Report Shows Strong Solar+Storage Market Growth… And Plenty of Room for Improvement

Author: Seth Mullendore,  Clean Energy Group | Project: Resilient Power Project 

Photo Credit: Lindsey Dillon, US DOE

Interest in pairing solar with battery storage has surged over the past few years, largely driven by concerns about the reliability of the country’s outdated electric grid and the reality of increasingly severe power outages.

Tesla recently announced that there may be more than 50,000 Powerwall battery systems installed at homes and business in California alone.

Despite soaring deployment numbers and increasing customer demand, little data has been available to understand the current state of the solar+storage market. A new report from Lawrence Berkeley National Laboratory provides a valuable initial look at residential and non-residential distributed solar+storage markets, showing significant growth and huge potential for the future.

In Behind-the-Meter Solar+Storage: Market Data and Trends, researchers at Berkeley Lab looked at data from 50,000 residential solar+storage installations and 1,000 non-residential installations, representing about 90% of paired systems installed through the end of 2020.

They found that, overall, about 17% of all installed U.S. battery storage capacity is paired with solar behind a customer’s utility meter. Surprisingly, all those customer-sited systems add up to more than the entire solar+storage capacity installed directly on the grid: roughly 550 MW of customer-sited solar+storage versus 420 MW of grid-sited systems. Two-thirds of the customer capacity comes from small residential systems, which tend to be sized around 5 kW.

Even so, most home solar systems are still being installed without storage. Roughly 6% of residential solar systems installed in 2020 included battery storage. Non-residential system attachment rates were even lower, with 2% of those solar systems paired with storage. As might be expected, the numbers vary greatly depending on location.

In Hawaii, where exported solar energy is either prohibited or compensated at a much lower rate, 80% of home solar and 40% of non-residential installations are being paired with storage. And in California, where wildfire-related utility outages have become a concern, a significant number of existing PV systems are being retrofitted to add storage.

Both states may offer a look into the future of solar+storage across the country as states reevaluate solar net metering policies and more regions experience an uptick in power outages resulting from extreme weather conditions.

System sizing

Another finding of the report concerns system sizing. Two battery manufacturers have dominated the residential storage market, Tesla and LG Chem. Both offer 5-kW batteries, with 13.5 kWh of energy storage capacity for Tesla’s Powerwall and 9.5 kWh of storage for LG Chem’s RESU 10H.

When comparing solar PV sizing to storage capacity, the researchers found that the batteries could storage an average of 30-80% of daily solar generation. Commercial installations have a greater variation in sizing, but are typically much larger than residential systems, with a median battery size of 100 kW and 200 kWh.

The report also explored the cost premium of adding storage to a solar installation. Across both residential and non-residential systems, incorporating battery storage was found to increase the cost of a solar installation by an average of $1.2 per watt. That represented about a 33% price increase for residential solar, increasing the average installed cost from $3.8 per watt for solar-alone to $5.0 per watt for solar+storage. For a typical residential PV system sized at 7 kW, that would translate into an added cost of $8,400 to incorporate battery storage.

Equity issues

The report also considered equity issues. It comes as no surprise that households installing solar+storage generally have higher incomes than regional averages, which also is the case for solar-alone. Berkeley Lab researchers found that the income gap for solar+storage is even more pronounced. Solar+storage adopters had median incomes that were 66% higher than average regional incomes as opposed to 41% higher for households only installing solar.

The findings illustrate the need for targeted low-income battery storage incentives and higher compensation levels to ensure more equitable solar+storage development, particularly for lower-income households with medically vulnerable members and those located in regions subject to extreme weather conditions where access to reliable electricity is a critical need.

The equity gap can also be seen in non-residential solar+storage. The researchers found that 70% of non-residential solar+storage systems have been installed at for-profit companies. Schools represent the one nonprofit sector realizing more significant development of solar+storage projects. Schools account for the majority of non-commercial solar+storage, representing 25% of non-residential installations. A minority of systems were installed to support nonprofit entities like community organizations, affordable housing providers, and local governments.

The report’s findings highlight a few key points.

First, customer-sited solar+storage has a large (and often underappreciated) potential to provide grid benefits, representing a larger combined capacity than all grid-sited projects. These small systems can be aggregated together to replace the capacity currently provided by fossil fuel power plants, cleaning up the grid while strengthening resilience by decreasing reliance on large-scale, centralized points of grid failure.

Second, the potential of customer-sited solar+storage is being underutilized. While paired solar and storage systems are becoming more common, they still represent only a small fraction of solar installations.

Every solar system installed without storage is a missed opportunity to turn a source of intermittent generation into a flexible grid resource and source of local reliability. There is also a massive opportunity to retrofit existing solar installations with battery storage.

Third, more needs to be done to ensure that solar+storage is being installed in lower-income areas. Low-income households and frontline communities are often more vulnerable to the impacts of power outages and have fewer resources available to respond and recover to extended outages. These communities should be prioritized in the design and implementation of policies and programs incentivizing greater solar and battery storage deployment.

So, customer-sited solar+storage has clearly come a long way and, clearly, still has a long way to go to reach its full potential.

To learn more about the new report from Berkeley Lab, Clean Energy Group hosted a webinar with the authors on August 19th – slides and a recording are available here.

 

This article was originally published in PV Magazine. 

Connecticut Powers into the Lead with Breakthrough Customer Battery Program

Author: Todd Olinsky-Paul, Clean Energy Group | Projects: Resilient Power Project, Energy Storage Policy  

Photo Credit: Christopher Boswell / Bigstock.com

With the long-anticipated approval of its new Statewide Electric Storage Program, Connecticut has just leapfrogged the rest of New England to become the new regional leader in distributed battery storage program development.

The new program adopted by the Connecticut Public Utilities Regulatory Authority is a massive 9-year initiative that combines up-front incentives with customer performance payments to achieve a goal of 580 MW of new distributed battery deployment. That capacity goal is evenly split between commercial and residential customers.

To put the scope of this new program in context, the Massachusetts ConnectedSolutions program, which served as a model for the Connecticut program, enrolled about 840 residential battery customers in 2020. In Vermont, Green Mountain Power has placed batteries behind 3,000 residential customer meters. The Connecticut program aims to enroll 10,000 residential customers in its first three years alone.

Also notable is the Connecticut program’s commitment to equitable access. The program doubles its up-front incentive for low-income participants and those in historically underserved communities. (Massachusetts, which is currently revising its ConnectedSolutions program for the next 3-year cycle, should now follow suite.) And the Connecticut program includes other equity provisions, such as low-cost loans, leases, and an on-bill payment option. The PURA order also directs program administrators to strive to place 40 percent of the residential batteries installed under the program in low-income and historically underserved communities.

This emphasis on equitable access is important because historically, new clean energy technologies tend to be adopted by the wealthy, bypassing the low-income communities that need them the most. In the case of energy storage, its resilience and energy cost-saving benefits are critical to underserved communities, which are hit hardest by natural disasters and the associated grid outages. For example, if properly installed at multifamily affordable housing facilities, Solar+storage can provide backup power to select loads while grids are down, allowing residents to shelter in place and supporting life-sustaining equipment such as air conditioning, water pumps, refrigeration and powered medical devices. During normal operating conditions, the same solar+storage systems can reduce electricity costs and earn revenues through program incentives and net metering.

Incentive rates are high enough to support the program’s ambitious goals. For example, proposed residential upfront incentive rates start at $3,950 for an average home battery system (Note that LMI rebate rates are double the level for non-LMI customers):

In addition to the up-front battery rebate, customers will receive performance payments when they allow their utility to dispatch their battery to reduce regional peak loads. Similar to ConnectedSolutions program performance incentives in other New England states, the proposed rates are $225/kW in the summer and $50/kW in the winter.

These rates are based on extremely thorough cost-effectiveness testing. The Connecticut Green Bank, which helped to develop the program, subjected BTM battery storage to five different cost/benefit tests. Scores on the most important of these, the RIM test, show that not only will batteries pay for themselves through benefits to customers and the grid, they will also not shift costs between customers. This was an essential feature of the program for PURA, which considers the RIM test the most important.

With the range of incentives and low-cost financing offered through the Statewide Electric Storage Program, customer batteries should pay for themselves well within the lifespan of the equipment.

This has been a good summer for distributed storage in New England. Just a month ago, Maine passed legislation setting a state storage procurement goal and directing Efficiency Maine to develop a distributed storage incentive program that is likely to look a lot like those adopted in Massachusetts, Rhode Island and Connecticut. Counting GMP’s program in Vermont and the Liberty Utilities pilot program in New Hampshire, every state in New England now has a distributed battery storage program operational or in development. This makes New England a national leader in distributed storage policy development.

CEG/CESA’s new report, Energy Storage Policy Best Practices from New England: Ten Lessons from Six States, highlights some of the valuable policy lessons that can be drawn from the New England experience. A webinar highlighting this report is scheduled for August 26; learn more here.

 

Todd Olinsky-Paul is senior project director at Clean Energy Group and Clean Energy States Alliance. CEG/CESA’s energy storage policy work in New England is supported by generous grants from the Barr Foundation, the John Merck Fund, and CEG’s Resilient Power Project and its funders.