Next 10 reports explore rapid changes to California grid driven by EVs, distributed energy resources and community choice aggregation
California’s grid is facing an era of rapid change. Three reports from Next 10, an independent, non-profit, non-partisan think tank, explore how the grid might be challenged or helped by the rise of electric vehicles; by the increase in distributed energy resources, such as rooftop solar panels; and by the growth of community choice aggregation, which allows cities and counties to join together to purchase electricity on behalf of their community members.
These innovations are all key elements in California’s efforts to transition to clean, renewable energy that is both reliable and affordable. As the state adds more variable renewable energy to the grid, these resources—electric vehicles, distributed energy resources and community choice aggregators—represent a challenge to the traditional energy management system but also provide opportunities for us to manage a more efficient and cleaner grid. There are a lot of complex issues for Californians — especially policymakers—to consider as we work toward a clean energy future.—F. Noel Perry, businessman and founder of Next 10
Electric Vehicles. California currently has about 369,000 plug-in electric passenger vehicles (PEVs). In order to reach Gov. Jerry Brown’s goal of 5 million PEVs by 2030, sales need to grow significantly. Also on the horizon: electric medium- and heavy-duty vehicles, and the prospect of private vehicle ownership being lowered by fleets of electric, self-driving PEVs.
Framework of Electric Mobility - Infrastructure - Charging - Grid Nexus
The California grid is well placed to handle rapid growth in PEVs but advance planning and smart policy can ease the transition for the state’s power system, according to Next 10’s report Electric Vehicles and the California Grid, by Anand R. Gopal and Julia Szinai of Lawrence Berkeley National Laboratory.
Among the report’s key takeaways:
Energy demand is only modestly increasing as PEV sales increase. The California Energy Commission forecasts that 3.9 million PEVs would add about 15,500 GWh of charging demand, equivalent to just about five% of California’s current total annual energy load. A Chevy Bolt driven 50 miles a day uses the same amount of electricity as an air conditioner cooling a 3-bedroom home for three hours.
Transportation trends towards automation and increased usage of mobility services like ride-hailing could rapidly expand the share of electric vehicles on the road, further increasing electricity demand. The estimated share of total light-duty vehicle miles traveled from ride-hailing vehicles could double from 10% to 20% between 2018 and 2020, based on projections from ride-hailing companies.
If regulators choose to require that these fleets move toward PEVs, this could have significant impacts for infrastructure and charging needs. Only about one% of total Uber and Lyft trip miles in California are made in electric vehicles (as of Q3 2017).
The growth of electric vehicles in California will require upgrades to the energy system, but the costs are likely to be low compared to the benefits. In areas with high concentrations of PEVs, the distribution system is likely to be the first part of the grid to require upgrades and management as a result of PEV growth. At an aggregate distribution system level, an analysis found that annual PEV-related distribution costs through 2030 are estimated at about only one% of the distribution revenue requirement of California’s three investor-owned utilities and the Sacramento Municipal Utility District combined.
Meanwhile, the authors’ analysis shows that if California were to move to smart charging of the 5 million electric vehicles targeted by Governor Brown’s goal, it could help reduce the amount of curtailed renewable energy by 50% in 2025.
According to the California Public Utilities Commission, flexible EV charging can generate resource cost savings of $100-200 million per year for the power system, compared to unmanaged EV charging.
New management strategies can help optimize potential benefits and minimize potential risks of more PEVs needing more electricity, but are challenging to implement. Managed charging programs—such as time-of use charging, which shifts charging to off-peak hours—could lessen stress on the grid, lower operating costs, and help integrate intermittent renewable energy.
Smart charging—which allows active electric vehicle charging to be turned on or off to coincide with times of low wholesale prices or high renewable generation—can curb incremental system operating costs and reduce renewable energy curtailment.
Such programs require well-designed, behaviorally aware incentives to entice large numbers of PEV owners to participate in them.
Hence, even though electric vehicle batteries could provide a source of energy storage to the grid, in practice this would be complex and costly. Stationary battery storage could be used to provide distribution system support, load-shifting, and ancillary services.
Distributed Energy Resources. Distributed energy resources are small technologies—including rooftop solar, energy storage, microgrids, load control, energy efficiency, and communication and control technologies—that produce, store, manage, and reduce the use of energy. They are small enough to be “distributed” all around the grid, close to customers and away from centrally located power plants.
California has already adopted virtually every policy conceived to encourage DERs, the Next 10 brief notes, and is a leader in deployment, as well. For example:
90% of the nation’s small-scale energy storage and nearly half of all US large-scale storage is in California.
California has more than 800,000 customers with rooftop solar systems, totaling more than 6,500 MW of capacity. The state has been adding 100,000 systems annually.
In May 2018, the California Energy Commission added rooftop solar as a building code requirement, which could lead to an additional 75,000 installations per year.
Smart grid investment is trending nationally and in California to help automate distribution system controls. Last year, nearly $2 billion was invested nationally, with California utilities having invested nearly $250 million.
As of early 2017, there were 36 operating microgrids in California, with an additional 80 under construction or planned. Altogether, these microgrids will provide over 650MW of peak capacity to the grid.
More than 220 MW of fuel cell systems have been installed in close to 200 California cities.
California is also a leader in energy efficiency programs, including building codes, appliance standards, and ratepayer-funded utility programs with investor-owned utilities investing more than $700 million annually in programs. Over the course of decades, these have reduced energy demand, saved customers money, reduced the need for investment and infrastructure, and cut pollution. But while California is a leader in energy efficiency, it is lagging behind in using flexible power demand to provide services to the grid, known as “demand response.”
Community Choice Aggregation. Communities across California are forming Community Choice Aggregators (CCAs) at a rapid rate since 2010, with more than half of them starting within the last two years. County and city governments administer CCAs as local alternatives to investor-owned utilities (IOUs).
Next 10’s report The Growth of Community Choice Aggregation: Impacts to California’s Grid, written by JR DeShazo, Julien Gattaciecca, and Kelly Trumbull of UCLA’s Luskin Center for Innovation, finds that if current growth trends continue, CCAs may serve a majority of California’s power consumers within the next 10 years, transforming California’s retail electricity sector.
According to the report, the rise of CCAs has both direct and indirect positive effects on overall renewable energy consumed in California, helping contribute to the state meeting its 2030 RPS targets approximately ten years in advance.
Even with such an important impact on the penetration of renewable energies, CCAs’ effects on the grid have been negligible so far. This is in part because when a CCA starts, it handles the needs of existing electric customers, and often gets power from existing power plants.
In the long term, though, CCAs’ impact on the grid depends on their energy procurement strategies and their local investments.
Among the report’s other findings:
CCAs are offering customers electricity with renewable energy content ranging from 37% to 100%, with an average of 52%.
IOUs are offering renewable content between 32% and 44%. They estimate a renewable content that exceeds 50% by 2020.
CCAs rely more on short-term and out-of-state renewable energy contracts, compared to IOUs, due in part to the fact that they are relatively new entities. It’s unclear if this pattern will persist as CCAs continue to mature.
CCAs compensate their rooftop solar customers for energy generated in excess of their consumption at rates up to three times higher than IOUs.
Some CCAs have demonstrated more success at engaging hard-to-reach customer groups in energy efficiency, compared to their IOU counterparts. For example, MCE’s multi-family energy efficiency program is more cost-effective than the comparable PG&E’s program.