Electric-drive vehicles for peak power in Japan
Introduction
Electric-drive vehicles (EDVs) have gained attention in the past few years due to growing public concerns about urban air pollution and other environmental and resource problems. In the United States, the California Air Resource Board (CARB) instituted an ambitious requirement for 10% of the new cars sold in the state to be zero-emission vehicles (ZEVs) by the year 2003, versions of which have been adopted by other states (Nadis and Mackenzie, 1993, p. 72). This boosted the development of EDVs and accordingly many auto-manufacturers have developed their own EDV models to meet this goal. EDVs include three primary types: battery-based, hybrid, and fuel cell. Battery and fuel cell vehicles are considered ZEVs, while hybrids are low-emission or ultra-low emission vehicles.
While an increase in battery-based EDVs is expected to increase electricity sales, extra generation capacity is not needed if the EDVs are recharged at times of low demand, such as overnight. In fact, as we argue here, there is a potential to reduce the peak load if EDVs are grid-connected to allow discharging of the electricity stored in their batteries, or running their on-board generators, during times of peak demand. This approach was suggested by Kempton and Letendre, 1997, Kempton and Letendre, 1999 who calculated the economic value of discharging battery electric vehicles as a peak power source and as spinning reserves. Kempton and Letendre conclude that in the US, under the right conditions, it can be cost-effective for the utility as well as for the vehicle owner. That is, the value to the utility of tapping stored electricity is greater than the total costs to the vehicle owner: two-way electrical connections, purchased energy, losses in charging and discharging, and the cost of wear from additional cycles on the battery. Kempton and Letendre (1997) also outline the design of a controller which would allow the utility to tap power when needed, limited by constraints set by the driver (for example, “I must have enough charge by 7 a.m. tomorrow to drive 20 km”).
In Japan, energy security issues are even more serious than in the US mainly due to its scarce resources. Japan has one of the lowest energy intensities (energy-use per unit of GNP) in the industrialized world, but its aggregate energy-use is still rising. While the government seeks nuclear power to solve both energy scarcity and greenhouse gas mitigation, the national debate on nuclear energy has been rapidly intensifying. The government is also engaged in several renewable energy programs, such as rooftop solar photovoltaic (PV) generation. Storage in EDVs improves the economics and performance of both nuclear and solar: Nuclear is best run at constant output, so storage helps even out the peaks and troughs of demand, while renewable energy fluctuates with sunlight or wind, so storage helps even out supply. Storage also helps solar match supply to demand peak, since the solar peak is a couple of hours earlier than the typical load peak. Therefore, EDVs would seem to be a promising way to add storage to the electric system, especially for a country like Japan, since automobiles are not used as frequently as in other industrialized countries, and since urban automobiles are typically idle through and past peak hours. Consequently, there are more vehicles available to be discharged during peaks, and each one can allow deeper discharge.
This paper applies the methods of Kempton and Letendre (1997) to evaluate the economic potential of EDVs for the Kanto region of Japan. The Kanto region houses major cities such as Tokyo, Yokohama, and Chiba. Although not analyzed here, we believe that EDVs can also be useful as peak power sources in the Kansai region (including the cities of Osaka, Kobe, and Kyoto), Chubu region (including Nagoya), and parts of other regions that have major cities with comprehensive public transportation systems as well.
The utility serving the Kanto region, the Tokyo Electric Power Company (TEPCO), has faced significant challenge in meeting its peak demand every year.1 In fact, TEPCO's annual load factor is low, below 60% (TEPCO, 1999, p. 29), mainly due to the enormous demand for space conditioning during the summer and winter. The policies we suggest would tap EDVs to reduce peak generation need, and thus reduce the need for further investment in peak generation capacity.
Section snippets
TEPCO service region
The service region of TEPCO covers the eight prefectures of the Kanto region and the eastern half of Shizuoka prefecture, with a total population of 42 million (about one-third of the country). Its annual electricity sales for 1998 was 265 billion kWh (TEPCO, 1999). Table 1 shows the population, electricity sales, and the number of automobiles in the TEPCO service region compared to Japan overall.
Potential maximum power output
We begin our analysis with a simple calculation of the potential peak resource from electric
Vehicles analyzed
The economic potential of EDV grid storage varies by the battery type, cost, maximum voltage, and vehicle characteristics. Thus we will use the five vehicles described below, and summarized in Table 2, for our analysis.
The first example vehicle is the GM's EV1, which uses a lead–acid (Pb/acid) battery. Among battery types, Pb/acid has the disadvantages of short cycle life, high weight, damage from deep discharge, and environmental lead pollution during manufacturing and recycling (Lave et al.,
Conditions for analysis
This analysis adopts the general approach of Kempton and Letendre (1997) but differs in several characteristics. Kempton and Letendre calculated peak power value in the US based on avoided cost, whereas we calculate value in the TEPCO region from announced rates and from rates extended to account for the economics of infrequent use. These rate schedule differences lead to a simpler (and more realistic) calculation of cost-effectiveness, as we shall see. This analysis also is based entirely on
The cost of discharge to the vehicle owner
Eq. (3) is used to determine the cost to the vehicle owner for allowing access to the stored energy in their vehicle. Table 7 presents the expected costs to the vehicle owner based on the number of times the stored energy is accessed during a given year.where CY is the cost per year, EC the energy capacity, DY the number of dispatches per year, BD the cost of battery degradation, ER the electricity rate (6.15 yen/kWh).
For the electricity charge rate, we will use 6.15 yen/kWh,
Economic benefit to the electric utility
Utilities have investigated the technical and economic feasibility of energy storage plants for load-leveling purposes for quite some time (Duchi et al., 1988). Rather than making assumptions about the value to utilities, in this analysis we will use the rate that TEPCO announced to seek individual power producers (IPPs) in 1997. These announced rates, shown in Table 8, illustrate that TEPCO is willing to pay a premium for power that is drawn on only a small proportion of the time — up to 33.7
Cost comparison
Table 10 summarizes the cost comparison between the utility's benefit and the owner's cost, using three purchase rates of peak electricity from EDVs.
The results show that using the rate of 33.7 yen/kWh, and assuming near-term costs as described earlier, only the CARB projected Nissan Altra has economic benefit. By contrast, using a projected rate of 50.2 yen/kWh, the current Nissan Altra is also cost-effective. Using 68.5 yen/kWh the current Toyota RAV4L EV is cost-effective as well. The Toyota
Conclusion
If one assumes the near-term cost of limited-production EDV battery manufacturing, and without any change in current rate structure, we find that electric vehicles cannot profitably sell peak power from their batteries. However, with a small change in rate schedules to allow for low load factors, and the expected decline in battery manufacturing costs with mass-production, we find that some battery EDVs could be very economical sources of peak power, benefiting both the utility and the vehicle
Acknowledgements
For comments on this paper, we are grateful to Stephen E. Letendre, Marty Bernard, Matthew Clouse, one reviewer who wishes to remain anonymous, and one anonymous referee for Energy Policy. We thank Timothy Lipman for help in locating battery data.
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