The U.K. government should learn from California and incentivize energy-storage technology to help move away from dirty fuels, a cross-party panel of lawmakers said.

Ministers should reform the Capacity Market, a subsidy program designed to lower the risk of blackouts, to reward both energy-storage projects and power users who lower consumption at times of high demand, Parliament’s Energy and Climate Change Committee said in a report published on Saturday. 

“There is an incredible opportunity for the U.K. to become a world leader in these disruptive technologies,” Chairman Angus MacNeil said. “Yet our current energy-security subsidies favor dirty diesel generation over smart new clean-tech solutions.”

Britain is trying to ensure it avoids power cuts as coal-fired power stations and aging atomic reactors close down. In March, the government said it would begin payments to power generators to guarantee electricity supply in the winter of 2017 to 2018, a year earlier than previously planned, in an attempt to encourage the building of new gas plants. 

Ministers should aim to spur projects that store excess power at times of low demand and feed it back into the grid when demand peaks, as well as those that encourage users to reduce their own demand, the committee said.

Get it Right

“We need to learn from California where strong public financial support and clear legislation have helped develop a storage industry and integrate storage infrastructure into the grid,” MacNeil said. “Getting demand-side response right will empower consumers, reduce bills, ease pressure on the grid, and lower carbon dioxide emissions.”

“We are fully committed to a low carbon energy future and the potential benefits that new technologies such as storage could bring to this,” the government’s Department for Business, Energy and Industrial Strategy said in an e-mailed statement. “However, for the capacity market to work effectively it relies on flexible technology that is ready to be deployed.”

The committee also concluded that there are only “limited” short-term effects on electricity and gas supply of the U.K.’s decision to withdraw from the European Union. It urged ministers to publish an emissions-reduction plan because “the vote to leave has reduced already weak investor confidence in the energy sector.”

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PAIA — The end of incentive programs doesn’t mean the door has closed on rooftop solar, but customers and businesses will have to start relying more on the still-growing technology of energy storage, industry experts explained at a community forum Thursday night.

Held at the Kaunoa Senior Center in Paia, the forum took a community-focused look at Maui’s energy future. After the Public Utilities Commission rejected the merger between Hawaiian Electric Co. and Florida-based energy company NextEra over the summer, the state now has a little more clarity on the path to its goal of 100 percent renewable energy by 2045, moderator Dick Mayer said.

But community involvement in this goal has become tougher since Maui Electric Co.’s net-metering program closed last October, and the customer-grid supply program hit its 5-megawatt capacity in June. Both gave customers credits for energy they sent to the grid.

Now, batteries are “the way forward for the grid,” said Brad Albert, co-owner of Rising Sun Solar.

“Industry-wide there’s a big transition going on,” Albert said. “Between the price of batteries coming down and what it can do for the grid, I think there’s a lot of opportunity.”

MECO’s customer self-supply program allows customers to install solar as long as they don’t export to the grid. However, the solar industry has had little time to adjust to the rising need for energy storage, and many companies are still working to create viable products. Rising Sun Solar, for example, has worked with Tesla and has a battery that Albert thinks will bring cost savings similar to the MECO programs.

“The issue today is that there is no compensation if you have a distributed battery for the energy services you could provide to the grid,” Albert said. “As soon as we create that incentive, I think we’ll have a lot more batteries to be installed. . . . Customers can be part of the solution.”

Stored energy could help residents in power outages, possibly bring energy to the grid in the future and reduce the need for fossil fuel, Albert said.

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A new cooperative integration of AutoGrid Flex energy management with sonnenBatterie energy storage systems will enables energy project developers to better monetize the flexible capacity of distributed energy resources.

San Francisco Bay Area-based AutoGrid Systems, and German battery integrator sonnen have partnered to help energy project developers, utilities and other energy service providers better manage, optimize and aggregate sonnen’s battery systems and other distributed energy resources (DERs). The agreement will fully integrate AutoGrid Flex energy management capabilities with sonnen’s residential and commercial energy storage technology systems.

Among flexibility value streams that may be enhanced through the partnership are: optimizing self-consumption in real time across multiple factors including peak demand charges and time-varying prices; participating in utility demand response and resource adequacy programs; and creating a virtual power plant to participate in wholesale capacity, energy and ancillary services markets.

AutoGrid applications are all built on the AutoGrid Energy Internet Platform (EIP), with patented Predictive Controls technology that leverages petabytes of smart meter, sensor and third-party data, along with powerful data science and high-performance computing algorithms, to monitor, predict, optimize and control the operations of millions of assets connected across global energy networks.

The AutoGrid Flex application suite provides advanced forecasting, real-time controls and scalable architecture to manage large numbers of distributed sonnenBatterie systems in combination with other DERs. This fleet management is key to optimizing the utilization of battery storage capacity for both the local site and the regional grid network, and AutoGrid Flex is already integrated with multiple wholesale markets, including CAISO, PJM and ERCOT, and underpins several of the world’s leading utility DER systems.

Designed to optimize all DER asset categories including distributed generation, battery storage, and demand response resources, AutoGrid Flex provides out-of-the-box support for all prevalent grid services and wholesale market programs spanning all customer segments – residential, commercial and industrial – through its three main applications: AutoGrid DROMS, an enterprise-grade demand response management system; AutoGrid DERMS, a distributed energy resource management system (DERMS) for providing targeted distribution-level grid-services; and AutoGrid VPP, a virtual power plant (VPP) solution for participation in wholesale markets.

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NEC Energy Solutions, a subsidiary of NEC Corporation, announced that it is supplying the Sterling Municipal Light Department (SMLD) of Sterling, Massachusetts, with a 2MW, 3.9 MWh energy storage solution.

Once the project is completed in December 2016, it will be the largest battery-based energy storage system installed in New England and the first utility-scale project in Massachusetts.

The installation will help boost grid resiliency against weather-related power outages, while also generating enhanced clean energy usage and cost savings to the town of Sterling. The project was funded in part due to a US$1.46 million grant from the Massachusetts Department of Energy Resources (DOER) — along with additional financial and technical assistance from the US Department of Energy, Office of Electricity (DOE-OE).

Additional technical support was provided by Clean Energy States Alliance (CESA) through its Energy Storage Technology Advancement Partnership (ESTAP) along with Clean Energy Group’s Resilient Power Project through a grant from the Barr Foundation.

Judith Judson, Massachusetts Department of Energy Resources Commissioner, said: “Energy storage technologies, especially when paired with renewable energy, have the potential to be a game changer for Massachusetts, helping to lower the cost of energy to ratepayers while reducing emissions. DOER’s Community Clean Energy Resiliency Initiative, through which this project received funding, is a testament to the Baker-Polito Administration’s commitment to embracing innovative clean energy solutions across the Commonwealth.”

Bud Collins, CEO of NEC Energy Solutions, “This project is the largest of its kind in New England and represents our ongoing commitment to deliver comprehensive, safe, and reliable energy storage solutions whether located across the globe, or like this one, in our own backyard. As a leader in providing energy storage solutions, we stand ready to implement further projects of this type here in the Commonwealth and in proud local support of the DOER energy storage initiatives that could make Massachusetts one of the largest energy storage markets in the world.”

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A new report published by Allied Market Research titled, Energy Storage Systems Market by Technology, End-User, and by Application-Global Opportunity Analysis and Industry Forecast, 2014-2022, projects that the world energy storage systems market is expected to reach $264,953 million by 2022 from $172,236 million in 2015, registering a CAGR of 6.4% from 2016 to 2022. It is anticipated that pumped hydro storage technology segment would generate the highest revenue throughout the forecast period. In the year 2015,Asia-Pacific led the global market and is expected to maintain its position throughout the forecast period.

According to Eswara Prasad, Team Lead Chemical Research at AMR, “China and South Korea are driving the growth of energy storage systems market in Asia-pacific with an increasing focus on production of electric vehicles in future.”

The increasing production of renewable energy by major economies across the world is driving the market for energy storage systems. Coupled with the increasing usage of renewable resources, the growing interest towards adoption of electric vehicles will also fuel the growth of energy storage systems. Inspite of increasing need for energy storage systems elements such as high capital investment and environmental concerns pose as a constraint to the market. High cost is another hurdle for the energy storage systems market owing to price sensitive nature of the buyers.

In the year 2015, grid storage was the largest end-user, with major share of world energy storage systems market, followed by transportation. Although there is a keen focus of major economies such as China, United Kingdom, France, Holland, Spain, Germany,Japan, U. S. on increased production of electric vehicles with an objective to save to high cost incurred due to fuel consumption.

Key findings of the Energy Storage System Market study: 

• Pumped hydro storage segment is expected to account for major market share in 2015 and is expected to stay in the dominating position along the forecast period
• Non-residential end-user segment is expected to grow at a CAGR of 7.6% during the forecast period
• Asia-Pacific is anticipated to lead the market throughout 2022, growing at a CAGR of 7.3%, in value terms.
• Flywheel is the fastest growing segment in the Asia-pacific region growing at an estimated CAGR of 28.9% in terms of value
• In North America, U. S occupies a major share of around 83.8% in 2015

In 2015, Europe and North America collectively accounted for nearly three-fifth of the worldwide demand for energy storage systems and are expected to grow at a steady pace during the forecast period. This is mainly due to increased focus of these economies on the production of renewable energy.

The report provides comprehensive analysis of the key players that operate in the world energy storage systems market such as LG Chem., ABB Ltd., AES Energy Storage, LLC, Beacon Power, LLC, BYD Company Limited, Convergent Energy and Power Inc., Greensmith Energy Management Systems, Eos Energy Storage, Seeo Inc., and S&C Electric Company. These players occupy a major share in the world energy storage systems market followed by other tier 2 and tier 3 players worldwide.

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Part I: Texas assumes a leading role in defining the value of storage

This first of four posts examining energy storage in Texas provides an introduction to storage technologies and describes the numerous utility-scale battery technologies currently operating in the state. The storage of electric energy is often called the “holy grail” of the future electric grid. While Massachusetts, California and Oregon have led in storage development through mandates and financial incentives, Texas is assuming a lead role in the nation through its innovative application of storage that further defines the vital role storage can play in enhancing grid reliability and lowering rates.

The combination of geology, climate, regulated and unregulated electric utilities, an independent system operator (ERCOT), Federal tax incentives that encourage intermittent wind and solar generation, and importantly, a business-friendly environment makes Texas an ideal test bed for storage technology. The diverse range of storage applications —now operating, and those in the pipeline — are defining how, when, and where storage will thrive in the future Texas market.

Storage Basics

Storage is not achieved through just a single technology. Different mechanisms include flywheels; compressed air energy, thermal, and pumped hydro storage; supercapacitors; and batteries, including solid state and flow batteries. All of these technologies except pumped hydro are active in Texas as either a research and demonstration project, a behind-the-meter end-user resource not connected to the grid, a resource to improve generator efficiency, or an active or planned third-party owned system connected to a utility distribution or transmission system. Including storage in the Texas market structure has been difficult because storage can function as both generation and load and can serve multiple functions. The language of the age-old electric market structure with clear separation of generation, transmission, distribution, and end-use does not comfortably accommodate the storage asset. Add to this ambiguity a diverse market structure and the complexity grows.

A structure that fits storage into Texas’s both restructured and vertically integrated market is now in place save for one major issue: The establishment of conditions under which regulated “wires” companies can own and operate storage and include the cost of the investment in the rate base. This issue is now squarely in front of the Texas Public Utility Commission (PUC). Under current rules, storage projects 10 MW or greater that are connected to the ERCOT grid require an Interconnection Agreement (IA) as specified in a standard protocol set up by ERCOT. Co-ops and municipally owned utilities (MUNIs) are exempt from the ERCOT IA requirement but must follow a separate PUC rule for distributed generation resources (DER). All projects smaller than 10 MW, if connected to a utility grid, need an IA between the utility and the storage provider.

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REDWOOD CITY, CA–(Marketwired – Oct 12, 2016) – AutoGrid Systems, the Energy Internet leader, and sonnen, Inc., the global leader in smart energy storage systems, have partnered to fully integrate AutoGrid’s flexibility management application suite, AutoGrid Flex™, with sonnen’s award-winning residential and commercial energy storage technology. Through this partnership, AutoGrid and sonnen will help energy project developers, utilities and other energy service providers better manage, optimize and aggregate sonnenBatterie systems and other distributed energy resources (DERs).

“sonnen’s advanced battery storage systems are already accelerating the world’s transition to a more distributed, renewable-friendly energy grid. By providing a platform that enables energy service providers to more easily aggregate these distributed storage systems, we will further accelerate this transformation,” said Dr. Amit Narayan, CEO of AutoGrid. “Our new partnership with sonnen will combine AutoGrid Flex software with sonnen’s intelligent battery storage systems, delivering higher project ROI to energy project developers and utilities who are seeking to deploy and manage fleets of DERs.”

The AutoGrid Flex application suite provides advanced forecasting, real-time controls and scalable architecture to manage large numbers of distributed sonnenBatterie systems in combination with other DERs. This fleet management is key to optimizing the utilization of battery storage capacity for both the local site and the regional grid network, and AutoGrid Flex is already integrated with multiple wholesale markets, including CAISO, PJM and ERCOT, and underpins several of the world’s leading utility DER systems.

By combining the best-in-class technologies of sonnen’s innovative battery systems and AutoGrid’s fleet management software, energy project developers, utilities and other energy service providers can rapidly monetize storage projects across multiple flexibility value streams by:

• Optimizing self-consumption in real time across multiple factors including peak demand charges and time-varying prices.
• Participating in utility demand response and resource adequacy programs.
• Creating a virtual power plant to participate in wholesale capacity, energy and ancillary services markets.

“By integrating our technologies in the U.S. market, sonnen and AutoGrid provide a solution that elegantly and intelligently manages DERs, including grid-connected sonnenBatterie systems, maximizing return-on-asset, reducing project delivery time and unlocking new revenue streams for utilities, energy project developers and energy managers,” said Christoph Ostermann, CEO of sonnen GmbH. “In Germany we have seen the value the virtual power plant model provides in balancing energy supply and demand by aggregating our sonnenBatterie systems. By adding AutoGrid Flex’s ability to optimize DER assets in support of grid services and wholesale energy programs for the U.S. market, our smart sonnenBatterie energy management systems will accelerate the adoption of a smarter, cleaner utility grid by reducing integration costs, improving ROI and increasing the use of DERs.”

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Critics called 2015 a “banner year” for energy storage. 

Now after a year of unprecedented growth, energy storage could be poised to best that performance, according to Navigant Research’s third quarter energy storage tracker.

“The North American market this year definitely has the potential to surpass the deployed capacity in 2015, especially considering how quickly new projects are being built today,” Ian McClenny, a research associate at Navigant, said.

Navigant projections show the North American storage market reaching just above 300 MW by year end.

A total of 221 MW (161 MWh) of energy storage was deployed in 2015 compared with 65 MW (86 MWh) in 2014, according to the Energy Storage Association.

Among the key drivers in the storage market, according to Navigant, are the proliferation of distributed, intermittent generation sources such as solar and wind power, which require increased load balancing, and the restructuring of electricity markets that will create new value streams for energy storage.

Among the notable developments so far this year is an increase in storage projects that use flow batteries and hybrid battery systems, the authors said, citing a Duke Energy project in North Carolina that combines a hybrid Aquion battery and a Maxwell Technologies ultracapcitor that will be used to fill both short and long duration energy needs from the single site at Duke’s Rankin substation.

The report also noted that distributed energy storage, which includes both behind-the-meter residential storage and community energy storage installations, accounted for about 14.2% of new the new storage installations so far this year, the highest percentage of any year yet.

Distributed energy storage systems (DESS), which includes C&I and microgrid installations, also accounted for 45.6% of the storage installations so far this year with the remainder, 54.4%, of the market comprised of utility scale installations.

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Outsiders could be forgiven for thinking that UK energy policy has abandoned renewables — consider the high-profile commitment to nuclear at Hinkley Point, and the Cameron government’s attack on feed in tariffs. It’s less well known that industry and government alike are taking a hard look at the possibilities forenergy storage.

While the Department for Energy and Climate Change (DECC) has been scrapped, its work wasn’t killed off. Last year came signs of the ‘smarter energy’ concept gaining ground — using systems and technology that could cut the need to invest in grid reinforcement and generation plant.

The government’s adviser, the National Infrastructure Commission, has calculated that a more flexible power system could save consumers up to £8 billion (US $9.8 billion) a year by 2030. Storage, of course, is a big part of this.

Before it was scrapped, DECC put out a call for evidence from all interested parties about the prospects for smart energy. Its findings are due to be published soon. Meanwhile the UK Solar Trade Association (STA) has been doing its own work.

“The combination of storage and solar is a long-term game changer rather than a short-term market bubble,” its report concluded.

STA wants to encourage field trials and for case studies to be made widely available. It’s especially keen to see the end of double-charging. Electrical storage systems are treated as generation: there’s a charge both for storing and importing (intermediary consumption); also for discharging and using that energy (final consumption).

No one knows what the impact of Brexit might be on, for instance, collaborative research. But, says David Pickup, STA policy manager and the report’s author, things could be done now. “We can learn from Germany,” he toldRenewable Energy World. “There you see the value of a 3-5-year strategy. They had a grant scheme for domestic systems, but the safety and standards requirement for these was quite strict.”

He feels there’s no reason why such knowledge and regulatory practice couldn’t be imported into the UK. Moreover, Pickup thinks the new government could be open to persuasion on storage.

“What’s been striking over the last few months is its evidence-based voice,” he said. “With solar and storage, costs are coming down and the benefits are clear — there are huge amounts of evidence that this is the right way to go.”

Is it worth pushing the newly-created Department for Business, Energy and Industrial Strategy (BEIS) for California-style targets? California has ordered its three largest utilities to reach 1.3 GW of storage by 2020. Interestingly, Pickup doesn’t think so.

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A Dutch startup called LeydenJar is boldly going where no one else in the energy storage field has apparently gone before. The company, a spinoff from the Energy Research Centre of the Netherlands, has come up with a new version of lithium-ion battery technology that uses 100% silicon instead of graphite.

At first glance, that’s a risky proposition, because normally silicon goes through destructive cycles of shrinkage and expansion when used in rechargeable batteries. However, if the new battery can be manufactured at scale with a reasonable lifespan, the payoff is an increase in capacity of up to 50% over conventional graphite-based energy storage.

With an all-silicon recipe, the LeydenJar team claims that it has increased the capacity of the anode in its new lithium-ion battery by a factor of 10.

They managed to do that without ending up with crumbled bits of battery on the floor by applying a one-machine, plasma-based fabrication method to the anode.

The silicon is deposited onto a copper substrate in nanoscale columns, achieving a height of about 10 microns (that’s the thickness required for commercial application, according to LeydenJar).

The resulting pattern of filled and empty spaces provides enough room for the silicon to expand safely when the battery is recharged.

Yet Another Happy Accident

The team also drew on lessons learned from failed experiments in the solar field. The silicon column approach dates back at least a dozen years, when researchers at the Energy Research Centre were trying to develop the material for use in solar cells.

That didn’t work out as planned, but all that effort was not lost since the technology has been transferred to the energy storage field.

The new battery’s ties to the solar field also carry over to the manufacturing process.

The plasma-based method enables commercial-scale production of what was previously possible only in small batches. As described by LeydenJar, there is a huge difference between their one-machine, one-step process and conventional anode production.

Conventional graphite anodes can be enhanced with small amounts of silicon, but that requires “active material, binder, and other components in a capital-intensive process consisting of slurry making, a coating process, a baking process, calendering and slitting.”

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