Hawaii regulators have approved six of eight proposed large solar plus storage projects, with all coming at or under 10 cents per kilowatt-hour.
Sunrun made a splash at the BNEF Summit in New York City at a time when utilities are increasingly struggling to adapt to new realities. But distributed energy resources have a long way to go to play a major role, and we will still need additional energy sources in future power systems.
Sunrun CEO Lynn Jurich. Image: Bloomberg
This article is an excerpt from the new whitepaper published by Microgrid Knowledge and Enel X North America, California’s Changing Time-of-Use Rates: Calculating the Impact on Behind-the-Meter Solar PV and Energy Storage.
For utilities, electricity is generally more expensive and complex to deliver when demand is high. To help cover these costs, California’s utilities have traditionally imposed time-of-use (TOU) rates, which created a daily schedule that applies different prices for power based on demand trends on the grid. When demand is highest, prices are highest under TOU rates.
At Solar Power Northeast representatives from Cypress Creek, Stem and Kearsage Energy discussed the possibilities and limitations of bringing big solar to New York and New England.
“500 MW might actually cover all of Rhode Island,” joked Paul Raducha, senior developer for Kearsage energy, but there’s real sentiment behind his quip. While states like California, Nevada and Arizona have seen utility-scale development at mind boggling scales, there are few massive solar plants yet on the East Coast north of Virginia.
Now let’s be honest, nobody is asking for or realistically expecting a multitude of 100 or more MW plants in New England and New York. So what is there to expect?