Pacific Sun Technologies
How California Utilities Are Managing Excess Solar Power
‘Virtual power plants’ would store renewable energy in batteries by day and redistribute it when demand surges after sunset
California utilities including PG&E Corp. , Edison International and Sempra Energy are testing new ways to network solar panels, battery storage, two-way communication devices and software to create “virtual power plants” that manage green power and feed it into the power grid as needed.
The Golden State is ramping up renewable energy as it pledges to be a bulwark against the Trump administration’s pro-fossil fuel policies. But first, it has to figure out what to do with all the excess power it generates when the sun is shining and the wind is blowing.
California’s solar farms create so much power during daylight hours that they often drive real-time wholesale prices in the state to zero. Meanwhile, the need for electricity can spike after sunset, sometimes sending real-time prices as high as $1,000 a megawatt-hour.
Utility companies are looking to correct that supply-demand mismatch and ease the strain on the electric grid as California considers retiring its last nuclear plant in 2025 while nearly doubling the power it gets from renewable sources to 50% by 2030.
Last month, power company AES Corp. flipped the switch on a bank of 400,000 lithium-ion batteries it installed in Escondido, Calif., for Sempra Energy. Sempra’s San Diego utility plans to use the batteries, made by Samsung SDI Co. Ltd., to smooth out power flows on its grid. Tesla Inc. is supplying batteries to a Los Angeles-area network that would serve Edison International, which would be the world’s largest of its kind when finished in 2020, according to the developer, Advanced Microgrid Solutions. The network would spread across more than 100 office buildings and industrial properties.
Tesla Inc. is supplying batteries to a Los Angeles-area network that would serve Edison International, which would be the world’s largest of its kind when finished in 2020, according to the developer, Advanced Microgrid Solutions. The network would spread across more than 100 office buildings and industrial properties.
When the Edison utility needs more electricity on its system, the batteries would be able to deliver 360 megawatt-hours of extra power to the buildings and the grid, enough to power 20,000 homes for a day, on short notice. At other times, the batteries would help firms hosting the arrays to cut their utility bills, said Susan Kennedy, chief executive of Advanced Microgrid Solutions, which is developing the project.
“It will show how you can use communication and control technology to make a bunch of distributed energy assets act like one big one,” said J.B. Straubel, Tesla’s chief technical officer.
The companies declined to say how much the project would cost.
PG&E plans to use clean energy to replace the 2,200-megawatt Diablo Canyon nuclear power plant, which it is proposing to shut down in 2025. The San Francisco utility, which plans to invest about $1 billion through 2020 to modernize its grid, is testing batteries, software and other technologies.
“We are rethinking the grid and how it operates,” said Steve Malnight, PG&E’s senior vice president of strategy and policy.
Virtual power plants remain a considerably more expensive option than building a traditional power plant to meet peak demand.
Stored power from lithium-ion batteries can do the work of a natural-gas peaker plant at an average cost of between $285 and $581 a megawatt-hour, according to a December report by Lazard Ltd. In contrast, electricity from a new gas peaker plant costs between $155 and $227 a megawatt-hour, according to Lazard.
But some of the equipment barely existed five years ago: As prices for technologies such as battery storage fall, utilities should be able to adopt more of them, said Michael Picker, president of the state Public Utilities Commission.
California currently has to sell excess solar power at low prices or give it away to utilities in Arizona and other states, through a real-time power market run by California’s Independent System Operator, which oversees the state grid.
Sometimes, offering the excess power at low prices isn’t enough and prices go negative, as a way for power suppliers to encourage other utilities to take power they can’t use. That happened on 178 days last year.
Utilities in Colorado, New York and other states that plan to get a higher percentage of their power from renewables are also experimenting with virtual power-plant technology.
Consolidated Edison Inc. is using solar panels, batteries and power conservation technologies at several dozen New York City buildings to reduce peak demand by as much as 52 megawatts. Because of the $200 million project, the utility can postpone installing more than $1 billion of conventional power equipment for another 20 years, said Matthew Ketschke, a Con Edison vice president.
Virtual power plants alone, however, may not solve problems created by boosting intermittent renewable energy.
In Arizona, regulators want to double the state’s renewable energy target to 30% by 2030. But some utilities worry that adding more solar power on top of California’s already-robust supply could be costly and wasteful, even with battery storage.