A new lithium-ion based energy storage system for ships has been launched by Rolls-Royce.

Dubbed SAVe Energy, it is said to be cost competitive and highly efficient that can be scaled depending on the energy and power requirements of the ships.

According to Rolls-Royce, a vessel can operate on batteries alone when in harbour or for a limited period with zero emission, depending on the specified battery capacity, with energy storage providing load smoothing and reducing the number of generators required to be operating.

It has been developed in partnership with ship firms Color Line, Norled and the Norwegian Coastal Administration Shipping Company, ensuring the system covers a wide variety of marine applications, including ferries, cruise vessels and multi-purpose vessels.

The development work was partly funded by the Norwegian Research Council of Norway’s ENERGIX programme.

Rolls-Royce has been delivering energy storage systems since 2010, however, the actual energy storage units were previously supplied by an external party.

Andreas Seth, EVP Electrical, Automation and Control – Commercial Marine at Rolls-Royce said: “The electrification of ships is building momentum. From 2010, we have delivered battery systems representing about 15MWh in total. However, now the potential deployment of our patent pending SAVe Energy in 2019 alone is 10-18MWh.

“Battery systems have become a key component of our power and propulsions systems and SAVe Energy is being introduced on many of the projects we are currently working on. This includes the upgrade programme for Hurtigruten’s cruise ferries, the advanced fishing vessel recently ordered by Prestfjord and the ongoing retrofits of offshore support vessels.”

New battery technology that could see electric vehicles being charged in a fraction of the time of current standards – and powered by either electricity or hydrogen – has been developed by a team of Scottish scientists.

Battery storage or fuel cell storage – this is a polarising topic for those in the game of developing electric car technology.

While a battery electric vehicle has the advantage of instant torque, quiet ride and zero tailpipe emissions, currently the speed with which an electric car can recharge is at best 30 minutes on a fast charger, or more often overnight if charged through a standard 3 phase outlet.

Hydrogen fuel cell technology – which stores the energy for the car in the form of hydrogen – is also tailpipe emission free, and while theoretically a fuel cell vehicle can be refuelled as quickly as a petrol or diesel vehicle, the technology is far more expensive.

Now, researchers at the University of Glasgow say they have created a flexible solution using nanomolecules that allow energy to be stored and output in the form of either electricity or hydrogen gas.

The breakthrough uses what the researchers are describing as an ‘exotic rust’ – a metal oxide that when added to water, can be charged with electricity.

Using this technology – which is still in prototype stage – EV drivers would be able to refuel cars in much the same way as is done at the petrol station today.

First, the used ‘rust’ liquid is removed using a special nozzle at the pump, then the car is refuelled using a second nozzle to replenish the car’s energy stores.

Professor Leroy Cronin, Regius Chair of Chemistry at the University of Glasgow, has published the breakthrough research in the journal Nature Chemistry and says the ‘flow’ liquid battery could be the answer to making EVs a real contender against fossil-fuel vehicles.

“Energy storage solutions that can act as both batteries and fuel generation devices (depending on the requirements of the user) could therefore revolutionize the uptake and use of renewably generated energy,” wrote the researchers in the journal.

It may not be smooth sailing for Pacific Gas and Electric’s landmark energy storage projects.

Totaling 567 MW, 2,270 MWh, the four projects were hailed as the largest battery storage investment ever proposed when PG&E submitted them for approval at the California Public Utilities Commission (CPUC) in late June. However, comments opposing the projects could slow down their approval and implementation.

Already, the state’s Office of Ratepayer Advocates (ORA) and the Direct Access Customer Coalition (DACC) have filed comments opposing the projects, prompting the CPUC to extend the approval process by at least 120 days. The comments raise questions about whether or not the energy storage projects are needed and whether PG&E’s proposal conforms to the commission’s directives.

The recently-filed comments have had very little public scrutiny, as they were only sent to the relevant parties and have not been posted on the CPUC website.

The cost of reliability

In their comments, the ORA, which is part of the CPUC, argues that the energy storage projects are not needed because the deficiency they are designed to fill will be met with new and planned transmission projects. The ORA claims the projects do not comply with CPUC resolution (E-4909) that authorized PG&E to issue a solicitation for the projects.

The resolution is designed to alleviate the need for an out-of-market contract for Calpine’s Metcalf Energy Center, a 564-MW gas-fired plant in San Jose. Calpine had told the California ISO that it would have to take the plant out of service because it was uneconomic, but the ISO determined the plant is needed, granting a reliability must run (RMR) contract.

In the resolution authorizing the storage projects, the CPUC expressed its concerns about the impact the RMR contracts would have on ratepayers and the lack of competition in the RMR process that can lead to “market distortions and unjust rates for power.”

The commission ordered PG&E to enter into energy storage contracts at “reasonable cost to ratepayers” and to take into consideration the cost and value and the results of previous, similar solicitations. But the ORA argues PG&E did not meet the CPUC’s requirements because the utility did not provide “analysis or explain how the cost of the four energy storage projects are reasonable taking into consideration the cost of the Metcalf RMR contract.” Nor did PG&E compare the four contracts to previous energy storage solicitations, the ORA said.

Customer Energy Management programme to be paid for through shared savings

Solar Energy Corporation of India (SECI) will issue a request for bids (RfB) for a 160MW hybrid solar and wind project combined with battery energy storage in the state of Andhra Pradesh on 20 August.

The tender for the hybrid project at Ramagiri, Anantapur District, has been on the cards for some time after SECI reached out to industry to establish how much interest there is in providing EPC services for it via an Expressions of Interest (EOI) issuance back in January.

The contract will be for design, engineering, supply, construction, erection, testing and commissioning of the hybrid plant, including 10 years of operations and maintenance (O&M) services. The contract will be awarded via international competitive bidding.

SECI has applied for financing from the World Bank to go towards the cost of the project.

A pre-bid meeting will be held on 31 August and the deadline for bid submissions will be 1 October.

Shared infrastructure for the project is likely to be provided by New and Renewable Energy Development Corporation of Andhra Pradesh (NREDCAP) while transmission evacuation facilities will be provided by Andhra Pradesh Transmission Company Limited (AP Transco). When first announced, the energy storage element of the project was tabbed at 40MWh capacity.

This project could become the largest and amongst the first of its kind built in India. However a smaller pilot project is also being planned in Kerala, as reported by PV Tech back in December 2017.

In March, Indian power minister R.K. Singh called on battery-based energy storage manufacturers to set up manufacturing units in India, particularly given the new focus on hybrid projects through the government’s recently finalised National Wind-Solar Hybrid policy, under which all forms of energy storage are eligible to be included in projects.

A new type of energy storage system could revolutionise energy storage and drop the charging time of electric cars from hours to seconds.

In a new paper published today in the journal Nature Chemistry, chemists from the University of Glasgow discuss how they developed a flow battery system using a nano-molecule that can store electric power or hydrogen gas giving a new type of hybrid energy storage system that can be used as a flow battery or for hydrogen storage.

Their ‘hybrid-electric-hydrogen’ flow battery, based upon the design of a nanoscale battery molecule can store energy, releasing the power on demand as electric power or hydrogen gas that can be used a fuel. When a concentrated liquid containing the nano-molecules is made, the amount of energy it can store increases by almost 10 times. The energy can be released as either electricity or hydrogen gas meaning that the system could be used flexibly in situations that might need either a fuel or electric power.

One potential benefit of this system is that electric cars could be charged in seconds, as the material is a pumpable liquid. This could mean that the battery of an electric car could be “recharged” in roughly the same length of time as petrol cars can be filled up. The old battery liquid would be removed at the same time and recharged ready to be used again.

The approach was designed and developed by Professor Leroy (Lee) Cronin, the University of Glasgow’s Regius Chair of Chemistry, and Dr. Mark Symes, Senior Lecturer in Electrochemistry, also at the University of Glasgow with Dr. Jia Jia Chen, who is a researcher in the team. They are convinced that this result will help pave the way for the development of new energy storage systems that could be used in electric cars, for the storage of renewable energy, and to develop electric-to-gas energy systems for when a fuel is required.

Professor Cronin said: “For future renewables to be effective high capacity and flexible energy storage systems are needed to smooth out the peaks and troughs in supply. Our approach will provide a new route to do this electrochemically and could even have application in electric cars where batteries can still take hours to recharge and have limited capacity. Moreover, the very high energy density of our material could increase the range of electric cars, and also increase the resilience of energy storage systems to keep the lights on at times of peak demand.”

For an RTO trying to fit energy storage in its system, one of the hardest tasks is how to characterize storage. It is supply and load, but RTO rules generally take a binary approach to power system resources. It has to be one or the other, not both.

That approach can hinder the use of energy storage in the capacity and energy markets, which many analysts say is key to optimizing the economics of energy storage.

FERC’s Order 841 directs RTOs such as MISO to change their rules to give energy storage broader access to participate in wholesale energy, capacity and ancillary services markets.

However, energy storage can not only act as generation and load, it can perform those functions from either side of the meter. Meanwhile, FERC’s jurisdiction only applies to wholesale power markets.

The question of proper jurisdiction could prove to be one of the most pivotal challenges. Existing regulations were not set up to handle distribution-connected storage devices that can also supply the wholesale market.

Stakeholders such as the Transmission Access Policy Study Group (TAPS) and Xcel Energy have filed at FERC arguing that the federal regulator does not have jurisdiction to mandate that energy storage resources on the distribution system be able to participate in wholesale markets.

In that filing, Xcel argued that allowing distribution-connected storage to provide retail and wholesale services “oversteps the limits on the Commission’s jurisdiction under the Federal Power Act by interfering in state jurisdiction over retail sales and affecting the ability to preserve distribution system reliability.”

MISO and other stakeholders in March filed with FERC asking for an extension on the deadline the regulatory agency set for Order 841 compliance, as well as clarification on the jurisdiction issue.

The automotive industry’s use of lithium-ion batteries is on track to grow seven-fold to 650 GWh by 2025, from 70 GWh in 2017; the increase in energy storage, although from a lower base, will add to this, says specialist international publisher Metal Bulletin.

It adds that the electrification of vehicles and the need to store electricity, generated by renewable energy sources such as wind and solar, point to huge demand growth for lithium-ion batteries.

Government subsidies and incentives in many countries – most notably China – are encouraging sales of electric vehicles (EVs) and e-buses.

For now, the cost of manufacturing EVs remains more expensive than a vehicle powered by a comparable petrol or diesel internal combustion engine (ICE), owing to the cost of the EV’s battery pack.

However, economies of scale are at work in bringing down battery costs; and as EV and ICE vehicle prices converge, the cheaper running cost of EVs is expected to make them the vehicle of choice.

Battery pack costs have fallen to around $200/kWh this year, from around $1 000/kWh in 2010, and may reach a battery cell cost of $100/kWh this year, with its battery pack costs expected to reach that level in 2020.

The $100/kWh price tag for a battery pack is thought to be the tipping point where EV and ICE costs are similar.

Metal Bulletin further expects many consumers to see EVs as a must-have status symbol well before prices converge. The publisher questions whether raw material supply will be able to respond in time.

“In most cases, the supply chain is coping with the rollout of EVs but the technology is at the start of the ‘S’-curve. The entire supply chain must work hard and in a coordinated way to feed this new supercharged era.

The supply response from raw material producers to processors, cathode and battery manufacturers and original-equipment manufacturers will be massive, with output needing to increase many times over in a short period to keep up with even the more conservative demand outlooks,” notes Metal Bulletin.

To keep pace with the changing dynamics of the energy markets, India is now working toward a National Energy Storage Mission (NESM). In February 2018, a committee with representatives from relevant ministries, industry associations, research institutions and experts, was constituted by the MNRE to propose a draft for setting up NESM in India.

The Minister for Power, Raj Kumar Singh, apprised the Lok Sabha about this initiative.

“The committee has proposed a draft NESM with objective to strive for leadership in energy storage sector by creating an enabling policy and regulatory framework that encourages manufacturing, deployment, innovation and further cost reduction,” Singh said.

Singh said NITI Aayog and the Rocky Mountain Institute’s joint report on India’s Energy Storage Mission has proposed a three-stage solution approach: creating an environment for battery manufacturing growth, scaling supply chain strategies and scaling battery cell manufacturing.

Energy storage is one of the most crucial and critical components missing in India’s energy infrastructure strategy and is a must to sustain India’s transformation from fossil fuels to renewables. Key areas for energy storage application include integrating renewable energy with distribution and transmission grids, setting rural micro-grids with diversified loads or standalone systems and developing the storage component of electric mobility plans.

Recently, the MNRE brought battery energy storage systems (BESS) under the ambit of the Solar Photovoltaics, Systems, Devices and Component Goods (Requirement for Compulsory Registration under BIS Act) Order 2017.

Mercom previously reported that India could account for more than one-third of the global market for electric vehicle (EV) batteries by 2030 if it becomes a 100-percent EV nation, according to a study conducted by Niti Aayog and the Rocky Mountain Institute.

India’s renewable energy sector needs a strong backbone in the form of a robust energy storage industry in order to sustain its growth trajectory. In a recent interview with Mercom, Naveen Sharma, the vice president of energy storage provider Exicom, noted that India’s current position in the battery manufacturing sector could hinder its plans to add more renewable energy. The solution, he said, is for the country to create a strategy to transform itself into a global hub for energy storage solutions.

CARMEL, Ind. — MISO last week laid out a more detailed proposal for how it will determine the capacity accreditation of electric storage resources under FERC Order 841.

The RTO is proposing to determine electric storage resources’ capacity based on two different measurements: the resource’s power output capability and its energy storage capacity as measured by MISO’s generator verification test capacity (GVTC).

Speaking at an Aug. 8 Resource Adequacy Subcommittee meeting, Senior Adviser of Capacity Market Administration Rick Kim said the rule will ensure both a megawatt and megawatt-hour measurement of a storage resource’s capability.

Kim said for storage resources under 10 MW or that have fewer than 12 months of operational data, MISO will apply a 5% default equivalent forced outage rate in its unforced capacity calculation. Other storage resources will be assigned a forced outage rate based on their quarterly data inputs to MISO’s generating availability data system (GADS). GADS reporting is required for storage resources 10 MW and above and optional for those under 10 MW.

Because NERC hasn’t yet addressed unit reporting for storage resources, Kim said resource operators should use the “miscellaneous” unit type option when reporting unit data.

“It’s going to be another year before we see registration of energy storage resources,” he added.

Kim also said storage resources connected to the transmission system will require either network resource interconnection service or firm transmission service with MISO to ensure capacity deliverability. If resources are connected at the distribution level, MISO will ensure deliverability with the distribution provider and transmission owner on a “case-by-case” basis, he said.

MISO has said that when storage resources are connected at the distribution level, market participants “must have sufficient metering or accounting for non-wholesale transactions to prevent double counting of energy.”

The RTO in June said it would accommodate Order 841 by dividing storage bid parameters into four operating modes: discharging, charging, continuous operations and offline. Market participants will be left to choose a mode for individual dispatch intervals and will also be responsible for managing the state of charge of their storage units. (See MISO Weighing Feedback to Storage Proposal.) Storage resources will be able to set prices under MISO’s extended LMP.