Evaluation method and evaluation device

Abstract

This evaluation method includes a step of comparing a first indicator related to electricity costs of a electricity consumer over a plurality of years in a case in which a distributed power supply system including at least one of a renewable energy power generation device and a fuel cell device is introduced with a second indicator related to electricity costs of the electricity consumer over a plurality of years in a case in which the distributed power supply system is not introduced. Both the first indicator over the plurality of years and the second indicator over the plurality of years are predicted in consideration of a purchase cost of environmental value for achieving a target value of an indicator related to CO2 emissions of the electricity consumer over a plurality of years.

Description

Evaluation Method and Evaluation Apparatus

[0001] The present disclosure relates to an evaluation method and an evaluation apparatus for introduction of a distributed power supply system.

[0002] Patent Document 1 below discloses a technique for evaluating introduction of distributed power sources such as solar cells, fuel cells, and storage batteries from an economic perspective and the like, and presenting a combination of distributed power sources.

[0003] Japanese Patent No. 7058254

[0004] In the technique described in Patent Document 1, a distributed power supply system is evaluated from an economic perspective, but there are still insufficient points as an evaluation for introduction of a distributed power supply system.

[0005] An object of the present disclosure is to provide an evaluation method and an evaluation apparatus for performing a more appropriate evaluation from an economic perspective compared to conventional technologies for introduction of a distributed power supply system by an electric power consumer.

[0006] In order to solve the above problem, an evaluation method according to one aspect of the present disclosure includes a step of comparing a first indicator related to electric power cost of an electric power consumer over a plurality of years when a distributed power supply system including at least one of a natural energy power generation device and a fuel cell device is introduced, with a second indicator related to electric power cost of the electric power consumer over a plurality of years when the distributed power supply system is not introduced, wherein both the first indicator over the plurality of years and the second indicator over the plurality of years are predicted in consideration of an environmental value purchase cost for achieving a target value of an indicator related to CO₂ emissions of the electric power consumer over the plurality of years.

[0007] Furthermore, an evaluation device according to one aspect of the present disclosure includes a memory for storing a first indicator relating to the electricity costs of a power consumer over several years when a distributed power system including at least one of a natural energy power generation device and a fuel cell device is introduced, and a second indicator relating to the electricity costs of a power consumer over several years when the distributed power system is not introduced, and a controller for comparing the first indicator over several years with the second indicator over several years, wherein both the first indicator over several years and the second indicator over several years are predicted taking into account the cost of purchasing environmental value to achieve the target value of the indicator relating to the CO2 emissions of the power consumer over several years.

[0008] One aspect of the present disclosure, the evaluation method and evaluation apparatus, has the effect of enabling a more appropriate evaluation from an economic standpoint compared to conventional technologies regarding the introduction of distributed power generation systems by electricity consumers.

[0009] Figure 1 shows an example of a distributed power system implementation. Figure 2 is a conceptual diagram of the evaluation device. Figure 3 is a flowchart of the evaluation method. Figure 4 shows the target renewable energy rate of electricity consumers over several years. Figure 5 shows a multi-year implementation plan for a distributed power system. Figure 6 shows a breakdown of the amount of electricity supplied to electricity consumers over several years. Figure 7 shows the lump-sum implementation cost over several years. Figure 8 shows the implementation cost paid in installments over several years. Figure 9 shows the first running cost over several years. Figure 10 shows the first electricity cost over several years. Figure 11 compares the cumulative value of the first electricity cost and the cumulative value of the second electricity cost over several years. Figure 12 compares the first electricity cost and the second electricity cost over several years.

[0010] In recent years, due to growing environmental awareness, there has been an increasing trend for electricity consumers to introduce distributed power systems, including distributed power sources such as renewable energy generators, fuel cells, and energy storage devices. Because these distributed power systems allow for flexible combinations of power sources, various combinations of power sources have been evaluated from an economic perspective, and the configuration of the distributed power system has been considered accordingly. However, conventionally, there has been no evaluation of the economic and long-term implications of electricity consumers introducing or not introducing distributed power systems.

[0011] Furthermore, in recent years, electricity consumers sometimes purchase environmental values ​​such as CO2 emission credits when their CO2 emission indicators exceed target values. Therefore, when evaluating the economic implications of electricity consumers adopting distributed power generation systems versus not adopting them, the cost of purchasing these environmental values ​​should also be considered.

[0012] Therefore, the evaluation method of the first aspect of this disclosure comprises the step of comparing a first indicator relating to the electricity costs of a power consumer over several years when a distributed power system including at least one of a natural energy power generation device and a fuel cell device is introduced with a second indicator relating to the electricity costs of a power consumer over several years when the distributed power system is not introduced, wherein both the first indicator over several years and the second indicator over several years are predicted taking into account the cost of purchasing environmental value to achieve the target value of the indicator relating to CO2 emissions of the power consumer over several years.

[0013] This evaluation method compares a first indicator of electricity costs for electricity consumers over several years when a distributed power generation system is introduced with a second indicator of electricity costs for electricity consumers over several years when a distributed power generation system is not introduced. Moreover, both the first and second indicators are predicted taking into account the purchase cost of environmental value. Therefore, according to the above evaluation method, it is possible to make a more appropriate economic assessment of the introduction of a distributed power generation system for electricity consumers compared to conventional technology.

[0014] The evaluation method of the second aspect of this disclosure is the evaluation method of the first aspect, wherein the distributed power system includes an energy storage device.

[0015] Because this evaluation method includes energy storage devices in the distributed power generation system, it allows for a more appropriate economic evaluation of the introduction of distributed power generation systems including energy storage devices by electricity consumers compared to conventional technologies.

[0016] The evaluation method of the third aspect of this disclosure compares the first indicator over multiple years with the second indicator over multiple years by displaying both the first indicator over multiple years and the second indicator over multiple years together on a display device, in the evaluation method of the first aspect.

[0017] This evaluation method displays both a first indicator spanning multiple years and a second indicator spanning multiple years together on a display unit, allowing users to intuitively confirm the evaluation of the introduction of a distributed power system via the display unit. Therefore, this evaluation method allows for a more appropriate evaluation of the introduction of a distributed power system by electricity consumers from an economic standpoint compared to conventional technologies.

[0018] The evaluation method of the fourth aspect of this disclosure is an evaluation method of any one of the first to third aspects, wherein the first indicator includes a first power cost which is the power cost itself, and the first power cost includes costs incurred in connection with the introduction of the distributed power system, the cost of purchasing electricity from the grid, and the cost of purchasing the environmental value, and the second indicator includes a second power cost which is the power cost itself, and the second power cost which includes the cost of purchasing electricity from the grid and the cost of purchasing the environmental value.

[0019] In this evaluation method, both the first and second indicators used for comparison include the cost of purchasing electricity from the grid and the cost of purchasing environmental value. Therefore, this evaluation method allows for a more appropriate economic assessment of the introduction of distributed power generation systems by electricity consumers compared to conventional technologies.

[0020] In recent years, governments and local authorities have sometimes set CO2 emission limits for electricity consumers. In this case, if an electricity consumer's CO2 emissions exceed their limit, they must purchase the excess amount as CO2 emission credits from others. There is also a system in place that allows the sale of CO2 emission reduction credits (credits) representing the amount of CO2 emissions reduced through measures such as CO2 emission reduction. Therefore, electricity consumers sometimes purchase CO2 emission credits or CO2 emission reduction credits.

[0021] Therefore, in the evaluation method of the fifth aspect of this disclosure, in the evaluation method of the fourth aspect, the environmental value includes CO2 emission rights or CO2 emission reduction rights to achieve the target CO2 emission value as the target value.

[0022] As mentioned above, the first and second indicators include the purchase cost of environmental value, but in the evaluation method described above, the environmental value includes CO2 emission rights or CO2 emission reduction rights. Therefore, this evaluation method allows for a more appropriate evaluation from an economic standpoint of the introduction of distributed power generation systems by electricity consumers compared to conventional technologies.

[0023] Furthermore, electricity consumers can purchase renewable energy certificates (electricity certificates) that prove that the grid electricity supplied by power generators is generated from renewable energy sources (solar, wind, hydro, geothermal, etc.). By purchasing these electricity certificates, electricity consumers can demonstrate that the electricity supplied by power generators is generated from renewable energy sources. For this reason, electricity consumers sometimes purchase electricity certificates.

[0024] Therefore, the evaluation method of the sixth aspect of this disclosure, in the evaluation method of the fourth or fifth aspect, includes electricity certificates for achieving the target renewable energy rate as the target value.

[0025] As mentioned above, the first and second indicators include the purchase cost of environmental value, but in the evaluation method described above, electricity certificates are included in the environmental value. Therefore, this evaluation method allows for a more appropriate evaluation from an economic standpoint of the introduction of distributed power generation systems by electricity consumers compared to conventional technologies.

[0026] The seventh aspect of the present disclosure is an evaluation method in any one of the fourth to sixth aspects, wherein the distributed power system includes the fuel cell device, and the first power cost includes the cost of purchasing hydrogen used for power generation by the fuel cell device.

[0027] As mentioned above, the first indicator includes the first electricity cost, but in the evaluation method described above, this first electricity cost includes the cost of hydrogen used to generate electricity for fuel cell systems. Therefore, this evaluation method allows for a more appropriate economic assessment of the introduction of distributed power generation systems by electricity consumers compared to conventional technologies.

[0028] The evaluation method of the eighth aspect of this disclosure is an evaluation method of any one of the fourth to seventh aspects, wherein the first indicator includes a first electricity unit price in the electricity use of the electricity consumer, the first electricity unit price is the value obtained by dividing the first electricity cost by the amount of electricity demanded by the electricity consumer, and the second indicator includes a second electricity unit price in the electricity use of the electricity consumer, the second electricity unit price is the value obtained by dividing the second electricity cost by the amount of electricity demanded by the electricity consumer.

[0029] In this evaluation method, the first and second indicators used for comparison include the first and second electricity unit prices, respectively. Therefore, this evaluation method allows for a more appropriate economic assessment of the introduction of distributed power generation systems by electricity consumers compared to conventional technologies.

[0030] Furthermore, in recent years, some companies have adopted internal carbon tax systems to promote decarbonization by assigning a price to their CO2 emissions (internal carbon tax), thereby expressing emissions in monetary terms. This internal carbon tax is also known as ICP (Internal Carbon Pricing).

[0031] Therefore, the evaluation method of the ninth aspect of this disclosure, in the evaluation method of the eighth aspect, includes a carbon tax within the electricity consumer for the first electricity cost and the second electricity cost.

[0032] As mentioned above, the first and second indicators used for comparison include the first and second electricity costs, respectively. However, in the evaluation method described above, both the first and second electricity costs include carbon taxes within the electricity consumer. Therefore, this evaluation method allows for a more appropriate economic assessment of the introduction of distributed power generation systems by electricity consumers compared to conventional technologies.

[0033] The evaluation method of the tenth aspect of the present disclosure is the evaluation method of the first aspect, wherein the first index includes a cumulative value of a first electricity cost, and the second index includes a cumulative value of a second electricity cost.

[0034] In this evaluation method, the first and second indicators used for comparison include the cumulative values ​​of the first and second electricity costs, respectively. Therefore, this evaluation method allows for a more appropriate economic assessment of the introduction of distributed power generation systems by electricity consumers compared to conventional technologies.

[0035] An evaluation method according to the eleventh aspect of this disclosure comprises, in the evaluation method according to the tenth aspect, a step of predicting the recovery period of the introduction cost of the distributed power system based on the comparison.

[0036] This evaluation method allows for a more appropriate economic assessment of the introduction of distributed power systems by electricity consumers compared to conventional technologies, in order to predict the payback period for the introduction costs of distributed power systems.

[0037] The evaluation method of the twelfth aspect of this disclosure is an evaluation method of any one of the first to eleven aspects, in which a multi-year introduction plan for the distributed power system is formulated based on the target values ​​of the multi-year CO2 emission indicators of the electricity consumer and the budget plan for CO2 emission reduction, and the first indicator is predicted as if the distributed power system were introduced based on the introduction plan.

[0038] This evaluation method allows for the prediction of a multi-year primary indicator of the implementation of a distributed power system, based on a multi-year implementation plan for the distributed power system. Therefore, this evaluation method allows for a more appropriate economic assessment of the implementation of distributed power systems by electricity consumers compared to conventional technologies.

[0039] The evaluation method of the 13th aspect of this disclosure comprises, in the evaluation method of the third aspect, a step of displaying on the display the introduction plan of the distributed power system, which is formulated based on the target value of the CO2 emission indicator of the electricity consumer and the budget plan for CO2 emission reduction.

[0040] In this evaluation method, the distribution power system implementation plan is displayed on a display unit. Therefore, according to this evaluation method, the proposer of the distribution power system implementation, who is a user of the display unit, or the electricity consumer who is presented with the information displayed on the display unit by the proposer, can easily understand the distribution power system implementation plan.

[0041] An evaluation apparatus according to a 14th aspect of this disclosure includes a memory for storing a first indicator relating to the electricity costs of a power consumer over several years when a distributed power system including at least one of a natural energy power generation device and a fuel cell device is introduced, and a second indicator relating to the electricity costs of a power consumer over several years when the distributed power system is not introduced, and a controller for comparing the first indicator over several years with the second indicator over several years, wherein both the first indicator over several years and the second indicator over several years are predicted taking into account the cost of purchasing environmental value to achieve the target value of the indicator relating to the CO2 emissions of the power consumer over several years.

[0042] According to this evaluation device, for the same reasons as the evaluation method of the first embodiment, it is possible to perform a more appropriate evaluation from an economic standpoint compared to conventional technology regarding the introduction of distributed power generation systems by electricity consumers.

[0043] Hereinafter, specific examples of the above aspects of the present disclosure will be described with reference to the accompanying drawings. All the specific examples described below are illustrative of the above aspects of the present disclosure. Therefore, the shapes, numerical values, components, arrangement positions and connection forms of components, etc. shown below do not limit the scope of the claims unless they are recited in the claims.

[0044] In addition, among the components described below, components that are not recited in the independent claim representing the most general concept of the present disclosure are described as optional components. Also, in the drawings, descriptions of components denoted by the same reference numerals may be omitted in some cases. The drawings schematically show each component for ease of understanding, and shapes, dimensional ratios, and the like may not be accurately represented.

[0045] Furthermore, in the operation of the apparatus, the order of steps may be changed as needed, and known steps may be added.

[0046] (Example of Introduction of Distributed Power Supply System) First, an example of introduction of a distributed power supply system 12 by a power consumer 10 will be described. FIG. 1 is a diagram showing an example of introduction of a distributed power supply system 12. FIG. 1(a) shows a mode of power supply to the power consumer 10 before the start of introduction of the distributed power supply system 12. The power consumer 10 of the present embodiment is a factory that produces products, and the power consumer 10 includes power consumption equipment 11 such as production equipment that produces products. In the present embodiment, as shown in FIG. 1(a), before the start of introduction of the distributed power supply system 12, power is supplied to the power consumption equipment 11 of the power consumer 10 only from a power generation business operator 20 such as an electric power company. Note that, hereinafter, power supplied from the power generation business operator 20 to the power consumer 10 is referred to as "grid power".

[0047] Fig. 1(b) shows a mode of power supply to a power consumer 10 in an intermediate stage of introduction of a distributed power supply system 12. In the present embodiment, as shown in Fig. 1(b), in the intermediate stage of introduction of the distributed power supply system 12, power is supplied from not only grid power but also the distributed power supply system 12 to power consumption equipment 11 of the power consumer 10. Note that the distributed power supply system 12 includes distributed power sources such as a natural energy power generation device 13, a fuel cell device 14, and a power storage device 15. However, the distributed power supply system 12 is not limited to the above configuration. For example, the distributed power supply system 12 may include only one of the above-described distributed power sources.

[0048] The aforementioned natural energy power generation device 13 is a device that generates power using natural energy, and examples thereof include solar power generation devices and wind power generation devices. Further, the fuel cell device 14 is a device that generates power by causing a chemical reaction between hydrogen, which is a fuel, and an oxide such as oxygen. Hydrogen, which is the fuel for the fuel cell device 14, includes a plurality of types of hydrogen such as gray hydrogen extracted from fossil resources and green hydrogen produced using renewable energy. Furthermore, the power storage device 15 is a device that temporarily stores and supplies power generated by other devices.

[0049] Fig. 1(c) shows a mode of power supply to the power consumer 10 after the completion of introduction of the distributed power supply system 12. In the present embodiment, as shown in Fig. 1(c), after the completion of introduction of the distributed power supply system 12, power is supplied only from the distributed power supply system 12 to the power consumption equipment 11 of the power consumer 10. However, even after the completion of introduction of the distributed power supply system 12, power may be supplied to the power consumption equipment 11 of the power consumer 10 from both a power generation business operator 20 and the distributed power supply system 12 in some cases.

[0050] (Evaluation Device) Next, an evaluation device 30 used in the evaluation method according to the present embodiment will be described. Fig. 2 is a conceptual diagram of the evaluation device 30. The evaluation device 30 includes a controller 31, a storage 32, an input device 33, and a display 34.

[0051] The controller 31 comprises an arithmetic processing unit and a memory unit for storing control programs. The arithmetic processing unit is, for example, a processor, and the memory unit is, for example, volatile memory. The controller 31 may be a single controller or a group of controllers working together. The memory unit 32 is, for example, non-volatile memory and is a device for storing various programs and information. The input device 33 is, for example, a keyboard operated by an operator and is a device for inputting various information. The display device 34 is, for example, a monitor and is a device for displaying various information.

[0052] Furthermore, the evaluation device 30 is connected to an information server (not shown) in a communicative manner, and this information server may execute the processing of the controller 31, which will be described later. In other words, the controller 31 may consist of multiple devices, including a server that is connected in a communicative manner.

[0053] (Evaluation Method Flow) Next, the evaluation method according to this embodiment will be described. The evaluation method according to this embodiment is a method for predicting indicators for evaluating the introduction of a distributed power source system 12 by a power consumer from an economic standpoint. More specifically, the evaluation method according to this embodiment compares a first indicator relating to the power cost of a power consumer 10 over several years when the distributed power source system 12 is introduced with a second indicator relating to the power cost of a power consumer 10 over several years when the distributed power source system 12 is not introduced. This will be explained in detail below.

[0054] <Setting Target Values> Figure 3 is a flowchart of the evaluation method according to this embodiment. As shown in Figure 3, in the flowchart of the evaluation method according to this embodiment, the operator first sets target values ​​(step S10). Specifically, the operator sets target values ​​for indicators related to CO2 emissions of the electricity consumer 10 over several years. Indicators related to CO2 emissions include, for example, CO2 emissions, CO2 emission reduction, electricity emission coefficient, and renewable energy rate.

[0055] In this embodiment, a multi-year target renewable energy rate is set as the target value for the CO2 emission indicator. The renewable energy rate refers to the proportion of electricity generated from renewable energy sources in the electricity supplied to electricity consumers or the electricity consumed by electricity consumers. Figure 4 shows the multi-year target renewable energy rate for electricity consumer 10. The thick line in Figure 4 represents the multi-year target renewable energy rate for electricity consumer 10. The worker sets the multi-year target renewable energy rate for electricity consumer 10, as shown by the thick line in Figure 4, based on information such as the standard values ​​and benchmark values ​​for renewable energy rates of the industry, country, and local government to which electricity consumer 10 belongs, as well as the electricity consumer 10's decarbonization plan. The above reference values ​​and standard values ​​are the target renewable energy rate to be achieved in the industry to which electricity consumer 10 belongs, the target renewable energy rate of other electricity consumers (for example, other companies) in the industry to which electricity consumer 10 belongs, and the target renewable energy rate to be achieved in the country or local government to which electricity consumer 10 belongs.

[0056] In the example shown in Figure 4, the 30-year period is divided into six 5-year periods, from the first to the sixth, with target renewable energy rates set for each period. The first period is before the introduction of the distributed power system 12 and corresponds to the state shown in Figure 1(a). The second and third periods are intermediate stages in the introduction of the distributed power system 12 and correspond to the state shown in Figure 1(b). The fourth through sixth periods are after the completion of the introduction of the distributed power system 12 and correspond to the state shown in Figure 1(c). Furthermore, the first through sixth periods shown in Figures 5 through 11 correspond to the first through sixth periods shown in Figure 4, respectively.

[0057] Furthermore, targets other than the target renewable energy rate may be set as target values ​​for indicators related to CO2 emissions. In this case, the same method as for the target renewable energy rate can be used to set the target. For example, when setting a target CO2 emission as a target value for indicators related to CO2 emissions, the operator can set multi-year target CO2 emission for electricity consumer 10 based on information such as the standard values ​​and benchmark values ​​for CO2 emissions of the industry, country, or local government to which electricity consumer 10 belongs, as well as electricity consumer 10's decarbonization plan. The above standard values ​​and benchmark values ​​are the target CO2 emission values ​​that electricity consumer 10 wants to achieve in its industry, the target CO2 emission values ​​of other electricity consumers (e.g., other companies) in its industry, and the target CO2 emission values ​​that electricity consumer 10 wants to achieve in its country or local government.

[0058] <Formulation of Implementation Plan> Next, in the evaluation method flow according to this embodiment, the worker formulates a multi-year implementation plan for the distributed power system 12 (step S20). In this embodiment, the worker formulates a multi-year implementation plan for the distributed power system 12 based on the target values ​​of the CO2 indicators (target renewable energy rate) and the budget plan for CO2 emission reduction set in step S10. The multi-year implementation plan for the distributed power system 12 may also be formulated by the controller 31.

[0059] Figure 5 shows a multi-year implementation plan for the distributed power system 12. In Figure 5, the multi-year implementation plan is shown using the rated output of the distributed power sources that make up the distributed power system 12 (the units of rated output are kW, MW, etc.). In the implementation plan shown in Figure 5, no distributed power sources are introduced in the first phase, a renewable energy power generation device 13, a fuel cell device 14, and an energy storage device 15 are introduced in the second phase, the number of fuel cell devices 14 is increased in the third phase, the number of fuel cell devices 14 is further increased in the fourth phase, and the configuration of the fourth phase is maintained in the fifth and sixth phases.

[0060] The introduction plan for the distributed power system 12 is not limited to that shown in Figure 5. For example, an introduction plan may be formulated to introduce at least one of the renewable energy power generation device 13 and the fuel cell device 14, or an introduction plan may be formulated to introduce at least one of the renewable energy power generation device 13 and the fuel cell device 14 and the energy storage device 15.

[0061] Furthermore, the introduction plan for the distributed power system 12 may include an introduction plan for replacing at least a portion of the distributed power system 12. In this embodiment, the service life of the renewable energy power generation device 13 is 25 years, and the service life of the fuel cell device 14 and the energy storage device 15 is 15 years. Therefore, although not shown in Figure 5, the introduction plan in this embodiment includes an introduction plan to replace the renewable energy power generation device 13 with a new one after 25 years from the time of introduction, and to replace the fuel cell device 14 and the energy storage device 15 with new ones after 15 years from the time of introduction.

[0062] Furthermore, in this embodiment, the introduction plan for the distributed power system 12 is formulated based on both target values ​​for CO2 emission indicators and a budget plan for CO2 emission reduction, but it may also be formulated based on either one of them. In addition, in this embodiment, the introduction plan for the distributed power system 12 is formulated based on the target renewable energy rate, but instead of this target renewable energy rate, or in addition to the target renewable energy rate, the introduction plan for the distributed power system 12 may also be formulated based on target values ​​for other CO2 emission indicators, such as target CO2 emissions.

[0063] <Display of Implementation Plan> Next, in the evaluation method flow according to this embodiment, the operator displays the multi-year implementation plan for the distributed power system 12 using the evaluation device 30 (step S30). In this embodiment, the operator inputs the data related to the multi-year implementation plan for the distributed power system 12 formulated in step S20 into the input device 33, and the controller 31 of the evaluation device 30 displays the multi-year implementation plan for the distributed power system 12 on the display 34 based on that implementation data.

[0064] <Prediction of the breakdown of electricity consumption> Next, in the evaluation method flow according to this embodiment, the controller 31 predicts the breakdown of the amount of electricity supplied to the electricity consumer 10 from each power supply source over several years (step S40). This breakdown of electricity consumption includes the amount of electricity supplied to the electricity consumer 10 from the renewable energy power generation device 13, the amount of electricity supplied to the electricity consumer 10 from the fuel cell device 14, the amount of electricity supplied to the electricity consumer 10 from the energy storage device 15, and the amount of grid power supplied to the electricity consumer 10.

[0065] Based on the data regarding the introduction plan of the distributed power system 12 entered by the operator in step S30, the controller 31 calculates or acquires the amount of electricity supplied from the renewable energy power generation device 13 to the power consumer 10, the amount of electricity supplied from the fuel cell device 14 to the power consumer 10, and the amount of electricity supplied from the energy storage device 15 to the power consumer 10. The controller 31 also predicts the amount of grid power supplied to the power consumer 10 by subtracting the amount of electricity supplied to the power consumer 10 by the distributed power system 12 (renewable energy power generation device 13, fuel cell device 14, and energy storage device 15) from the power consumer 10's demand amount (amount of electricity consumed). In this embodiment, the power consumer 10's demand amount is predicted to be the same every year, but this is not limited to this.

[0066] Figure 6 shows the breakdown of electricity supplied to electricity consumer 10 over several years (units of electricity are kHh, MHh, etc.). In the example shown in Figure 6, in the first period, all of the electricity supplied to electricity consumer 10 is from the grid. From the second to the fourth period, the proportion of electricity supplied from the distributed power system 12 (natural energy power generation device 13, fuel cell device 14, energy storage device 15) to electricity consumer 10 gradually increases, and from the fourth to the sixth period, all of the electricity supplied to electricity consumer 10 is supplied from the distributed power system 12.

[0067] <Prediction of the First Indicator> Next, in the evaluation method flow according to this embodiment, the controller 31 predicts the first indicator for the electricity consumer 10 over several years when the distributed power system 12 is introduced (step S50). The first indicator in this embodiment is an indicator related to electricity cost. The first indicator includes the first electricity cost, the first electricity unit price, and the cumulative value of the first electricity cost. Furthermore, the first electricity cost includes the costs incurred with the introduction of the distributed power system 12 and the first running costs. In this embodiment, these costs (i.e., the first indicator) are predicted by performing steps S51 to S55. Each step will be described below.

[0068] <Prediction of costs associated with the introduction of a distributed power system> First, the controller 31 predicts the costs that will be incurred over several years if the distributed power system 12 is introduced (step S51). The costs associated with the introduction of the distributed power system 12 include at least the introduction cost of the distributed power system 12, and may also include running costs incurred after the introduction of the distributed power system 12. Here, the lump-sum introduction cost is predicted, and then the installment-based introduction cost is predicted.

[0069] Here, memory 32 stores predicted data of the unit cost of distributed power capacity over several years. The unit cost of distributed power capacity is the unit cost of capacity of the renewable energy power generation device 13 and at least one of the fuel cell device 14 to be introduced based on the distributed power introduction plan. Furthermore, if the distributed power system 12 includes an energy storage device 15, the unit cost of capacity of the energy storage device 15 is also included. Based on the multi-year introduction plan for the distributed power system 12 formulated in step S20 and the predicted data of the unit cost of distributed power capacity over several years obtained from memory 32, the controller 31 predicts the multi-year lump-sum introduction cost when the distributed power system 12 is introduced.

[0070] Furthermore, in this embodiment, the running costs incurred after the introduction of the distributed power system 12 may include the cost of purchasing hydrogen. The cost of purchasing hydrogen is the cost of purchasing hydrogen used for power generation by the fuel cell device 14. The memory 32 stores predicted hydrogen unit price data for multiple years. The memory 32 may also store predicted hydrogen unit price data for multiple years for each type of hydrogen, such as green hydrogen and gray hydrogen. The controller 31 predicts the amount of hydrogen used by the fuel cell device 14 over multiple years from the amount of electricity that the fuel cell device 14 will supply to the power consumer 10, as predicted in step S40. Then, the controller 31 predicts the hydrogen purchase cost over multiple years based on the predicted amount of hydrogen used by the fuel cell device 14 and the predicted hydrogen unit price data for multiple years obtained from the memory 32.

[0071] Figure 7 shows the lump-sum installation costs over multiple years when the distributed power system 12 predicted by the controller 31 is implemented. In the example shown in Figure 7, the renewable energy power generation device 13, fuel cell device 14, and energy storage device 15 are installed in the first year of the second phase, and the lump-sum installation costs for these are shown. In addition, the fuel cell device 14 is installed in the first year of the third and fourth phases, respectively, and the lump-sum installation costs for these are shown. Furthermore, since the fuel cell device 14 and energy storage device 15 have a service life of 15 years, the fuel cell device 14 and energy storage device 15 installed in the first year of the second phase are replaced in the first year of the fifth phase. Therefore, the lump-sum installation costs for these are shown in the first year of the fifth phase. Furthermore, in the first year of the sixth phase, the fuel cell device 14 installed in the first year of the third phase is replaced, and the lump-sum installation cost for this is shown.

[0072] Next, the controller 31 predicts the installment costs for introducing the distributed power supply system 12 over multiple years. The installment costs are the total introduction costs for introducing the distributed power supply system 12 based on the introduction plan, paid in installments each year from the introduction year to the end of its useful life. In the case of introducing the distributed power supply system 12, distributed power sources with various useful lives may be introduced in various introduction years. In this embodiment, the installment costs for each distributed power source are predicted for each useful life and each introduction year, and these are added together to predict the installment costs for the distributed power supply system 12.

[0073] Figure 8 shows the installment-based installation costs over multiple years. Figure 8 corresponds to the lump-sum installation costs shown in Figure 7. For example, the installment-based installation costs for each year of the second period are calculated by adding the cost of the renewable energy power generation device 13 installed in the first year of the second period divided by its useful life of 25 years, and the cost of the fuel cell device 14 and energy storage device 15 divided by their respective useful lives of 15 years. Similarly, the installment-based installation costs for each year of the third period are calculated by adding the cost of the fuel cell device 14 purchased in the first year of the third period divided by its useful life of 15 years to the installment-based installation costs for each year of the second period. The installment-based installation costs for each year from the fourth period onward are predicted in the same manner. Note that Figures 7 and 8 may also include not only the lump-sum or installment-based installation costs but also the running costs incurred after the installation of the distributed power system 12 as costs associated with the introduction of the distributed power system 12.

[0074] <Prediction of the First Running Cost> Next, the controller 31 predicts the first running cost, which is the running cost over several years when the distributed power system 12 is introduced (step S52). The first running cost in this embodiment includes at least the cost of purchasing electricity and the cost of purchasing environmental value. The first running cost may also include a carbon tax. These costs will be explained in order below.

[0075] [Electricity Purchase Cost] The electricity purchase cost is the cost for electricity consumer 10 to purchase grid electricity. The electricity purchase cost varies depending on the supplier, such as the power company. The memory 32 stores predicted electricity unit price data for grid electricity over several years for each supplier. In this embodiment, the controller 31 displays the electricity unit price for grid electricity for each supplier on the display 34 in a menu selectable format, and the operator (user) uses the input 33 to select the electricity unit price of the supplier. Based on this, the controller 31 predicts the electricity purchase cost over several years, using the amount of grid electricity supplied to electricity consumer 10 predicted in step S40 and the predicted electricity unit price data for grid electricity selected by the operator obtained from the memory 32.

[0076] [Cost of purchasing environmental value] The cost of purchasing environmental value is the cost of purchasing environmental value such as CO2 emission rights, CO2 emission reduction rights, and electricity certificates. Electricity consumer 10 may purchase all environmental value or only some of it. Therefore, it is possible to predict the cost of purchasing all environmental value or the cost of purchasing some of the environmental value.

[0077] In some cases, the government or local authorities may set CO2 emission limits for electricity consumers 10. If an electricity consumer 10's CO2 emissions exceed these limits, the consumer 10 must purchase the excess amount as CO2 emission credits from other consumers. Therefore, consumers may purchase CO2 emission credits to achieve their CO2 emission targets. In addition to the above-mentioned CO2 emission credits, there is also a growing movement to allow the buying and selling of CO2 emission reduction credits (credits) resulting from CO2 emission reduction measures such as the introduction of energy-saving equipment and the use of renewable energy. Therefore, consumers may also purchase CO2 emission reduction credits to achieve their CO2 emission targets.

[0078] The controller 31 predicts the CO2 emissions of electricity consumers 10 over multiple years from the breakdown of electricity consumption from each power source over multiple years predicted in step S40, and predicts the amount of CO2 emission credits or CO2 emission reduction credits to be purchased over multiple years from the difference between the predicted CO2 emissions of electricity consumers 10 over multiple years and the predetermined target CO2 emissions over multiple years. The memory 32 also stores predicted data on the unit price of CO2 emission credits or CO2 emission reduction credits over multiple years. The controller 31 then predicts the cost of purchasing CO2 emission credits or CO2 emission reduction credits over multiple years based on the predicted amount of CO2 emission credits or CO2 emission reduction credits to be purchased over multiple years and the predicted data on the unit price of CO2 emission credits or CO2 emission reduction credits over multiple years obtained from the memory 32.

[0079] Furthermore, electricity consumers 10 can purchase renewable energy certificates (electricity certificates) that prove that the grid electricity supplied by power generators 20 is generated from renewable energy sources (solar, wind, hydro, geothermal, etc.). By purchasing these electricity certificates, electricity consumers 10 can demonstrate that the electricity supplied by power generators 20 is generated from renewable energy sources. For this reason, electricity consumers 10 may purchase electricity certificates in order to achieve their target renewable energy rate.

[0080] The controller 31 predicts the renewable energy rate of electricity consumers 10 over multiple years from the breakdown of electricity consumption from each power source over multiple years predicted in step S40, and predicts the amount of electricity certificates to be purchased over multiple years from the difference between the predicted renewable energy rate of electricity consumers 10 over multiple years and a preset target renewable energy rate over multiple years. The memory 32 also stores predicted data on the unit price of electricity certificates over multiple years. The controller 31 then predicts the cost of purchasing electricity certificates over multiple years based on the predicted amount of electricity certificates to be purchased over multiple years and the predicted data on the unit price of electricity certificates over multiple years obtained from the memory 32.

[0081] The controller 31 predicts the renewable energy rate of the electricity consumer 10 by predicting the proportion of electricity generated from renewable energy supplied to the electricity consumer 10 from the distributed power system 12 within the electricity consumer 10's total electricity demand. Furthermore, the proportion of electricity generated from renewable energy supplied to the electricity consumer 10 from the distributed power system 12 within the electricity consumer 10's total electricity demand can be predicted from the breakdown of electricity supplied to the electricity consumer 10 predicted in step S40.

[0082] However, the amount of electricity generated from renewable energy supplied from the distributed power system 12 to the electricity consumer 10 does not include the amount of electricity supplied from the fuel cell device 14 to the electricity consumer 10 when the fuel cell device 14 generates electricity using gray hydrogen, but does include the amount of electricity supplied from the fuel cell device 14 to the electricity consumer 10 when the fuel cell device 14 generates electricity using green hydrogen. Since green hydrogen is hydrogen obtained by water electrolysis using electricity generated using renewable energy, it is included in renewable energy in this disclosure.

[0083] [Carbon Tax] Furthermore, some companies may adopt an internal carbon tax system to promote decarbonization, where they assign a price to their own CO2 emissions (internal carbon tax) and express emissions in monetary terms. An internal carbon tax is also called ICP (Internal Carbon Pricing). Therefore, electricity consumers 10 may have to pay a carbon tax depending on the agreement of the company they belong to.

[0084] The controller 31 predicts the CO2 emissions of electricity consumers 10 over multiple years based on the breakdown of electricity consumption from each power source over multiple years predicted in step S40. The memory 32 stores the carbon tax rates within electricity consumers 10 over multiple years. The controller 31 then predicts the carbon tax over multiple years based on the predicted CO2 emissions of electricity consumers 10 over multiple years and the carbon tax rates within electricity consumers 10 over multiple years obtained from the memory 32.

[0085] In this embodiment, the sum of the above-mentioned electricity purchase costs, environmental value purchase costs, and carbon tax is defined as the first running cost. Figure 9 shows the first running cost over several years. In the example shown in Figure 9, since the first period is before the introduction of the distributed power system 12, the first running cost includes the cost of purchasing grid electricity, but does not include the cost of purchasing environmental value or the carbon tax. Furthermore, the first running cost for the second and third periods includes the cost of purchasing grid electricity, the cost of purchasing environmental value, and the carbon tax. Moreover, since the introduction of the distributed power system 12 is completed from the fourth period onward, the first running cost includes the carbon tax, but does not include the cost of purchasing grid electricity or the cost of purchasing environmental value. If the distributed power system 12 includes a fuel cell device 14, the hydrogen fuel cost, which is incurred as a running cost after the introduction of the distributed power system 12, may be added to the running cost shown in Figure 9. In this case, the hydrogen fuel cost will be added to the running cost from the second period onward.

[0086] <Prediction of the First Power Cost> Next, the controller 31 predicts the first power cost over several years (step S53). The "first power cost" here refers to the power cost itself, and in this embodiment, it is the total cost when the distributed power system 12 is introduced. However, the first cost is not limited to the total cost. In this embodiment, the controller 31 predicts the first power cost over several years by adding up the introduction cost over several years, which is predicted in step S51, the running costs incurred after the introduction of the distributed power system over several years, and the first running cost over several years, which is predicted in step S52. Figure 10 is a diagram showing the first power cost (total cost) over several years. Figure 10 is a diagram that combines the introduction cost over several years, which is predicted in Figure 8, and the first running cost over several years, which is predicted in Figure 9. In the example shown in Figure 10, the first power cost is high from the second to the fourth period, but gradually decreases in the fifth and sixth periods.

[0087] In this embodiment, the installment payment introduction cost predicted in step S51 is used to predict the first power cost, but other introduction costs may be used. For example, the lease fee for the distributed power system 12 may be used instead of the installment payment introduction cost. In other words, the introduction cost for the distributed power system 12 includes not only the cost based on the purchase of the distributed power system 12, but also the lease fee incurred from leasing the distributed power system 12.

[0088] <Prediction of the First Electricity Unit Price> Next, the controller 31 predicts the first electricity unit price for the electricity usage of electricity consumer 10 over several years (step S54). The "first electricity unit price" here is the value obtained by dividing the first electricity cost by the amount of electricity demanded by electricity consumer 10. Therefore, the controller 31 predicts the first electricity unit price by dividing the first electricity cost (total cost) shown in Figure 10 by the amount of electricity demanded by electricity consumer 10.

[0089] In this embodiment, as shown in Figure 6, the total amount of electricity supplied to the electricity consumer 10, that is, the amount of electricity demanded by the electricity consumer 10, is predicted to be the same every year. Therefore, the first electricity unit price over multiple years, obtained by dividing the first electricity cost over multiple years by the amount of electricity demanded by the electricity consumer 10, will also show the same trend as the first electricity cost over multiple years (see Figure 10). However, the prediction that the amount of electricity demanded by the electricity consumer 10 will be the same every year is just an example and is not limited to this.

[0090] <Prediction of the cumulative value of the first power cost> Next, the controller 31 predicts the cumulative value of the first power cost over several years (step S55). The controller 31 predicts the cumulative value of the first power cost over several years by sequentially adding up the first power cost for each year predicted in step S53.

[0091] Figure 11 compares the cumulative value of the first electricity cost over several years with the cumulative value of the second electricity cost over several years, which will be described later. The solid line in Figure 11 represents the cumulative value of the first electricity cost over several years. As shown in Figure 11, the cumulative value of the first electricity cost increases year by year.

[0092] By performing steps S51 to S55 described above, the controller 31 predicts the first electricity cost, the first electricity unit price, and the cumulative value of the first electricity cost, which are included in the first indicator. The first electricity unit price and the cumulative value of the first electricity cost are predicted based on the first electricity cost, which includes the cost of purchasing environmental value. Therefore, it can be said that the first electricity cost, the first electricity unit price, and the first electricity cost are all predicted taking into account the cost of purchasing environmental value to achieve the target values ​​of the CO2 emission indicators for the electricity consumer 10 over several years.

[0093] <Prediction of the Second Power Cost> Next, in the evaluation method flow according to this embodiment, the controller 31 predicts a second indicator for the power consumer 10 over several years in the case where the distributed power system 12 is not introduced (step S60). The second indicator in this embodiment is an indicator related to power cost, just like the first indicator. The second indicator includes the second power cost, the second power unit price, and the cumulative value of the second power cost. In this embodiment, these costs (i.e., the second indicator) are predicted by performing steps S61 to S623. Each step will be described below.

[0094] <Prediction of the Second Power Cost> First, the controller 31 predicts the second power cost over several years (step S61). The "second power cost" here refers to the power cost itself, and in this embodiment, it is the total cost when the distributed power system 12 is not introduced. However, the second power cost is not limited to the total cost. Unlike the first power cost, the second power cost does not include the costs incurred when introducing the distributed power system 12. Therefore, the second power cost (total cost) in this embodiment is the running cost when the distributed power system 12 is not introduced.

[0095] The second electricity cost includes at least the cost of purchasing electricity and the cost of purchasing environmental value. The second electricity cost may also include a carbon tax. The cost of purchasing electricity, the cost of purchasing environmental value, and the carbon tax have been explained in step S52, so their explanation is omitted here. Figure 12 is a diagram comparing the first and second electricity costs over several years. The dashed line in Figure 12 shows the second electricity cost over several years. In the example shown in Figure 12, the second power source cost continues to rise from the first to the sixth period.

[0096] <Prediction of the second electricity unit price> Next, the controller 31 predicts the second electricity unit price for the electricity usage of electricity consumer 10 over several years (step S62). The "second electricity unit price" here is the value obtained by dividing the second electricity cost by the amount of electricity demanded by electricity consumer 10. Therefore, the controller 31 predicts the second electricity unit price by dividing the second electricity cost (which is both the running cost and the total cost) shown in Figure 12 by the amount of electricity demanded by electricity consumer 10.

[0097] In this embodiment, as shown in Figure 6, the total amount of electricity supplied to the electricity consumer 10, that is, the amount of electricity demanded by the electricity consumer 10, is predicted to be the same every year. Therefore, the second electricity unit price over multiple years, obtained by dividing the second electricity cost over multiple years by the amount of electricity demanded by the electricity consumer 10, will also show the same trend as the second electricity cost over multiple years. However, the prediction that the amount of electricity demanded by the electricity consumer 10 will be the same every year is just an example and is not limited to this.

[0098] <Prediction of the cumulative value of the second power cost> Next, the controller 31 predicts the cumulative value of the second power cost over several years (step S63). The controller 31 predicts the cumulative value of the second power cost over several years by sequentially adding up the second power cost for each year predicted in step S51. The dashed line in Figure 11 shows the cumulative value of the second power cost over several years. As shown in Figure 11, the cumulative value of the second power cost increases year by year.

[0099] By performing steps S61 to S62 described above, the controller 31 predicts the second electricity cost, the second electricity unit price, and the cumulative value of the second electricity cost, which are included in the second indicator. The first electricity unit price and the cumulative value of the first electricity cost are predicted based on the first electricity cost, but the first electricity cost includes the cost of purchasing environmental value. Therefore, it can be said that the second electricity cost, the second electricity unit price, and the second electricity cost are all predicted taking into account the cost of purchasing environmental value to achieve the target values ​​of the CO2 emission indicators for the electricity consumer 10 over several years.

[0100] <Comparison Display> Next, in the evaluation method flow according to this embodiment, the controller 31 compares a first indicator over multiple years with a second indicator over multiple years (step S90). In other words, the controller 31 compares indicators related to electricity costs over multiple years for a power consumer with and without introducing a distributed power system 12. In this embodiment, the controller 31 compares the first electricity cost over multiple years with the second electricity cost, compares the first electricity unit price over multiple years with the second electricity unit price, and compares the cumulative value of the first electricity cost over multiple years with the added value of the second electricity cost.

[0101] In this embodiment, the controller 31 compares the first indicator and the second indicator, both spanning multiple years, by displaying them on the display 34. For example, when the controller 31 compares the first and second power costs over multiple years, it displays a graph on the display 34 as shown in Figure 12. The solid line in Figure 12 represents the first power cost and corresponds to the bar graph in Figure 10. In the example shown in Figure 12, the first and second power costs are the same in the first period before the introduction of the distributed power system 12. In the second period, the first power cost is higher than the second power cost, but from the third period onward, the first power cost is lower than the second power cost.

[0102] Furthermore, when comparing the first and second electricity unit prices over multiple years, the controller 31 displays a graph of both indicators side-by-side on the display unit 34. In addition, when comparing the cumulative value of the first electricity cost over multiple years with the cumulative value of the second electricity cost, the controller 31 displays a graph like the one shown in Figure 11 on the display unit 34. In the example shown in Figure 11, in the first period before the introduction of the distributed power supply system 12, the cumulative value of the first electricity cost and the cumulative value of the second electricity cost are the same. From the second to the third period, the cumulative value of the first electricity cost is higher than the cumulative value of the second electricity cost, but from the fourth period onward, the cumulative value of the first electricity cost is lower than the cumulative value of the second electricity cost. Note that when comparing the first and second indicators over multiple years, the controller 31 may display the numerical values ​​side-by-side on the display unit 34 instead of graphs of both indicators.

[0103] <Prediction of the recovery period of the introduction costs> Next, in the evaluation method flow according to this embodiment, the controller 31 predicts the recovery period of the introduction costs of the distributed power system 12 (step S80). When the distributed power system 12 is introduced, costs associated with the introduction of the distributed power system 12 are required, but running costs (first running costs) can be suppressed because the purchase costs of environmental value etc. can be reduced. Therefore, the "recovery period of the introduction costs of the distributed power system 12" is the time when the cumulative value of running costs reduced by introducing the distributed power system 12 exceeds the cumulative value of costs associated with the introduction of the distributed power system 12. Furthermore, the above recovery period can also be said to be the time when the cumulative value of the first power cost when the distributed power system is introduced exceeds the cumulative value of the second power cost when the distributed power system is not introduced.

[0104] In this embodiment, the controller 31 predicts the recovery period for the cost of introducing the distributed power system 12 by comparing the first power cost (total cost when the distributed power system 12 is introduced) and the second power cost (total cost when the distributed power system 12 is not introduced), as shown in Figure 11. Specifically, the controller 31 predicts that the time when the graph of the first power cost and the graph of the second power cost intersect is the recovery period for the cost of introducing the distributed power system 12.

[0105] In the example shown in Figure 11, the graph of the first power cost and the graph of the second power cost intersect in the latter half of the fourth period, so the controller 31 predicts that this period is the time when the introduction cost of the distributed power system 12 will be recovered. After step S80 is performed, the flow of the evaluation method according to this embodiment is completed. This concludes the explanation of the flow of the evaluation method according to this embodiment.

[0106] As explained above, steps S10 to S80 are performed by an operator or the controller 31, but the entity performing each step is not limited to those described above. For example, the controller 31 may perform all of steps S10 to S80.

[0107] As described above, the evaluation method according to this embodiment compares a first indicator over several years when a distributed power system is introduced with a second indicator over several years when the distributed power system is not introduced. Both the first and second indicators over several years are predicted taking into account the cost of purchasing environmental value. Therefore, according to the evaluation method according to this embodiment, the introduction of a distributed power system 12 by a power consumer 10 can be evaluated more appropriately from an economic standpoint compared to the conventional technology.

[0108] From the above description, many improvements and other embodiments of the disclosure will be apparent to those skilled in the art. Therefore, the above description should be construed as illustrative only and is provided for the purpose of teaching those skilled in the art the best mode of carrying out the disclosure. The details of its structure and / or function can be substantially modified without departing from the spirit of the disclosure.

[0109] One aspect of this disclosure can be used in an evaluation method for an indicator that allows for a more appropriate evaluation from an economic standpoint compared to conventional technology regarding the introduction of a distributed power source system by electricity consumers, and in a control method for an evaluation device that displays said indicator.

[0110] 10: Electricity consumers 11: Electricity consumption equipment 12: Distributed power generation systems 13: Renewable energy power generation equipment 14: Fuel cell equipment 15: Energy storage equipment 20: Power generation operators 30: Evaluation equipment 31: Controllers 32: Memory devices 33: Input devices 34: Display devices

Claims

1. An evaluation method comprising the step of comparing a first indicator of electricity costs for a power consumer over several years when a distributed power system including at least one of a renewable energy power generation device and a fuel cell device is introduced with a second indicator of electricity costs for a power consumer over several years when the distributed power system is not introduced, wherein both the first indicator and the second indicator over several years are predicted taking into account the cost of purchasing environmental value to achieve the target value of the indicator of CO2 emissions for the power consumer over several years.

2. The evaluation method according to claim 1, wherein the distributed power system includes an energy storage device.

3. The evaluation method according to claim 1, wherein the first indicator over multiple years and the second indicator over multiple years are displayed together on a display device, thereby comparing the first indicator over multiple years and the second indicator over multiple years.

4. The evaluation method according to any one of claims 1 to 3, wherein the first indicator includes a first power cost which is the power cost itself, and the first power cost includes costs incurred in connection with the introduction of the distributed power system, the cost of purchasing electricity from the grid, and the cost of purchasing the environmental value, and the second indicator includes a second power cost which is the power cost itself, and the second power cost which includes the cost of purchasing electricity from the grid and the cost of purchasing the environmental value.

5. The evaluation method according to claim 4, wherein the environmental value includes CO2 emission rights or CO2 emission reduction rights to achieve the target CO2 emission value.

6. The evaluation method according to claim 4 or 5, wherein the environmental value includes electricity certificates for achieving the target renewable energy rate as the target value.

7. The evaluation method according to any one of claims 4-6, wherein the distributed power system includes the fuel cell device, and the first power cost includes the cost of purchasing hydrogen used for power generation by the fuel cell device.

8. The evaluation method according to any one of claims 4-7, wherein the first indicator includes a first electricity unit price in the electricity use of the electricity consumer, the first electricity unit price is the value obtained by dividing the first electricity cost by the amount of electricity demanded by the electricity consumer, and the second indicator includes a second electricity unit price in the electricity use of the electricity consumer, the second electricity unit price is the value obtained by dividing the second electricity cost by the amount of electricity demanded by the electricity consumer.

9. The evaluation method according to claim 8, wherein the first electricity cost and the second electricity cost include a carbon tax within the electricity consumer.

10. The evaluation method according to claim 1, wherein the first indicator includes a cumulative value of a first electricity cost, and the second indicator includes a cumulative value of a second electricity cost.

11. The evaluation method according to claim 10, further comprising the step of predicting the recovery period of the introduction costs of the distributed power system based on the comparison.

12. The evaluation method according to any one of claims 1 to 11, wherein a multi-year introduction plan for the distributed power system is formulated based on the target values ​​of the multi-year CO2 emission indicators of the electricity consumer and the budget plan for CO2 emission reduction, and the first indicator is predicted to be the value when the distributed power system is introduced based on the introduction plan.

13. The evaluation method according to claim 3, further comprising the step of displaying on the display device the introduction plan for the distributed power system, which was formulated based on the target values ​​of the CO2 emission indicators of the electricity consumer and the budget plan for reducing CO2 emissions.

14. An evaluation device comprising: a memory for storing a first indicator relating to the electricity costs of a power consumer over several years when a distributed power system including at least one of a renewable energy power generation device and a fuel cell device is introduced, and a second indicator relating to the electricity costs of a power consumer over several years when the distributed power system is not introduced; and a controller for comparing the first indicator over several years with the second indicator over several years, wherein both the first indicator over several years and the second indicator over several years are predicted taking into account the cost of purchasing environmental value to achieve the target value of the indicator relating to CO2 emissions of the power consumer over several years.

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