CN113517691A - Multi-type power supply cooperative scheduling method based on peak-valley time-of-use electricity price - Google Patents

Multi-type power supply cooperative scheduling method based on peak-valley time-of-use electricity price Download PDF

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CN113517691A
CN113517691A CN202110810568.XA CN202110810568A CN113517691A CN 113517691 A CN113517691 A CN 113517691A CN 202110810568 A CN202110810568 A CN 202110810568A CN 113517691 A CN113517691 A CN 113517691A
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power
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CN113517691B (en
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李琳玮
宁光涛
何礼鹏
陈明帆
黄亮
梁亚峰
黄丽格
马立红
程西
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Hainan Power Grid Co Ltd
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Abstract

The invention provides a multi-type power supply cooperative scheduling method based on peak-valley time-of-use electricity price, which comprises the following steps: acquiring the day-ahead predicted output of each wind power plant through a wind power prediction system; constructing corresponding mathematical models according to the operating characteristics and system safety constraints of different types of power generating units, wherein the different types of power generating units comprise a thermal power generating unit, a hydroelectric generating unit, a nuclear power generating unit, a wind power generating unit and electrochemical energy storage; solving to obtain the change condition of the load after implementing the time-of-use electricity price mechanism according to the proportion of the transferable load in the total load; and solving the mathematical model to obtain the start-up and shut-down plans and the pre-output data of different types of power supply units, the charge-discharge time period and the charge-discharge power of electrochemical energy storage and the scheduling condition of interruptible loads by taking the minimum total running cost of the system as an objective function. The invention can reduce the load peak-valley difference of the power system and the operation cost of the thermal power generating unit and the nuclear power generating unit, and improve the operation economy of the system.

Description

Multi-type power supply cooperative scheduling method based on peak-valley time-of-use electricity price
Technical Field
The invention relates to the technical field of power dispatching, in particular to a multi-type power supply cooperative dispatching method based on peak-valley time-of-use electricity price.
Background
At present, low-carbon energy consumption structures mainly based on renewable energy sources such as wind power and photovoltaic are vigorously developed in China, and high-proportion renewable energy source grid connection is a basic characteristic of future power systems. Renewable energy power generation is random, intermittent and fluctuating, and brings more operating pressure to the system. In order to cope with peak shaving pressure caused by random output of wind power generation, a dispatcher often needs to configure a rotating standby with high capacity. Because wind power output has certain anti-peak-shaving characteristics, when the wind power output is higher at night, the load is in the low valley, the load level is higher in the daytime, the wind power output is smaller, the load peak-valley difference of the system is indirectly enlarged, the peak shaving pressure of the system is increased, the system is easy to face the situation of insufficient flexibility resources, and the waste of renewable energy power generation resources is often caused. The traditional unit combination model does not take electrochemical energy storage and flexible load into consideration at the same time and relies on a thermal power generating unit and a gas power generating unit to carry out peak shaving. Thermal power generating units and gas-electric power generating units which are used as peak shaving units often need to be started and stopped frequently, the running condition that the load rate is not high when the load of the thermal power generating units is low is easily caused, and the running efficiency of the system is reduced.
Disclosure of Invention
In view of the above, the present invention provides a multi-type power source co-scheduling method based on peak-valley time-of-use electricity prices, so as to overcome or at least partially solve the above problems in the prior art.
In order to achieve the above object, the present invention provides a multi-type power supply cooperative scheduling method based on peak-valley time-of-use electricity price, comprising the following steps:
s101, acquiring the day-ahead predicted output of each wind power plant through a wind power prediction system;
s102, constructing corresponding mathematical models according to the operating characteristics and system safety constraints of different types of power generating units, wherein the different types of power generating units comprise a thermal power generating unit, a hydroelectric generating unit, a nuclear power generating unit, a wind power generating unit and electrochemical energy storage;
s103, solving to obtain the change condition of the load after implementing the time-of-use electricity price mechanism according to the proportion of the transferable load in the total load;
and S104, solving the mathematical model by taking the minimum total system operation cost as an objective function to obtain the start-up and shut-down plans and the pre-output data of the power supply units of different types, the charge-discharge time period and the charge-discharge power of the electrochemical energy storage and the scheduling condition of interruptible loads.
Further, the constraint conditions of the thermal power generating unit include:
Figure BDA0003168066700000021
Figure BDA0003168066700000022
Figure BDA0003168066700000023
Figure BDA0003168066700000024
the formula (1) represents the upper and lower output limit constraints of the thermal power generating unit, wherein
Figure BDA0003168066700000025
The output power of the thermal power generating unit at the time t of the node i,
Figure BDA0003168066700000026
and
Figure BDA0003168066700000027
respectively representing the maximum value and the minimum value of the output of the thermal power generating unit; formula (2) represents the ramp rate constraint of the thermal power generating unit, ri upAnd ri downThe maximum values of the upward and downward climbing speeds of the thermal power generating unit are respectively; formula (3) represents a minimum startup time constraint of the thermal power unit; equation (4) represents the minimum shutdown time constraint of the thermal power unit.
Further, the constraint conditions of the hydroelectric generating set comprise:
Figure BDA0003168066700000028
Figure BDA0003168066700000031
Figure BDA0003168066700000032
the formula (5) represents the upper and lower output limit constraints of the hydroelectric generating set,
Figure BDA0003168066700000033
and
Figure BDA0003168066700000034
respectively representing the maximum value and the minimum value of the output of the hydroelectric generating set; equation (6) represents the ramp rate constraint of the hydroelectric generating set,
Figure BDA0003168066700000035
and
Figure BDA0003168066700000036
respectively representing the downward and upward climbing speed limit values of the hydroelectric generating set; equation (7) represents the water yield constraint of the hydroelectric generating set, WhRepresenting the maximum amount of water generated.
Further, the constraint conditions of the nuclear power generating unit include:
Figure BDA0003168066700000037
Figure BDA0003168066700000038
Figure BDA0003168066700000039
Figure BDA00031680667000000310
Figure BDA00031680667000000311
Figure BDA00031680667000000312
the formula (8) represents that the nuclear power unit can only operate in one of the operating states of full power and low power; the formulas (10) and (11) respectively represent that the full-power working state and the low-power working state of the nuclear power unit respectively operate at fixed values; equations (12) and (13) represent minimum operating time constraints that the nuclear power unit should meet in full and low power operating states, respectively.
Further, the system safety constraint also comprises a power balance constraint, a reserve capacity constraint and a line power flow constraint, wherein the expression of the power balance constraint is shown as a formula (14),
Figure BDA00031680667000000313
wherein the content of the first and second substances,
Figure BDA0003168066700000041
and
Figure BDA0003168066700000042
respectively representing the output of a thermal power generating unit, a hydroelectric generating unit, a nuclear power generating unit and a wind power generating unit at the time t of the node i;
Figure BDA0003168066700000043
and
Figure BDA0003168066700000044
respectively representing the electrochemical energy storage charging power and the electrochemical energy storage discharging power at the moment t of the node i; di,tRepresenting the load at time t of node i;
the expression for the reserve capacity constraint is shown in equation (15),
Figure BDA0003168066700000045
wherein the content of the first and second substances,
Figure BDA0003168066700000046
respectively representing the maximum output of a thermal power generating unit, a hydroelectric generating unit and a nuclear power generating unit at the time t of the node i; rtIndicating the rotational reserve capacity of the system at time t;
the expression for the line flow constraint is shown in equation (16),
Figure BDA0003168066700000047
wherein, γil、γjl、γkl、γul、γvlRespectively representing power distribution factors of a thermal power generating unit, a wind power generating unit, a hydroelectric generating unit, electrochemical energy storage and load on the power transmission line l;
Figure BDA0003168066700000048
represents the transmission power upper limit value of the transmission line l.
Further, the step S103 specifically includes the following steps:
s201, dividing the load in the system into fixed loads
Figure BDA0003168066700000049
And flexible load
Figure BDA00031680667000000410
The flexible load comprises a translatable load
Figure BDA00031680667000000411
And interruptible load
Figure BDA00031680667000000412
Determining transferable load and interruptible load at Total load Di,tThe proportion of (A) to (B):
Figure BDA00031680667000000413
Figure BDA00031680667000000414
Figure BDA00031680667000000415
wherein, a and beta are respectively the proportion of the transferable load and the interruptible load in the total load, and an elastic matrix of the time-of-use electricity quantity and the electricity price is established according to the demand price elasticity and the demand price cross elasticity:
Figure BDA0003168066700000051
in the formula (21), Qp、QfAnd QvRespectively representing the power consumption, Δ Q, in different periodsp、ΔQfAnd Δ QvRespectively representing the degree of change in power consumption, P, over different periods of timep、PfAnd PvRespectively represent the electricity prices in different periods, p, f and v respectively represent the peak, flat and valley periods, epsilonijThe elasticity coefficient represents that the time period electric quantity of the same price and the electricity price are in a reverse variation relation, and the expression of epsilon is as follows:
Figure BDA0003168066700000052
wherein P and delta P respectively represent electricity price and variation of electricity price, and L and delta L respectively represent electric quantity and variation of electric quantity;
s202, establishing a calculation model of the actual power consumption and the compensation cost of the interruptible load, wherein the actual power consumption of the interruptible load can be represented as follows:
Figure BDA0003168066700000053
Figure BDA0003168066700000054
equation (22) describes the interruptible load at time t at node i
Figure BDA0003168066700000055
And state variables of the occurrence of interrupts
Figure BDA0003168066700000056
The relationship between the two or more of them,
Figure BDA0003168066700000057
for the actual load value of the interruptible load,
Figure BDA0003168066700000058
a binary variable representing the occurrence of a load interrupt, and equation (23) representing the limit of the number of times that the system can interrupt the load with an interrupt, where NiThe maximum number of times that the interruptible load of the node i can be interrupted in the scheduling period T;
the calculation model expression of interruptible load compensation cost is as follows:
Figure BDA0003168066700000061
wherein λilloadRepresents the unit penalty cost for an interruption of the interruptible load,
Figure BDA0003168066700000062
to characterize the binary variable of the interruptible load at which the interruption occurs,
Figure BDA0003168066700000063
indicating that the load is interrupted.
Further, the step S104 specifically includes the following steps:
s301, establishing a fuel cost calculation model of the thermal power generating unit, and calculating thermal power output data;
s302, solving the mathematical model to obtain the processing condition of each type of unit, the scheduling condition of interruptible load and the total running cost of the system.
Further, the fuel cost calculation model of the thermal power generating unit is represented as:
Figure BDA0003168066700000064
supposing that the output interval of the thermal power generating unit is [ p ]min,pmax]With n +1 successively larger dots (x)0，x1，…,xk,xn)(k＝0,1,2…, n) equally divide the interval into n sub-intervals, where x0＝pmin，xn＝pmaxFor each cell, the approximation linearization is performed with secant:
Figure BDA0003168066700000065
the abscissa is represented by the SOS2 type variable of the GAMS software as:
Figure BDA0003168066700000066
and identifying the subsection interval in which the thermal power output is positioned through the SOS2 type variable, and performing linear calculation by adopting a corresponding secant.
Further, the step S302 specifically includes:
calculating the fuel cost F generated by the thermal power generating unit and the nuclear power generating unitfuel：
Figure BDA0003168066700000071
Calculating the starting and stopping cost F of the thermal power generating uniton/off：
Figure BDA0003168066700000072
Calculating the fuel cost of the nuclear power unit:
Figure BDA0003168066700000073
calculating the minimum total running cost of the system:
min F＝Ffuel+Fon/off+Fdlload (31)
compared with the prior art, the invention has the beneficial effects that:
according to the multi-type power supply cooperative scheduling method based on the peak-valley time-of-use electricity price, when the day-ahead scheduling output of each type of power supply is determined, part of loads collected by users are taken as interruptible loads to participate in power grid scheduling, and the charging and discharging behaviors of electrochemical energy storage and the change condition of transferable loads under the time-of-use electricity price mechanism are considered at the same time.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is apparent that the drawings in the following description are only preferred embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained based on these drawings without inventive efforts.
Fig. 1 is a schematic overall flow chart of a multi-type power supply collaborative scheduling method based on peak-valley time-of-use electricity price according to an embodiment of the present invention.
Fig. 2 is a graph of total daily load curve and wind farm output of the system provided by the embodiment of the invention.
Fig. 3 is a total load graph before and after the time-of-use electricity price is implemented according to the embodiment of the present invention.
Fig. 4 is a histogram of the charge/discharge power of electrochemical energy storage provided by an embodiment of the present invention.
Fig. 5 is a graph of output curves of various types of power units according to the embodiment of the present invention.
Fig. 6 is a plan for starting and stopping the thermal power generating unit after time-of-use electricity price is implemented according to the embodiment of the present invention.
Fig. 7 is a plan for starting and stopping the thermal power generating unit after time-of-use electricity price is not implemented according to the embodiment of the present invention.
Detailed Description
The principles and features of this invention are described below in conjunction with the following drawings, the illustrated embodiments are provided to illustrate the invention and not to limit the scope of the invention.
Referring to fig. 1, the present embodiment provides a method for multi-type power supply collaborative scheduling based on peak-valley time-of-use electricity price, where the method includes the following steps:
s101, acquiring the day-ahead predicted output of each wind power plant through a wind power prediction system.
In the step, the predicted output of each wind power plant of the system on the next day is obtained by using a wind power prediction system, and because the output of the wind generation set has randomness, the output is set according to the predicted output of the wind generation set in a day-ahead plan, namely, the power generation plans of other sets are arranged on the basis of considering all wind power consumption.
S102, constructing corresponding mathematical models according to the operating characteristics and system safety constraints of different types of power generating units, wherein the different types of power generating units comprise thermal power generating units, hydroelectric power generating units, nuclear power generating units, wind power generating units and electrochemical energy storage units.
And S103, solving to obtain the change condition of the load after the time-of-use electricity price mechanism is implemented according to the proportion of the transferable load in the total load.
And S104, solving the mathematical model by taking the minimum total system operation cost as an objective function to obtain the start-up and shut-down plans and the pre-output data of the power supply units of different types, the charge-discharge time period and the charge-discharge power of the electrochemical energy storage and the scheduling condition of interruptible loads.
In step S102, the constraint conditions of the thermal power generating unit include:
Figure BDA0003168066700000081
Figure BDA0003168066700000082
Figure BDA0003168066700000091
Figure BDA0003168066700000092
the formula (1) represents the upper and lower output limit constraints of the thermal power generating unit, wherein
Figure BDA0003168066700000093
The output power of the thermal power generating unit at the time t of the node i,
Figure BDA0003168066700000094
and
Figure BDA0003168066700000095
respectively representing the maximum value and the minimum value of the output of the thermal power generating unit; formula (2) represents the ramp rate constraint of the thermal power generating unit, ri upAnd ri downThe maximum values of the upward and downward climbing speeds of the thermal power generating unit are respectively; formula (3) represents a minimum startup time constraint of the thermal power unit; equation (4) represents the minimum shutdown time constraint of the thermal power unit.
The constraint conditions of the hydroelectric generating set comprise:
Figure BDA0003168066700000096
Figure BDA0003168066700000097
Figure BDA0003168066700000098
the formula (5) represents the upper and lower output limit constraints of the hydroelectric generating set, wherein
Figure BDA0003168066700000099
The output of the hydroelectric generating set at the moment t of the node i,
Figure BDA00031680667000000910
and
Figure BDA00031680667000000911
respectively representing the maximum value and the minimum value of the output of the hydroelectric generating set; equation (6) represents the ramp rate constraint of the hydroelectric generating set,
Figure BDA00031680667000000912
and
Figure BDA00031680667000000913
respectively representing the downward and upward climbing speed limit values of the hydroelectric generating set; equation (7) represents the water yield constraint of the hydroelectric generating set, WhRepresenting the maximum amount of water generated.
The power regulation of the nuclear power unit requires longer time and is not high in flexibility, so that the nuclear power unit generally runs at full power, only two working states of the nuclear power unit, namely the full power running state and the low power running state, are considered in the embodiment, and the constraint conditions of the nuclear power unit include:
Figure BDA00031680667000000914
Figure BDA00031680667000000915
Figure BDA0003168066700000101
Figure BDA0003168066700000102
Figure BDA0003168066700000103
Figure BDA0003168066700000104
wherein, the formula (8) represents that the nuclear power unit can only operate in one of the operating states of full power and low power,
Figure BDA0003168066700000105
and
Figure BDA0003168066700000106
the method comprises the following steps of respectively representing binary indicating variables of two running modes of full power and low power of a nuclear power unit, and when the variable is 1, representing that the nuclear power unit is in the running mode; the expressions (10) and (11) respectively show that the full power and low power working states of the nuclear power unit respectively operate at fixed values,
Figure BDA0003168066700000107
and
Figure BDA0003168066700000108
the power generation power of the nuclear power unit is respectively the power generation power under the full power and low power operation modes; equations (12) and (13) represent minimum operating time constraints that a nuclear power unit should meet in full and low power operating states, respectively, where Ti nu,AAnd Ti nu,GRespectively representing the minimum operation time of an A mode and a G mode of the nuclear power unit; t denotes a scheduling period.
As an optional implementation, the system safety constraints further include a power balance constraint, a reserve capacity constraint, and a line power flow constraint, wherein the power balance constraint is expressed as follows:
Figure BDA0003168066700000109
wherein the content of the first and second substances,
Figure BDA00031680667000001010
and
Figure BDA00031680667000001011
respectively representing the output of a thermal power generating unit, a hydroelectric generating unit, a nuclear power generating unit and a wind power generating unit at the time t of the node i;
Figure BDA00031680667000001012
and
Figure BDA00031680667000001013
respectively representing the electrochemical energy storage charging power and the electrochemical energy storage discharging power at the moment t of the node i; di,tRepresenting the load at time t on node i.
The expression for the reserve capacity constraint is as follows:
Figure BDA00031680667000001014
wherein the content of the first and second substances,
Figure BDA0003168066700000111
respectively representing the maximum output of a thermal power generating unit, a hydroelectric generating unit and a nuclear power generating unit at the time t of the node i; rtIndicating the rotational reserve capacity of the system at time t.
The expression for the line flow constraint is as follows:
Figure BDA0003168066700000112
wherein, γil、γjl、γkl、γul、γvlRespectively representing power distribution factors of a thermal power generating unit, a wind power generating unit, a hydroelectric generating unit, electrochemical energy storage and load on the power transmission line l;
Figure BDA0003168066700000113
represents the transmission power upper limit value of the transmission line l.
As an optional implementation manner, the step S103 specifically includes the following steps:
s201, dividing the load in the system into fixed loads
Figure BDA0003168066700000114
And flexible load
Figure BDA0003168066700000115
The flexible load comprises a translatable load
Figure BDA0003168066700000116
And interruptible load
Figure BDA0003168066700000117
Determining transferable load and interruptible load at Total load Di,tThe proportion of (A) to (B):
Figure BDA0003168066700000118
Figure BDA0003168066700000119
Figure BDA00031680667000001110
equation (17) represents the total load of the system at the time t of the node i. a and beta are respectively the proportion of the transferable load and the interruptible load in the total load, and an elastic matrix of the time-sharing electric quantity and the electricity price is established according to the demand price elasticity and the demand price cross elasticity:
Figure BDA00031680667000001111
in the formula (21), Qp、QfAnd QvRespectively representing the power consumption, Δ Q, in different periodsp、ΔQfAnd Δ QvRespectively representing the degree of change in power consumption, P, over different periods of timep、PfAnd PvRespectively represent the electricity prices in different periods, p, f and v respectively represent the peak, flat and valley periods，εijThe elasticity coefficient represents that the electric quantity and the electricity price in the time period of the same price are in a reverse variation relation, the transferable load can flexibly adjust the specific electricity utilization time period according to the peak-valley time-of-use electricity price, the elasticity coefficient of the electricity price reflects the sensitivity of the fluctuation of the electric quantity of a user to the fluctuation of the electricity price, and the expression of the electricity price coefficient epsilon is as follows:
Figure BDA0003168066700000121
wherein P and Δ P represent electricity prices and variation in electricity prices, respectively, and L and Δ L represent electric quantity and variation in electric quantity, respectively.
S202, establishing a calculation model of the actual power consumption and the compensation cost of the interruptible load, wherein the actual power consumption of the interruptible load can be represented as follows:
Figure BDA0003168066700000122
Figure BDA0003168066700000123
equation (22) describes the interruptible load at time t at node i
Figure BDA0003168066700000124
And state variables of the occurrence of interrupts
Figure BDA0003168066700000125
The relationship between the two or more of them,
Figure BDA0003168066700000126
for the actual load value of the interruptible load,
Figure BDA0003168066700000127
a binary variable representing the occurrence of a load interrupt, and equation (23) representing the limit of the number of times that the system can interrupt the load with an interrupt, where NiFor the interruptible load of node i during the scheduling period TThe highest number of interrupts that can occur.
The calculation model expression of interruptible load compensation cost is as follows:
Figure BDA0003168066700000128
wherein λilloadRepresents the unit penalty cost for an interruption of the interruptible load,
Figure BDA0003168066700000129
to characterize the binary variable of the interruptible load at which the interruption occurs,
Figure BDA0003168066700000131
indicating that the load is interrupted.
As an optional implementation manner, the step S104 specifically includes the following steps:
s301, establishing a fuel cost calculation model of the thermal power generating unit, and calculating thermal power output data.
Illustratively, the fuel cost calculation model of the thermal power generating unit is represented by a quadratic function as:
Figure BDA0003168066700000132
in the formula (25), the reaction mixture,
Figure BDA0003168066700000133
and
Figure BDA0003168066700000134
and a quadratic term, a primary term and a constant term respectively representing a quadratic function relation of fuel cost and generated power of the thermal power generating unit.
Supposing that the output interval of the thermal power generating unit is [ p ]min,pmax]With n +1 successively larger dots (x)0，x1，…,xk,xn) ( k 0,1,2, …, n) equally dividing the interval into n sub-intervals, where x0＝pmin，xn＝pmaxFor each cell, the approximation linearization is performed with secant:
Figure BDA0003168066700000135
the abscissa is represented by the SOS2 type variable of the GAMS software as:
Figure BDA0003168066700000136
in the equation (27), at most two boolean variables are 1, and therefore, the segment interval in which the thermal power output is located is identified by the SOS2 type variable, and linear calculation is performed by using the corresponding secant.
S302, solving the mathematical model to obtain the processing condition of each type of unit, the scheduling condition of interruptible load and the total running cost of the system.
In this embodiment, considering the flexible load and the multi-type power supply collaborative scheduling model of electrochemical energy storage, the total operating cost of the system in the scheduling period is minimum as an objective function, and includes two parts: fuel cost, startup and shutdown cost and interruptible load compensation cost required by power generation of the thermal power generating unit and the nuclear power generating unit, wherein the step S302 specifically comprises the following steps:
calculating the fuel cost F generated by the thermal power generating unit and the nuclear power generating unitfuel：
Figure BDA0003168066700000141
Calculating the starting and stopping cost F of the thermal power generating uniton/off：
Figure BDA0003168066700000142
Calculating the fuel cost of the nuclear power unit:
Figure BDA0003168066700000143
calculating the minimum total running cost of the system:
min F＝Ffuel+Fon/off+Fdlload (31)
in the above-mentioned formula, the first and second groups,
Figure BDA0003168066700000144
and
Figure BDA0003168066700000145
respectively representing single starting cost and stopping cost of the thermal power generating unit;
Figure BDA0003168066700000146
and
Figure BDA0003168066700000147
the method is characterized by comprising the following steps of respectively obtaining a primary term and a constant term of a fuel cost and power generation power function expression of a nuclear power unit.
In one embodiment of the invention, with reference to the existing power supply planning and grid structure of the power grid in a certain area: the area has 9 thermal power units, 3 hydroelectric power units, 5 wind power units and 2 nuclear power units. In order to highlight the influence of high-proportion wind power integration on day-ahead scheduling of the system, the installed wind power capacity of the system in the specific embodiment is enlarged to be 2.5 times of that of a reference region. Table 1 shows installed capacities and proportions of various power sources in the system, in addition, 3 electrochemical energy storages are added on the original basis, basic parameters of the electrochemical energy storages are shown in table 4, peak-valley time-of-use electricity prices in the area are shown in table 5, and a demand elastic matrix capable of transferring loads is as follows:
Figure BDA0003168066700000148
TABLE 1 installed Capacity and proportion of various power supplies of the System
Figure BDA0003168066700000149
Figure BDA0003168066700000151
TABLE 2 Total and interruptible loads for each time period of the System
Figure BDA0003168066700000152
TABLE 2 Total and interruptible loads for each time period of the System (see Table above)
Figure BDA0003168066700000153
TABLE 2 Total and interruptible loads for each time period of the System (see Table above)
Figure BDA0003168066700000154
TABLE 3 basic parameters of thermal power generating units
Figure BDA0003168066700000155
TABLE 4 basic parameters of electrochemical energy storage
Figure BDA0003168066700000156
Figure BDA0003168066700000161
TABLE 5 Peak-to-valley time-of-use Power rates in certain areas
Figure BDA0003168066700000162
The load and wind power output curve is shown in fig. 2, the peak load time period is 10-12, the maximum wind power output time period is 5-6, the wind power output presents a certain degree of inverse peak regulation characteristic, the peak regulation pressure of partial thermal power generating units, hydroelectric power peak regulation units and other peak regulation units is increased, and the economical efficiency of system operation is influenced. The electricity consumption of the partial load in each time interval is adjusted by implementing the time-of-use electricity price, and the adjusted load curve is shown in fig. 3. As can be seen from FIG. 3, the peak load before adjustment is 4000.78MW, the valley load is 2613.13MW, and the load peak-to-valley difference before adjustment is 1387.65 MW; by carrying out load transfer, the adjusted peak charge is 3728.72MW, the valley charge is 2858.18MW, the load peak-valley difference after the time-of-use electrovalence mechanism is implemented is 870.54MW, and the load peak-valley difference is reduced by 37.26% in the same ratio. It can be seen that the user is guided to spontaneously adjust the electricity utilization time period according to the time-of-use electricity price mechanism, the load peak-valley difference can be effectively reduced, and the operation pressure of the system is relieved.
As can be seen from fig. 4, the charging period of the electrochemical energy storage is mainly concentrated in periods 3 to 7, wherein the maximum charging power of the electrochemical energy storage occurs in periods 5 to 6, and the maximum charging power of each group of energy storage systems is 100MW, 60MW, respectively, for a total of 260 MW. The charging period of electrochemical energy storage is mainly concentrated at night, the wind power output is large, and the load is small; the maximum discharge period of the electrochemical energy storage is periods 8 and 9, the loads adjusted in the periods 8 and 9 respectively reach 3286.06MW and 3296.40MW, and the period 9 is the minimum wind power output period in the whole scheduling cycle. Therefore, the electrochemical energy storage participates in the coordinated optimization operation of the multiple types of power supplies of the system, the peak-reversal regulation characteristic of wind power output can be improved, electric energy is stored when wind power is surplus and the load is low, the operation pressure when the load of the system is high and the wind power output is insufficient can be relieved, the time-space transfer of the wind power is realized, and the economical efficiency of the operation of the system is improved.
As can be seen from fig. 5, the nuclear power generating units all operate according to full power output, the nuclear power generating units serve as base load units, the system fully consumes the wind power generating units according to the predicted output of the wind power generating units, the thermal power generating units mainly serve as waist load units, and part of the thermal power generating units and the hydroelectric power generating units serve as peak shaving units. The electrochemical energy storage is charged when the wind power output is large at night and the load is at the valley, and is discharged when the wind power output level is low at the peak of the electricity consumption in the daytime, so that the peak regulation effect is also realized.
As can be seen from fig. 6, the operated thermal power generating units are G2, G4, G5, G6 and G9, the operated thermal power generating units are operated as base load units in the scheduling cycle in the whole period, the periods 1 to 6 are load valley periods at night, and when the period is from 7 to 24 in the daytime, although the load is increased, the output of the thermal power generating units is not increased, so that the operating efficiency of the thermal power generating units is improved.
As can be seen from fig. 7, in the case of not implementing the time-of-use electricity price, the thermal power generating units that are operated are G1, G2, G5, G6, G8 and G9, wherein the thermal power generating units G2, G5, G6 and G9 are operated as base load units in the whole period of the scheduling cycle, and the periods 1 to 6 are the nighttime load valley periods, so that the rest of the thermal power generating units are not turned on. When the day time interval is from 7 to 24, the load is increased, the G1 and G8 of the thermal power generating unit are added to exert the power output, and the peak regulation effect is exerted. Compared with the situation of implementing time-of-use electricity price, the power of a thermal power generating unit needs to be newly added, and the operation efficiency of the thermal power generating unit is not high.
It can be seen from table 6 that the fuel cost of the system operation is reduced after the time-of-use electricity price is implemented, the times of starting and stopping the thermal power generating unit are reduced, and the economy of the whole system operation is improved to a certain extent.
TABLE 6 System operating economics around real-time-of-use electricity prices
Figure BDA0003168066700000171
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.

Claims (9)

1. A multi-type power supply cooperative scheduling method based on peak-valley time-of-use electricity price is characterized by comprising the following steps:
s101, acquiring the day-ahead predicted output of each wind power plant through a wind power prediction system;
s102, constructing corresponding mathematical models according to the operating characteristics and system safety constraints of different types of power generating units, wherein the different types of power generating units comprise a thermal power generating unit, a hydroelectric generating unit, a nuclear power generating unit, a wind power generating unit and electrochemical energy storage;
s103, solving to obtain the change condition of the load after implementing the time-of-use electricity price mechanism according to the proportion of the transferable load in the total load;
and S104, solving the mathematical model by taking the minimum total system operation cost as an objective function to obtain the start-up and shut-down plans and the pre-output data of the power supply units of different types, the charge-discharge time period and the charge-discharge power of the electrochemical energy storage and the scheduling condition of interruptible loads.
2. The multi-type power supply collaborative scheduling method based on peak-valley time-of-use electricity price according to claim 1, wherein the constraint conditions of the thermal power generating unit include:
Figure FDA0003168066690000011
Figure FDA0003168066690000012
Figure FDA0003168066690000013
Figure FDA0003168066690000014
the formula (1) represents the upper and lower output limit constraints of the thermal power generating unit, wherein
Figure FDA0003168066690000015
The output power of the thermal power generating unit at the time t of the node i,
Figure FDA0003168066690000016
and
Figure FDA0003168066690000017
respectively representing the maximum value and the minimum value of the output of the thermal power generating unit; formula (2) represents the ramp rate constraint of the thermal power generating unit,
Figure FDA0003168066690000018
and
Figure FDA0003168066690000019
the maximum values of the upward and downward climbing speeds of the thermal power generating unit are respectively; formula (3) represents a minimum startup time constraint of the thermal power unit; equation (4) represents the minimum shutdown time constraint of the thermal power unit.
3. The peak-valley electricity price-of-time based multi-type power supply collaborative scheduling method according to claim 1, wherein the constraint conditions of the hydroelectric generating set include:
Figure FDA0003168066690000021
Figure FDA0003168066690000022
Figure FDA0003168066690000023
the formula (5) represents the upper and lower output limit constraints of the hydroelectric generating set,
Figure FDA0003168066690000024
and
Figure FDA0003168066690000025
respectively representing the maximum value and the minimum value of the output of the hydroelectric generating set; equation (6) represents the ramp rate constraint of the hydroelectric generating set,
Figure FDA0003168066690000026
and
Figure FDA0003168066690000027
respectively representing the downward and upward climbing speed limit values of the hydroelectric generating set; equation (7) represents the water yield constraint of the hydroelectric generating set, WhRepresenting the maximum amount of water generated.
4. The peak-valley electricity price-of-time based multi-type power supply collaborative scheduling method according to claim 1, wherein the constraint conditions of the nuclear power generating unit include:
Figure FDA0003168066690000028
Figure FDA0003168066690000029
Figure FDA00031680666900000210
Figure FDA00031680666900000211
Figure FDA00031680666900000212
Figure FDA00031680666900000213
the formula (8) represents that the nuclear power unit can only operate in one of the operating states of full power and low power; the formulas (10) and (11) respectively represent that the full-power working state and the low-power working state of the nuclear power unit respectively operate at fixed values; equations (12) and (13) represent minimum operating time constraints that the nuclear power unit should meet in full and low power operating states, respectively.
5. The method of claim 1, wherein the system safety constraints further include a power balance constraint, a reserve capacity constraint, and a line power flow constraint, the power balance constraint is expressed as formula (14),
Figure FDA0003168066690000031
wherein the content of the first and second substances,
Figure FDA0003168066690000032
and
Figure FDA0003168066690000033
respectively representing the output of a thermal power generating unit, a hydroelectric generating unit, a nuclear power generating unit and a wind power generating unit at the time t of the node i;
Figure FDA0003168066690000034
and
Figure FDA0003168066690000035
respectively representing the electrochemical energy storage charging power and the electrochemical energy storage discharging power at the moment t of the node i; di,tRepresenting the load at time t of node i;
the expression for the reserve capacity constraint is shown in equation (15),
Figure FDA0003168066690000036
wherein the content of the first and second substances,
Figure FDA0003168066690000037
respectively representing the maximum output of a thermal power generating unit, a hydroelectric generating unit and a nuclear power generating unit at the time t of the node i; rtIndicating the rotational reserve capacity of the system at time t;
the expression for the line flow constraint is shown in equation (16),
Figure FDA0003168066690000038
wherein, γil、γjl、γkl、γul、γvlRespectively representing power distribution factors of a thermal power generating unit, a wind power generating unit, a hydroelectric generating unit, electrochemical energy storage and load on the power transmission line l;
Figure FDA0003168066690000039
represents the transmission power upper limit value of the transmission line l.
6. The method according to claim 1, wherein the step S103 specifically comprises the following steps:
s201, dividing the load in the system into fixed loads
Figure FDA00031680666900000310
And flexible load
Figure FDA00031680666900000311
The flexible load comprises a translatable load
Figure FDA00031680666900000312
And interruptible load
Figure FDA00031680666900000313
Determining transferable load and interruptible load at Total load Di,tThe proportion of (A) to (B):
Figure FDA0003168066690000041
Figure FDA0003168066690000042
Figure FDA0003168066690000043
wherein, a and beta are respectively the proportion of the transferable load and the interruptible load in the total load, and an elastic matrix of the time-of-use electricity quantity and the electricity price is established according to the demand price elasticity and the demand price cross elasticity:
Figure FDA0003168066690000044
in the formula (21), Qp、QfAnd QvRespectively representing the power consumption, Δ Q, in different periodsp、ΔQfAnd Δ QvRespectively representing the degree of change in power consumption, P, over different periods of timep、PfAnd PvRespectively represent the electricity prices in different periods, p, f and v respectively represent the peak, flat and valley periods, epsilonijThe elasticity coefficient represents that the time period electric quantity of the same price and the electricity price are in a reverse variation relation, and the expression of epsilon is as follows:
Figure FDA0003168066690000045
wherein P and delta P respectively represent electricity price and variation of electricity price, and L and delta L respectively represent electric quantity and variation of electric quantity;
s202, establishing a calculation model of the actual power consumption and the compensation cost of the interruptible load, wherein the actual power consumption of the interruptible load can be represented as follows:
Figure FDA0003168066690000046
Figure FDA0003168066690000051
equation (22) describes the interruptible load at time t at node i
Figure FDA0003168066690000052
And state variables of the occurrence of interrupts
Figure FDA0003168066690000053
The relationship between the two or more of them,
Figure FDA0003168066690000054
for the actual load value of the interruptible load,
Figure FDA0003168066690000055
a binary variable representing the occurrence of a load interrupt, and equation (23) representing the limit of the number of times that the system can interrupt the load with an interrupt, where NiThe maximum number of times that the interruptible load of the node i can be interrupted in the scheduling period T;
the calculation model expression of interruptible load compensation cost is as follows:
Figure FDA0003168066690000056
wherein λilloadRepresents the unit penalty cost for an interruption of the interruptible load,
Figure FDA0003168066690000057
to characterize the binary variable of the interruptible load at which the interruption occurs,
Figure FDA0003168066690000058
indicating that the load is interrupted.
7. The method according to claim 1, wherein the step S104 specifically comprises the following steps:
s301, establishing a fuel cost calculation model of the thermal power generating unit, and calculating thermal power output data;
s302, solving the mathematical model to obtain the processing condition of each type of unit, the scheduling condition of interruptible load and the total running cost of the system.
8. The peak-valley electricity price-of-time based multi-type power supply collaborative scheduling method according to claim 7, wherein a fuel cost calculation model of the thermal power generating unit is expressed as:
Figure FDA0003168066690000059
supposing that the output interval of the thermal power generating unit is [ p ]min,pmax]With n +1 successively larger dots (x)0，x1，…,xk,xn) (k 0,1,2, …, n) equally dividing the interval into n sub-intervals, where x0＝pmin，xn＝pmaxFor each cell, the approximation linearization is performed with secant:
Figure FDA00031680666900000510
the abscissa is represented by the SOS2 type variable of the GAMS software as:
Figure FDA0003168066690000061
and identifying the subsection interval in which the thermal power output is positioned through the SOS2 type variable, and performing linear calculation by adopting a corresponding secant.
9. The method according to claim 7, wherein the step S302 specifically includes:
calculating the fuel cost F generated by the thermal power generating unit and the nuclear power generating unitfuel：
Figure FDA0003168066690000062
Calculating the starting and stopping cost F of the thermal power generating uniton/off：
Figure FDA0003168066690000063
Calculating the fuel cost of the nuclear power unit:
Figure FDA0003168066690000064
calculating the minimum total running cost of the system:
min F＝Ffuel+Fon/off+Fdlload (31)
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