of historical net load forecast error in period t; K t is the number of elements in the distribution of historical net load forecast errors for period t; and They are the ceiling and floor operators respectively.

[0106] The ramp-up demand capacity of the power system is obtained by the following formula and downhill demand capacity

[0107]

[0108]

[0109]

[0110]

[0111]

[0112]

[0113]

[0114]

[0115] in, is the positive net load forecast error caused by inaccurate net load forecast in time period t, is the negative error of net load forecast caused by inaccurate net load forecast in period t, P tnet，p is the net load forecast value for period t, is the net load forecast value for period t+1, P t net,r is the actual value of daily net load in period t, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in period t respectively; and They are the uncertainty demand capacities of the up and down ramp demand capacities that meet the preset confidence level.

[0116] Specifically, the ramp demand capacity of the power system consists of two parts: one is the change in the net load of the power system in the next period compared with the current period, which is called the deterministic demand capacity of the ramp demand capacity; the other is the additional ramp demand capacity generated to meet the net load forecast deviation of the power system with a certain confidence level, which is called the uncertain demand capacity of the ramp demand capacity. The ramp demand of the system in period t:

[0117]

[0118]

[0119] Among them, the deterministic demand capacity of the ramp demand capacity can be expressed by the net load forecast value:

[0120]

[0121]

[0122] The variable subscripts t and t+1 distinguish the two adjacent time periods before and after the variable.

[0123] Calculate the upper and lower limits of the error rate for a certain confidence level for this period. The calculation formula is:

[0124] r u，t =r n，t and

[0125] r l，t =r n，t and

[0126] Among them, C is the confidence level, which can generally be 95%, 90% and 85%.

[0127] Positive net load forecast error caused by inaccurate net load forecast for period t Negative net load forecast error caused by inaccurate net load forecast for period t Determined by the following formula:

[0128]

[0129]

[0130] By deducting the deterministic FRP capacity in the opposite direction from the net load forecast error of the power system, the uncertainty demand capacity of the up and down ramp demand capacity can be calculated. and The calculation formula is as follows:

[0131]

[0132]

[0133] In a possible implementation manner, obtaining the climbing demand shortage cost of the power system according to the climbing demand capacity of the power system includes: obtaining the climbing demand shortage price under the upper and lower climbing demand shortage capacity intervals d by the following formula:

[0134]

[0135]

[0136]

[0137]

[0138] in, and are the upper and lower climbing price limits, α d and β d are the expected loss probabilities of the system under the upper and lower ramp demand shortage capacity intervals d, respectively; and They are the up-ramp and down-ramp demand shortage capacities in time period t respectively; and They are the upward and downward climbing demand shortage price curves in period t respectively.

[0139] The up and down ramp demand shortfall costs are obtained by the following formula:

[0140]

[0141]

[0142] in, and They are the shortfall costs of uphill and downhill climbing respectively.

[0143] Specifically, when calculating the cost of the ramp demand shortage, historical data is used to analyze the distribution of violations of power balance to determine the risk of load shedding and power abandonment under different ramp demand capacities. The ramp demand shortage price is the loss that may be caused by insufficient climbing capacity of the power system. The loss probability of the power system in different shortage intervals of the climbing demand capacity is multiplied by the upper limit of the bidding price in the electric energy market to obtain the loss caused by insufficient climbing capacity of the power system. The climbing demand shortage prices under different upper and lower climbing demand shortage capacity intervals d are as follows:

[0144]

[0145]

[0146] When the ramp demand capacity changes from uncertain demand capacity to deterministic demand capacity, the corresponding ramp shortfall expected loss is as follows:

[0147]

[0148]

[0149] Based on this, the calculation method of the up and down climbing demand shortage cost is as follows:

[0150]

[0151]

[0152] In a possible implementation, the day-ahead clearing is performed based on the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost of the power system as the optimization target, and the day-ahead clearing result is obtained by constructing the day-ahead optimization objective function minf:

[0153]

[0154] Among them, T, Ω G ,Ω B ,Ω SL and Ω IL They are the day-ahead optimized time period set, thermal power unit set, energy storage set, new energy station set, transferable load set and curtailable load set; and are the thermal power fuel cost and start-up and shutdown cost of the i-th thermal power unit in time period t; C SL and C IL They are the unit call price of the load that can be transferred and the unit call price of the load that can be curtailed; and are the discharge price and charging price of the b-th energy storage power station in time period t respectively; P i,t is the output of the i-th thermal power unit in time period t, and are the discharge power and charging power of the b-th energy storage power station in time period t respectively; and P x,t are the call amount of the kth transferable load and the call amount of the xth curtailable load in time period t, respectively; and They are the shortfall costs of uphill and downhill climbing respectively.

[0155] According to the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, based on the day-ahead optimization objective function, combined with the system load balance constraints, line safety constraints, climbing demand capacity constraints, thermal power unit constraints, electrochemical energy storage constraints, new energy station constraints, transferable load constraints and reducible load constraints, the day-ahead clearing is carried out to obtain the day-ahead clearing result.

[0156] Specifically, the day-ahead optimization period set in this implementation includes 24 periods. By considering the quotation of conventional thermal power units, the quotation of new energy power stations and energy storage power stations, and the quotation of loads without quotation, a corresponding clearing model is established with the lowest cost as the optimization goal.

[0157] Fuel cost of thermal power units and shutdown costs as follows:

[0158]

[0159]

[0160] Where a, b and c are the bid coefficients of the ith thermal power unit in the electricity market; u i,t is the start-stop state variable of the i-th thermal power unit in time period t, with a value of 1 for start-up and 0 for shutdown; ΔT is the length of a time period; is the single start-up and shutdown cost of the i-th thermal power unit.

[0161] The system load balancing constraint can be expressed as:

[0162]

[0163] Among them, P b,t is the output power of the b-th energy storage station in period t, with discharge as positive and charge as negative; is the actual output of the nth renewable energy station in period t; D t is the load size of the system in the tth period; are the power of the kth transferable load transferred to the t period (positive value) and the power transferred out of the t period (negative value), respectively; is the Lagrange multiplier corresponding to the market power balance.

[0164] The line safety constraint is to ensure that the line transmission power does not exceed the allowed safety range when the node load demand changes within the static safety domain, which can be expressed as:

[0165]

[0166] Among them, Ω L is the system line collection; (·) T is the matrix transpose operation; are the injection transfer distribution factor vectors of the unit node and load node to line l respectively; is the injection transfer distribution factor of the tie line power exchange node to line l; t is the output vector of all units in period t; P L,t is the load vector of all nodes at time t; is the upper limit of line 1 power transmission.

[0167] The ramping demand capacity constraint means that in the electric energy ramping auxiliary service market, the sum of the winning capacities of all ramping units should be equal to or greater than the system's minimum ramping demand, and the winning up and down climbing capacity of each winning ramping auxiliary service unit or load should not exceed the maximum up and down climbing capacity that its unit or load can provide.

[0168] The ramp demand capacity constraint can be expressed as:

[0169]

[0170]

[0171] in, They are the up-ramp and down-ramp demand capacities required by the system in period t respectively; They are the up / down ramp capacity provided by the i-th thermal power unit and the up / down ramp capacity provided by the b-th energy storage power station during period t respectively; are the Lagrange multipliers corresponding to the total climbing amount constraints respectively.

[0172] The constraints of thermal power units include the output constraints of thermal power units, the ramp constraints of thermal power units and the minimum start-stop time constraints of thermal power units. Among them, the output constraints of thermal power units can be expressed as:

[0173] The output constraint of the i-th thermal power unit in the t-th period is:

[0174]

[0175]

[0176] in, and P i are the installed capacity and minimum technical output of the i-th thermal power unit respectively.

[0177] The climbing constraint of thermal power units can be expressed as:

[0178] The ramp constraint of the i-th thermal power unit in the t-th period is:

[0179]

[0180]

[0181] Among them, ΔP i UP With ΔP i DN are the up-slope limit and down-slope limit of the i-th thermal power unit respectively; ΔP i ST With ΔP i SH are the start-up and shutdown climbing limits of the i-th thermal power unit, T i,t , H i,t They are respectively the startup action variable and shutdown action variable of the i-th thermal power unit in the t-th period.

[0182] The minimum start and stop time constraint of thermal power units can be expressed as:

[0183] The minimum continuous startup time constraint of the i-th thermal power unit in a scheduling cycle:

[0184]

[0185]

[0186] Among them, g is the continuous timing sequence number after the unit starts or stops; T i ON is the minimum continuous start-up time of the i-th thermal power unit; T i OFF is the minimum continuous shutdown time of the i-th coal-fired unit.

[0187] Electrochemical energy storage constraints include charge and discharge power constraints, charge state constraints, and energy storage charge and discharge times constraints.

[0188] Among them, the charge and discharge power constraints can be expressed as:

[0189]

[0190]

[0191] c b,t +d b,t ≤1

[0192] Among them, c b,t ,d b,t are the charging state and discharging state of the b-th energy storage power station at the start time of time period t, respectively; a value of "1" indicates charging / discharging during this time period, and a value of "0" indicates no charging / discharging; They are respectively the maximum discharge power and maximum charging power of the b-th energy storage power station in period t.

[0193] The state of charge constraint can be expressed as:

[0194]

[0195]

[0196]

[0197] Among them, t0 is the starting time of the initial period of the optimization cycle; and SOC b0 are respectively the state of charge and set value of the b-th energy storage power station at the beginning of the initial period of the optimization cycle, for example, set to 50%; are the charging and discharging efficiencies of the b-th energy storage power station respectively; and are the minimum state of charge and maximum state of charge of the bth energy storage power station respectively.

[0198] The energy storage charge and discharge times constraint can be expressed as:

[0199] y b,t =|c b,t -c b,t-1 |

[0200]

[0201] Among them, y b,t is the charge-discharge switching action variable of the b-th energy storage power station in the t-th period; It is the maximum number of charge and discharge switching times of energy storage in a single day.

[0202] The constraints of new energy stations can be expressed as:

[0203]

[0204] in, It is the predicted maximum output of the nth new energy station.

[0205] The transferable load constraint can be expressed as:

[0206]

[0207]

[0208]

[0209] in, P SL,k and are the minimum and maximum values ​​of the kth transferable load respectively.

[0210] The curtailable load constraint can be expressed as:

[0211]

[0212] in, P XL,x , are the upper and lower limits of the load reduction amount of the xth load that can be reduced respectively.

[0213] In a possible implementation, the method of performing intraday rolling clearing based on the day-ahead clearing result, combined with the intraday load forecast value and the intraday new energy output forecast value of the power system, taking the sum of the power generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost of the power system as the minimum as the optimization target, and obtaining the intraday rolling clearing result includes: constructing an intraday optimization objective function

[0214]

[0215] Among them, T' is the intraday optimization period set, Ω N is the set of new energy stations, λ n,t and λ loss,t are the power abandonment price of the nth renewable energy station in time period t and the system unit load shedding penalty price, P loss,t is the load shedding power in time period t; is the actual output of the nth renewable energy station in period t; It is the predicted maximum output of the nth renewable energy station in period t.

[0216] The deterministic demand capacity of the ramp demand capacity of the power system is updated by the following formula:

[0217]

[0218]

[0219] in, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in the updated time period t, respectively; P rn,t is the intraday net load forecast value of time period t; P m，t+1 It is the intraday net load forecast value of time period t+1.

[0220] Update the system load balancing constraints as follows:

[0221]

[0222]

[0223]

[0224]

[0225]

[0226] in, and They are respectively the up-ramp and down-ramp capacities called by the i-th thermal power unit in the intra-day period t and the up-ramp and down-ramp capacities called by the b-th energy storage power station.

[0227] Update the electrochemical energy storage constraint by:

[0228]

[0229] Among them, SOC b,t is the state of charge of the b-th energy storage station in time period t, SOC b,t－1 is the charge state of the b-th energy storage power station in time period t-1; and are the charging and discharging efficiencies of the b-th energy storage power station respectively; and are the minimum state of charge and maximum state of charge of the b-th energy storage power station respectively; is the rated capacity of the bth energy storage power station; Δt is the length of a time period.

[0230] According to the intraday load forecast value and the intraday new energy output forecast value of the power system, the day-ahead clearing results and the updated deterministic demand capacity of the ramp demand capacity of the power system, based on the intraday optimization objective function, combined with the updated system load balance constraints, line safety constraints, ramp demand capacity constraints, thermal power unit constraints, updated electrochemical energy storage constraints, new energy station constraints, transferable load constraints and reducible load constraints, rolling clearing is performed in each period of the day to obtain the intraday rolling clearing results.

[0231] For details, see Figure 2In the intraday stage, the optimization goal is to minimize the sum of the power system's power generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost. According to the latest future intraday load forecast value and intraday new energy output forecast value, combined with the unit combination result obtained by day-ahead clearing, intraday rolling clearing is performed every 15 minutes, and the rolling period of intraday rolling clearing is the remaining time of the day.

[0232] The day-ahead clearing results usually include the start-stop combination of conventional thermal power units, the pre-output of each unit, and the reserved ramp capacity. The day-ahead clearing results are used in the thermal power unit constraints and updated system load balance constraints in intraday clearing to apply the unit combination results of the day-ahead clearing results to intraday clearing.

[0233] Except for the updated system load balance constraints and the updated electrochemical energy storage constraints, the remaining constraints for intraday clearing are the same as those in the day-ahead clearing stage except for the number of time periods, and will not be repeated here.

[0234] By analyzing the distribution of historical net load forecast errors on similar typical days and the same time periods, the ramp demand capacity of the corresponding time period can be obtained, and the ramp demand capacity of each time period of the corresponding typical day can be obtained more accurately; the ramp shortage price corresponding to different ramp demand capacities can effectively reflect the scarcity of the system's ramp capacity, and can effectively play the role of ramping in assisting market regulation; at the same time, energy storage stations and flexible loads are used to reduce net load fluctuations in the day-ahead market, and in the uncertain environment of intraday market wind and solar power, the ramp demand capacity provider unit provides a more refined flexible climbing capability on a time scale, effectively improving real-time flexibility.

[0235] The following are device embodiments of the present invention, which can be used to implement the method embodiments of the present invention. For details not disclosed in the device embodiments, please refer to the method embodiments of the present invention.

[0236] See also Figure 3 In another embodiment of the present invention, a system for joint clearing of electric energy and ramp demand capacity is provided, which can be used to implement the above-mentioned method for joint clearing of electric energy and ramp demand capacity. Specifically, the system for joint clearing of electric energy and ramp demand capacity includes a ramp demand shortage cost determination module, a day-ahead clearing module and an intraday clearing module.

[0237] Among them, the climbing demand shortage cost determination module is used to obtain the climbing demand capacity of the power system based on the distribution of the historical net load forecast error of the power system, and obtain the climbing demand shortage cost of the power system according to the climbing demand capacity of the power system; the day-ahead clearing module is used to perform day-ahead clearing based on the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and climbing demand shortage cost of the power system as the optimization target, and obtain the day-ahead clearing result; the intraday clearing module is used to perform intraday rolling clearing based on the day-ahead clearing result, combined with the intraday load forecast value and the intraday new energy output forecast value of the power system, with the minimum sum of the power system power generation cost, power abandonment cost, load shedding cost and climbing demand shortage cost of the power system as the optimization target, and obtain the intraday rolling clearing result.

[0238] In a possible implementation manner, obtaining the ramp demand capacity of the power system based on the distribution of the historical net load forecast error of the power system includes: obtaining the upper limit r of the net load forecast error rate at the preset confidence level in each time period by the following formula: u,t and the lower limit of the net load forecast error rate r l,t :

[0239] r u，t =r n，t and

[0240] r l，t =r n，t and

[0241] Where C is the preset confidence level; r n,t is the historical net load forecast error rate corresponding to the nth element in the distribution of historical net load forecast errors in time period t; r t is the distribution of historical net load forecast error in period t; K t is the number of elements in the distribution of historical net load forecast errors for period t; and They are the ceiling and floor operators respectively.

[0242] The ramp-up demand capacity of the power system is obtained by the following formula and downhill demand capacity

[0243]

[0244]

[0245]

[0246]

[0247]

[0248]

[0249]

[0250]

[0251] in, is the positive net load forecast error caused by inaccurate net load forecast in time period t, is the negative error of net load forecast caused by inaccurate net load forecast in period t, P t net，p is the net load forecast value for period t, is the net load forecast value for period t+1, P t net,r is the actual value of daily net load in period t, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in period t respectively; and They are the uncertainty demand capacities of the up and down ramp demand capacities that meet the preset confidence level.

[0252] All relevant contents of each step involved in the embodiment of the aforementioned method for joint clearing of electric energy and ramp demand capacity can be referred to the functional description of the functional modules corresponding to the system for joint clearing of electric energy and ramp demand capacity in the embodiment of the present invention, and will not be repeated here.

[0253] The division of modules in the embodiments of the present invention is schematic and is only a logical function division. There may be other division methods in actual implementation. In addition, each functional module in each embodiment of the present invention may be integrated into one processor, or may exist physically separately, or two or more modules may be integrated into one module. The above-mentioned integrated modules may be implemented in the form of hardware or in the form of software functional modules.

[0254] In another embodiment of the present invention, a computer device is provided, the computer device including a processor and a memory, the memory is used to store a computer program, the computer program includes program instructions, and the processor is used to execute the program instructions stored in the computer storage medium. The processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components, etc., which are the computing core and control core of the terminal, which are suitable for implementing one or more instructions, and are specifically suitable for loading and executing one or more instructions in the computer storage medium to implement the corresponding method flow or corresponding function; the processor described in the embodiment of the present invention can be used for the operation of the method for joint clearing of electric energy and ramp demand capacity.

[0255] In another embodiment of the present invention, the present invention also provides a storage medium, specifically a computer-readable storage medium (Memory), which is a memory device in a computer device for storing programs and data. It is understandable that the computer-readable storage medium here can include both built-in storage media in the computer device and, of course, extended storage media supported by the computer device. The computer-readable storage medium provides a storage space, which stores the operating system of the terminal. In addition, one or more instructions suitable for being loaded and executed by the processor are also stored in the storage space, and these instructions can be one or more computer programs (including program codes). It should be noted that the computer-readable storage medium here can be a high-speed RAM memory or a non-volatile memory, such as at least one disk memory. The processor can load and execute one or more instructions stored in the computer-readable storage medium to implement the corresponding steps of the method for jointly clearing the electric energy and the ramp demand capacity in the above embodiment.

[0256] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0257] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowchart and / or block diagram, as well as the combination of processes and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0258] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0259] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process in the computer or other programmable device. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0260] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention rather than to limit it. Although the present invention has been described in detail with reference to the above embodiments, ordinary technicians in the relevant field should understand that the specific implementation methods of the present invention can still be modified or replaced by equivalents. Any modification or equivalent replacement that does not depart from the spirit and scope of the present invention should be covered within the scope of protection of the claims of the present invention.

Claims

1. A method for jointly clearing electric energy and ramp demand capacity, characterized in that: include: The ramp demand capacity of the power system is obtained based on the distribution of the historical net load forecast error of the power system, and the ramp demand shortfall cost of the power system is obtained according to the ramp demand capacity of the power system; According to the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, the day-ahead clearing is performed with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost as the optimization goal, and the day-ahead clearing result is obtained; According to the day-ahead clearing results combined with the daily load forecast value and the daily renewable energy output forecast value of the power system, the intraday rolling clearing is carried out with the minimum sum of the power system's power generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost as the optimization goal to obtain the intraday rolling clearing results.

2. The method for jointly clearing electric energy and ramp demand capacity according to claim 1 is characterized in that: The distribution of the historical net load forecast error of the power system is obtained in the following way: Several historical net load forecast error rates of the power system on the same typical day and in the same time period are obtained, and the historical net load forecast error rates are arranged from small to large into an error rate set as the distribution of the historical net load forecast error of the power system.

3. The method for jointly clearing electric energy and ramp demand capacity according to claim 1 or 2, characterized in that: The ramp demand capacity of the power system obtained based on the distribution of the historical net load forecast error of the power system includes: The upper limit of the net load forecast error rate r under the preset confidence level in each period is obtained by the following formula: u,t and the lower limit of the net load forecast error rate r l,t : r u，t =r n，t and r l，t =r n，t and Where C is the preset confidence level; r n,t is the historical net load forecast error rate corresponding to the nth element in the distribution of historical net load forecast errors in time period t; r t is the distribution of historical net load forecast error in period t; K t is the number of elements in the distribution of historical net load forecast errors for period t; and They are respectively the rounding up operator and the rounding down operator; The ramp-up demand capacity of the power system is obtained by the following formula and downhill demand capacity in, is the positive net load forecast error caused by inaccurate net load forecast in time period t, is the negative error of net load forecast caused by inaccurate net load forecast in period t, P t net，p is the net load forecast value for period t, is the net load forecast value for period t+1, P t net,r is the actual value of daily net load in period t, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in period t respectively; and They are the uncertainty demand capacities of the up and down ramp demand capacities that meet the preset confidence level.

4. The method for jointly clearing electric energy and ramp demand capacity according to claim 3 is characterized in that: The step of obtaining the ramp demand shortfall cost of the power system according to the ramp demand capacity of the power system comprises: The ramp demand shortfall price under the upper and lower ramp demand shortfall capacity interval d is obtained by the following formula: in, and are the upper and lower climbing price limits, α d and β d are the expected loss probabilities of the system under the upper and lower ramp demand shortage capacity intervals d, respectively; and They are the up-ramp and down-ramp demand shortage capacities in time period t respectively; and They are the upward and downward ramp demand deficit price curves in period t respectively; The up and down ramp demand shortfall costs are obtained by the following formula: in, and They are the shortfall costs of uphill and downhill climbing respectively.

5. The method for jointly clearing electric energy and ramp demand capacity according to claim 1, characterized in that: According to the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, the day-ahead clearing is performed with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost as the optimization goal, and the day-ahead clearing results include: Construct the day-ahead optimization objective function min f: Among them, T, Ω G ,Ω B ,Ω SL and Ω IL They are the day-ahead optimized time period set, thermal power unit set, energy storage set, new energy station set, transferable load set and curtailable load set; and are the thermal power fuel cost and start-up and shutdown cost of the i-th thermal power unit in time period t; C SL and C IL They are the unit call price of the load that can be transferred and the unit call price of the load that can be curtailed; and are the discharge price and charging price of the b-th energy storage power station in time period t respectively; P i,t is the output of the i-th thermal power unit in time period t, and are the discharge power and charging power of the b-th energy storage power station in time period t respectively; and P x,t are the call amount of the kth transferable load and the call amount of the xth curtailable load in time period t, respectively; and They are the uphill and downhill demand shortfall costs respectively; According to the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, based on the day-ahead optimization objective function, combined with the system load balance constraints, line safety constraints, climbing demand capacity constraints, thermal power unit constraints, electrochemical energy storage constraints, new energy station constraints, transferable load constraints and reducible load constraints, the day-ahead clearing is carried out to obtain the day-ahead clearing result.

6. The method for jointly clearing electric energy and ramp demand capacity according to claim 5, characterized in that: According to the day-ahead clearing results, combined with the daily load forecast value and the daily new energy output forecast value of the power system, the daily rolling clearing is performed with the minimum sum of the power system generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost as the optimization goal, and the daily rolling clearing results include: Constructing intraday optimization objective function Among them, T' is the intraday optimization period set, Ω N is the set of new energy stations, λ n,t and λ loss,t are the power abandonment price of the nth renewable energy station in time period t and the system unit load shedding penalty price, P loss,t is the load shedding power in time period t; is the actual output of the nth renewable energy station in period t; is the predicted maximum output of the nth renewable energy station in period t; The deterministic demand capacity of the ramp demand capacity of the power system is updated by the following formula: in, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in the updated time period t, respectively; P rn,t is the intraday net load forecast value of time period t; P m，t+1 is the intraday net load forecast value for period t+1; Update the system load balancing constraints as follows: in, and They are the up-ramp and down-ramp capacities called by the i-th thermal power unit in the intraday period t and the up-ramp and down-ramp capacities called by the b-th energy storage power station; Update the electrochemical energy storage constraint by: Among them, SOC b,t is the state of charge of the b-th energy storage station in time period t, SOC b,t－1 is the charge state of the b-th energy storage power station in time period t-1; and are the charging and discharging efficiencies of the b-th energy storage power station respectively; and are the minimum state of charge and maximum state of charge of the b-th energy storage power station respectively; is the rated capacity of the b-th energy storage power station; Δt is the length of a time period; According to the intraday load forecast value and the intraday new energy output forecast value of the power system, the day-ahead clearing results and the updated deterministic demand capacity of the ramp demand capacity of the power system, based on the intraday optimization objective function, combined with the updated system load balance constraints, line safety constraints, ramp demand capacity constraints, thermal power unit constraints, updated electrochemical energy storage constraints, new energy station constraints, transferable load constraints and reducible load constraints, rolling clearing is performed in each period of the day to obtain the intraday rolling clearing results.

7. A system for clearing electric energy and ramp demand capacity, characterized in that: include: A ramp demand shortfall cost determination module is used to obtain the ramp demand capacity of the power system based on the distribution of the historical net load forecast error of the power system, and to obtain the ramp demand shortfall cost of the power system according to the ramp demand capacity of the power system; The day-ahead clearing module is used to perform day-ahead clearing based on the day-ahead load forecast value and the day-ahead new energy output forecast value of the power system, with the minimum sum of the power system power generation cost, unit start-up and shutdown cost, energy storage charging and discharging call cost, flexible load call cost and ramp demand shortfall cost as the optimization target, and obtain the day-ahead clearing result; The intraday clearing module is used to perform intraday rolling clearing based on the day-ahead clearing results, combined with the intraday load forecast value and the intraday new energy output forecast value of the power system, with the minimum sum of the power system's system power generation cost, power abandonment cost, load shedding cost and ramp demand shortfall cost as the optimization goal, to obtain the intraday rolling clearing results.

8. The electric energy and ramp demand capacity combined clearing system according to claim 7 is characterized in that: The ramp demand capacity of the power system obtained based on the distribution of the historical net load forecast error of the power system includes: The upper limit of the net load forecast error rate r under the preset confidence level in each period is obtained by the following formula: u,t and the lower limit of the net load forecast error rate r l,t : r u，t =r n，t and r l，t =r n，t and Where C is the preset confidence level; r n,t is the historical net load forecast error rate corresponding to the nth element in the distribution of historical net load forecast errors in time period t; r t is the distribution of historical net load forecast error in period t; K t is the number of elements in the distribution of historical net load forecast errors for period t; and They are respectively the rounding up operator and the rounding down operator; The ramp-up demand capacity of the power system is obtained by the following formula and downhill demand capacity in, is the positive net load forecast error caused by inaccurate net load forecast in time period t, is the negative error of net load forecast caused by inaccurate net load forecast in period t, P t net，p is the net load forecast value for period t, is the net load forecast value for period t+1, P t net,r is the actual value of daily net load in period t, and are the deterministic demand capacities of the up-ramp and down-ramp demand capacities in period t respectively; and They are the uncertainty demand capacities of the up and down ramp demand capacities that meet the preset confidence level.

9. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the computer program, the steps of the method for jointly clearing electric energy and ramp demand capacity as described in any one of claims 1 to 6 are implemented.

10. A computer-readable storage medium storing a computer program, characterized in that: When the computer program is executed by a processor, the steps of the method for jointly clearing electric energy and ramp demand capacity as claimed in any one of claims 1 to 6 are implemented.

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