JP2022165295A - Power demand adjustment system, power demand adjustment method, power demand adjustment program, and recording medium of them - Google Patents

Abstract

To provide a power demand adjustment system, a power demand adjustment method, a power demand adjustment program, and a recording device of them, which is effective for stably supplying in a general power transmission and distribution business operator by suppressing an output vibration of a power generator to achieve both of economical efficiency and controllability.SOLUTION: A power system demand adjustment system comprises: a price database 21 that stores a price previously set with a function in each power generator connected to a power system or in each output of the power generator; an AR distribution part 26 that allocates a local request power (AR) to the power generator in accordance with the function of the price of each power generator by taking in the price of each power generator from the price database 21; a real time EDC calculation part 32 that calculates a real time EDC value of the power generator; and a command value formation part 22 that forms a target command value from the real time EDC value and an allocation result of the AR.SELECTED DRAWING: Figure 1

Description

The present invention relates to an electric power supply and demand adjustment system, an electric power supply and demand adjustment method, an electric power supply and demand adjustment program, and a recording medium thereof for adjusting supply and demand of an electric power system.

Currently, with the legal unbundling of general power transmission and distribution companies, it is planned to introduce a supply and demand adjustment market for general power transmission and distribution companies to procure balancing power. When designing a supply and demand adjustment market, it is necessary to satisfy the following requirements: ensuring neutrality in market operations and price transparency, realizing efficient supply and demand adjustment using market mechanisms, and stably procuring the necessary adjustment capacity. .

Therefore, disclosure of supply and demand adjustment market prices, merit order power generation based on adjustment costs, utilization of power sources other than conventional general electric utilities and demand response (hereinafter referred to as DR), power sources with high adjustment flexibility (frequency A mechanism for evaluating power supply for adjustment) is being considered. In particular, it is essential to ensure fairness and transparency in the procurement and operation of balancing capacity from the perspective of smoothly promoting the introduction of a balancing market. Supply and demand adjustment by merit order is important.

Patent No. 3930218 Patent No. 4856468 Japanese Patent Application No. 2015-184056

Currently, when allocating the regional demand (AR) to each generator, priority is given to controllability by making use of the response characteristics of the generator, such as the output change speed ratio. Since it will be allocated according to the adjustment cost by introducing it, there will be a trade-off relationship between economic efficiency and controllability, which may lead to a decrease in controllability. It should be noted that the power generator for supply and demand adjustment referred to here includes not only normal power generators such as thermal power and hydraulic power, but also power sources such as storage batteries and DR.

The embodiments of the present invention have been made in view of the above circumstances, and are effective in achieving both economic efficiency and controllability, and suppressing the output oscillation of the generator to provide a stable supply of electricity to general power transmission and distribution companies. An object of the present invention is to provide an adjustment system, an electric power supply and demand adjustment method, an electric power supply and demand adjustment program, and a recording medium thereof.

In order to achieve the above problems, the power supply and demand adjustment system according to this embodiment includes the following components.
(1) A detector that detects the amount of frequency change (ΔF) and the amount of power flow change (ΔPT) in the power system.
(2) A setting unit for setting the power interchange amount (P0) in the power system.
(3) An AR calculation unit that calculates a regional power demand (AR) using the frequency change amount (ΔF), the interconnection line power flow change amount (ΔPT), and the power interchange amount (P0).
(4) an AR smoothing unit for smoothing the area demand power (AR);
(5) A price database that stores a price set by a function for each generator connected to the power system or for each output of the generator.
(6) an AR allocation unit that takes the price from the price database and allocates the area demand power (AR) to the generator according to a function of the price caused by fluctuations in output of the generator;
(7) A real-time EDC calculator for calculating the real-time EDC value of the generator.
(8) A command value creation unit that creates a target command value from the real-time EDC value and the result of allocation of the regional power demand (AR).
(9) A command value transmission unit that transmits the target command value to the generator.

Embodiments of the present invention can also be regarded as a power supply and demand adjustment method in which a computer executes the operations of the above components, a power supply and demand adjustment program that causes a computer to perform the operations of the above components, and a recording medium for the power supply and demand adjustment program. can.

1 is a configuration diagram of a power system supply and demand adjustment system according to a first embodiment; Flowchart showing supply and demand adjustment processing in the first embodiment A diagram outlining the LFC model according to the merit order Diagram showing the allocation method based on the price difference (left: when instructed to lower, right: when instructed to raise) Diagram showing the upward adjustment price (Up) and downward adjustment price (Down) for each generator Diagram showing an example of the upward adjustment price (V1), the downward adjustment price (V2), and the generator current price (P _NOW )/planned price (P _PLAN ) Diagram showing price transitions with current output changes A diagram showing price transitions as planned values change A diagram showing the price difference at the time of raising orders and the distribution coefficient according to the price ranking Diagram showing the price difference at the time of the down order and the distribution coefficient according to the price ranking Main part configuration diagram of power system supply and demand adjustment system in the fourth embodiment A diagram showing an example of a case where the starting point of averaging is determined every 30 minutes in the modification of the fourth embodiment. Main part configuration diagram of power system supply and demand adjustment system in the fifth embodiment Diagram showing an example of linear approximation of upward adjustment (V1) price/downward adjustment (V2) Diagram showing Merit Order List Synthesis Method (Based on Planned Value) Diagram showing Merit Order List Synthesis Method (Based on Current Price) Principal part configuration diagram of power system supply and demand adjustment system in the sixth embodiment

(First embodiment)
[Constitution]
A first embodiment of the power supply and demand adjustment system will be described with reference to FIG. The first embodiment is an electric power supply and demand adjustment method in which a computer executes the operation of each component constituting an electric power supply and demand adjustment system, or an electric power supply and demand adjustment program and an electric power supply and demand adjustment that cause a computer to execute the operation of each component. It can also be regarded as a recording medium for programs.

FIG. 1 is a configuration diagram of the first embodiment. Among the symbols in FIG. 1, 1 indicates a power system, 2 a computer, 3 another system, 4 an interconnection line, and 5 an MMI (man-machine interface). The electric power system 1 is interconnected with another system 3 via an interconnection line 4 .

A plurality of generators G1, G2, . The generator G may be regarded not only as a single generator G, but also as a power generation unit including the generator G. The types of the generator G include, for example, a high-speed machine such as a hydraulic machine, a medium-speed machine such as an oil-fired power machine, a low-speed machine such as a coal-fired power machine, and the like.

The power system 1 may be connected in parallel with natural energy power generation units that utilize natural energy (also referred to as natural energy power generation units for short). Natural energy power generation units include, for example, photovoltaic power generation units, wind power generation, ocean current power generation, geothermal power generation, and the like. Also, in the power system 1, a ΔF detection unit 7 that detects the amount of frequency change (ΔF) in the power system 1, a ΔPT detection unit 8 that detects the amount of change in the power flow (ΔPT) of the interconnection line, A setting unit 9 is provided for setting the amount of electric power (P0). The ΔF detection unit 7 and the ΔPT detection unit 8 respectively transmit the detected frequency change amount (ΔF) and interconnection line power flow change amount (ΔPT) to the computer 2, and the setting unit 9 calculates the set power interchange amount (P0). The data is transmitted to the computer 2.

The computer 2 is composed of a computer or the like, and is installed in a control room or the like that performs power monitoring control. The calculator 2 includes generator output input units 201 to 20n (abbreviated as generator output input unit 20) and command value generators 221 to 22n (abbreviated as command and command value transmission units 231 to 23n (also abbreviated as command value transmission unit 23) for transmitting the target command value to each generator G are provided.

Each generator G and computer 2 are connected to a generator output input section 20 and a command value transmission section 23 in each computer 2 via a signal line 11 for detection and a signal line 12 for control. The information from the generator output input unit 20 is transmitted to the command value creation unit 22, after which the command value creation unit 22 creates a target command value for each generator G, and the command value transmission unit 23 generates each power generation. It is transmitted to machine G.

The calculator 2 is provided with a price database 21 , an AR calculation section 24 , an AR smoothing section 25 , an AR allocation section 26 and a real-time EDC calculation section 32 . The price database 21 is a storage unit that stores a price set by a function for each generator G connected to the electric power system 1 or for each output of the generator G (hereinafter simply referred to as the price of the generator G). The price set as a function for each generator G or for each output of the generator G is set discretely, that is, stepwise, for example. In the first embodiment, a price corresponding to the current output of the generator G is stored as the price stored in the price database 21 . Note that the price database 21 may be provided within the computer 2, or may be provided outside the computer 2, for example, in a cloud or the like.

The AR calculation unit 24 inputs the frequency change amount (ΔF), the interconnection line power flow change amount (ΔPT), and the power interchange amount (P0), and uses these to calculate the regional demand power (AR). The AR smoothing unit 25 receives the regional demand power (AR) calculated by the AR calculation unit 24 and smoothes it. The AR distribution unit 26 takes in the price of the generator G from the price database 21, distributes the regional demand power (AR) smoothed for each generator G according to the price function, and obtains the distribution result of the regional demand power (AR) is input to the command value generation unit 22 .

The real-time EDC calculator 32 calculates a real-time EDC value for each generator G and inputs the real-time EDC value to the command value generator 22 . When the current value is used as a reference, the command value creation unit 22 inputs the output signal of each generator G, the real-time EDC value, and the distribution result of the regional demand power (AR), and from these, the target for each generator G Create a command value. When the planned value is used as a reference, the command value creation unit 22 inputs the planned value of each generator G, the real-time EDC value, and the distribution result of the regional demand power (AR), and from these, for each generator G Create a target command value. The command value transmission unit 23 transmits the target command value created by the command value creation unit 22 to each generator G. FIG.

(Summary of supply and demand adjustment)
EDC stands for Economic Load Dispatch (EDC). This EDC and load frequency control (LFC: Load Frequency Control, hereinafter referred to as LFC) are collectively called supply and demand adjustment. An outline of supply and demand adjustment is described below.

The demand (load) of the electric power system constantly fluctuates seasonally, temporally, and instantaneously. The load fluctuations are thought to be caused by the superimposition of various vibrations with small fluctuation widths, pulsating components with periodicity, and irregular fluctuation components. It is mainly divided into three components: a fringe component for short-period fluctuations of up to about ten minutes, and a sustain part for long-period fluctuations of ten minutes or more.

Cyclic period fluctuations of several minutes can be adjusted by optimizing the characteristics of the governor in power plants that operate in governor-free operation. As for the fluctuation, the LFC detects the frequency deviation and the amount of power fluctuation to adjust the output of the generator. In addition, since the sustain portion can be considered as part of the variation governed by the daily load curve, the economic operation of the power plant is the main subject, and the EDC adjusts the supply.

The main purpose of LFC is to maintain the interconnector power flow and system frequency constant, and to carry out the most economical operation plan in EDC. The LFC commands output adjustment of each generator connected to the electric power system according to changes in the frequency of the system and the power flow of the interconnection line with other systems at the central load dispatching center. This output adjustment command is not issued to all power generators, but is issued to oil-fired thermal power units and hydraulic power units that do not cause problems even if rapid output fluctuations are performed, and is issued to nuclear power units and coal-fired thermal power units. Furthermore, for operational reasons, power generation units (power supply facilities that include generators and supply power to the power system) are generally not issued output adjustment commands.

(LFC)
In this way, in the LFC, since the command is issued from the central load dispatching center, there is generally a delay of several tens of seconds before the output of the generator actually changes. There are three types of LFC, and most electric power companies in Japan use the TBC method (3).

(1) Constant frequency control method (FFC method) that detects the amount of frequency change (ΔF) and adjusts the output of the power generation unit to reduce ΔF, and only maintains the grid frequency at the specified value.
(2) Constant-interconnection power control (FTC) that detects the amount of change in the power flow of the interconnection line (ΔPT) and adjusts the output of the power generation unit to reduce ΔPT, and maintains only the interconnection line power flow at a specified value method)
(3) Frequency bias that detects frequency variation (ΔF) and interconnection line power flow variation (ΔPT), calculates regional demand power (AR) from these, and adjusts the output of the power generation unit according to that amount Tie line power control (TBC method)

LFC of the TBC method is performed in the following procedure.
[1] Using the frequency variation (ΔF) and the interconnection line power flow variation (ΔPT), calculate the regional power demand (AR) using formula (a).
AR=−K・ΔF+ΔPT (a)
where AR: area demand [MW]
K: system constant [MW/Hz]
ΔF: frequency deviation [Hz]
ΔPT: Interconnection power flow deviation [MW]
Power flow into own system is in positive direction If the value of Regional Electricity Request (AR) is positive, it is necessary to increase the output of the power generating units in the system as a whole. Conversely, if the value is negative, it is necessary to reduce the output of the power generating units in the system as a whole.

[2] When filtering the regional power demand (AR), filter by exponential smoothing, etc. using the past regional power demand (AR), and reduce the regional power demand (AR) to a low-speed machine slow thermal power plant) and high speed plant (for example, hydraulic power plant with fast output change speed). In addition, there is also a method in which the area demand power (AR) is frequency-decomposed, and low-speed machines share short-cycle components, and high-speed machines share long-cycle components.

[3] When distributing filtered or frequency-resolved area demand power (AR) to each power generation unit, for all power generation units where supply and demand adjustment is performed separately for low-speed machines and high-speed machines, the power generation unit or the output margin ratio.

[4] When calculating the target command value for each power generation unit, calculate by adding the distributed regional demand power (AR), the real-time EDC value calculated by EDC, or the current output. In some cases, the target command value is provided with upper and lower limits so that it does not deviate from a certain reference value.

[5] Each power generation unit receives a target command value from the central load dispatching center, and the output of each power generation unit fluctuates, resulting in changes in the system frequency and the power flow of the interconnection line.
[6] Return to step [1].

(EDC)
The EDC commands output adjustments of each generator at the central dispatch center for the slow and large changes seen in the daily load curve. This slow load change can be predicted with great accuracy from past experience. It is common to determine the output of the power generation unit to be the lowest cost, ie less fuel cost, for this predicted load. The most common method is the equal incremental fuel cost rule (equal lambda method).

An example of the equal lambda method, which is used in most electric power companies in Japan, will be described below. EDC is to issue a power generation unit command for output adjustment to each power generation unit from the central load dispatch center of each electric power company, and is carried out according to the following procedure.

[1] Set the initial value of λ.
[2] Calculate the output of each generating unit equal to λ. If this value is below the minimum output, set it to the minimum output, and if it is above the maximum output, set it to the maximum output.
[3] Calculate the total output of the power generating units.

[4] If the total output is less than the load, increase λ. Conversely, if the total output exceeds the load, decrease λ.
[5] Repeat [2] to [4] above until the total output and the load are sufficiently close.
By adjusting the output of the generator in the manner described above, control is performed to bring the frequency of the entire system and the power flow of the interconnection line between power companies closer to the prescribed values.

[action]
FIG. 2 is a flowchart showing AR allocation processing in the first embodiment. First, the amount of change in frequency (ΔF) and the amount of change in power flow (ΔPT) detected from the power system 1 are input to the AR calculation unit 24 in the computer 2, where the area demand power (AR) is calculated. (step S20). Next, the AR smoothing unit 25 smoothes the regional demand power (AR) (step S21).

Then, the AR allocation unit 26 obtains the distribution value of the regional demand power (AR) for each generator G (step S22), and the real-time EDC calculation unit 32 obtains the EDC value of each generator G ( step S204). The command value generator 22 receives the regional demand power (AR) and the EDC value of each generator G and generates a target command value (step S23). After that, the target command value is transmitted by the command value transmitter 23 (step S24), and the target command value is output to each generator G (step S25).

As shown in FIGS. 1 and 2, in the first embodiment, the regional power demand (AR) after smoothing is distributed to each generator G. FIG. In the AR distribution unit 26 according to the first embodiment, when distributing the regional demand power (AR), instead of using the conventional output change speed ratio or the output margin ratio, It captures the price and distributes it according to this price function. More specifically, the regional demand power (AR) is distributed by using a function based on the price difference of the generator G caused by the output fluctuation of the generator G. Such a method of distributing the regional power demand (AR) can be said to be a method of distributing according to the merit order, in which the price corresponding to the output of the generator G, that is, the adjustment cost can be selected in descending order.

A method of distributing the smoothed regional demand power (AR) to each generator G according to the merit order will be specifically described below. Standards for distributing the LFC control command value include a method of distributing a planned value and a method of distributing a current output.

FIG. 3 shows an overview of the LFC model. As shown in FIG. 3, the value (ΔP') after considering the change amount constraint between control cycles from the LFC allocation amount (ΔP) is the planned value (P _PLAN ) or current output (P _NOW ) of each generator G. , and the target command value is determined. When the area demand power (AR) after smoothing is large, the allocation amount (ΔP) allocated to each generator G may be larger than the output changeable amount of each generator G. In this case, each generator G will respond within its current output.

（1） The following equation (1) indicates the weight of the regional demand power (AR) distribution for each generator G.

(1)

Here, "V~i" shown on the left side of equation (1) is a function of the price set for the output of each generator G. The distribution amount of the regional demand power (AR) to each generator G is calculated by the product of the regional demand power and the weight of the distribution in each generator G [AR x wi]. In addition to the output (current value) or planned output (EDC command value or BG planned value), a target command value will be created.

In order to adopt a merit-order allocation method, it is necessary to determine V~i, which is a function of the price, so that the lower the price, the larger the price when commanding an increase, and conversely, the higher the price, the higher the price when commanding a decrease. . As described above, the AR distribution unit 26 of the first embodiment takes in the price of the generator G from the price database 21, and distributes the smoothed regional power demand (AR) for each generator G according to the price function. However, as mentioned above, the area demand power (AR) is distributed by using a function based on the price difference of the generator G caused by the output fluctuation of the generator G. That is, by using the above formula (1) and the following formulas (2) to (5), the lower the price (that is, the lower the price) of the generator G at the time of the increase command, the larger the price difference becomes. weight increases. Conversely, when the price is lowered, the higher the price of the generator G (that is, the higher the price), the greater the price difference, and the greater the weight of the allocation.

（2）

（3） (When instructed to raise)

(2)

(3)

（4）

（5）
Nは使用する発電機Ｇの台数、V_MAXは各発電機Ｇの現在値（現在出力）に対応する価格の最大値、V_MINは最小値である。 (When instructed to lower)

(Four)

(Five)
N is the number of generators G to be used, V _MAX is the maximum price corresponding to the current value (current output) of each generator G, and V _MIN is the minimum price.

In FIG. 4, the right side shows the price difference when an increase command is given, and the left side shows the price difference when a drop command is given. In FIG. 4, the length of the line segment with arrows at both ends indicates the price difference. As is clear from FIG. 4, the lower the price of the generator G, the greater the price difference at the time of the increase command, and the lower the price of the generator is given priority. Conversely, when the price is lowered, the higher the price of the generator G, the greater the price difference, and the higher the price of the generator, the higher the price.

FIG. 5 shows the adjustment costs used in the merit order method. As shown in Figure 5, the prices corresponding to the output of generator G are the upward adjustment price (V1) when the output of generator G is adjusted upward, and the downward adjustment price when the output of generator G is adjusted downward. There are two types of prices called (V2). As can be seen from FIG. 5, both the upward adjustment price (V1) and the downward adjustment price (V2) are set discretely (stepwise).

In Figure 5, the upward adjustment price (V1) and the downward adjustment (V2) are set so as to be offset vertically, but the upper dark line indicates the upward adjustment price (V1), and the lower color is lighter. The line indicates the downward adjustment price (V2). The price unit is yen/kWh. The upward adjustment price (V1) and the downward adjustment price (V2) are set stepwise, meaning that even if the output of generator G on the horizontal axis changes, there is a range of output where the price remains the same. . This range of output is called the output band corresponding to the price (hereinafter simply output band).

FIG. 6 shows an example of the upward adjustment price (V1) and the downward adjustment price (V2), the current value of the generator G, and the planned value. In FIG. 6, portions indicated by P12, P23, P34, P45, and P56 are output bands corresponding to prices. The raising adjustment price (V1) is V11 for the output band P12, V12 for the output band P23, V13 for the output band P34, V14 for the output band P45, and V15 for the output band P56. The downward adjustment price (V2) is V21 for output band P12, V22 for output band P23, V23 for output band P34, V24 for output band P45, and V25 for output band P56.

[effect]
According to the first embodiment, the price database 21 stores prices discretely set for the output of the generator G, and the regional demand power for each generator G according to the price function taken in from the price database 21. and an AR allocation unit 26 for allocating (AR). Here, the price function used by the AR allocation unit 26 to allocate the regional demand power (AR) is a function based on the price difference. For this reason, in the first embodiment, when an increase command is given, the price difference between the generator G with a lower price becomes larger, and the lower price generator can be prioritized. The higher the generator G, the greater the price difference, and the higher the price generator can be given priority.

As a result, it becomes possible to allocate the regional demand power (AR) to each generator G according to the merit order, and it is possible to reliably adjust the supply and demand according to the merit order. According to such a first embodiment, from the position of neutrality of system operators with respect to market participants, contributing to ensuring fairness and transparency in procurement of adjustment capacity by general power transmission and distribution companies It can contribute to the improvement of the quantity and quality of procureable reserve capacity through the participation of various power generation companies, etc., and the more efficient utilization of reserve capacity by general power transmission and distribution companies.

In addition, in the first embodiment, since the AR allocation unit 26 allocates the regional demand power (AR) to each generator G according to a function based on the price difference of each generator G, the generator G having a large price difference Area demand power (AR) will be distributed as much as possible. For this reason, it is possible to reflect the size of the price difference in the distribution of regional power demand (AR). Therefore, it is possible to contribute to the realization of regional power demand (AR) distribution that emphasizes economic efficiency.

(Second embodiment)
By the way, when the output of the generator G changes so that the output band changes from P23 to P34 in Fig. 6, if the price is raised (V1), the price will increase by the price difference V13-V12 (yen/kWh). If it is the downward adjustment price (V2), the price will be higher by the price difference V23-V22 (yen/kWh). Conversely, if the output of generator G changes so that the output band changes from P34 to P23, the price will be lower by the amount of the price difference V13 - V12 (yen/kWh) if the adjusted price is raised (V1). Therefore, if the downward adjustment price (V2) is used, the price will be reduced by the price difference V23-V22 (yen/kWh).

Here, if the output changes across the output band corresponding to the discretely set prices, and if such changes occur frequently, the price will change frequently. Taking the discretely set prices on the horizontal axis and looking at changes in price over time, for example, when the current output of generator G shown in FIG. 7 changes, V2⇒V1⇒V2⇒V3⇒V4 In addition, prices will change frequently. Such a phenomenon can occur both during upward adjustment and during downward adjustment.

If the price changes frequently like this, the values of the price functions shown in the above formulas (1) to (5) will also change significantly. As a result, the amount of change in the target command value that is output to the generator G also inevitably increases, and there is a possibility that the generator G will experience output oscillation. Therefore, as a means for suppressing the output oscillation of the generator G, it is effective to suppress price changes. The following second to fifth embodiments are examples of power supply and demand adjustment systems capable of suppressing price changes according to the output of the generator G and suppressing output oscillations of the generator G. .

[Constitution]
One of the reasons why the price changes frequently is that the price is based on the current output price of the generator G, which changes from moment to moment. In the second embodiment, the price stored in the price database 21 is not the price corresponding to the current output of the generator G, but is based on a planned value that is constant during a certain period (for example, a 30-minute period). A price is set and stored, and the AR distribution unit 26 distributes the regional demand power (AR) to each generator G according to the price function based on this planned value. More specifically, it allocates regional demand (AR) according to a function based on the price difference based on the plan value.

[Action and effect]
In the second embodiment, the price database 21 stores prices based on the preset planned output of the generator G, and the AR distribution unit 26 calculates the price difference A function based on , and distributes the regional demand power (AR) for each generator G. As for the planned value, the output of the generator G is constant during a certain period (for example, a 30-minute period), so the output does not change across the output band, and the price never change. In other words, changes in the planned output are not as frequent as the current output of the generator G, and price changes can be suppressed. Therefore, the amount of change in the target command value output to the generator G can be kept within a certain range, and the output oscillation of the generator G can be effectively suppressed.

For example, the price associated with the change in the current output shown in FIG. 7 frequently transitions like V2⇒V1⇒V2⇒V3⇒V4. On the other hand, in the second embodiment, as shown in FIG. 8, it is possible to greatly reduce the transition of price from V1 to V3, which accompanies the change in planned value. According to the second embodiment as described above, the target command value for the generator G can be stably output, and the controllability can be improved while ensuring economic efficiency.

(Third Embodiment)
In the above-described second embodiment, the price is determined according to the current output of the generator G as a price change factor, but the price change factor is not limited to this. For example, a function based on price differentials can itself be a factor in frequent price changes. In other words, if the regional power demand (AR) is distributed based on the price difference, the larger the price difference, the easier the regional power demand (AR) will be distributed, and the share to other generators G will be reduced accordingly. It will be. As a result, the output fluctuation of the generator G may increase.

[Constitution]
Therefore, in the third embodiment, the regional requested power (AR) is distributed according to the order of price instead of distributing the regional requested power (AR) according to the function using the price difference. This is because even if the price changes over the output band of the generator G, the ranking of the prices assigned to the prices of the plurality of generators G may not change. The price database 21 according to the third embodiment stores the price ranking of each generator G, and the AR allocation unit 26 takes in the price ranking from the price database 21, and based on the price ranking, the generator G Area demand power (AR) is distributed to each area. Even with such an allocation, the AR allocating unit 26 will allocate the regional demand power (AR) to each generator G according to the price function.

In the third embodiment, a reference frequency is set in advance as the frequency of price changes accompanying output changes across the output band of the generator G, and output changes across the output band of the generator G are set in advance. If the frequency of price changes associated with , exceeds the reference frequency, the regional demand power (AR) may be distributed to each generator G based on the order of prices. FIG. 9 shows the price difference and the distribution coefficient associated with the price ranking when instructing an increase, and FIG. 10 shows the price difference and the distribution coefficient associated with the price ranking when instructing a decrease.

[Action and effect]
In the third embodiment, the AR allocation unit 26 fetches the price rankings from the price database 21, determines allocation coefficients according to the price rankings, and allocates the regional power demand (AR) to each generator G. FIG. Therefore, in the third embodiment, it is possible to stably distribute the regional requested power (AR) compared to the case where the regional requested power (AR) is distributed using a function based on the price difference, and the power generation Fluctuations in the target command value output to machine G can be suppressed.

As described above, in the third embodiment, the AR distribution unit 26 distributes the regional demand power (AR) to each generator G in order of price, thereby suppressing fluctuations in the target command value and Output vibration can be easily suppressed. As a result, it becomes possible to more stably construct a power supply and demand adjustment system that achieves both economic efficiency and controllability. In addition, as a third embodiment, it is also possible to allocate the regional power demand (AR) using a monotonically increasing function value of the order instead of the order of the price.

(Fourth embodiment)
[Constitution]
FIG. 11 shows a configuration diagram of the essential parts of the fourth embodiment. As shown in FIG. 11, in the fourth embodiment, an average output calculator 33 is provided within the calculator 2 . The average output calculator 33 obtains the average output per unit time of the current output of the generator G. FIG. The AR distribution unit 26 takes in the average output from the average output calculation unit 33 and distributes the regional power demand (AR) to each generator G according to the price function corresponding to this average output. As the price that does not change as much as the price according to the current output of the generator G, a price corresponding to the average output per unit time of the current output of the generator G may be used.

[Action and effect]
In the fourth embodiment, the average output calculation unit 33 obtains the average output per unit time at the current output of the generator G, and the AR distribution unit 26 calculates for each generator G according to the price function corresponding to this average output. Allocate Area Requested Power (AR). Therefore, in the fourth embodiment, compared to the current output of the generator G, which changes from moment to moment, a relatively stable average output can be derived, and price fluctuations corresponding to this average output are reduced, The variability of the value of the function based on the price difference is also reduced. Therefore, fluctuations in the target command value output to the generator G are suppressed, and the output oscillation of the generator G is less likely to occur.

According to the fourth embodiment as described above, the target command value for the generator G can be stably output, output oscillation of the generator G can be avoided, and controllability can be ensured while ensuring economic efficiency. can be improved. Moreover, in the fourth embodiment, it is possible to use the amount of electric power for 30 minutes (which corresponds to the average output) for adjusting the price, which is the adjustment cost.

In addition, as a modification of the fourth embodiment, instead of the average price over a certain period of time in the past, for example, as shown in FIG. 12, the starting point of averaging is changed every 30 minutes, You can ask for it. According to such an embodiment, it is possible to suppress the output vibration of the generator G more reliably, and it is possible to improve the economic efficiency and the controllability in a well-balanced manner.

(Fifth embodiment)
[Constitution]
As the price that does not change as much as the price according to the current output of the generator G, in addition to the price corresponding to the average output per unit time shown in the fourth embodiment, for example, a discretely set price There is an approximate price that is a linear approximation of Therefore, as shown in FIG. 13, in the fifth embodiment, an approximate price calculator 34 is provided in the computer 2. FIG. The approximate price calculator 34 obtains an approximate price by linearly approximating the price stored in the price database 21 . The AR allocator 26 receives the approximate price from the approximate price calculator 34 and allocates the regional power demand (AR) to each generator according to a function of the approximate price.

[Action and effect]
In the fifth embodiment, the approximate price calculation unit 34 obtains an approximate price of discretely set prices, and the AR allocation unit 26 allocates the regional power demand (AR) to each generator G according to the function of the approximate price. be able to. Therefore, as shown in Figure 14, there is no sudden step-like change in the upward adjustment price (V1) or the downward adjustment price (V2), and the fluctuation of the value of the function based on the price difference becomes moderate. .

Therefore, even if the target command value output to the generator G fluctuates, the fluctuation is smooth, and the output oscillation of the generator G can be effectively suppressed. Therefore, the target command value for the generator G can be stably output, and the economy and controllability can be efficiently improved.

In the linear approximation of the price, instead of obtaining one linear approximation for the maximum and minimum widths, it is also possible to use an approximate price represented by a piecewise linear line corresponding to each output band. In such an embodiment, the variation in the value of the function based on the price difference is more gradual, and the variation in the target command value output to the generator G is also smoother. As a result, it is possible to suppress the output oscillation of the generator G more efficiently.

(Sixth embodiment)
As shown in FIGS. 1 and 2, in the above embodiment, after the AR distribution unit 26 distributes the regional demand power (AR) of each generator G, the command value creation unit 22 creates the target command value. It will happen. The command value creation unit 22 calculates the target command value using, for example, formula (6) or formula (7). is to be selected.

Target command value = Area demand power (AR) + BG planned value (6)
Target command value = area demand power (AR) + current output (7)

15 and 16, the generation of the target command value by the formulas (6) and (7) will be explained. When the command value generator 22 adopts the formula (6), it generates the target command value as shown in FIG. In this case, the concept of the BG planned value reference is similar to imbalance settlement, and since the BG planned value is used as the reference, adjustment costs can be reduced, which is advantageous in terms of economy. On the other hand, since the BG planned value does not greatly deviate, it becomes difficult for the generator G to follow the target command value, and controllability may be sacrificed.

Also, when the command value generator 22 adopts the formula (7), the target command value is generated as shown in FIG. In this case, since the current output is used as a reference, the generator G can follow the target command value well. Therefore, there is an advantage in terms of controllability, but on the other hand, there is a possibility that the BG value will greatly deviate from the planned value, and the adjustment cost will increase, sacrificing economy.

In normal operation, it is common to adopt the formula (6) and use the EDC function based on the BG planned value, and the LFC function to cover the deviation from that as the distribution value of the regional demand power (AR). . As mentioned earlier, these functions can be selected by the operator from formulas (6) and (7), but basically, formula (6), which emphasizes economic efficiency, is more suitable for operation. often desirable. However, when distributing the area demand power (AR) by the merit order method, there is a possibility that the target command value will be insufficient by adding up from the BG planned value.

(Constitution)
FIG. 17 shows a configuration diagram of the essential parts of the sixth embodiment. As shown in FIG. 17, in the sixth embodiment, determination units 351 to 35n (also referred to as determination unit 35 for short) are connected to command value generation units 221 to 22n.

The determination unit 35 determines whether or not a target command value is reached by accumulating the regional demand power (AR) distributed to each generator G from a preset BG plan value. When the determination unit 35 determines that the target command value is reached by accumulating from the BG planned value, the command value creation unit 22 creates the target command value using the BG planned value (that is, employs the above equation (6) ).

Further, when the determination unit 35 determines that the target command value cannot be reached by adding up the BG planned value, the command value creation unit 22 takes in the current output of the generator G instead of the BG planned value and uses the current output. to create the target command value (that is, the above formula (7) is adopted). It should be noted that Σ is the sum of the generators G to be subjected to LFC control.

(action)
The determination unit 35 switches between formulas (6) and (7) under the following conditions <1> and <2>.
<1> When the regional demand power (AR) exceeds 0, that is, when it is "at the time of adjustment to increase", the determination unit 35 makes a judgment based on [regional demand power AR+ΣBG planned value≦Σcurrent output].
<2> When the regional power demand (AR) is less than 0, that is, during "lower adjustment", the determination unit 35 makes a determination based on [regional power demand AR+ΣBG planned value≧Σcurrent output].

Under any condition, when the determining unit 35 determines that the target command value is insufficient by adding up the BG planned value, the command value generating unit 22 generates the target command value using the formula (7). Further, if the determination unit 35 determines that the target command value is sufficient by building up the BG planned value, the command value creation unit 22 creates the target command value using equation (6).

(effect)
According to the sixth embodiment as described above, when the regional demand power (AR) is distributed according to the merit order, when the determination unit 35 determines that the target command value is sufficient by accumulating from the BG planned value In this case, the command value generating unit 22 can adopt the formula (6) to ensure the economic advantage.

Further, when the judgment unit 35 judges that there is a possibility that the target command value is insufficient by accumulating from the BG planned value, the command value creation unit 22 adopts the above equation (7) and accumulates from the current output. to create the desired target command value. Therefore, when distributing the regional demand power (AR) according to the merit order, it is possible to obtain a target command value based on the current output, so that the generator G follows well and controllability is improved.

[Other embodiments]
While embodiments including variations have been described, these embodiments are provided by way of example and are not intended to limit the scope of the invention. These embodiments can be implemented in various other forms, and various omissions, replacements, and modifications can be made without departing from the scope of the invention. These embodiments and their modifications are included in the scope and spirit of the invention, as well as the scope of the invention described in the claims and equivalents thereof.

For example, in addition to the price database 21, the computer 2 may include a price function based on the price difference of the price corresponding to the output of the generator G, or a database for storing the order of the price. Also good. In addition, in the above fourth and fifth embodiments, the components for obtaining the average output and the approximate price are independently provided in the calculator 2, but this is not restrictive. The regional power demand (AR) may be allocated after setting the price based on the output fluctuation of the AR distribution unit 26, or after setting the price linearly approximated by the AR allocator 26, the regional power demand (AR) may be allocated. may Further, the prices stored in the price database 21 are not limited to those set discretely, and may be prices set continuously.

1: Power system 2: Calculator 21: Price database 20: Generator output input unit 22: Command value creation unit 23: Command value transmission unit 24: AR calculation unit 25: AR smoothing unit 26: AR distribution unit 3: Other system 32 : Real-time EDC calculator 33: Average output calculator 34: Approximate price calculator 35: Judgment unit 4: Interconnection line 5: MMI (man-machine interface)
6: Natural energy power generation unit G: Generator 7: ΔF detection unit 8: ΔPT detection unit 9: Setting unit

Claims (9)

a detection unit that detects a frequency change (ΔF) and a power flow change (ΔPT) in a power system;
a setting unit that sets the power interchange amount (P0) in the power system;
an AR calculation unit that calculates a regional power demand (AR) using the frequency change amount (ΔF), the interconnection line power flow change amount (ΔPT), and the power interchange amount (P0);
an AR smoothing unit that smoothes the area demand power (AR);
a price database that stores a price set by a function for each generator connected to the power system or for each output of the generator;
an AR allocation unit that takes the price from the price database and allocates the area demand power (AR) to the generators according to a function of the price;
a real-time EDC calculator that calculates a real-time EDC value of the generator;
a command value creation unit that creates a target command value from the distribution result of the real-time EDC value and the regional power demand (AR);
and a command value transmission unit that transmits the target command value to the generator. 2. The power supply and demand adjustment system according to claim 1, wherein said price database stores said price set based on a preset planned output of said generator. The price database stores a price ranking assigned to the prices set for the plurality of generators or a monotonically increasing function value of the ranking;
3. The electric power supply and demand adjustment system according to claim 1, wherein said AR allocating unit allocates said regional power demand (AR) to each of said power generators based on said order or said monotonically increasing function value. An average output calculation unit for obtaining an average output per unit time of the generator,
4. The electric power supply and demand adjustment system according to claim 1, wherein said AR allocating unit allocates said regional power demand (AR) to each said generator according to a price function corresponding to said average output. An approximate price calculation unit that obtains an approximate price by linearly approximating the price,
5. The power supply and demand adjustment system according to any one of claims 1 to 4, wherein said AR allocating unit allocates said regional demand power (AR) to each said generator according to said approximate price function. A determination unit that determines whether or not the target command value is reached by accumulating the regional demand power (AR) distributed to each generator from a preset planned value,
The command value creation unit is
When the determination unit determines that the target command value is reached, the target command value is created using the planned value,
The electric power according to any one of claims 1 to 5, wherein when the determination unit determines that the target command value is not reached, the current output of the generator is taken in and the target command value is created using the current output. Supply and demand adjustment system. a detection step of detecting frequency variation (ΔF) and interconnection line power flow variation (ΔPT) in a power system;
a setting step of setting the power interchange amount (P0) in the power system;
an AR calculation step of calculating a regional demand power (AR) using the frequency change amount (ΔF), the interconnection line power flow change amount (ΔPT), and the power interchange amount (P0);
an AR smoothing step of smoothing the area demand power (AR);
a price storing step of storing the price set by the function for each generator connected to the electric power system or for each output of the generator;
an AR allocation step of taking the price from the price database and allocating the area demand (AR) to the generators according to a function of the price;
a real-time EDC calculation step of calculating a real-time EDC value of the generator;
a command value creation step of creating a target command value from the distribution result of the real-time EDC value and the regional power demand (AR);
and a command value transmission step of transmitting the target command value to the generator. An electric power supply and demand adjustment program for a computer provided in an electric power supply and demand adjustment system,
a detection step of detecting frequency variation (ΔF) and interconnection line power flow variation (ΔPT) in a power system;
a setting step of setting the power interchange amount (P0) in the power system;
an AR calculation step of calculating a regional demand power (AR) using the frequency change amount (ΔF), the interconnection line power flow change amount (ΔPT), and the power interchange amount (P0);
an AR smoothing step of smoothing the area demand power (AR);
a price storing step of storing the price set by the function for each generator connected to the electric power system or for each output of the generator;
an AR allocation step of taking the price from the price database and allocating the area demand (AR) to the generators according to a function of the price;
a real-time EDC calculation step of calculating a real-time EDC value of the generator;
a command value creation step of creating a target command value from the distribution result of the real-time EDC value and the regional power demand (AR);
and a command value transmission step of transmitting the target command value to the generator. A recording medium recording the power supply and demand adjustment program according to claim 8 .

Images