Energy storage deployments in New York have grown faster than anticipated since the state began a major push in 2018, according to the New York State Energy Research and Development Authority (NYSERDA).

Governor Andrew Cuomo announced in 2018 that the state had set an energy storage target of 1.5 gigawatts by 2025. The goal is to reach 3.0 gigawatts by 2030. Bridge incentives worth $350 million were authorized to help accelerate New York’s energy storage market.

Since then, NYSERDA has awarded incentive funds to nine projects that total 360 megawatts and nearly 1,400 megawatt-hours, Greentech Media reported.

“Across the board, it’s grown faster than we expected it would when we scoped out the incentive and roadmap,” Jason Doling, who oversees NYSERDA’s energy storage program, told the outlet. Even though the state project incentives decrease over time, that hasn’t slowed development because project costs have been declining, he noted.

Last September saw the completion of the state’s largest ever lithium-ion battery installation — Key Capture Energy’s 20-megawatt project in Saratoga County. Besides being the largest, it was the first under NYSERDA’s energy storage incentive program.

The public benefit corporation says that New York’s energy storage industry could provide an estimated $3 billion in gross benefits by 2030, including reducing carbon dioxide emissions and contributing to the state’s goal of reaching 50% electricity from renewable sources.

“There is a growing appetite for storage and storage paired with intermittent [renewables] to meet peak demand,” Doling said, according to Greentech Media. “That won’t change; that will only increase.”

New job openings at Giga Shanghai (Tesla Gigafactory 3) shine light on Tesla’s plans for solar and energy storage in China. Tesmanian has reported that on March 6th, Tesla China posted two job openings related to solar and energy storage. It seems this was the first time Tesla China had posted any type of job openings on its official Wechat account, and is also the first time Tesla China is looking for project managers in those related fields. This came about after Elon Musk shared a tweet of Tesla’s worldwide solar business expansion.

Tesla China is looking for project managers who will design and execute solar projects for both commercial and residential customers. The other job post is for someone to help develop energy storage projects and will be based at Tesla Gigafactory 3 in Shanghai.

Just as with the vehicle side of its business, China seems like a smart move for Tesla’s energy side. It’s also great for us in America because it shows that China supports an American business operating there despite the drama between our leaders.

As for the environment, well, the coronavirus pandemic has provided some light into what is possible with clean tech. China’s air has been significantly cleaner during the outbreak. Air pollution levels dropped by almost a quarter in February as coal-fired power plants and industrial facilities were ramped down in high-risk areas. This was done to try to prevent the spread of the coronavirus. NASA reported that nitrogen dioxide, a pollutant from burning fossil fuels, had levels down as low as 30%.

Some critics are concerned about Tesla’s future in solar and energy since Tesla and Panasonic ended their joint partnership at the Buffalo Gigafactory, but this could be due to Tesla figuring out better ways to develop and produce solar technology without the aid of Panasonic. Sometimes good things have to end for better things and better ways of doing those things to come along.

As California experienced uncharacteristically low precipitation in February, normally its peak rainy season, parts of the state are moving into drought conditions. This is likely to increase wildfire prevalence in the state in 2020, and it underscores the point that communities need to be thinking about a range of strategies to increase their resilience to wildfires. One of these strategies is the way that communities approach their electricity systems.

Distributed energy resources (DERs)—such as on-site solar, battery energy storage, and microgrids—can both help decrease the likelihood of wildfires and protect communities from their worst effects. City governments have an important role to play to help accelerate deployment of these technologies and solutions by lowering the barriers to adoption, investing in critical facilities and community microgrids, enhancing energy efficiency, and engaging in utility planning and regulatory processes.

Wildfires Cause Disproportionate Harm to Our Most Vulnerable Communities

The fires in California have recently shown us that severe climate-related emergencies are the new normal (California’s wildfire “season” is becoming a year-round phenomenon), and the costs can be astronomical. The economic impacts of the 2018 fires alone have been estimated at $400 billion—nearly twice the biennial budget for the entire state. The costs of the mandatory blackouts, or Public Safety Power Shutoffs (PSPSs), that California utilities have been implementing to try to avoid additional wildfire damage are exorbitant as well. Consider, for example, the cost of outages on schools: the PSPS implemented by PG&E during the Kincade Fire caused approximately 500,000 students to miss school, at an estimated societal cost of $14 million dollars per day.

Those most affected by wildfire impacts are the elderly, the very young, the medically vulnerable, and low-income communities, which are disproportionately communities of color. A nationwide study by researchers at the University of Washington showed that Native Americans are six times more vulnerable to wildfire impacts than whites. Blacks and Hispanics are about 50 percent more vulnerable. These communities struggle to pay for fire safety measures and insurance before an event and for rebuilding after an event. These vulnerabilities are further heightened by price-gouging on rentals in the wake of wildfires, exacerbating California’s housing shortage. During and after these events, the rich tend to leave and the poor tend to stay; poverty rates can climb by a full percentage point in areas hit by major disasters.

Cities Must Lead in Promoting Resilience Solutions

While companies can leave in the wake of disasters, cities cannot. Local governments are responsible to their residents and to the local businesses and institutions who remain or return. Cities need to protect their local economies and retain employers and workers. Building resilience is an essential part of that equation.

One way in which cities are acting to build resilience is by taking greater control of their energy systems. At the extreme end of the spectrum, San Jose and San Francisco are evaluating the potential to municipalize their energy systems (i.e., buying the local electricity infrastructure and running it as a city utility), which could allow them to emphasize investments like local microgrids in their resource planning. Others are using their community choice aggregation programs to implement similar solutions.

Earlier this year, Secretary Brouillette of the U.S. Department of Energy launched the Trump Administration’s Energy Storage Grand Challenge Program. The initiative is designed to be a comprehensive effort to accelerate the development of next-generation energy storage technology that will position the United States as a global market leader. This program represents a continuation of the administration’s efforts to improve U.S. infrastructure, energy independence, and reliability.

The Grand Challenge builds on the $158 million Advanced Energy Storage Initiative announced in President Trump’s Fiscal Year 2020 budget request. According to a statement from the Department of Energy, the vision for the Energy Storage Grand Challenge is to create and sustain global leadership in energy storage utilization and exports, with a secure domestic manufacturing supply chain that is independent of foreign sources of critical materials, by 2030. While research and development (R&D) is the foundation of advancing energy storage technologies, the Department recognizes that global leadership also requires addressing associated challenges.

Using a coordinated suite of R&D funding opportunities, prizes, partnerships, and other programs, the Energy Storage Grand Challenge sets the following goals for the U.S. to reach by 2030:

Technology Development: Establish ambitious, achievable performance goals, and a comprehensive R&D portfolio to achieve them;

Technology Transfer: Accelerate the technology pipeline from research to system design to private sector adoption through rigorous system evaluation, performance validation, siting tools, and targeted collaborations;

Policy and Valuation: Develop best-in-class models, data, and analysis to inform the most effective value proposition and use cases for storage technologies;

Manufacturing and Supply Chain: Design new technologies to strengthen U.S. manufacturing and recyclability, and to reduce dependence on foreign sources of critical materials; and

Workforce: Train the next generation of American workers to meet the needs of the 21st century electric grid and energy storage value chain.

Energy storage has become more common among infrastructure projects, given recent government efforts like the Energy Storage Grand Challenge Program, continued volatility on the grid, challenges in meeting demand, aging transmission infrastructure, grid instability, price fluctuations, as well as increasing activity in the market for power purchase agreements. To address these issues, some business owners are looking to lower their costs through generation and storage of energy.

In light of these developments, innovative financing will likely evolve as a more prominent part of battery storage projects, as new technologies develop and lenders become more comfortable with the risk/return analysis for such projects. As the energy storage market grows, financial institutions will continue to become more involved wherever they can offer a lower cost of funding as understanding of the complexities and risks of such projects continues to grow. Project financing, public-private partnerships, private equity investment, and specialized funds that invest in energy storage, will become more common among such projects.

Italian multinational Nidec has started work on the first energy storage system in mainland France as part of an €80m ($89m) pilot project for French transmission system operator RTE.

The project called ‘RINGO’ is to build a storage system to optimize management of energy flows on the transmission grid in Vingeanne in the Côte-d’Or department of eastern France. RINGO is RTE’s name for its “virtual power lines” research.

RTE hopes the pilot will prevent grid congestion at times of peak demand by experimenting with the storage of all surplus wind and solar energy and its subsequent return to the grid.

The company says that “a project that sees battery storage systems become an integral part of modern electricity grids and key elements for realizing the vision of an electric and sustainable future”.

The Vingeanne site is in a region of high wind and the lithium-ion battery chosen for the pilot has a storage capacity of 12 MW/24MWh, which Nidec says is equal to the amount of energy produced by five wind turbines.

Work started in January and commissioning and testing are hoped to begin in March 2021.

Milan-headquartered Nidec said today that the development of large-scale energy storage is “a great industrial challenge to meet the fundamental energy transition from polluting to sustainable and renewable sources, necessary to reduce greenhouse gas emissions and mitigate global warming.”

Last week’s Energy Storage Summit, held at the Victoria Park Plaza in London, brought together some of the biggest and best the industry has to offer.

The Energy-Storage.News team was on hand to document the event, picking out some key themes that emerged as the Summit entered its fifth year.

1. Interest in non lithium-ion storage is there, but there are challenges ahead.

Whilst lithium-ion may have dominated many of the presentations and panel discussions at the two-day event, the signs of a growing appetite for non-lithium ion technology were certainly appearing. Talk turned to lithium-ion alternatives, and the longer duration and seasonal storage that often comes with it, in almost every panel discussion at the conference.

Across the conference, speakers agreed that storage may now be capable of solving intermittency as renewables come onto the grid, the big question is now to be seasonal storage, with hydrogen lauded as a possible solution by Manuel Baritaud, senior economist of the energy department of the European Investment Bank.

However, on a panel session dedicated to non lithium-ion technology, Gauthier Dupont, director of power business batteries at NGK Europe warned that cost competitiveness remains a huge challenge for alternative technology.

This, combined with a lack of visibility of new technologies and projects deployed by companies specialising in these technologies, means that lithium-ion alternatives are often overlooked, even when a technology might be better suited to that specific application, and funding difficult to secure.

Describing the discrepancy of R&D investment between lithium-ion and non lithium technologies as “a joke”, Dupont stressed the importance of access to investment and how partnerships are key to non lithium-ion storage.

“We have great technology, but we will not succeed alone,” DuPont said.

1. Revenue stacking continues to de-risk projects for investors as more firms turn to co-location.

Revenue stacking is not a particularly new topic for the Energy Storage Summit, or for anyone making a profit – or attempting to make a profit – from energy storage.

However, greater weight is being given to the importance of projects having the agility to switch between multiple revenue streams, as well as the stacking of revenues through co-location with other low carbon technology, with the topic regularly acknowledged as one of the big enablers of storage throughout the event.

Access to a variety of markets, including frequency response, the UK’s Capacity Market and wholesale optimisation, was lauded as being what makes battery storage projects financially viable by EDF Energy’s director of energy solutions Vincent de Rul, adding that while it is a difficult market, “it is possible”.

A land of high energy consumption, reliant on imported fossil fuels, Japan is also globally known as a country where everything from traditional crafts to high-tech industries are always striving to improve and innovate. As the energy market moves towards deregulation and wider competition, the solar PV sector within that bigger picture moves away from the feed-in tariff (FiT) subsidy-driven phase.

Just announced as this edition of PV Tech Power went to press (mid-February 2020), were FiTs for the 2020 Japanese financial year, which begins in April. While small-scale solar of under 10kW capacity continues to receive a fairly generous ¥22 (US$0.20) per kWh, anything between 10kW and 50kW gets ¥13 and 50kW to 250kW gets ¥12; anything larger than that has to compete in auctions.

“The big difference [to previous years] is that anything over 250kW has to enter into a competitive bidding process. It was the case that [only] 500kW capacity projects and over were eligible for auctions but it is now at the 250kW+ threshold,” says Izumi Kaizuka, manager at Tokyo-headquartered analysis firm RTS Corporation.

Of a possible 416MW in a recent auction, only 39.8MW of contracts were handed out by the Ministry of Economy, Trade and Industry (METI) across 27 bids from an initial 72 project proposals, totalling 185.6MW. Successful bid prices ranged from ¥12.57 (US$0.115)/kWh to just ¥10.99 (US$0.1)/kWh.

“The price was low, but also having spoken to many in the industry, developers are really busy with contracts for projects that are not yet in operation but have been awarded the FiT in previous years; they are working very hard to get these built, rather than being able to focus on new projects,” Kaizuka says.

“Anything awarded up to 2014 needs to be built this year or show evidence of construction by this March, so they are extremely busy and are finding it difficult to even think about new projects.”

Indeed, the first few years of the FiT saw dozens of gigawatts of awarded projects apparently stall, for various and widely reported reasons. So, as our show preview for the upcoming PV Expo in Tokyo demon- strates (see p.100), activity in the ground- mounted sector focuses to a greater extent on these already-awarded but nowhere- near shovel-ready projects.

Taken from a different perspective however, the ¥22 per kWh for sub-10kW projects remains fairly generous. Kaizuka says it is also indicative of both a natural market shift and government policy shifting solar away from the fields – and hills and mountains – of Japan and towards domestic, commercial and industrial rooftops. These still-to-come rooftop sites will join Japan’s existing high installed base of ground-mount capacity (installations have ranged from over 6GW to 9GW in years since 2013 with around 10.5GW deployed in 2015, the ‘peak’ year of the FiT).