Integrated solar solutions company Q CELLS has officially launched a home solution that promises a “100% sustainable power supply,” through combining solar and battery storage to meet the majority of demand and a digital cloud solution to cover the rest.

Now available in Germany and expected to be “shortly” rolled out into other markets, the Q CELLS Q.HOME Cloud can either be added to new solar PV systems or retrofitted to existing systems. Customers can basically use the Cloud to connect to renewable energy generation in Germany and Austria and use it to source the remaining portion of energy that their solar-plus-battery system is unable to provide. The company says it adjusts the available and expected quota of energy to meet the size and location installation of each solar system and storage unit, claiming in a release sent today that “every customer receives a tailor-made, transparent and fair cloud solution”.

The early days of solar energy becoming a popular choice for homeowners in Germany and much of the rest of the world saw PV systems feed energy directly into the grid and the homeowner paid for the electricity in the form of feed-in tariffs (FiTs). Increasingly, feed-in tariff policies are ending or the sums paid are falling in price as governments phase FiTs out, making the self-consumption of solar energy the logical choice, partly enabled by the falling cost of home battery storage.

While residential solar and storage purchases are often an environmental decision or a decision made of the desire for energy dependence, in parts of the world where electricity is expensive, self-consumption can offer an opportunity to get system payback over time.

In some parts of the world including Germany, system owners can still receive some FiTs – albeit at reduced prices than before – for feeding surplus energy into the grid once their battery is full. In Japan, for example, new rules expected to come into effect in the next few years will stipulate that self-consumption must be achieved and only the surplus after demand is met can receive the feed-in tariff.

Beside a sprawling solar panel factory in the eastern Chinese city of Suzhou stands a drab two-storey building that few people ever enter. Inside, stark rows of batteries store cheap electricity while the city sleeps each night. In the morning, when energy use and prices go up, the batteries release their power to the factory next door, reducing its electricity bill.

When this demonstration project started operating in 2017, it was a proof of concept for energy storage, an industry that was about to receive explicit support from the national government and which seemed sure to grow alongside renewable energy for decades to come.

Two-and-a-half years later, stalling reform, shifting policy and a slowing economy had put the sector in crisis even before the coronavirus pandemic struck. “It’s gotten very difficult to do energy storage,” says Paul Man, general manager of Anxin, an energy storage company, which is part of the Golden Concord energy conglomerate that owns the Suzhou solar panel factory. “If government policy doesn’t change, energy storage won’t be doable in China.”

According to industry group China Energy Storage Alliance (CNESA), newly installed battery-powered storage capacity shrank by nearly a quarter year-on-year in 2019. Companies whose sole business is energy storage “are under enormous pressure to survive, regardless of the epidemic,” says Wang Si, senior policy research manager at CNESA. “Some smaller companies will go bankrupt.”

Energy storage is, in theory, an attractive proposition. It can help keep down the energy costs of businesses and improve an electricity grid’s stability and flexibility. On a larger scale, energy storage will be crucial in moving countries from predictable but polluting fuels like coal to fickle but climate-friendly alternatives. In times with little wind or sunshine, giant batteries can keep the lights on. The Suzhou facility, at 10 megawatt-hours, has the capacity to power 1,600 homes for a day.

After the Chinese government gave official support in October 2017 by releasing its first national policy document on energy storage, newly installed electrochemical – battery-powered – energy storage capacity surged from 120.9 megawatts in 2017 to 682.9 megawatts in 2018, according to figures from CNESA. (There are various other storage technologies, but batteries receive the most interest for their flexibility in scale and location.)

Customized Energy Solutions and the U.S. Energy Storage Association have released the StorageIQ Q1 2020 Quarterly Summary, a brief report outlining RTO/ISO actions, rulemaking and state and regulatory proceedings that have impacted energy storage across the United States in 2020.

The Northeast

In Q1, storage developments in the Northeast were led by three main markets: New York, Massachusetts and Virginia. In New York, NYISO’s Distributed Energy Resource filing, one which set the capacity value for storage at 2-, 4-, and 6-hour durations was approved by the Federal Energy Regulatory Commission (FERC). The state also approved changes to its Buyer Side Mitigation policy that will make it easier for storage to pass a Buyer Side Mitigation test and be deemed economical. New York committed over $200 million to proposed storage projects and NYSERDA opened existing incentives to bulk storage projects in the ConEdison territory, which includes the coveted storage markets of York City and the lower Hudson Valley.

Massachusetts, meanwhile, led all ISO-NE states in terms of regulatory developments relating to storage, namely at the Department of Public Utilities and the Department of Energy Resource, which submitted the finalized Clean Peak Standard. On the whole, ISO-NE was directed by FERC to improve practices in its capacity market auction, though claims of the mistreatment of storage in the auction were dismissed.

Virginia boasted the most notable legislative development related to storage, with the state passing a deployment target of 3,100 MW by 2035. Not to be overlooked, Maryland reauthorized and improved a first-in-the-nation energy storage tax credit program for businesses and households installing energy storage systems.

Central and West

ERCOT made meaningful strides in regards to the treatment of hybrid storage systems, advancing a Key Topic & Concept covering registration, market operation and settlement for dc-coupled systems.

Out West, CAISO filed energy storage model revisions to further comply with FERC’s Order 841, while the state of California’s public utilities commission advanced proceedings on the future of Resource Adequacy, Integrated Resource Planning (IRP), the Self-Generation Incentive Program, and microgrids. All of these topics, while differing in scope, highlight the consideration of both distributed and grid-connected storage being primary electric resource types in future generation mixes. Specifically, the IRP’s approved Reference System Portfolio sets a mandate for nearly 9 GW of new battery storage and another 1 GW of pumped or similar long-duration storage by 2030.

Energy solutions company Alfen has seen its quarterly revenue climb across all three of its business lines, with its energy storage arm seeing revenues increase by 144% against the first quarter of 2019.

The Euronext Amsterdam exchange-listed company posted strong financial results as a whole for Q1 2020, with its EBITDA jumping from €1.7 million (US$1.83 million) in Q1 2019 to €4.6 million in Q1 2020.

Its EV charging equipment arm saw the biggest increase during the quarter, with its revenues jumping from €4.5 million in Q1 2020 to €13.2 million, an increase of 194%.

The company cited the growing market for EVs, increasing volumes under the framework agreements that have been set up over the last few years, “new client wins” and further internationalisation for its growth, adding that its business in the UK, the Netherlands and Germany experienced strong growth in particular. Over the quarter, it produced around 13,200 charge points, up 207% from Q1 2019.

Alfen is also planning to relocate its EV charging operation to larger facilities in a move to significantly expanding its production capacity.

Its energy storage systems business line meanwhile generated revenues of €3.2 million, up 144% from Q1 2019.

This was a result of a “significant pick-up in the demand for energy storage projects” in comparison to the first quarter of 2019, which Alfen said was characterised by “challenging market circumstances”.

Electric utility Southern California Edison (SCE) has announced seven battery-based energy storage projects of 770MW total capacity.

The projects are aimed to bridge energy supply shortfalls in California, direct renewable energy to the grid and improve grid performance.

According to the California Public Utilities, the proposed storage projects will allow the state to meet its growing energy needs while maintaining efforts to reduce greenhouse carbon emissions by 2030.

William Walsh, SCE Vice President of Energy Procurement & Management, said: “These new emissions-free projects will help us ensure the reliability of the grid for our customers and integrate an ever-increasing amount of clean renewable energy over the next decade.”

The seven contracts form part of the SCE Pathway 2045, a research-based strategy to comply with carbon-neutrality by 2045.

Fluence has been able to keep working on “all but two or three” of 73 utility-scale battery projects, with battery energy storage increasingly considered an essential part of grid infrastructure in many parts of the world.

Energy-Storage.news spoke to John Zahurancik, chief commercial officer at the technology provider formed in a joint venture (JV) between power project developer AES Corporation and engineering giant Siemens.

Zahurancik said that while there have been some necessary delays and adjustments to working practises to minimise the possibility of COVID-19 transmissions, nearly all of the company’s project pipeline is “moving ahead in one form or another”.

“We’re very actively out and doing installations of equipment in most pieces these are utility-scale energy storage installations that the construction of those has in most spots been exempted from restrictions on shutting a business down or it’s considered to be part of critical infrastructure development,” the Fluence COO said.

A ‘bigger and bigger part of the conversation’: Energy transition and economic recovery
Longer term, John Zahurancik said that energy storage will be “part of the conversation” in how economies move to restart and move forwards once the pandemic is finally under control. Energy storage has been an “increasing part of the conversation in terms of infrastructure,” in replacing ageing infrastructure as well as in terms of the transition to a cleaner and more efficient electrical grid already, he said.

“We see more of the infrastructure planners, whether those are utilities or regulatory bodies, or other people that are dealing with long-term infrastructure, include energy storage as part of their long-term planning cycles. We’re seeing people conduct solicitations, procurements for energy storage all around the world in different forms.

In some places it’s aimed at strengthening the generation side, in complement to renewables, in other cases it’s aimed at strengthening the transmission and distribution side, you even see energy storage at the customer-sited level for resiliency and cost reduction,” Zahurancik said.

(Washington, D.C. – May 5, 2020) EDF joins allies supporting the Federal Energy Regulatory Commission today for virtual oral argument in a case that will have a vital impact on America’s clean energy future.

This morning a three judge D.C. Circuit panel will hear argument by teleconference about FERC’s Order 841 – an order that permits energy storage to compete fairly in wholesale power markets. EDF is supporting the order.

“FERC’s order 841 creates an even playing field for energy storage to compete with traditional fossil fuel generators, which is an essential step to realizing cleaner, healthier air and a clean energy future for America,” said EDF attorney Michael Panfil. “Order 841 removes market barriers for energy storage and unlocks its enormous public health, environmental and cost-saving potential.”

FERC’s Order 841 “remove[s] barriers to the participation of electric storage resources” in wholesale power markets. The order could catalyze energy storage deployment by up to 50 gigawatts, according to expert analysis. The order unlocks critical benefits from such deployment while carefully respecting longstanding state authority to craft climate, clean air and clean energy policy.

Opponents, including an association of traditional utility companies and NARUC, have sued to block the rule. They will argue against it today, opposite attorneys for FERC.

EDF is intervening in the case in support of FERC’s order, along with NRDC and VoteSolar, both represented by EarthJustice.

A coalition of clean energy trade associations including the Energy Storage Association, the Solar Energy Industries Association, and the Advanced Energy Economy, also intervened in the case in support of FERC Order 841. A coalition of state Attorneys General and a coalition of innovative tech companies including Sunrun, Tesla, Vivint Solar Developer, and ENGIE Storage Services have filed amicus briefs in support of the order.

South Australia’s principal electricity Transmission Network Service Provider (TNSP), ElectraNet, recently won Energy Networks Australia’s 2019 Industry Innovation Award for its Dalrymple Battery Energy Storage System (BESS). The remarkable project is now in full commercial operation and is the first BESS in the National Electricity Market (NEM) to provide both regulated network reliability and security services alongside competitive market services.

As one of the most extensive regional transmission systems in Australia, ElectraNet’s network extends across some 200,000 square kilometres.

The transmission network has more than 90 substation sites and 5,500 circuit kilometres of transmission lines operating at 275,000 and 132,000 volts.

The Australian Energy Market Operator’s (AEMO) Integrated System Plan (ISP), published in July 2018, highlighted that energy storage has a significant role to play in the future energy system with the continued growth of intermittent renewable energy sources.

The Dalrymple BESS showcases the widest range of services provided by a grid-connected BESS in the NEM, covering both energy and system security services.

ElectraNet designed, built and owns the Dalrymple BESS and leases commercial operation to AGL. The project received part-funding from the Australian Renewable Energy Agency (ARENA).

Objectives and rationale

The objectives of the project were to demonstrate that utility-scale battery storage can effectively:

• Provide network reliability and security services alongside competitive market services in a network with a high penetration of renewable non- synchronous generation
• Provide “seamless” islanded operation with 100 per cent renewable generation following transmission outages
• Demonstrate a commercial model for the provision of regulated services and competitive energy market services, and build delivery capability for such assets
• The Dalrymple 30MW, 8MWh BESS is the first transmission grid-connected battery in the NEM providing both regulated and competitive market services.

US-based utility company Southern California Edison (SCE) has signed seven contracts for 770MW of battery-based energy storage capacity to strengthen California’s electric system reliability.

SCE has signed agreements Southern Power, NextEra Energy Resources, TerraGen Power and LS Power to procure the capacity.

The company has signed three 15-year contracts with NextEra Energy Resources for a total capacity of 460MW. It has signed two 20-year contracts with Southern Power for a total capacity of 160MW.

The other contracts include a ten-year contract with TerraGen Power for 50MW capacity and a 15-year contract term with LS Power for 100MW.

A majority of the energy storage projects will be located adjacent to the solar power plant to charge the battery over the term of the contract.

SCE has signed contracts with Southern Power for its Garland and Tranquillity projects that have a capacity of 88MW and 72MW respectively.

NextEra Energy has been contracted for the Blythe 2, Blythe 3 and McCoy projects with a capacity of 115MW, 115MW and 230MW respectively.

On the other hand, TerraGen Power has signed a contract with SCE for its Sanborn project for a capacity of 50MW while LS Power secured contracts for its Gateway 1-2 project.

SCE Energy procurement and management vice-president William Walsh said: “These new emissions-free projects will help us ensure the reliability of the grid for our customers and integrate an ever-increasing amount of clean renewable energy over the next decade.