JP2020176590A - Well characteristic estimation system of geothermal power generation plant, well characteristic estimation method and well characteristic estimation program therefor, and geothermal power generation plant - Google Patents

Abstract

To provide a well characteristic estimation system of a geothermal power generation plant, its well characteristic estimation method and well characteristic estimation program, and a geothermal power generation plant capable of making an appropriate flow rate of a geothermal fluid undergoing air jetting from a well by accurately grasping a change in a well characteristic.SOLUTION: A well characteristic estimation system includes an acquisition part for acquiring information on a steam flow rate of a geothermal fluid and a hot water flow rate of the geothermal fluid to pressure when the pressure undergoing air jetting from a well 2 fluctuates in the case that a geothermal power generation plant 1 for performing power generation by using the geothermal fluid undergoing air jetting from at least one well 2 operates, and an estimation part for estimating a well characteristic showing relations of the pressure undergoing air jetting from the well, the steam flow rate, and the hot water flow rate on the basis of the information acquired by the acquisition part.SELECTED DRAWING: Figure 1

Description

The present invention relates to a well characteristic estimation system for a geothermal power plant, a well characteristic estimation method thereof, a well characteristic estimation program, and a geothermal power plant.

In a geothermal power plant, steam separated from a geothermal fluid (mainly a mixed fluid of steam and hot water) ejected from a well is introduced into a steam turbine to generate electricity. Therefore, when the geothermal fluids extracted from a plurality of wells are merged and used, the flow rate of the geothermal fluid to be blown is controlled based on the well characteristics (pressure and flow rate characteristics of the fumes fluid) in each well. However, well management is being carried out to maximize the generated power (for example, Patent Document 1).

Japanese Unexamined Patent Publication No. 2-232495

However, in the operation of the well, for example, the steam flow rate and the hot water flow rate were related to the initial well characteristics (fumarole pressure (wellhead pressure)) by the fumarole test (test conducted at the initial stage, etc.) performed at the time of completion. Characteristic) is acquired. After the initial well characteristics are acquired, the well characteristics are often not measured in the middle of operation for continuous operation. After the well is integrated into the power generation facility system (after the power plant is in operation), the well must be disconnected from the power generation facility system in order to acquire the characteristics of the well, and the well is disconnected. It was not easy to acquire the well characteristics unless there were special circumstances, because there is a risk that the generated power will decrease. In other words, it was not possible to grasp the changes in well characteristics associated with operation.

On the other hand, in a well, if the extraction flow rate of geothermal steam is increased too much, the attenuation of the well may become large, and if the extraction flow rate of geothermal steam is reduced and the pressure is raised too much, the flow rate may suddenly decrease. For this reason, if well management is performed based on the well characteristics acquired in the past even though the well characteristics have changed, well control may become inappropriate, and the wells may become inappropriate. There was a possibility of promoting the attenuation (shortening of life) of the well. If a specific well is attenuated, it is necessary to excavate a new well in place of the attenuated well in order to avoid a decrease in generated power, which may lead to an increase in cost. For this reason, well management is often operated based on the intuition and experience of experts, and the issues are proper adjustment of fumarolic pressure and steam flow rate in the well and extension of the life of the well. There is.

The present invention has been made in view of such circumstances, and is a geothermal power plant capable of accurately grasping changes in well characteristics and optimizing the flow rate of geothermal fluid ejected from the well. It is an object of the present invention to provide a well characteristic estimation system, a well characteristic estimation method thereof, a well characteristic estimation program, and a geothermal power plant.

A first aspect of the present invention is the above, when a geothermal power plant that generates power using a geothermal fluid ejected from at least one well is in operation and the pressure ejected from the well fluctuates. An acquisition unit that acquires information on the steam flow rate of the geothermal fluid and the hot water flow rate of the geothermal fluid with respect to the pressure, and the pressure and the steam flow rate that are ejected from the well based on the information acquired by the acquisition unit. , And an estimation unit for estimating well characteristics indicating the relationship between the hot and cold water flow rates, and a well characteristic estimation system for a geothermal power plant.

According to the above configuration, although the well characteristics change according to the operation, it was difficult to acquire the well characteristics during the operation of the geothermal power plant, but the well characteristics were obtained based on multiple information acquired during the operation. Well characteristics can be easily estimated. That is, the well characteristics of the well can be grasped more accurately, the flow rate of the geothermal fluid fumarole from the well can be adjusted appropriately, and the well management can be performed more efficiently. By managing the wells more accurately, it is possible to extend the life of the wells.

In addition, in order to estimate the well characteristics based on a plurality of information of the jet pressure in the well, the steam flow rate of the geothermal fluid, and the hydrothermal flow rate of the geothermal fluid, which can be obtained while the power plant is in operation, for example, a well is used. It is possible to grasp the characteristics of wells even if they are still installed in the power generation equipment system.

In the well characteristic estimation system, the estimation unit may estimate the well characteristics for each of the plurality of wells.

According to the above configuration, in order to estimate the well characteristics of each well for a plurality of wells, the characteristics of each well are grasped more accurately and the wells are blown from each well. The flow rate of the geothermal fluid can be adjusted appropriately, and each well can be effectively managed.

In the well characteristic estimation system, the acquisition unit acquires the total flow rate of steam in the geothermal fluid ejected from each well as the information related to the steam flow rate, and the information related to the hot water flow rate. As a result, the total flow rate of hot water in the geothermal fluid ejected from each of the wells is acquired, and the estimation unit performs regression analysis based on the total flow rate of steam and the total flow rate of hot water. The well characteristics may be estimated.

According to the above configuration, as information for estimating the well characteristics, the total flow rate of steam in the geothermal fluid ejected from each well and the total flow rate of hot water in the geothermal fluid ejected from each well. Since it was decided to estimate the well characteristics that indicate the relationship between the pressure of each well and the steam flow rate and the hot water flow rate by regression analysis, etc., while minimizing the number of measuring instruments such as flow meters. , Well characteristics can be estimated.

In the well characteristic estimation system, the acquisition unit acquires a partial total flow rate of steam in the geothermal fluid ejected from each well as the information related to the steam flow rate, and relates to the hot water flow rate. As the information, a partial total flow rate of hot water in the geothermal fluid ejected from each of the wells is acquired, and the estimation unit is based on a partial total flow rate of steam and a partial total flow rate of hot water. The well characteristics for each well may be estimated by regression analysis.

According to the above configuration, as information for estimating the well characteristics, for example, the geothermal fluid ejected from at least a part of the wells is collected in one gas-water separator. For some wells such as systems, obtain the partial total flow rate of steam in the geothermal fluid ejected from each well and the partial total flow rate of hot water in the geothermal fluid ejected from each well. , It was decided to estimate the well characteristics showing the relationship between the pressure of each well and the steam flow rate and hot water flow rate by regression analysis and the like. Therefore, for example, it is possible to improve the estimation accuracy of the well characteristics of each well as compared with the case of acquiring the total flow rate of steam in the geothermal fluid fumarole from each well.

In the well characteristic estimation system, the acquisition unit acquires the flow rate of steam in the geothermal fluid ejected from each well as the information related to the steam flow rate, and uses the information related to the hot water flow rate. , The flow rate of hot water in the geothermal fluid ejected from each of the wells is acquired, and the estimation unit estimates the well characteristics for each of the wells based on the flow rate of steam and the flow rate of hot water. It may be that.

According to the above configuration, as information for estimating the well characteristics, the flow rate of steam in the geothermal fluid ejected from each well and the flow rate of hot water in the geothermal fluid ejected from each well are acquired. Therefore, it is possible to accurately estimate the well characteristics of each well.

In the well characteristic estimation system, the opening degree of the flow rate adjusting valve for the geothermal fluid provided for the specific well is adjusted by a predetermined amount, and the fluctuation in the amount of power generated due to the adjustment is suppressed. A valve control unit for controlling the flow rate adjusting valve of the geothermal fluid provided for the well is provided, and the acquisition unit obtains the information after the control of each flow rate adjusting valve is executed by the valve control unit. It may be acquired.

According to the above configuration, when the flow rate control valve of a specific well is changed by a predetermined amount, the flow rate control valves of other wells are controlled to suppress fluctuations in the amount of power generated by the geothermal power plant. Therefore, it is possible to obtain the fluctuation amount of the jet pressure, the steam flow rate, and the hot water flow rate due to the adjustment of the flow rate adjusting valve of a specific well with almost no fluctuation in the power generation amount. That is, it is possible to estimate the well characteristics based on the acquired information with almost no fluctuation in the amount of power generation.

The well characteristic estimation system may include a correlation calculation unit that calculates the correlation of each well based on the well characteristics of each well estimated in the past predetermined period.

According to the above configuration, each well may not be independent, such as when it is conducting in the underground reservoir, and it was difficult to find the correlation between each well, but in the past predetermined period. It can be expected that the correlation of each well will be discovered by referring to the well characteristics of each well estimated in. For example, by modifying the geothermal fluid reservoir model using the discovered correlation, the state of the geothermal fluid reservoir beneath the ground can be grasped more accurately, while considering the correlation of each well. It is also possible to optimize the flow rate of the geothermal fluid that erupts from each well.

In the well characteristic estimation system, when the total flow rate of steam ejected from each well was made constant by using the estimated well characteristics of each well, fumarole was ejected from each well. An optimization unit that determines the combination of fumarolic pressures in each well so that the total flow rate of hot water is within a predetermined range including the minimum value may be provided.

According to the above configuration, by using the well characteristics, it is possible to accurately grasp the characteristics of each well and optimize the flow rate of the geothermal fluid ejected from each well. A combination of hot water flow rates in each well such that the total flow rate of hot water ejected from each well approaches the minimum value within a predetermined range including the minimum value when the total flow rate of the well is constant. It becomes possible to estimate. The flow rate value of hot water from each well is selected and set so that the total flow rate of hot water fumarole from each well approaches the minimum value within a predetermined range including the minimum value. This makes it possible to suppress the shortening of the life of each well.

A second aspect of the present invention is a separator that separates the geothermal fluid ejected from the well into steam and hot water, a steam turbine that is rotationally driven by the steam separated by the separator, and a rotary connection with the steam turbine. It is a geothermal power plant equipped with the above-mentioned generator and the well characteristic estimation system of the above geothermal power plant.

A third aspect of the present invention is the above, when a geothermal power plant that generates power using a geothermal fluid ejected from at least one well is operating and the pressure of the vapor ejected from the well fluctuates. The acquisition step of acquiring information on the steam flow rate of the geothermal fluid and the hot water flow rate of the geothermal fluid with respect to the pressure, and the pressure and the steam flow rate of jetting from the well based on the information acquired in the acquisition step. This is a method for estimating well characteristics of a geothermal power plant, which includes an estimation step for estimating well characteristics indicating the relationship between the hot water flow rate and the above.

A fourth aspect of the present invention is the above, when a geothermal power plant that generates power using a geothermal fluid ejected from at least one well is operating and the pressure of the vapor ejected from the well fluctuates. An acquisition process for acquiring information on the steam flow rate of the geothermal fluid and the hot water flow rate of the geothermal fluid with respect to the pressure, and the pressure and the steam flow rate to be ejected from the well based on the information acquired in the acquisition process. , And an estimation process for estimating the well characteristics indicating the relationship between the hot and cold water flow rates, and a well characteristic estimation program for a geothermal power plant for causing a computer to execute.

According to the present invention, it is possible to accurately grasp the change in the characteristics of the well and to make the flow rate of the geothermal fluid fumarole from the well appropriate.

It is a figure which shows the schematic structure of the geothermal power generation plant provided with the well characteristic estimation system which concerns on 1st Embodiment of this invention. It is a functional block diagram which showed the function which the well characteristic estimation apparatus which concerns on 1st Embodiment of this invention has. It is a figure which showed an example of the well characteristic which concerns on 1st Embodiment of this invention. It is a figure which showed the variation example of the well characteristic which concerns on 1st Embodiment of this invention. It is a figure which showed the example of the well characteristic estimated by the well characteristic estimation apparatus which concerns on 1st Embodiment of this invention. It is a figure which showed the example of scoring in the well characteristic estimation apparatus which concerns on 1st Embodiment of this invention. It is a figure which shows the flowchart of the process of the well characteristic estimation apparatus which concerns on 1st Embodiment of this invention. It is a functional block diagram which showed the function which the well characteristic estimation apparatus which concerns on 2nd Embodiment of this invention has. It is a functional block diagram which showed the function which the well characteristic estimation apparatus which concerns on 3rd Embodiment of this invention has.

[First Embodiment]
Hereinafter, the well characteristic estimation system of the geothermal power plant according to the present invention, the well characteristic estimation method thereof, the well characteristic estimation program, and the first embodiment of the geothermal power plant will be described with reference to the drawings. The well characteristic estimation system can be widely applied to any geothermal power generation plant that generates power by the geothermal fluid ejected from the well 2, and is limited to the geothermal power generation plants having the configurations described below. It's not a thing. Further, the well characteristic estimation system (well characteristic estimation device 20) may be configured to include at least an acquisition unit 21 and an estimation unit 22.

FIG. 1 is a diagram showing a schematic configuration of a geothermal power generation plant 1 provided with a well characteristic estimation system according to a first embodiment of the present invention. In this embodiment, for example, a case where three wells 2 are provided will be described. The geothermal power generation plant 1 shown in FIG. 1 is, for example, a flash cycle type geothermal power generation plant, but the well characteristic estimation system is similarly applied to a geothermal power generation plant having another configuration such as a binary cycle type. It is possible. Further, in FIG. 1, for example, three wells 2 are provided, three brackish water separators 5 are provided, and one reduction well 19 is provided. However, if at least one well 2 is provided, the above The present invention can be appropriately applied regardless of the configuration.

As shown in FIG. 1, the geothermal power generation plant 1 according to the present embodiment includes a geothermal fluid transport pipe (two-phase fluid transport pipe) 3 and a jet air flow rate adjusting valve (hereinafter, simply referred to as “flow rate adjusting valve 4”). , A gas-water separator 5, a hot water pipe 6, a steam pipe 7, a steam turbine 8, a water recovery device 10, and a cooling tower 11 are mainly provided. Further, a well characteristic estimation device (well characteristic estimation system) 20 as shown in FIG. 2 is applied to the geothermal power generation plant 1.

The geothermal fluid transport pipe 3 is a pipe that guides the geothermal fluid ejected from the well (geothermal well) 2 to the gas-water separator 5. A magma chamber is formed underground, and this heat heats rainwater that has permeated underground, groundwater that has flowed in, and the like to form a geothermal reservoir. Geothermal fluid is accumulated in the geothermal reservoir and is taken out to the ground by the well 2. The geothermal fluid transport pipe 3 transports the geothermal fluid from the geothermal reservoir to the air-water separator 5 via the well 2. The geothermal fluid is a two-phase mixed fluid mainly composed of steam and hot water.

The flow rate adjusting valve (injection flow rate adjusting valve) 4 is provided on the geothermal fluid transport pipe 3, and adjusts the flow rate (injection amount) of the geothermal fluid flowing from the well 2 into the air-water separator 5. The fumarolic pressure in the well 2 can also be adjusted by adjusting the flow rate adjusting valve 4.

Further, on the geothermal fluid transport pipe 3, a pressure gauge 16 for measuring the jet pressure (wellhead pressure) is provided on the upstream side of the geothermal fluid flow of the flow rate adjusting valve 4. The pressure gauge 16 measures the pressure of the geothermal fluid fumarole from the well 2. It should be noted that an on-off valve 13 may be provided on the most upstream side of the geothermal fluid flow on the geothermal fluid transport pipe 3 (near the outlet of the well 2) to control the conduction state (conduction state or non-conduction state) of the geothermal fluid. Good.

The gas-water separator 5 is a device (separator) that separates a geothermal fluid, which is a two-phase mixed fluid supplied by a geothermal fluid transport pipe 3, into steam and hot water. The hot water separated by the steam separator 5 is guided to the hot water pipe 6, and the steam separated by the steam separator 5 is guided to the steam pipe 7.

The hot water pipe 6 is a pipe that guides the hot water separated by the steam separator 5 to the reduction well 19. By returning hot water to the underground geothermal reservoir via the reduction well 19, depletion of the geothermal fluid in the underground geothermal reservoir is suppressed. The hot water separated by each brackish water separator 5 merges at the hot water pipe 6 and is pumped to the reduction well 19 via the pump 14. If the reduction well 19 can be pumped by its own pressure, the pump 14 may not be used. Further, the flow rate of the hot water sent to the reduction well 19 is measured by a flow meter 17 provided on the hot water pipe 6. In this embodiment, the hot water flow rate (total flow rate) after the hot water separated by each brackish water separator 5 is merged is measured, and the hot water flow rate of each well is estimated by regression analysis or the like. Although the case of this is described, the flow rate of the hot water separated by each brackish water separator 5 may be measured. Further, a plurality of reduction wells 19 may be provided.

The steam pipe 7 is a pipe that guides the steam separated by the steam separator 5 to the steam turbine 8. The steam separated by each steam separator 5 merges at the steam pipe 7 and is supplied to the steam turbine 8. The flow rate of steam sent to the steam turbine 8 is measured by a flow meter 18 provided on the steam pipe 7. In this embodiment, the steam flow rate of each well is estimated by measuring the flow rate (total flow rate) of the steam after the steam separated by each steam separator 5 merges and performing regression analysis or the like. As will be described, the flow rate of the steam separated by each air-water separator 5 may be measured. Further, the steam pipe 7 is provided with a flow rate adjusting valve 15 for the steam after the steam separated by each steam separator 5 is merged to control the supply flow rate of the steam to the steam turbine 8. Good.

The steam turbine 8 rotationally drives the turbine blades with the energy of the steam supplied by the steam pipe 7, and rotationally drives the generator 9 connected to the rotating shaft of the turbine blades to generate power.

The condenser 10 is a device that condenses and condenses the steam that has finished its work in the steam turbine 8 by cooling it with cooling water. The condensed condensate (warm water) is supplied to the cooling tower 11.

The cooling tower 11 is a device that evaporatively cools the hot water condensed in the condenser 10. Specifically, the hot water supplied to the cooling tower 11 is sprayed from the spraying portion on the upper part of the cooling tower 11. A part of the sprayed hot water evaporates when it comes into contact with the air circulated by the blower of the cooling tower 11, and the latent heat accompanying the evaporation cools the other hot water to become water. The chilled water is stored in the water tank of the cooling tower 11 as cooling tower water. The cooling tower water stored in the water tank is supplied to the condenser 10 as cooling water via the pump 12.

The well characteristic estimation device 20 estimates the well characteristics for each well 2 provided in the geothermal power generation plant 1. In particular, the well characteristic estimation device 20 is a device capable of estimating well characteristics even when the geothermal power generation plant 1 is in operation. The case where the geothermal power generation plant 1 is in operation means that the wells 2 are installed together after the geothermal power generation plant 1 is completed. Further, the case where the geothermal power generation plant 1 is in operation means that the geothermal fluid ejected from the well is circulated into the geothermal power generation plant 1, for example, by at least the pressure gauge 16 and the flow meters 17 and 18. It suffices as long as it can be measured.

The well characteristic estimation device 20 is composed of, for example, a CPU (central processing unit) (not shown), a memory such as a RAM (Random Access Memory), a computer-readable recording medium, and the like. A series of processing processes for realizing various functions described later is recorded in a recording medium or the like in the form of a program, and the CPU reads this program into a RAM or the like to execute information processing / arithmetic processing. As a result, various functions described later are realized. The program is installed in a ROM or other storage medium in advance, is provided in a state of being stored in a computer-readable storage medium, or is distributed via a wired or wireless communication means. Etc. may be applied. Computer-readable storage media include magnetic disks, magneto-optical disks, CD-ROMs, DVD-ROMs, semiconductor memories, and the like.

FIG. 2 is a functional block diagram showing the functions of the well characteristic estimation device 20. As shown in FIG. 2, the well characteristic estimation device 20 includes an acquisition unit 21, an estimation unit 22, and an optimization unit 23.

In the acquisition unit 21, the pressure (injection pressure) ejected from the well 2 fluctuates when the geothermal power generation plant 1 that generates power using the geothermal fluid ejected from at least one well 2 is operating. At that time, information on the steam flow rate of the geothermal fluid and the hot water flow rate of the geothermal fluid with respect to the pressure is acquired. For example, when the flow rate adjusting valve 4 is operated for some purpose in a specific well 2, the fumarole pressure fluctuates, and the steam flow rate and the hot water flow rate fluctuate. The acquisition unit 21 acquires the value of the steam flow rate and the value of the hot water flow rate with respect to the value of the fumarole pressure as information at the opportunity of such a fluctuation of the fumarole pressure.
As shown in FIG. 1, in the present embodiment, for example, three wells 2 are provided, a pressure gauge 16 for measuring the fumes pressure of each well 2, a flowmeter 17 for measuring the total flow rate of hot water, and a flowmeter 17. A flow meter 18 for measuring the total flow rate of steam is provided. Therefore, the acquisition unit 21 acquires the fumarole pressure of each well 2 from the pressure gauge 16 as information related to the fumarole pressure in the well 2. In addition, the acquisition unit 21 acquires the total flow rate of steam in the geothermal fluid ejected from each well 2 from the flow meter 18 as information related to the steam flow rate, and from the flow meter 17 as information related to the hot water flow rate. , Obtain the total flow rate of hot water in the geothermal fluid ejected from each well 2. The various acquired information is output to the estimation unit 22. The estimation unit 22 estimates the fumarole pressure, steam flow rate, and hot water flow rate for each well 2 by regression analysis or the like.

The information regarding the steam flow rate of the geothermal fluid and the information regarding the hot water flow rate of the geothermal fluid acquired by the acquisition unit 21 are not limited to the acquisition of the total flow rate and can be changed as appropriate. For example, a steam flow meter and a hot water flow meter may be provided for each well 2. In this case, the acquisition unit 21 acquires the flow rate of steam in the geothermal fluid ejected from each well 2 as information related to the steam flow rate, and is ejected from each well 2 as information related to the hot water flow rate. Obtain the flow rate of hot water in the geothermal fluid. If each flow rate of each well 2 can be measured, it is possible to provide a measuring instrument on either the upstream side or the downstream side of the brackish water separator 5. Further, when a flow meter is provided on the upstream side of the steam separator 5, a two-phase flow meter may be provided because the measurement target is a two-phase mixed fluid. The two-phase flow meter is a measuring instrument capable of measuring the flow rate of the liquid phase fluid (hot water) and the flow rate of the gas phase fluid (steam) in the two-phase mixed fluid with the two-phase mixed fluid as the measurement target.

Further, for example, when one steam separator 5 is provided for a plurality of wells 2, or when a plurality of steam separators 5 are provided for one well 2, steam A flow meter and a hot water flow meter may be provided for each brackish water separator 5. In this case, targeting a part of the wells 2 composed of at least a part of the plurality of wells 2, the acquisition unit 21 uses the steam in the geothermal fluid ejected from each well 2 as information on the steam flow rate. As information on the hot water flow rate, the partial total flow rate of hot water in the geothermal fluid ejected from each well 2 is acquired.

That is, as will be described later, each well 2 has information on the jet pressure in the well 2 acquired by the acquisition unit 21, information on the steam flow rate of the geothermal fluid, and information on the hot water flow rate of the geothermal fluid. The information is not limited to the above, and can be applied as long as the information can identify the jet pressure, steam flow rate, and hot water flow rate corresponding to the above.

Based on the information acquired by the acquisition unit 21, the estimation unit 22 estimates the well characteristics showing the relationship between the pressure, steam flow rate, and hot water flow rate of fumaroles from the well 2. In the present embodiment, the estimation unit 22 uses the information related to the steam flow rate and the information related to the hot water flow rate acquired by the estimation unit 22 in the latest designated period (past predetermined period) for the plurality of wells 2. , Estimate well characteristics. The latest designated period is, for example, the latest 1 to 6 months or the latest 1 year. The well characteristic is a fumarole characteristic peculiar to each well 2. For example, as shown in FIG. 3, a characteristic in which the flow rate of steam and the flow rate of hot water are related to the fumarole pressure (wellhead pressure). Is. The solid line shows the steam flow rate, and the broken line shows the hot water flow rate. In the well 2 that fumaroles the geothermal fluid, the well characteristics may change over time depending on the operation. In the operation of the well 2, for example, the initial well characteristics are measured by a fumarole test conducted at the time of completion. For example, assuming that the well characteristics shown in FIG. 3 are the initial characteristics, the well characteristics change as shown in FIG. 4 as the well 2 is operated after being incorporated into the geothermal power generation plant 1. However, after the well 2 is incorporated into the geothermal power generation plant 1, the well 2 must be disconnected from the geothermal power generation plant 1 in order to acquire the characteristics of the well. Since there is a risk of reducing the generated power and the well characteristics are not acquired unless there are special circumstances, it is difficult to accurately grasp the well characteristics after the change.

On the other hand, in the well 2, if the extraction flow rate of the geothermal steam is increased too much, the attenuation of the well may become large, and if the extraction flow rate of the geothermal steam is reduced and the pressure is raised too much, the flow rate may suddenly decrease. .. For this reason, if well management is performed based on the well characteristics acquired in the past even though the well characteristics have changed, correct well management cannot be performed and the well 2 is attenuated (short). There was a risk of accelerating the lifespan. Therefore, the estimation unit 22 determines the characteristics of the well (after the change due to the operation) in the latest designated period based on the information that can be acquired even when the well 2 is installed in the geothermal power generation plant 1. To estimate.

The information related to the steam flow rate and the information related to the hot water flow rate with respect to the fumarole pressure acquired by the estimation unit 22 are acquired in the following cases. For example, when the flow rate adjusting valve 4 is operated for a specific well 2, the fumarole pressure, steam flow rate, and hot water flow rate fluctuate. Therefore, when the flow rate adjusting valve 4 is operated for the well 2 for some purpose, the acquisition unit 21 acquires the measured value from each measuring instrument and outputs it to the estimation unit 22. In the present embodiment, since the pressure gauge 16 provided in each well 2, the flow meter 18 for measuring the total flow rate of steam, and the flow meter 17 for measuring the total flow rate of hot water are provided, the estimation unit 22 is provided with. The jet pressure of each well 2, the total flow rate of steam, and the total flow rate of hot water changed by the operation of the flow rate adjusting valve 4 are input as a set. It is preferable that the acquired date and time and the identification information of the well 2 corresponding to the operated flow rate adjusting valve 4 are also input to the set. Further, the fumarolic pressure of each well 2 before and after the change due to the operation of the flow rate adjusting valve 4, the total flow rate of steam, and the total flow rate of hot water may be input to the estimation unit 22 as a set. ..

Then, the estimation unit 22 estimates the fumes pressure, steam flow rate, and hot water flow rate in each well 2 for each well 2 by regression analysis or the like based on the total flow rate of steam and the total flow rate of hot water. Specifically, based on the identification information of the well 2 corresponding to the operated flow rate adjusting valve 4, it is possible to grasp which flow rate adjusting valve 4 (well 2) has caused the total flow rate to fluctuate. it can. Therefore, the flow rate of steam and the flow rate of hot water for each well 2 can be estimated by performing regression analysis or the like on the changed total flow rate.

In this way, in the estimation unit 22, when the fumarole pressure changes due to the operation of the flow rate adjusting valve 4 for the specific well 2, the fumarole pressure, the steam flow rate, and the heat of each well 2 occur. The water flow rate is collected and accumulated as a set. Then, the estimation unit 22 collects and accumulates information (for example, 1 month to 6 months, 1 year, etc.) in the latest designated period (for example, the relationship between the fumarolic pressure of each well 2, the steam flow rate, and the hot water flow rate). The well characteristics of each well 2 are estimated based on the information related to). The estimation unit 22 acquires a plurality of information related to the relationship between the fumarolic pressure, the steam flow rate, and the hot water flow rate of each well 2 in the latest designated period, and estimates the well characteristics of each well 2.

FIG. 5 shows a plot of the relationship (actual measurement) between the fumarole pressure, the steam flow rate, and the hot water flow rate acquired in the latest designated period for an arbitrary well 2. As shown in FIG. 5, by using the relationship (actual measurement) between the fumarolic pressure of each well 2 in the recent designated period, the steam flow rate, and the hot water flow rate, in the latest designated period in any well 2. The tendency of well characteristics can be obtained. Therefore, the estimation unit 22 analyzes (statistical analysis, etc.) the relationship between the fumarole pressure, the steam flow rate, and the hot water flow rate acquired within the recent designated period, thereby recently designating each well 2. Estimate well characteristics over time. For the analysis, a fitting method such as the least squares method or the maximum likelihood estimation method may be used, or a well in the latest designated period of each well 2 using a trained model obtained by machine learning. It is also possible to estimate the characteristics. The multiple pieces of information used in the analysis include the relationship between the acquired fumarole pressure, steam flow rate, and hot water flow rate, as well as the characteristics of the characteristics obtained in the initial characteristics of the fumarole test conducted at the time of completion (for example, the upper part is convex). The quadratic curve of) may be considered.

The estimation unit 22 estimates the well characteristics of each well 2 by performing the above processing. The estimated well characteristics of each well 2 are used by the optimization unit 23 for well management.

The optimization unit 23 optimizes the operating state of each well 2 by using the estimated well characteristics of each well 2. Specifically, the optimization unit 23 uses the estimated well characteristics of each well 2 to make the total flow rate of steam fumaroles from each well 2 constant, and fumaroles from each well 2. The combination of fumarolic pressures in each well 2 is determined so that the total flow rate of the generated hot water approaches the minimum value within a predetermined range including the minimum value. By keeping the total flow rate of fumaroles constant, the amount of power generated by the geothermal power generation plant 1 is kept constant, and by reducing the total flow rate of the fumaroled hot water, the attenuation of the well 2 is suppressed. It has the effect of extending the life of the well 2. On the other hand, if the fumarole pressure is increased too much to reduce the total flow rate of hot water, the fumarole in the well 2 may stop, so the minimum value of the total flow rate of hot water does not include the range where the total flow rate is too small. It is a thing.
By referring to the well characteristics of each well 2, the optimization unit 23 can grasp the relationship between the fumarolic pressure, the steam flow rate, and the hot water flow rate in each well 2. Therefore, the optimization unit 23 is fumarinated from each well 2 based on the well characteristics of each well 2 under the optimum conditions (when the total flow rate of steam fumarole from each well 2 is constant). The combination of fumarolic pressures in each well 2 is estimated so that the total flow rate of hot water is within a predetermined range including the minimum value). In addition, within a predetermined range including the minimum value, the lower limit value is a value that does not include the stop of the well eruption due to a decrease in the hot water flow rate, and in the predetermined range, the upper limit value is a large attenuation of the well 2 It is set so that both conditions are satisfied and the value is close to the minimum value as long as the well 2 does not include the one that shortens the life.

Then, the combination of the operating states of each well 2 of the geothermal power generation plant 1 is optimized by controlling the flow rate adjusting valve 4 of each well 2 based on the estimated combination of the jet pressures of each well 2. It becomes possible. That is, when the total flow rate of steam ejected from each well 2 is constant and the amount of power generated by the geothermal power generation plant 1 is kept constant, the total flow rate of hot water ejected from each well 2 is the minimum value. By managing the wells in such a manner, it is possible to extend the life of the well 2 by suppressing the attenuation of the well 2 due to the excessive hot water flow rate while maintaining the required steam flow rate.

Here, in order to optimize the combination of fumarole pressures in each well 2, the optimization unit 23 facilitates selection by scoring the flow rate of hot water in each well 2. .. If the flow rate of hot water ejected from the well 2 is too small, the pressure may drop sharply and the fumarole may stop, while if it is too large, the attenuation of the well 2 may be promoted. There is sex (reason for inadequacy). Therefore, in consideration of the unsuitable reason, a score weighting function as shown in FIG. 6 is set corresponding to each well 2. In the score weighting function shown in FIG. 6, the vertical axis is the weight (score) and the horizontal axis is the ratio of the hot water flow rate to the maximum value of the hot water flow rate (hot water flow rate ratio), and is convex upward in consideration of the unsuitable reason. It is a function. That is, the weight (score) is set low in the region where the hot water flow rate is too small and the region where the hot water flow rate is too large. In the operation of the well 2, if the flow rate of hot water is too small, the fumarole may stop, but in order to suppress the attenuation of the well 2 and plan long-term operation, the flow rate of hot water should be increased as much as possible. It is preferable to suppress it. Therefore, although the score weighting function is convex upward, it is preferable that the maximum value is set in the region where the hot water flow rate is smaller. In the optimization unit 23, the hot water flow rate of each well 2 is scored by the score weighting function.

Since the characteristics of each well 2 are different, it is preferable that the score weighting function as shown in FIG. 6 is set for each well 2 and evaluated for each well 2, but it is unified for each well 2. The score weight function may be set.

Then, the optimization unit 23 sets the total flow rate of steam fumaroles (flow rate of steam supplied to the steam turbine 8) from each well 2 constituting the plurality of wells 2 in response to the power generation request. When the set total flow rate of steam is constant, the combination of fumarolic pressures of each well 2 having the highest total weight score is specified. Specifically, the optimization unit 23 allocates the steam flow rate to each of the wells 2 under the condition that the total flow rate of steam is constant. Then, in each well 2, the fumarole pressure and the hot water flow rate corresponding to the assigned steam flow rate are specified based on the estimated well characteristics, and the specified hot water flow rate is scored. Then, the scores evaluated in each well 2 are totaled with respect to the combination condition of the fumarole pressure of each well 2.

In this way, the optimization unit 23 sets a plurality of patterns for allocating the steam flow rate to each well 2, similarly scores the hot water flow rate to calculate the total, and combines the fumarolic pressures of each well 2. It is the total value of the points under the conditions. From the above calculation, the total value of the scores is calculated in a plurality of patterns of the combination condition of the fumarole pressure of each well 2. Therefore, the pattern with the highest total score calculated is specified, and each well 2 in the specified pattern is specified. Identify the combination of fumarolic pressures. By doing so, the optimum condition (when the total flow rate of steam fumaroles from each well 2 is constant, the total flow rate of hot water fumaroles from each well 2 is within a predetermined range including the minimum value. It is possible to estimate the combination of fumarolic pressures in each well 2 that is within the range).

The flow rate adjusting valve 4 of each well 2 is controlled so as to be a combination of the estimated fumarole pressures of each well 2, and the operating state of each well 2 is optimized. The control of the flow rate adjusting valve 4 of each well 2 may be automatically executed or may be manually executed by an operator or the like.

Next, the processing by the well characteristic estimation device 20 described above will be described with reference to FIG. 7. The flow shown in FIG. 7 is executed when the estimation start instruction of the well characteristics is instructed by, for example, an operator of the geothermal power generation plant 1. The instruction to start estimating the well characteristics may be automatically instructed by the system incorporated in the geothermal power generation plant 1.

First, information on the jet pressure in the well 2, the steam flow rate of the geothermal fluid, and the hydrothermal flow rate of the geothermal fluid is acquired (S101). Specifically, the fumarolic pressure of each well 2, the total flow rate of steam in the geothermal fluid ejected from each well 2, and the total flow rate of hot water in the geothermal fluid ejected from each well 2 are acquired.

Then, based on the fountain pressure in the geothermal fluid ejected from each well 2 and the total flow rate of steam, and the total flow rate of hot water in the geothermal fluid ejected from each well 2, the jet air in each well 2 The pressure, steam flow rate and hot water flow rate are estimated (S102). Note that S102 can be omitted when measuring the steam flow rate and the hot water flow rate in each well 2 with a measuring instrument.

Then, the well characteristics of each well 2 are estimated based on the fumarole pressure, steam flow rate, and hot water flow rate of each well 2 (S103).

Then, based on the estimated characteristics of each well, the optimum condition (when the total flow rate of steam fumaroles from each well 2 is constant, the total flow rate of hot water fumaroles from each well 2 is the minimum value. It is estimated that the combination of fumarolic pressures of each well 2 is within a predetermined range including (S104).

The flow rate adjusting valve 4 of each well 2 may be automatically controlled by using the estimated combination of the jet pressures of each well 2, or the combination of the jet pressures of each well 2 may be used by the operator. Etc. may be notified to artificially adjust the flow rate adjusting valve 4 of each well 2.

As described above, according to the well characteristic estimation system of the geothermal power plant according to the present embodiment, the well characteristic estimation method thereof, the well characteristic estimation program, and the geothermal power plant, the well characteristics have been conventionally set to the well. Although it changes over time according to the operation of the well 2, it was difficult to acquire it during the operation of the geothermal power plant 1. However, the well characteristics can be easily obtained by the estimation unit 22 of the well characteristic estimation device 20 of the present embodiment. It becomes possible to estimate. That is, the well characteristics of the well 2 can be grasped more accurately, the flow rate of the geothermal fluid fumarole from the well 2 can be made appropriate, and the well management can be performed more efficiently. By managing the wells more accurately, it is possible to extend the life of the wells 2. Further, in order to estimate the well characteristics based on a plurality of information related to the jet pressure in the well 2 that can be acquired while the geothermal power plant 1 is in operation, the steam flow rate of the geothermal fluid, and the hydrothermal flow rate of the geothermal fluid, for example. , It is possible to grasp the characteristics of the well even if the well 2 is still inserted in the geothermal power plant 1.

In addition, as information for estimating the well characteristics, the total flow rate of steam in the geothermal fluid ejected from each well 2 and the total flow rate of hot water in the geothermal fluid ejected from each well 2 are acquired. Since it was decided to estimate the well pressure, steam flow rate, and hot water flow rate for each well 2 by regression analysis, etc., it is possible to estimate well characteristics while minimizing the number of measuring instruments such as flow meters. It becomes.

In addition, since it is possible to accurately grasp the characteristics of each well 2 by using the characteristics of the wells, the total amount of hot water fumaroles from each well 2 is assumed to be constant when the total flow rate of steam is constant. It is possible to estimate the combination of fumarolic pressures of each well 2 or the combination of hot water flow rates so that the flow rate approaches the minimum value within a predetermined range including the minimum value. By setting the flow rate value of hot water in each well 2 so that the total flow rate of hot water fumarole from each well 2 approaches the minimum value within a predetermined range including the minimum value, the shortness of the well 2 It is possible to suppress the life extension.

[Second Embodiment]
Next, a well characteristic estimation system for a geothermal power plant according to a second embodiment of the present invention, a well characteristic estimation method thereof, a well characteristic estimation program, and a geothermal power plant will be described.
In the first embodiment described above, the acquisition unit 21 acquires the measured value from each measuring instrument when the flow rate adjusting valve 4 is operated for the well 2 for some purpose, but in the present embodiment A case where the flow rate adjusting valve 4 is intentionally controlled to acquire the measured value from each measuring instrument will be described. Hereinafter, the well characteristic estimation system of the geothermal power generation plant 1 according to the present embodiment, the well characteristic estimation method thereof, the well characteristic estimation program, and the geothermal power generation plant 1 will be mainly described with respect to the differences from the first embodiment. ..

As shown in FIG. 8, the well characteristic estimation device 20 in the present embodiment includes a valve control unit 24.

The valve control unit 24 adjusts the opening degree of the geothermal fluid flow rate adjusting valve 4 provided for the specific well 2 by a predetermined amount, and suppresses the fluctuation of the amount of power generation due to the adjustment. The flow rate adjusting valve 4 of the geothermal fluid provided for the well 2 is controlled. That is, the valve control unit 24 intentionally controls the flow rate adjusting valve 4 of the specific well 2 to fluctuate the fumarole pressure and the like, and actively causes the acquisition unit 21 to acquire information.

For this purpose, the valve control unit 24 first determines the well 2 that controls the flow rate adjusting valve 4. Regarding the determination of the well 2, the well 2 may be particularly desired to acquire the characteristics of the well, and for all the wells 2, for example, the amount of changeable opening degree of the flow rate adjusting valve 4 having a large geothermal fluid flow rate. The processing may be performed in an appropriately determined order, such as in order from the one with the largest value. Then, the valve control unit 24 adjusts the opening degree of the flow rate adjusting valve 4 of the specific well 2 by a predetermined amount. The predetermined amount is set to an opening fluctuation amount at which changes in fumarole pressure and the like can be sufficiently confirmed by adjusting the flow rate adjusting valve 4. Further, a predetermined amount may be set by an operator or the like of the geothermal power generation plant 1.

By controlling the specific flow rate adjusting valve 4, the amount of steam may fluctuate greatly and the amount of power generated by the geothermal power generation plant 1 may fluctuate. Therefore, the valve control unit 24 adjusts the flow rate of the specific well 2. When adjusting the valve 4, the control amount of the flow rate adjusting valve 4 of the other well 2 is determined so as to suppress the fluctuation amount of the power generation amount generated by the adjustment. For example, the valve control unit 24 sets the fluctuation amount of the steam flow rate required in another well 2 so as to cancel the fluctuation amount of the steam flow rate generated when the flow rate adjusting valve 4 of the specific well 2 is adjusted. It is calculated using the well characteristics, and the control amount of the flow rate adjusting valve 4 of these other wells 2 is determined.

By doing so, even if the flow rate adjusting valve 4 of the specific well 2 is adjusted, the fluctuation amount of the power generation amount can be suppressed by controlling the flow rate adjusting valve 4 of the other well 2, so that the geothermal power generation can be performed. It is possible to obtain the jet pressure, the steam flow rate, and the hot water flow rate associated with the adjustment of the flow rate adjusting valve 4 of the specific well 2 with almost no change in the power generation amount of the plant 1. Further, since the fluctuation of the amount of power generation is suppressed by controlling the flow rate adjusting valve 4 of the other well 2, the opening degree of the specific well 2 can be greatly adjusted, and the flow rate adjusting valve of the specific well 2 can be adjusted. It is possible to obtain a wider range of well pressure, steam flow rate, and hot water flow rate associated with the adjustment of 4. That is, it is possible to acquire information on well characteristics at a position of operating conditions away from the operating point in actual operation.

Then, the acquisition unit 21 acquires information after the control of each flow rate adjusting valve 4 is executed by the valve control unit 24. That is, the acquisition unit 21 acquires and accumulates the fumarole pressure, the steam flow rate, and the hot water flow rate after the flow rate adjusting valve 4 is controlled by the valve control unit 24.

As described above, according to the well characteristic estimation system of the geothermal power plant according to the present embodiment, the well characteristic estimation method thereof, the well characteristic estimation program, and the geothermal power plant, the flow rate adjustment of the specific well 2 is performed. When the valve 4 is changed by a predetermined amount, the flow control valve 4 of the other well 2 is controlled to suppress the fluctuation of the power generation amount, so that the power generation amount of the geothermal power generation plant 1 is hardly changed. It is possible to acquire information on fluctuations in the jet pressure, steam flow rate, and hydrothermal flow rate due to the adjustment of the flow rate adjusting valve 4 of the specific well 2. That is, it is possible to estimate the well characteristics based on the acquired information without changing the amount of power generated by the geothermal power generation plant 1.

[Third Embodiment]
Next, a well characteristic estimation system for a geothermal power plant according to a third embodiment of the present invention, a well characteristic estimation method thereof, a well characteristic estimation program, and a geothermal power plant will be described.
The wells 2 are related to each other in the underground reservoir and may not have independent characteristics. Therefore, in the present embodiment, the correlation of each well 2 is calculated. Hereinafter, the well characteristic estimation system of the geothermal power generation plant 1 according to the present embodiment, the well characteristic estimation method thereof, the well characteristic estimation program, and the geothermal power generation plant 1 are different from the first embodiment and the second embodiment. Will be mainly explained.

As shown in FIG. 9, the well characteristic estimation device 20 in the present embodiment includes a correlation calculation unit 25. The well characteristic estimation device 20 may include the valve control unit 24 described above.

The correlation calculation unit 25 calculates the correlation of each well 2 based on the well characteristics of each well 2 estimated in the past predetermined period. In the underground reservoir, when the same stratum is used as the water source, a correlated phenomenon may occur, for example, when the fumarole amount of one well 2 is increased, the fumarole amount of the other well 2 is decreased. .. In the well characteristic estimation device 20 described above, it is possible to acquire the characteristics of each well 2 in a state where each well 2 is inserted into the geothermal power generation plant 1 (for example, a state in which fumaroles are being performed in each well 2). Therefore, there is a possibility that the information related to the correlation of each well 2 is included in the estimated well characteristics.

Therefore, the correlation calculation unit 25 calculates the correlation between the wells 2 by comparing the well characteristics of the wells 2 estimated in the past predetermined period (for example, one year, two years, etc.) with each other. ..

Specifically, the correlation calculation unit 25 identifies wells 2 having similar changes over time (tendencies of change) in well characteristics. Since the well characteristics depend on the state of the underground reservoir, it is highly possible that the wells 2 having similar changes over time in the well characteristics are related to each other. Therefore, it is possible to analyze the structure of the underground reservoir based on the found correlation.

For example, by modifying the geothermal fluid reservoir model using the discovered correlation, the state of the geothermal fluid reservoir beneath the ground can be grasped more accurately, while considering the correlation of each well 2. It is also possible to optimize the flow rate of the geothermal fluid ejected from each well 2.

As described above, according to the well characteristic estimation system of the geothermal power plant according to the present embodiment, the well characteristic estimation method thereof, the well characteristic estimation program, and the geothermal power plant, each well 2 is a geothermal fluid. It was difficult to find the correlation between each well 2 because it may not be independent, such as when it is conducting with other wells 2 in the underground reservoir of the above, but each well estimated in the past predetermined period. It can be expected that the correlation of each well 2 will be discovered by referring to the characteristics of the well 2. For example, by modifying the geothermal fluid reservoir model using the discovered correlation, the state of the geothermal fluid reservoir beneath the ground can be grasped more accurately, and the correlation of each well 2 is considered. However, it is also possible to optimize the flow rate of the geothermal fluid ejected from each well 2. Therefore, improvement in the accuracy of well management can be expected.

The present invention is not limited to the above-described embodiment, and various modifications can be made without departing from the gist of the invention. It is also possible to combine each embodiment.

1: Geothermal power plant 2: Well 3: Geothermal fluid transport pipe 4: Flow control valve 5: Gas-water separator 6: Hot water pipe 7: Steam pipe 8: Steam turbine 9: Generator 10: Condenser 11: Cooling Tower 12: Pump 13: On-off valve 14: Pump 15: Flow control valve 16: Pressure gauge 17: Flow meter 18: Flow meter 19: Condenser 20: Well characteristic estimation device 21: Acquisition unit 22: Estimator 23: Optimal Chemical unit 24: Valve control unit 25: Correlation calculation unit

Claims (11)

When a geothermal power plant that generates power using the geothermal fluid ejected from at least one well is in operation and the pressure ejected from the well fluctuates, the steam flow rate of the geothermal fluid with respect to the pressure. And the acquisition unit that acquires information related to the hot water flow rate of the geothermal fluid, and
Based on the information acquired by the acquisition unit, an estimation unit that estimates well characteristics indicating the relationship between the pressure, the steam flow rate, and the hot water flow rate of fumaroles from the well, and an estimation unit.
Well characteristic estimation system for geothermal power plants. The well characteristic estimation system for a geothermal power plant according to claim 1, wherein the estimation unit estimates the well characteristics for each of the plurality of wells. The acquisition unit acquires the total flow rate of steam in the geothermal fluid ejected from each well as the information related to the steam flow rate, and the jet air from each well as the information related to the hot water flow rate. Obtain the total flow rate of hot water in the geothermal fluid
The well characteristic estimation system for a geothermal power plant according to claim 2, wherein the estimation unit estimates the well characteristics for each well by regression analysis based on the total flow rate of steam and the total flow rate of hot water. .. The acquisition unit acquires a part of the total flow rate of steam in the geothermal fluid ejected from each of the wells as the information related to the steam flow rate, and obtains the total flow rate of a part of the steam in the geothermal fluid as the information related to the hot water flow rate. Obtain the partial total flow rate of hot water in the geothermal fluid ejected from
The well of the geothermal power plant according to claim 2, wherein the estimation unit estimates the well characteristics for each well by regression analysis based on the partial total flow rate of steam and the partial total flow rate of hot water. Well characteristic estimation system. The acquisition unit acquires the flow rate of steam in the geothermal fluid ejected from each well as the information related to the steam flow rate, and is ejected from each well as the information related to the hot water flow rate. Obtain the flow rate of hot water in the geothermal fluid
The well characteristic estimation system for a geothermal power plant according to claim 2, wherein the estimation unit estimates the well characteristics for each well based on the flow rate of steam and the flow rate of hot water. The opening degree of the flow rate adjusting valve for the geothermal fluid provided for the specific well is adjusted by a predetermined amount, and is provided for the other well so as to suppress the fluctuation of the amount of power generation due to the adjustment. A valve control unit for controlling the flow rate adjusting valve of the geothermal fluid is provided.
The well characteristic estimation system for a geothermal power plant according to any one of claims 2 to 5, wherein the acquisition unit acquires the information after the valve control unit controls each flow rate control valve. The geothermal power generation according to any one of claims 2 to 6, further comprising a correlation calculation unit for calculating the correlation of each well based on the well characteristics of each well estimated in the past predetermined period. Well characteristic estimation system for plants. When the total flow rate of steam fumarole from each well is constant using the well characteristics of each of the estimated wells, the total flow rate of hot water fumarole from each well is the minimum value. The well characteristic estimation system for a geothermal power plant according to any one of claims 2 to 7, further comprising an optimization unit for determining a combination of fumarolic pressures in each well so as to be within a predetermined range including. A separator that separates the geothermal fluid fumaroles into steam and hot water,
A steam turbine that is rotationally driven by steam separated by a separator,
A generator that is rotationally connected to the steam turbine,
The well characteristic estimation system for a geothermal power plant according to any one of claims 1 to 8.
Geothermal power plant equipped with. When a geothermal power plant that generates power using the geothermal fluid ejected from at least one well is in operation and the pressure ejected from the well fluctuates, the steam flow rate of the geothermal fluid with respect to the pressure. And the acquisition process to acquire information on the hot water flow rate of the geothermal fluid, and
Based on the information acquired in the acquisition step, an estimation step of estimating the well characteristics showing the relationship between the pressure, the steam flow rate, and the hot water flow rate of fumaroles from the well, and an estimation step.
Well characteristics estimation method for geothermal power plants including. When a geothermal power plant that generates power using the geothermal fluid ejected from at least one well is operating, when the pressure ejected from the well fluctuates, the steam flow rate of the geothermal fluid with respect to the pressure. And the acquisition process to acquire information related to the hot water flow rate of the geothermal fluid, and
Based on the information acquired in the acquisition process, an estimation process for estimating the well characteristics indicating the relationship between the pressure, the steam flow rate, and the hot water flow rate of fumaroles from the well, and
A well characteristic estimation program for a geothermal power plant to run a computer.

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