JP7660493B2 - Power system control device, power system control method and program - Google Patents

Description

The present invention relates to a power system control device, a power system control method, and a program.

The abstract of the following Patent Document 1, which is a background technology of this technical field, states that "In a method for operating a distributed power system having a generator that is connected to or disconnected from a distribution line and a generator control device that controls the generator, a voltage fluctuation limit amount at a connection point when the generator transitions from a connected state to a disconnected state is set, and the generator control device acquires an output fluctuation amount of the generator and a voltage fluctuation amount at the connection point, and, assuming that the output of the generator and the voltage at the connection point fluctuate at the same rate, calculates an estimated voltage drop amount at the connection point when the generator transitions from a connected state to a disconnected state based on a ratio of the reference output of the generator to the output fluctuation amount and the voltage fluctuation amount, determines whether the estimated voltage drop amount is within the range of the voltage fluctuation limit amount, and, if it is determined that the estimated voltage drop amount is outside the range of the voltage fluctuation limit amount, adjusts the operating power factor of the generator so that the estimated voltage drop amount falls within the range of the voltage fluctuation limit amount."

JP 2007-53866 A

However, in the above-mentioned technology, there is a demand for more appropriate control of the power system.
The present invention has been made in consideration of the above-mentioned circumstances, and an object of the present invention is to provide a power system control device, a power system control method, and a program that can appropriately control a power system.

To solve the above problem, the power system control device of the present invention comprises: a power generation amount acquisition unit that acquires a predetermined type of power generation amount, which is a power generation amount belonging to a predetermined type in each of a plurality of areas included in a power system; a system configuration acquisition unit that acquires system configuration information including the line impedance of the transmission line in the plurality of areas; a system countermeasure planning unit that plans system countermeasures for the power system; and a control instruction unit that outputs an area control command that commands the power factor of a generator included in any of the plurality of areas. The system countermeasure planning unit is characterized by comprising an effect evaluation unit that evaluates the effect of changing the power factor of the generator based on the predetermined type of power generation and the system configuration information and outputs the evaluation result as evaluation data; and a system countermeasure review unit that causes the control instruction unit to output the area control command based on the evaluation data.

The present invention allows for proper control of the power system.

FIG. 2 is a schematic diagram of a power system etc. in the first embodiment. FIG. 1 is a block diagram of a computer. FIG. 2 is a block diagram showing the functions of a power system control device. FIG. 11 is a diagram showing an example of wide area cross-sectional information. FIG. 13 is a diagram showing a configuration of contingency condition data; FIG. 11 is a diagram showing another example of wide area cross-sectional information. FIG. 13 is a diagram showing an example of a system fault analysis screen. FIG. 13 is a diagram showing yet another example of wide area cross-sectional information. FIG. 13 is a diagram showing another example of the system fault analysis screen. FIG. 4 is a diagram showing an example of a generator power factor curve in the first embodiment. FIG. 4 is a diagram illustrating an example of a transmission line voltage in the first embodiment. FIG. 11 is a diagram showing an example of a generator power factor curve in the second embodiment. FIG. 11 is a diagram illustrating an example of a transmission line voltage in the second embodiment. FIG. 11 is a block diagram of a power system control device according to a third embodiment. FIG. 13 is a diagram illustrating an example of a benefit evaluation table. FIG. 13 is a diagram illustrating an example of an investment cost evaluation table. FIG. 13 is an explanatory diagram of the operation of an investment cost-benefit evaluation unit.

[Overview of the embodiment]
The Paris Agreement was adopted at the 21st Conference of the Parties to the United Nations Framework Convention on Climate Change (COP21) in 2015, and a new international framework for reducing greenhouse gas emissions from 2020 onwards was laid out. Japan's goal is to reduce greenhouse gas emissions by 26.0% in 2030 compared to 2013 levels, and by 80% in 2050. To achieve this goal, the Agency for Natural Resources and Energy, in its 2015 Long-Term Energy Supply and Demand Outlook, has set a mid-term target of a renewable energy ratio of 22-24% in the power generation mix in 2030. Under this policy, Japan is promoting the introduction of renewable energy (RE), such as solar, wind, biomass, geothermal and hydroelectric power. The share of RE in Japan's total power generation has increased from 12% in 2014 to 16% in 2019, and this ratio is expected to continue to increase.

However, it is expected that power grids to which RE is connected will face various challenges, including supply and demand balance, excess transmission capacity, voltage fluctuations, frequency fluctuations, and stability. This is due to the fact that the output of variable renewable energy (VRE) such as solar and wind power generation is affected by ever-changing weather conditions, the reduction in the number of thermal power synchronous generators reduces system inertia, and the limited number of suitable locations for solar and wind power generation increases the transmission capacity when delivering electricity from VRE generation sites to demand sites, making it easy for localized transmission line overloads to occur.

In response to these issues, grid expansion plans are being made to ensure a stable supply of VRE electricity from supply points to demand points. For example, within Japan, for offshore wind power generation in Chiba and off the coast of Akita, where an increase in future connections is expected, construction is being planned to increase the number of transmission lines to Tokyo, an area of demand, and to increase transmission capacity. Similarly, for solar power generation in Kyushu, where an increase in future connections is also expected, plans are being made to increase the operating capacity of the Chugoku-Kyushu interconnector. However, the enormous costs involved in these grid expansion plans is an issue.

In this situation, where it is necessary to consider not only simply increasing the proportion of VRE but also stability and economic efficiency at the same time, it is important to ensure the stability of the power system while reducing investment by improving the control of existing facilities. One example of improving the control of existing facilities is power factor adjustment of generators. Power factor adjustment is the adjustment of the ratio of active power and reactive power supplied from the power source generated by the power source. Active power is the power consumed to operate home appliances, for example. Reactive power is not consumed as electricity, but has the effect of maintaining the voltage of the power system by inputting and outputting energy from the power source according to the system situation. Originally, power companies aim to sell electricity, so they operate various devices to increase the proportion of active power as much as possible. However, it is thought that improving system stability by reactive power will become important in the future to address the decrease in stability of the power system due to the increase in VRE.

By applying the technology of Patent Document 1 described above, it is believed that a distributed power system can be constructed that calculates an estimated voltage drop at the interconnection point from the generator output of the distributed power source and the interconnection state to the distribution line, and adjusts the operating power factor of the wind power generator. In this way, adjusting the power factor of an existing generator has the advantage that it can be achieved more cheaply than installing new equipment to address issues such as a shortage of reactive power supply due to an increase in the amount of renewable energy connected. However, as mentioned above, conventional generators generate as much active power as possible, and generate reactive power as needed depending on the voltage at the substation to which they are connected. Therefore, they do not have a process to generate reactive power according to instructions for power factor adjustment from an external agency, even if it means compromising economic efficiency.

The challenges involved in establishing such a process will be summarized from the perspective of the electricity transmission and distribution business operators responsible for stabilizing the grid, and the power generation business operators who own generators. For electricity transmission and distribution business operators, for example, when electricity is generated in Kyushu and transmitted to the main demand area in Kansai, the power generation and demand areas are geographically separated, and electricity is transmitted across each area. This creates a challenge for them when considering measures to deal with power grid accidents; they are increasingly required to take into account not only the power grid area under their own jurisdiction, but also the power grids under the jurisdiction of other electricity transmission and distribution business operators. This is due to the fact that suitable locations for introducing renewable energy are ubiquitous, and the power generation and consumption areas are geographically separated.

For this reason, it is preferable to establish a framework for collecting data from different electricity transmission and distribution companies when identifying issues that arise when such long-distance power transmission occurs and when determining the generator power factor to resolve these issues. In addition, power generation companies have the challenge of having difficulty determining the generator power factor required for grid stabilization on their own, as there is no process for them to receive instructions directly from electricity transmission and distribution companies regarding power factor adjustment. Furthermore, as mentioned above, operating a generator in a way that adjusts the power factor and outputs a lot of reactive power can potentially reduce economic efficiency, so it is preferable to establish a mechanism that allows power generation companies to enjoy benefits for contributing to grid stabilization.

In the embodiment described later, a system is realized that integrates information from the power transmission and distribution business operator and the power generation business operator to adjust the power factor of the generator and improve system stability. Details will be described later, but in the embodiment described later, the power transmission and distribution business operator creates a cross section of a wide-area power system that simulates the power system of each area, such as one that spans multiple power companies. Next, a system analysis is performed on the created wide-area power system, and generators that can contribute to improving system stability by changing the power factor are extracted. Based on the extraction result, the power generation business operator adjusts the power factor of the generator and adjusts the ratio and amount of active power and reactive power. It is preferable to build a mechanism in which the power transmission and distribution business operator and the power generation business operator share the benefits of the adjustment result, such as an increase in the amount of VRE connection, and mutually benefit from it. In this way, according to the embodiment described later, a system in which the power transmission and distribution business operator and the power generation business operator exchange information together makes it possible to achieve a reduction in greenhouse gas emissions by improving the stability of the power system while reducing the cost of reinforcing the system.

[First embodiment]
<Power System>
FIG. 1 is a schematic diagram of a power system 250 and the like in the first embodiment.
The power system 250 is divided into a plurality of (n) areas AR-1 to AR-n. Some of these areas AR-1 to AR-n include a power plant 252. The power plant 252 may be, for example, a thermal or nuclear power plant, or may be a renewable energy power plant. Some of the areas AR-1 to AR-n include generators 260, 262, and 264. The generators 260, 262, and 264 are mainly synchronous generators and may include a flywheel or the like. These generators may be components of the power plant 252. The power system control device 100 controls the power factor and the like of each of the generators 260, 262, and 264.

Each area AR-1 to AR-n may be under the jurisdiction of the same electricity transmission and distribution business operator, or may be under the jurisdiction of different electricity transmission and distribution business operators. Furthermore, in the following explanation, when there are multiple components or information that have the same or similar functions or meanings, they may be explained by adding a "-" and a numerical value to the same reference symbol, for example, "Area AR-1" and "Area AR-n". However, when there is no need to distinguish between these multiple components, they may be explained by omitting the numerical value and adding a "-", for example, "Area AR".

Power System Control Device
FIG. 2 is a block diagram of a computer 900 .
The power system control device 100 shown in Fig. 1 includes one or more computers 900 shown in Fig. 2. In Fig. 2, the computer 900 includes a CPU 901, a RAM 902, a ROM 903, a HDD 904, a communication I/F 905, an input/output I/F 906, and a media I/F 907. The communication I/F 905 is connected to a communication circuit 915. The input/output I/F 906 is connected to an input/output device 916. The media I/F 907 reads and writes data from a recording medium 917. The ROM 903 stores a control program executed by the CPU, various data, and the like. The CPU 901 executes an application program loaded into the RAM 902 to realize various functions.

Figure 3 is a block diagram showing the functions of the power system control device 100, and each block in the diagram shows a function realized by an application program or the like. That is, the power system control device 100 includes an RE power generation amount acquisition unit 110 (power generation amount acquisition means, power generation amount acquisition unit, power generation amount acquisition step), a system configuration acquisition unit 120 (system configuration acquisition step, system configuration acquisition means), a system countermeasure planning unit 130 (system countermeasure planning step, system countermeasure planning means), a control instruction unit 140 (control instruction step, control instruction means), and a display control unit 150. Note that "RE" is an abbreviation for renewable energy.

(RE power generation amount acquisition unit 110)
The RE power generation amount acquisition unit 110 includes an RE database 112. The RE database 112 stores RE introduction amounts PR-1 to PR-n (renewable energy power generation amount, predetermined type power generation amount) and RE introduction prediction values PRE-1 to PRE-n (predetermined type power generation amount, prediction value). Here, the RE introduction amounts PR-1 to PR-n represent the current introduction amount of renewable energy (power generation amount by renewable energy) in each area AR-1 to AR-n (see FIG. 1) of the power system 250. In addition, the RE introduction prediction values PRE-1 to PRE-n are prediction values of the RE introduction amounts PR-1 to PR-n in the future. Here, the renewable energy is, for example, the power generation amount by onshore wind power, offshore wind power, solar power, wave power, tidal power, running water, geothermal power, or biomass. However, the renewable energy is not limited to these.

(System configuration acquisition unit 120)
The system configuration acquisition unit 120 includes a system configuration database 122. The system configuration database 122 stores system configuration information DD-1 to DD-n for each of the areas AR-1 to AR-n (see FIG. 1). Each system configuration information DD includes the following information for the area:
- System configuration (connection of transmission and distribution lines),
- Line impedance of each transmission line (R + jX),
- Capacitance to earth of each transmission line (susceptance: jB),
- System configuration included in future system expansion plan information,
Specifications of the generators included in the area. Furthermore, the system configuration information DD includes various data other than those mentioned above for various power flow calculations, state estimation, and time series change calculations.

(System Measures Planning Unit 130)
The system countermeasure planning unit 130 refers to various information acquired from the RE power generation amount acquisition unit 110 and the system configuration acquisition unit 120, plans system countermeasures for the power system, and evaluates the effects of the various information for power system reinforcement planning. The system countermeasure planning unit 130 includes a wide-area system cross-section creation unit 131, a contingent fault condition selection unit 132, a system impact evaluation unit 133, a system countermeasure review unit 135 (system countermeasure review step, system countermeasure review means), and an effect evaluation unit 136 (effect evaluation step, effect evaluation means). The system countermeasure planning unit 130 stores system reinforcement plan information that identifies locations where system reinforcement is required based on a wide-area power system 250 that covers the power systems of each area.

(Wide-area system cross section creation unit 131)
The wide-area system cross section creation unit 131 generates wide-area cross section information DE and area cross section information DF-1 to DF-n based on the RE introduction prediction value PRE and the system configuration information DD. Here, the wide-area cross section information DE is information that represents a power system cross section (time cross section) that covers each of the areas AR1 to An, and is information that simulates the state of the power system 250 when renewable energy is connected. In addition, the area cross section information DF-1 to DF-n is information that represents a power system cross section (time cross section) for each of the areas AR-1 to AR-n.

However, RE output, generator output, etc. change in various ways over a period of time, such as from one day to one year. For this reason, the wide-area system cross-section creation unit 131 creates area cross-section information DF and wide-area cross-section information DE for multiple time cross-sections. The number of time cross-sections created varies depending on the state of the target power system 250 (see Figure 1), but it is a good idea to divide a day into several hours and prepare a collection of these for one year. For example, if one day is divided into 24 hours, the cross-sections for one year will be 24 x 365 = 8640 cross-sections.

(Contemplated fault condition selection unit 132)
The contingent fault condition selection unit 132 creates contingent fault condition data DG to evaluate stability when an accident occurs in the power system 250, based on the wide area cross section information DE and area cross section information DF created by the wide area system cross section creation unit 131. Here, an accident in the power system is, for example, a ground fault accident in a power transmission line, a generator dropping out, etc. The stability evaluated by the contingent fault condition data DG is, for example, synchronous stability, voltage stability, frequency stability, etc.

(System Impact Assessment Unit 133)
The system influence evaluation unit 133 calculates system constraint conditions DI before the system fault (normal time) and at the time of the system fault based on the wide area cross section information DE, the area cross section information DF, and the contingent fault condition data DG. Here, the system constraint conditions DI include the generator internal phase difference angle in synchronous stability, the maximum and minimum values of the frequency in frequency stability, the load margin up to the nose point of the P-V curve in voltage stability, the transient voltage, and the transient overload.
The system influence evaluation unit 133 uses the wide area cross section information DE and area cross section information DF created by the wide area system cross section creation unit 131 to simulate the contingency fault cases (see FIG. 5 , C1, C2, etc.) selected by the contingency fault condition selection unit 132, performs power flow calculations and transient stability calculations when a fault occurs, and evaluates stability in the event of a system accident. Then, the system influence evaluation unit 133 outputs the stability evaluation result as system influence evaluation information DJ.
Furthermore, the system influence assessment unit 133 executes a power flow calculation and a transient stability calculation when the selected contingent fault case occurs.

(System Countermeasures Examining Unit 135)
The system countermeasure examining unit 135 verifies the effect of improving system stability by regulating the power factor of the generator as a countermeasure in the case where the system constraint conditions DI cannot be satisfied in the event of a system accident, based on the system constraint conditions DI and the system impact evaluation information DJ output from the system impact evaluation unit 133. That is, the system countermeasure examining unit 135 formulates countermeasures for improving the stability of the power system based on the results of evaluation by the system impact evaluation unit 133, and outputs the results as countermeasure proposal data DM.

(Effect evaluation unit 136)
The effect evaluation unit 136 evaluates (verifies) the details of the power factor adjustment of the generator indicated in the countermeasure proposal data DM, and outputs the evaluation result as evaluation data DP to the system countermeasure review unit 135. If this evaluation data DP indicates that "the improvement of system stability can be expected to be equal to or greater than a predetermined value by adjusting the power factor of the generator," the system countermeasure review unit 135 transmits a countermeasure execution command DR, such as "change the power factor of the generator," to the control instruction unit 140 based on the countermeasure proposal data DM.

(Control instruction unit 140)
The control instruction unit 140 includes a plurality of control units 142-1 to 142-n corresponding to areas AR-1 to AR-n (see FIG. 1). The control units 142-1 to 142-n output area control commands DS-1 to DS-n to command changes in the power factor of generators to the corresponding areas AR-1 to AR-n. The control targets of the control unit 142 are generators and loads included in each area AR, but may also be batteries, chargeable and dischargeable secondary batteries, storage batteries for electric vehicles, flywheels, phase modifying equipment, and the like.

The area control commands DS-1 to DS-n output to each area AR-1 to AR-n are also transferred to the RE power generation amount acquisition unit 110 and the system configuration database 122. As a result, the RE power generation amount acquisition unit 110 updates the RE introduction forecast values PRE-1 to PRE-n based on the area control commands DS-1 to DS-n. Similarly, the system configuration acquisition unit 120 updates the contents of the system configuration information DD-1 to DD-n based on the area control commands DS-1 to DS-n.

(Display Control Unit 150)
The display control unit 150 displays various types of information in the power system control device 100 on a display or the like included in the input/output device 916 (see FIG. 2).

<Details of various information, etc.>
The above-mentioned various types of information will be described in detail below.
First, FIG. 4 is a diagram showing an example of the wide area cross-sectional information DE.
4, the wide-area cross-sectional information DE represents the state of a portion of the power system 250 (see FIG. 1). In the illustrated example, the wide-area cross-sectional information DE includes two areas AR-10 and AR-11. Area AR-10 includes an RE power generation unit 210, an electricity demand area 230, and a power transmission line 220 connecting the two. The RE power generation unit 210 is equipped with three RE power sources 212, 214, and 216.

In addition, area AR-11 includes two power demand areas 232, 234. The RE power generation unit 210 in area AR-10 and the power demand area 232 in area AR-11 are connected by a power transmission line 222. In addition, the power demand areas 232, 234 in area AR-11 are connected by a power transmission line 224. In this way, the RE power generation unit 210 supplies power to the power demand areas 230, 232, 234.

In this way, the area cross section information DF created by the wide-area system cross section creation unit 131 (see Figure 2) does not necessarily describe elements contained in one area (e.g., AR-1), but can also describe elements contained in multiple areas. That is, in the example shown in Figure 4, the area cross section information DF simulates the RE power generation unit 210, transmission line 220, and power demand area 230 in area AR-1, and the power demand areas 232, 234, and transmission line 224 in area AR-2.

FIG. 5 is a diagram showing the configuration of the contingency condition data DG.
5, a plurality of contingency condition data DG are created corresponding to various dates and times, and a set of these is called a contingency condition database 300. The contingency condition database 300 is stored in the contingency condition selection unit 132 (see FIG. 3). Each contingency condition data DG includes date and time data 301, a contingency case column 302, a fault location column 303, and a fault mode column 304. Here, the intervals between the date and time data 301 in the plurality of contingency condition data DG may be any interval.

The assumed fault case column 302 stores the numbers (C1, C2, ...) of assumed fault cases corresponding to various fault modes. The fault location column 303 stores the assumed fault location. The fault mode column 304 stores the line phase, number of lines, fault mode, etc. related to the assumed fault.

For example, the fault mode column 304 for the contingency fault case C1 stores character string data "3φ6LG (ABCA'B'C')". The "3φ6LG" portion of this string indicates a three-phase, six-wire ground fault. Also, "(ABCA'B'C')" indicates that a ground fault has occurred between phases A, B, C, A', B', and C'. Contingency fault case C1 in FIG. 5 indicates that a three-phase, six-wire ground fault occurs at the transmission end of transmission line A1 (not shown).

Similarly, contingent fault case C2 indicates that a three-phase, six-wire ground fault occurs at the transmission end of transmission line A2 (not shown). Similarly, contingent fault case C3 indicates that a three-phase, six-wire ground fault occurs at the transmission ends of both transmission lines A1 and A2. Furthermore, contingent fault case C4 indicates that a power site PS1 (not shown) becomes disconnected. Furthermore, contingent fault case C5 indicates that a three-phase, six-wire ground fault occurs at the transmission end of transmission line B1 (not shown).

In this way, since the contingency condition database 300 contains various information, the contingency condition selection unit 132 (see FIG. 3) can select various contingency conditions. In addition, the system impact evaluation unit 133 (see FIG. 3) can calculate system impact evaluation information DJ for various contingency conditions.

FIG. 6 is a diagram showing another example of the wide area cross-sectional information DE.
The wide-area cross-sectional information DE shown in Fig. 6 is for when a grid accident occurs, and in addition to the elements shown in Fig. 4, grid accident information 401, 402, and 403 is added. These grid accident information 401, 402, and 403 are information related to accidents that have occurred in the power transmission lines 220, 222, and 224, respectively, and the illustrated positions are positions where the grid accidents occurred.

(System accident analysis screen 5)
FIG. 7 is a diagram showing an example of the system fault analysis screen 5. As shown in FIG.
The system fault analysis screen 5 is a screen displayed by the display control unit 150.
The system fault analysis screen 5 includes a system diagram display field 501 , a legend display field 504 , a date field 512 , a time field 514 , and a contingency condition selection result section 530 .

The system diagram display field 501 is an area that illustrates the system diagram of the power system 250 (see FIG. 1), and its contents are created by the wide-area system cross-section creation unit 131. In the system diagram display field 501, system information such as synchronous machine power sources, RE power sources, loads, transformers, busbars, and lines are displayed as icons and symbols. The synchronous machine power sources are, for example, the above-mentioned generators 260, 262, and 264. The legend display field 504 is an area that shows the meanings of the icons and symbols shown in the system diagram display field 501. In addition, the date field 512 and the time field 514 allow the user to specify a date and time by operation, and display the specified date and time. The contents of the system diagram display field 501 and the assumed fault condition selection result unit 530 described later change according to the date and time specified in the date field 512 and the time field 514.

The contingency condition selection result section 530 includes, in the column direction, a contingency case column 531, a power control amount column 532 and a negative control amount column 533 of the system stabilization control amount column, a generator phase angle column 534, a voltage column 535, and a frequency column 536. Using these columns, the contingency condition selection result section 530 displays the analysis results of the power flow calculation and the transient stability.

The row direction of the contingency condition selection result section 530 is contingency cases C1, C2, ..., which is the same as that of the contingency condition database 300 (see FIG. 5). The generator phase angle column 534, voltage column 535, and frequency column 536 indicate whether the system constraint condition DI can be satisfied for the generator phase angle, voltage, and frequency for the contingency cases C1, C2, ..., respectively. That is, if the system constraint condition DI can be satisfied, "○" is displayed, and if the system constraint condition DI cannot be satisfied, "×" is displayed. The system constraint condition DI is, for example, a constraint such as "the generator phase angle can be maintained at 100 degrees or less even during a system accident," and the specific content is determined appropriately depending on the configuration of the power system 250, etc.

FIG. 8 is a diagram showing still another example of the wide area cross-sectional information DE.
In the wide area cross section information DE shown in Fig. 8, in addition to the elements shown in Fig. 4, grid accident information 402 and generators 260, 262, 264 are added. This figure is a diagram for explaining the procedure for identifying a generator to be subject to power factor control. First, it is assumed that an accident related to the grid accident information 402 has occurred in the power transmission line 222. This state corresponds to the contingency fault case C4 in the contingency fault condition selection result unit 530 shown in Fig. 7. In the example shown in the contingency fault case C4 in Fig. 7, the grid constraint condition DI cannot be satisfied for any of the generator phase angle, voltage, and frequency.

This determination result that "the system constraint condition DI cannot be satisfied" is included in the system impact evaluation information DJ supplied from the system impact evaluation unit 133 (see FIG. 3) to the system measure examination unit 135. The system measure examination unit 135 then identifies the problem occurrence position PP based on the system constraint condition DI and the system impact evaluation information DJ. Here, the "problem occurrence position PP" is a position on the power system 250 where a problem occurs in which a specified power quality cannot be satisfied if the system constraint condition DI cannot be satisfied. In the example of FIG. 8, for example, the power demand area 232 is the problem occurrence position PP.

The system countermeasure examination unit 135 selects a generator that can supply inertial force and reactive power in order to improve the power quality at the problem occurrence location PP. In the example of FIG. 8, it is assumed that the generator 262 is selected. This generator 262 is connected to the power transmission line 222 on the area AR-11 side of the location of the system accident information 402. Therefore, the generator 262 is a generator that can contribute to solving the problem.

In this case, the countermeasure proposal data DM output by the system countermeasure review unit 135 includes information specifying the generator 262 and the active power and reactive power that the generator 262 should output. However, instead of the active power and reactive power that the generator 262 should output, the power factor of the generator 262 may be specified by the countermeasure proposal data DM. The system countermeasure review unit 135 also analyzes the degree of improvement in system stability by changing the power factor of the selected generator 262 for such system accident information 402. This degree of improvement in system stability is also included in the countermeasure proposal data DM.

FIG. 9 is a diagram showing another example of the system fault analysis screen 5. As shown in FIG.
The display contents in Fig. 9 are the same as those shown in Fig. 7 except for the row of the contingency case C4 in the contingency condition selection result part 530. In the row of the contingency case C4, "x → o" is displayed in the generator phase angle column 534, the voltage column 535, and the frequency column 536. This means that before the countermeasure proposal data DM is applied, it is "x" (the grid constraint condition DI cannot be satisfied), but when the countermeasure proposal data DM is applied (in the above example, when the power factor of the generator 262 is changed), it changes to "o" (the grid constraint condition DI can be satisfied).

The process by which the display contents of the system fault analysis screen 5 change from that of FIG. 7 to that of FIG. 9 will be described with reference to FIG. 3. The countermeasure proposal data DM output by the system countermeasure examination unit 135 is supplied to the effect evaluation unit 136. The effect evaluation unit 136 evaluates and verifies the effect of the indicated countermeasure proposal (changing the power factor of the generator 262 in the above example), and outputs the result as evaluation data DP. The system fault analysis screen 5 in FIG. 9 updates the display contents of the generator phase angle column 534, voltage column 535, and frequency column 536 for the assumed fault case C4 based on the contents of the evaluation data DP.

In this way, if the evaluation data DP for the countermeasure proposal data DM is positive (improvement in system stability is expected), the system countermeasure review unit 135 transmits the contents of the countermeasure proposal data DM to the control instruction unit 140 as a countermeasure execution command DR.

FIG. 10 is a diagram illustrating an example of a generator power factor curve in the first embodiment.
Here, the "generator power factor curve" indicates the range in which the ratio of the active power and the reactive power of the generator can be changed. In FIG. 10, the horizontal axis indicates the active power P, and the vertical axis indicates the reactive power Q. When the reactive power Q is positive (in the direction of the lagging supply amount 802), the generator is in an overexcitation state, and its output current is in a lagging phase. When the reactive power Q is negative (in the direction of the leading supply amount 804), the generator is in an underexcitation state, and its output current is in a leading phase. In other words, by changing the excitation current of the generator stator, the lagging supply amount 802 and the leading supply amount 804 can be adjusted, and the ratio of the active power and the reactive power can be adjusted. The dashed line 806 is the limit of the lagging power factor at the rated capacity, and the dashed line 808 is the limit of the leading power factor at the rated capacity.

Point 820 in FIG. 10 is the operating point of the generator before the fault occurs. The roughly semicircular curve passing through points 810A, 810B, 810C, and 810D in the figure is called the generator power factor curve 810. Here, points 810A and 810B shown in the figure are determined according to the maximum value of the excitation current that can be passed through the rotor coil of the generator, etc. Also, points 810B and 810C are determined according to the maximum value of the armature current that can be passed through the stator coil of the generator, etc.

In addition, points 810C and 810D are determined according to the temperature rise of the stator core and the stator core end, etc. The control unit 142 (see FIG. 3) can freely set the operating point as long as it is within the approximately semicircular region surrounded by the generator power factor curve 810 and the vertical axis. For example, the control unit 142 can move the operating point to point 822.

FIG. 11 is a diagram illustrating an example of a power transmission line voltage in the first embodiment.
In Fig. 11, the vertical axis represents the transmission line voltage V, and the horizontal axis represents time t. Voltage change characteristics 920 and 922 are characteristics when the generator operating points are points 820 and 822 (see Fig. 10), respectively. Moreover, both of the voltage change characteristics 920 and 922 are characteristics when a system accident of contingent fault case C4 (see Fig. 9) occurs at time t1. Moreover, level V1 is a voltage operation target value determined by the system operator.

If the generator's operating point is point 820 (see FIG. 10), when a system accident occurs at time t1, the transmission line voltage V will eventually fall below level V1, as shown in voltage change characteristic 920. In such a case, it is advisable to move the operating point to point 822 in FIG. 10. This causes the transmission line voltage V to change in accordance with voltage change characteristic 922, making it possible to control the transmission line voltage V so that it is at or above level V1.

[Second embodiment]
Next, a second embodiment will be described. In the following description, parts corresponding to those in the first embodiment described above are given the same reference numerals, and the description thereof may be omitted.
The configuration and operation of the second embodiment are substantially similar to those of the first embodiment (FIGS. 1 to 9). However, in the first embodiment, as shown in FIG. 10, the generator output is kept substantially constant, and the sharing ratio of active power and reactive power is changed on the generator power factor curve 810 of the generator. In contrast, in this embodiment, the generator output is changed to reduce the absolute value of the active power, thereby suppressing the power flow in the power system before a transmission line accident and improving stability during the accident.

FIG. 12 is a diagram showing an example of a generator power factor curve in the second embodiment.
The generator power factor curve 810 shown in Fig. 12 is similar to that of the first embodiment (see Fig. 10). However, in this embodiment, when the operating point of the generator before the occurrence of a fault is point 830, the control unit 142 (see Fig. 3) moves the operating point from point 830 to point 832, and then moves it to point 834. In this respect, the operation of this embodiment differs from that of the first embodiment.

In other words, in this embodiment, by moving the operating point to point 834, it is possible to significantly reduce the active power output by the generator while maintaining the reactive power output by the generator at a relatively large value. As a result, if the generator is driven by, for example, a turbine, it is possible to reduce the amount of fuel consumed by the turbine, and the generator can be operated more economically.

FIG. 13 is a diagram illustrating an example of a transmission line voltage in the second embodiment.
In FIG. 13 as well, the vertical axis is the transmission line voltage V, and the horizontal axis is the time t. Voltage change characteristics 930, 932, and 934 are characteristics when the generator operating point is at point 830, 832, and 834 (see FIG. 12), respectively. Moreover, the voltage change characteristics 930, 932, and 934 are all characteristics when a system accident of the contingency fault case C4 (see FIG. 9) occurs at time t1. Moreover, the level V2 is the operation target value in this embodiment. The voltage change 934 when the operating point is moved to point 834 can suppress the voltage drop at the time of the transmission line accident compared with the voltage change 930 before the change and the voltage change 932 during the change. For example, it is possible to adjust the transmission line voltage V so that it does not become less than the operation target value V2 of the voltage determined by the system operator.

[Third embodiment]
In the first and second embodiments described above, the operating point of the generator is moved to point 822 (see FIG. 10) or point 834 (see FIG. 12). However, moving the operating point in this way reduces the active power output by the generator. Generally, power generation companies want to output as much active power as possible to increase opportunities to sell electricity, so moving the operating point as described above creates a problem of losing opportunities to sell electricity. Therefore, in this embodiment, the power transmission and distribution company evaluates the benefits of adjusting the power factor of the generator and shares the results with the power generation company, so that the power generation company can also benefit.

14 is a block diagram of a power system control device 103 according to the third embodiment. In the following description, the same reference numerals are used to designate parts corresponding to the parts of the other embodiments described above, and the description thereof may be omitted.
The power system control device 103 includes elements similar to those of the power system control device 100 of the first embodiment (see FIG. 3 ). In addition, the power system control device 103 includes a benefit evaluation unit 152, an investment cost evaluation unit 154, and an investment cost/benefit evaluation unit 160.

FIG. 15 is a diagram showing an example of the benefit assessment table 310 stored in the benefit assessment unit 152. As shown in FIG.
The benefit assessment table 310 has an item column 312 and an assessment result column 314. The item column 312 stores various items for assessing the benefit of a change in the power factor of the generator. For example, the item column 312 stores items such as the cost of reducing fossil fuels associated with the introduction of RE, the cost of reducing carbon dioxide emission rights purchases, the cost of reducing grid reinforcement, and the like.

The evaluation result column 314 also stores the benefit amount corresponding to each of these items and a total benefit amount A (benefit) which is the sum of the benefit amounts of each of these items. The benefit evaluation unit 152 shown in FIG. 14 evaluates the benefit of the change in the power factor of the generator from an economic point of view based on this benefit evaluation table 310.

FIG. 16 is a diagram showing an example of the investment cost evaluation table 320 stored in the investment cost evaluation unit 154. As shown in FIG.
The investment cost evaluation table 320 has an item column 322 and an evaluation result column 324. The item column 322 stores various items for evaluating the investment or loss amount when changing the power factor of the generator. For example, the item column 322 stores items such as loss of electricity selling opportunity, labor costs required for generator control, and reduction in useful life due to equipment fatigue.

The evaluation result column 324 also stores the investment amount, which is the amount of investment or loss corresponding to each of these items, and the total investment amount B (investment cost), which is the sum of the investment amounts of these items. The investment cost evaluation unit 154 shown in FIG. 14 evaluates the investment cost for the change in the power factor of the generator or the loss cost due to the change in the power factor of the generator from an economic point of view based on this investment cost evaluation table 320.

FIG. 17 is a diagram illustrating the operation of the investment cost-benefit assessment unit 160.
As described above, the benefit evaluation unit 152 calculates the total benefit amount A, and the investment cost evaluation unit 154 calculates the total investment amount B. The investment cost benefit evaluation unit 160 calculates the evaluation result C for adjusting the power factor of the generator based on these amounts. The evaluation result C may be calculated, for example, by "C=A-B" or by "C=A/B". By determining the evaluation result C in this way, it becomes possible to distribute profits between the power transmission and distribution business operator and the power generation business operator. For example, when the evaluation result C is calculated by "C=A-B", the amount related to the evaluation result C can be distributed between the power transmission and distribution business operator and the power generation business operator.

[Effects of the embodiment]
As described above, according to the embodiment, the system countermeasure planning unit 130 is equipped with an effect evaluation unit 136 that evaluates the effect of changing the power factors of the generators 260, 262, 264 based on the predetermined types of power generation amounts (PR-1 to PR-n, PRE-1 to PRE-n) and the system configuration information DD-1 to DD-n and outputs the evaluation result as evaluation data DP, and a system countermeasure review unit 135 that causes the control instruction unit 140 to output area control commands DS-1 to DS-n based on the evaluation data DP.

As a result, the effect evaluation unit 136 evaluates the effect of changing the power factor of the generators 260, 262, and 264 and outputs the evaluation result as evaluation data DP, thereby enabling the power system 250 to be appropriately evaluated.

Moreover, it is more preferable that the predetermined type of power generation amount (PR-1 to PR-n, PRE-1 to PRE-n) is an amount including a renewable energy power generation amount (PR-1 to PR-n), which is the amount of power generation by onshore wind power, offshore wind power, solar power, wave power, tidal power, running water, geothermal power, or biomass, or a predicted value (PRE-1 to PRE-n) of the renewable energy power generation amount (PR-1 to PR-n). This makes it possible to appropriately suppress instability factors that occur in the power system 250 due to renewable energy power generation when the power system 250 includes a renewable energy power generation unit.

In addition, the system countermeasure planning unit 130 further includes a wide area system cross section creation unit 131 that creates wide area cross section information DE representing the contents of the power system cross section spanning multiple areas AR-1 to AR-n based on the specified types of power generation (PR-1 to PR-n, PRE-1 to PRE-n) and system configuration information DD-1 to DD-n, a contingency condition selection unit 132 that selects contingency condition data DG that represents the fault conditions to be analyzed, and a system impact evaluation unit 133 that performs power flow calculations and transient stability calculations when a fault occurs related to the selected contingency condition data DG and outputs the results as system impact evaluation information DJ, and it is even more preferable that the system countermeasure review unit 135 outputs countermeasure proposal data DM, which is the result of planning measures to improve the stability of the power system based on the system impact evaluation information DJ, and the effect evaluation unit 136 outputs evaluation data DP as the result of verifying the countermeasure proposal data DM. As a result, the system countermeasure review unit 135 can output countermeasure proposal data DM based on the system impact evaluation information DJ, and the effect evaluation unit 136 can output evaluation data DP as the verification result of the countermeasure proposal data DM.

Moreover, it is more preferable that the wide-area system cross-section creation unit 131 creates the wide-area cross-section information DE by acquiring the renewable energy power generation amounts (PR-1 to PR-n) or the forecast values (PRE-1 to PRE-n) and the system configuration information DD-1 to DD-n for the multiple areas AR-1 to AR-n from the power generation amount acquisition unit (110). This makes it possible to create a more appropriate wide-area cross-section information DE based on the renewable energy power generation amounts (PR-1 to PR-n) or the forecast values (PRE-1 to PRE-n) for the multiple areas AR-1 to AR-n and the system configuration information DD-1 to DD-n.

Moreover, it is more preferable that the system impact assessment unit 133 determines the system constraint conditions DI during accidents and normal times based on the wide-area cross-sectional information DE and the contingency condition data DG. This allows the system constraint conditions DI to be determined based on various contingency condition data DG.

Moreover, it is more preferable that the system constraint condition DI includes any one of the generator internal phase difference angle in synchronous stability, the maximum or minimum value of the frequency in frequency stability, the load margin up to the nose point of the P-V curve in voltage stability, the transient voltage, or the transient overload. This makes it possible to clarify the specific parameter values such as the generator internal phase difference angle and the maximum or minimum value of the frequency for various contingent fault condition data DG.

Moreover, when it is determined that the system constraint condition DI cannot be satisfied, it is even more preferable for the system impact assessment unit 133 to identify the problem occurrence position PP, which is the position in the power system where the problem occurs. This makes it possible to clarify the problem occurrence position PP.

Moreover, it is more preferable that the countermeasure proposal data DM includes information that identifies the generators 260, 262, 264 that can alleviate the problem at the problem occurrence position PP corresponding to the contingency condition data DG when their power factors are changed. This makes it possible to clarify the generators 260, 262, 264 that can alleviate the problem in the countermeasure proposal data DM.

Moreover, it is more preferable that the evaluation data DP includes information verifying the effect of changing the power factor of the generators 260, 262, and 264. This makes it possible to clarify the effect of changing the power factor of the generators 260, 262, and 264.

Moreover, it is more preferable that the evaluation data DP includes the results of evaluating the effects corresponding to any of the system constraint conditions DI. This makes it possible to obtain evaluation data DP according to the system constraint conditions DI.

Moreover, it is more preferable that the system countermeasure examination unit 135 transmits a countermeasure execution command DR including a command to change the power factor of the generators 260, 262, and 264 to the control instruction unit 140, and the control instruction unit 140 changes the power factor of the generators 260, 262, and 264 based on the countermeasure execution command DR. This allows the power factor of the generators 260, 262, and 264 to be changed in response to the countermeasure execution command DR.

Furthermore, after the system countermeasure examination unit 135 transmits the countermeasure execution command DR to the control instruction unit 140, it is more preferable that the control instruction unit 140 further changes the output of the generators 260, 262, and 264 based on the countermeasure execution command DR. This allows the output of the generators 260, 262, and 264 to be changed in response to the countermeasure execution command DR.

Moreover, it is even more preferable to further include a benefit evaluation unit 152 that evaluates the benefit (A) using information from the effect evaluation unit 136, an investment cost evaluation unit 154 that evaluates the investment cost (B) using information from the control instruction unit 140, and an investment cost benefit evaluation unit 160 that outputs an evaluation result C that shows the relationship between the benefit (A) and the investment cost (B). This makes it possible to obtain an evaluation result C that corresponds to the benefit (A) and the investment cost (B).

Moreover, it is more preferable that the benefit (A) relates to any one of the costs of reducing fossil fuels, the costs of purchasing carbon dioxide emission rights, or the costs of enhancing the grid. This makes it possible to obtain an evaluation result C according to the costs of reducing fossil fuels, etc.

Moreover, it is more preferable that the investment cost (B) is a cost related to any of the following: lost electricity selling opportunities, labor costs required for generator control, or reduced useful life due to equipment fatigue. This allows an evaluation result C to be obtained according to lost electricity selling opportunities, etc.

Moreover, it is more preferable that the evaluation result C is the result of dividing the benefit (A) by the investment cost (B), or the result of subtracting the investment cost (B) from the benefit (A). This allows an appropriate evaluation result C to be obtained.

[Modification]
The present invention is not limited to the above-mentioned embodiment, and various modifications are possible. The above-mentioned embodiment is exemplified to explain the present invention in an easy-to-understand manner, and is not necessarily limited to those having all the configurations described. In addition, it is possible to replace a part of the configuration of one embodiment with the configuration of another embodiment, and it is also possible to add the configuration of another embodiment to the configuration of one embodiment. In addition, it is possible to delete a part of the configuration of each embodiment, or to add or replace other configurations. In addition, the control lines and information lines shown in the figure show those that are considered necessary for explanation, and do not necessarily show all the control lines and information lines necessary on the product. In reality, it may be considered that almost all the configurations are connected to each other. Possible modifications of the above-mentioned embodiment are, for example, as follows.

(1) In the above embodiment, an example was described in which the RE introduction amount (renewable energy power generation amount or its predicted value) was applied as the "predetermined type of power generation amount." However, the "predetermined type of power generation amount" is not limited to the RE introduction amount, and any power generation amount, such as thermal power, hydroelectric power, or nuclear power, may be applied.

(2) The hardware of the power system control devices 100 and 103 in the above embodiments can be realized by a general computer, so programs for executing the various processes described above may be stored on a storage medium or distributed via a transmission line.

(3) In addition, although each of the above-mentioned processes has been described in the above embodiment as software-based processes using a program, some or all of the processes may be replaced with hardware-based processes using an ASIC (Application Specific Integrated Circuit) or an FPGA (Field Programmable Gate Array), etc.

(4) The various processes performed in the above embodiments may be executed by a server computer via a network (not shown), and the various data stored in the above embodiments may also be stored in the server computer.

100, 103 Power system control device 110 RE power generation amount acquisition unit (power generation amount acquisition means, power generation amount acquisition unit, power generation amount acquisition step)
120 System configuration acquisition unit (system configuration acquisition step, system configuration acquisition means)
130 System countermeasure planning unit (system countermeasure planning step, system countermeasure planning means)
131 Wide-area system cross-section creation unit 132 Expected fault condition selection unit 133 System impact evaluation unit 135 System countermeasures examination unit (system countermeasures examination step, system countermeasures examination means)
136 Effect evaluation unit (effect evaluation step, effect evaluation means)
140 Control instruction unit (control instruction step, control instruction means)
152 Benefit evaluation unit 154 Investment cost evaluation unit 160 Investment cost benefit evaluation unit 250 Power system 260, 262, 264 Generator 900 Computer A Total benefit amount (benefit)
B Total investment amount (investment cost)
C Evaluation result DE Wide area cross-sectional information DG Expected fault condition data DI System constraint conditions DJ System impact evaluation information DM Countermeasure proposal data DP Evaluation data DR Countermeasure execution command PP Problem occurrence location AR-1 to AR-n Area DD-1 to DD-n System configuration information DS-1 to DS-n Area control command PR-1 to PR-n RE introduction amount (renewable energy power generation amount, specified type power generation amount)
PRE-1 to PRE-n RE introduction forecast value (prescribed type of power generation, forecast value)

Claims (15)

a power generation amount acquiring unit that acquires a predetermined type of power generation amount, which is a power generation amount belonging to a predetermined type in each of a plurality of areas included in the power system;
A system configuration acquisition unit that acquires system configuration information including line impedances of power transmission lines in the plurality of areas;
A system countermeasure planning unit that plans system countermeasures for the power system;
a control instruction unit that outputs an area control command that instructs a power factor of a generator included in any one of the plurality of areas,
The system countermeasure planning unit includes:
an effect evaluation unit that evaluates an effect when a power factor of the generator is changed based on the predetermined type of power generation amount and the system configuration information, and outputs an evaluation result as evaluation data;
a system countermeasure examination unit that causes the control instruction unit to output the area control command based on the evaluation data. 2. The power system control device according to claim 1, wherein the predetermined type of power generation amount is a renewable energy power generation amount which is a power generation amount by onshore wind power, offshore wind power, solar power, wave power, tidal power, running water, geothermal power, or biomass, or an amount including a predicted value of the renewable energy power generation amount. The system countermeasure planning unit includes a wide-area system cross-section creation unit that creates wide-area cross-section information representing the contents of a power system cross-section across a plurality of the areas based on the predetermined type of power generation amount and the system configuration information;
a contingency condition selection unit that selects contingency condition data representing a fault condition to be analyzed;
a power system influence evaluation unit that performs a power flow calculation and a transient stability calculation when a fault related to the selected contingency fault condition data occurs, and outputs the results as power system influence evaluation information;
The power system measure examination unit outputs countermeasure proposal data which is a result of planning a countermeasure for improving the stability of the power system based on the power system impact evaluation information;
The power system control device according to claim 2 , wherein the effect evaluation unit outputs the evaluation data as a verification result of the countermeasure proposal data. 4. The power system control device according to claim 3, wherein the wide-area system cross-section creation unit creates the wide-area cross-section information by acquiring the renewable energy power generation amount or the forecast value and the system configuration information for a plurality of the areas from the power generation amount acquisition unit. The power system control device according to claim 3 , wherein the system influence assessment unit determines system constraint conditions during an accident and during normal operation based on the wide-area cross-sectional information and the contingency fault condition data. The power system control device according to claim 5, wherein the system constraint conditions include any one of a generator internal phase difference angle in synchronous stability, a maximum or minimum value of frequency in frequency stability, a load margin up to a nose point of a P-V curve in voltage stability, a transient voltage, or a transient overload. The power system control device according to claim 6 , wherein the system influence evaluation unit identifies a problem occurrence position, which is a position in the power system where a problem occurs, when it is found that the system constraint condition cannot be satisfied. The power system control device according to claim 7, characterized in that the countermeasure proposal data includes information for identifying the generator that can alleviate the problem when a power factor is changed for the problem at the problem occurrence position corresponding to the contingency fault condition data. The power system control device according to claim 8 , wherein the evaluation data includes information verifying an effect when a power factor of the generator is changed. The power system control device according to claim 9 , wherein the evaluation data includes a result of evaluating an effect corresponding to any one of the system constraint conditions. the power system countermeasure examination unit transmits a countermeasure execution command including an instruction to change a power factor of the generator to the control instruction unit;
The power system control device according to claim 10 , wherein the control instruction unit changes a power factor of the generator based on the countermeasure execution command. After the power system countermeasure examination unit transmits the countermeasure execution command to the control instruction unit,
The power system control device according to claim 11 , wherein the control instruction unit further changes an output of the generator based on the countermeasure execution command. A benefit evaluation unit that evaluates benefits using information from the effect evaluation unit;
an investment cost evaluation unit that evaluates the investment cost using information from the control instruction unit;
an investment cost benefit evaluation unit that outputs an evaluation result indicating a relationship between the benefit and the investment cost;
The benefit relates to any one of the following: abatement costs of fossil fuels, abatement costs of carbon dioxide emission rights purchases, or abatement costs of grid upgrades;
The investment cost is a cost related to any one of the following: loss of electricity selling opportunities, labor costs required for generator control, or reduced useful life due to equipment fatigue;
The power system control device according to claim 1 , wherein the evaluation result is a result of dividing the benefit by the investment cost, or a result of subtracting the investment cost from the benefit. a power generation amount acquisition step of acquiring a predetermined type of power generation amount, which is a power generation amount belonging to a predetermined type in each of a plurality of areas included in the power system;
A system configuration acquisition step of acquiring system configuration information including line impedances of power transmission lines in the plurality of areas;
A system countermeasure planning step of planning a system countermeasure for the power system;
a control instruction step of outputting an area control command for instructing a power factor of a generator included in any one of the plurality of areas,
The power system countermeasure planning step includes:
an effect evaluation step of evaluating an effect when the power factor of the generator is changed based on the predetermined type of power generation amount and the system configuration information, and outputting an evaluation result as evaluation data;
and a system countermeasure examination step of causing the area control command to be output in the control instruction step based on the evaluation data. Computer,
a power generation amount acquiring means for acquiring a predetermined type of power generation amount, which is a power generation amount belonging to a predetermined type in each of a plurality of areas included in the power system;
A system configuration acquisition means for acquiring system configuration information including line impedances of power transmission lines in the plurality of areas;
A system countermeasure planning means for planning a system countermeasure for the power system;
a program for causing the control instruction means to function as a control instruction means for outputting an area control command for instructing a power factor of a generator included in any one of the plurality of areas,
The power system countermeasure planning means includes:
an effect evaluation means for evaluating an effect when a power factor of the generator is changed based on the predetermined type of power generation amount and the system configuration information, and outputting an evaluation result as evaluation data;
and a system countermeasure examination means for causing the control instruction means to output the area control command based on the evaluation data.

Images