The Impact of TOU on PV - Go West
As of January 1, 2007, PV homeowners who sign up for the California Solar Initiative (CSI) are required to switch to a domestic time-of-use (TOU) rate. In addition to the traditional seasonal variations in the price of electricity, under this rate structure the electricity bill will be calculated based on whether a customer buys power on peak ( between 12 pm and 6 pm) or off peak (between 6:01 pm and 11:59 am). What has always mattered to electric generation and distribution companies—the time of day that power gets used and generated—will now matter to the customer, too.
We modeled the effect of PV on the bill under these two rate structures for a typical residential electricity customer, using data from the software program, PV Watts 2, and Itron’s eShape, a database of load profiles for residential electricity and gas usage. We also determined the size of the PV system that would be needed to approach zeroing out the monthly electric bill for a typical residential customer.
For our modeling exercise, we used the most common profile for a San Diego region home from Itron’s eShape—a residential, southwest-facing, single-family home with central air conditioning and gas heat. This profile uses an inland designation for purposes of establishing baseline electricity allotment, which assumes some on-peak use of air conditioning during the summer. (The translation from Itron’s usage curve into data points introduces a potential small margin of error.) System design assumptions include a 15º tilt, true azimuth readings, a 5.5 kW DC array, 92020 zip code and a 0.75 derate factor for PV Watts 2.
Under the DR tariff, a 5.5kW DC system was needed to generate enough electricity so that the customer would end up owing almost nothing for electricity usage (see Table 1). With the new SDG&E TOU rate structure, we found that the same-sized PV system yielded a different financial outcome (see Table 2). In the first scenario, the south-facing array outperformed the west-facing one. In the second scenario with the DR-TOU tariff, the scenarios are reversed. The west-facing array outperforms the south-facing array.
Additional savings would result from shifting loads from on peak times to off peak times. This does not mean using any less electricity—although that would be useful as well—but rather changing the time that common high usage items are used. Using the same PV setup and azimuths, but reducing the on-peak usage to 20% during summer, spring, and autumn, allows a customer to save an additional $90 per year for the south-facing setup, and an additional $24 per year for the west-facing one (see Table 3). Because south- and west-facing systems have a tilt and azimuth that maximizes summertime performance, and because they produce most of their power during the 12 pm-6 pm peak window, a customer may save more under the TOU tariff than under the DR tariff.
By shifting some energy uses to off-peak times, a well-sited, appropriately sized PV system could end up costing less in 2007 than it would have in 2006—even though per-watt rebate levels have dropped and PV costs continue to fluctuate.
John Supp is the residential solar program manager at the San Diego Regional Energy Office, which is based in San Diego, California. Andrew McAllister is the director of operations at the San Diego Regional Energy Office.
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