A team of engineers led by 94-year-old John Goodenough, professor in the Cockrell School of Engineering at The University of Texas at Austin and co-inventor of the lithium-ion battery, has developed the first all-solid-state battery cells that could lead to safer, faster-charging, longer-lasting rechargeable batteries for handheld mobile devices, electric cars and stationary energy storage.  

Goodenough’s latest breakthrough, completed with Cockrell School senior research fellow Maria Helena Braga, is a low-cost all-solid-state battery that is noncombustible and has a long cycle life (battery life) with a high volumetric energy density and fast rates of charge and discharge. The engineers describe their new technology in a recent paper published in the journal Energy & Environmental Science.  

“Cost, safety, energy density, rates of charge and discharge and cycle life are critical for battery-driven cars to be more widely adopted. We believe our discovery solves many of the problems that are inherent in today’s batteries,” Goodenough said.   The researchers demonstrated that their new battery cells have at least three times as much energy density as today’s lithium-ion batteries. A battery cell’s energy density gives an electric vehicle its driving range, so a higher energy density means that a car can drive more miles between charges. The UT Austin battery formulation also allows for a greater number of charging and discharging cycles, which equates to longer-lasting batteries, as well as a faster rate of recharge (minutes rather than hours).

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When Google first launched a website two years ago that collects data on solar rooftops, called Project Sunroof, it only covered a few cities. But this week, the search engine giant announced the solar site is now crunching data for every single U.S. state, including 60 million rooftops across the country.

The expansion means that Google’s Project Sunroof is starting to get a much clearer picture of how much rooftop solar capacity there actually is in the U.S. Project Sunroof uses data from Google Maps and Google Earth, combined with 3-D modeling and machine learning to determine the solar electricity potential of individual roofs.

Potential solar customers — or just the solar-curious — can enter their addresses into the site and get information about how much a solar system on their roof might cost and how much money they might save over time by going solar.

Google’s product manager Joel Conkling told GTM the goal of Project Sunroof is “to get data into the hands of people thinking about solar, and who are making decisions about solar.” He added that “the hope is [to] help people make more quantitative decisions about solar.”

The large amount of data being collected by Google also means that the internet company’s project could be a helpful tool not only for consumers interested in solar, but also for solar companies looking to bring in new customers, as well as academic researchers and even utilities.

Now that Project Sunroof’s availability is countrywide, Google’s amassed data has started to reveal some interesting trends and information. For one thing, Google says that 79 percent of the rooftops it’s analyzed are viable for solar, which is good news for rooftop solar providers.

That doesn’t mean that 79 percent of rooftops should or will adopt solar, though. Rather, it means that 79 percent technically get enough sun to be able to accommodate solar panels.

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To sustainably power electronics by converting mechanical energy into electricity, energy storage is essential to supply a stable regulated electric output, something traditionally realized by a direct connection between the two components through a rectifier. Unfortunately, this may lead to low energy-storage efficiency. However, a new article in Nature Communications shows how to design a charging cycle to maximize energy-storage efficiency by modulating the charge flow in the system. This is demonstrated on a triboelectric nanogenerator TENG with a motion-triggered switch.  

IDTechEx notes that TENG harvesting was only invented five years ago and yet first commercial products using TENGs will be sold this year. The energy storage in a TENG circuit needs to be more efficient and even physically integrated to maximise market potential.   Theoretical and experimental comparisons have now verified that the new charging cycle can enhance the charging rate, improving maximum energy-storage efficiency by up to 50% and saturation voltage by at least a factor of two.  

One can now store the energy harvested by TENGs utilizing ambient mechanical energy, such as vibration, to drive portable, wearable and implantable electronics – all growing areas of activity. 

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Solar power is potentially the greatest single energy source outside of controlled nuclear fusion, but the Sun is literally a fair weather source that relies on daytime and clear skies. To make solar energy a reliable, 24-hour source of energy, a team of scientists at Sweden’s Chalmers University of Technology in Gothenburg is developing a liquid energy storage medium that can not only release energy from the Sun on demand, but is also transportable.

The Chalmers team has been working on variants of its system, called a MOlecular Solar Thermal (MOST), for over six years, with a conceptual demonstration in 2013. It differs from other attempts to store solar energy in things like heated salts and reversing exothermic reactions in that the MOST system stores the energy directly in the bonds of an organic chemical.

In this case, the scientists exposed a hydrocarbon called norbornadiene to light. This alters the chemical bonds, turning it into quadricyclane. Altering the temperature of the quadricyclane or exposing it to a catalyst reverses the effect and energy in the form of heat is released and carried off by a water jacket.

According to the team, the present system converts 1.1 percent of sunlight directly into chemical bonds, which is 100 times more efficient than the 2013 version that could only manage 0.01 percent. In addition, the new liquid storage system replaces ruthenium, a rare metal, with carbon-based elements that are much cheaper. Additionally, it can go through over 140 store and release energy cycles without noticeable degradation.

“The technique means that we can store the solar energy in chemical bonds and release the energy as heat whenever we need it.” says team leader Kasper Moth-Poulsen. “Combining the chemical energy storage with water heating solar panels enables a conversion of more than 80 percent of the incoming sunlight.”

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Scientists in China and the United States are working on a novel way to kill two birds with one stone: capturing carbon-dioxide pollution to use in an energy-storage system that can back up clean sources like solar and wind.

Compressed air is already employed in one of the cheapest forms of energy storage. When windmills are spinning and the sun is shining, excess energy is used to compress air that later, when the air is still and the sky dark, is blasted through turbines mixed with natural gas. But that method produces a lot of waste heat and its own carbon footprint.

Using CO2 in a different way could avoid those problems.

“Now, we have been thinking about how to use CO2 for energy storage,” Curtis M. Oldenberg, a senior scientist at Lawrence Berkeley National Laboratory, told me via email, “and came up with the idea of using it as the working fluid in a closed loop and having the gas spin a turbine without combustion.”

Working with colleagues at LBL and the North China Electric Power University in Beijing, Oldenburg proposed a system in which captured CO2 is compressed—when the wind is blowing or the sun is shining—to a supercritical fluid state and pumped into a reservoir in a deep saline aquifer. When there’s no wind or the sky is dark, the CO2 can be released to a more shallow, low-pressure reservoir. As it rushes from the high-pressure reservoir to the low-pressure reservoir, it spins a turbine, producing electricity.

Their model achieved higher energy-storage density than conventional compressed-air systems, the scientists contend in a paper they published last July in the journal Energy Conversion and Management.

Chinese scientists had already considered using CO2 to smooth the intermittency of Chinese wind farms. In 2015, scientists from Xi’an Jiaotong University published a performance analysis of a system using liquid carbon dioxide.

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Energy storage lies at the heart of grid digitisation and is part of a larger trend of technologies that is disrupting South Australia’s network for the better, according to Terry Teoh, General Manager of Engineering at ZEN Energy.

Ahead of his presentation on monetising storage at the grid edge in Adelaide’s CBD at the Australian Energy Storage Conference, June 14 – 15 2017 at the new International Convention Centre Sydney, Mr Teoh said battery storage currently has strong market potential in South Australia and the National Electricity Market (NEM).

“Energy storage and the ability to perform peer transactions lie at the heart of grid digitisation and will drive the democratisation of energy, just as we are seeing the democratisation of services, media and R&D,” Mr Teoh says.

“Global experience shows that commercial behind the meter storage is challenging. Yet the market potential in South Australia, and more broadly in the NEM states, is significant.”

Mr Teoh and Zen Energy are undertaking a groundbreaking project demonstrating real-time optimisation and monetisation of battery storage in the NEM by connecting four high-profile Adelaide CBD buildings to 513kWh of behind the meter storage.

The four sites – the Art Gallery, State Library, Adelaide High School and the Adelaide City Council works depot in Thebarton – were chosen for their contrasting load and occupancy patterns, and their potential to apply battery storage in conjunction with solar and demand response.

In his interview for the Australian Energy Storage Conference, Mr Teoh said the $1 million project will play a defining role in opening up the commercial storage market, starting in South Australia.

“It will provide real implementation experience and benefit quantification of batteries located in commercial sites, monetising multiple value streams,” he says.

“It will turn a theoretical concept into a commercially executable reality for commercial and industrial customers looking for a lifeline to alleviate their energy price distress in South Australia.”

Zen has also been working on other battery storage projects including the ‘Big Battery Project’ which proposes installing a battery in Port Augusta capable of storing between 50-150MWh of energy. This is one of the projects aiming to address South Australia’s grid instability and the need for a backup if power is lost.

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The University of Hawaii-Manoa Cancer Center and John A. Burns School of Medicine, adjacent facilities in Honolulu, have joined with Hawaiian Electric  on a demand-response demonstration project that uses battery energy storage to deliver power during periods of peak energy use, according to a March 21 report by Pacific Business News.

The two UH divisions are trying to save money manage electricity more efficiently by reducing or avoiding demand peaks. If the trial is successful, the knowledge gained from it also will help HECO to manage the grid more effectively.

Peter Rosegg, a HECO spokesperson, told PBN , “As with any ‘pilot,’ the plan is determined by how the project works. It is still being reviewed by engineers, so total cost and schedule are yet to be determined.” However, the project is anticipated to be completed about six months from the time of system installation.

Costs will be shared between the commercial energy storage vendor, Green Charge and Hawaiian Electric.”

, told PBN that project is scheduled to be completed six months from the time of installation.

“There is no cost to the university,” Miles Topping, director of Energy Management for UH, told the local business news outlet.

Demand response programs, which include offering lower and higher prices during certain times of the day through time-of-use rates, have become a high priority for Hawaiian Electric. Indeed, the utility plans to fully implement its demand-response programs, which include offering lower or higher prices during certain times of the day through time-of-use rates, by year-end 2017, it told PBN last October.

Traditionally, when demand for power fluctuates throughout the day, utilities have met that demand with generating units by adjusting the output or supply of power.

As variable renewable resources such as wind and solar increase, this technique has become more challenging to apply. The utility told PBN that, by offering lower or higher prices during certain times of the day, some demand-response programs could encourage customers to shift energy use to times when solar and wind produces the most power, which could optimize renewable sources that otherwise might be wasted.

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Time is running out for stakeholders offering comments to Washington’s Utilities and Transportation Commission (WUTC) on its draft policy statement regarding how energy storage is treated by investor-owned utilities’ (IOUs) in their integrated resource planning (IRP).  

The commission issued its draft document at the beginning of this month as part of a lengthy undertaking to evaluate the potential roles of mostly large-scale in front of meter energy storage in utility networks which began in May 2015.

Investor-owned utilities in the US offer up integrated resource plans to their regional regulators which outline and explain how they are preparing to meet forecasted peak and energy demand over the coming year.

The WUTC said that following a 2015 whitepaper and subsequent workshop events it had concluded that advances in energy storage and the need for decarbonisation and modernisation of networks meant the technologies had a likely role in IRP going forward. The commission determined to offer guidance for utilities to follow, leading to the latest draft policy. Respondents have until 3 April this year to respond to the 17-page WUTC policy document.

“The Commission releases this draft policy statement for comment, and requests responses from interested persons to assist the Commission in developing a final policy statement that provides useful guidance to investor-owned utilities (IOUs), vendors seeking to promote energy storage for use by IOUs, and those interested in the use of energy storage on electric distribution systems,” the draft said.

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HOW much power does a tweetstorm involving two tech tycoons, the prime minister of Australia and 8.5m Twitter followers generate? Enough, at least, to supercharge a debate about the future role of batteries in the world’s energy mix.

Elon Musk, a Silicon Valley entrepreneur (pictured), may be best known for his gravity-defying ambition, but his core product is the battery: whether for his Tesla cars, for the home or for grid-scale electricity storage. He gave the last of these an unexpected jolt of publicity on March 10th, by responding to a blackout-inspired challenge on Twitter from an Australian software billionaire, Mike Cannon-Brookes. Mr Musk said he could install 100 megawatt hours (MWh) of battery storage in the state of South Australia in 100 days to help solve an energy crisis it faces, or it would be free of charge. “That serious enough for you?” he asked.

In response, Malcolm Turnbull, the prime minister, communicated with Mr Musk and appeared to turn from pro-coal sceptic into battery believer. On March 14th Jay Weatherill, the premier of South Australia, went further. Declaring that the national electricity market was “broken”, he said the state would launch its own A$550m ($415m) plan to build a 100MW battery system, as well as a gas-fired power station, with public funds. Mr Musk may have got what he wanted. He is “good at bringing nerdy subjects to a broad audience”, says Julia Attwood of Bloomberg New Energy Finance.

Are batteries now cheap enough to be a cost-effective way of solving energy crises like that in southern Australia, brought on since July by storms, heatwaves, the intermittency of solar and wind power and the closure of coal- and gas-fired power stations? The answer, says Michael Ottaviano of Carnegie Clean Energy, which is hoping to sell its own grid-scale battery systems to the state, is “no”—especially under current market structures.

True, battery prices have plummeted and Mr Musk’s price, of about $250 per kilowatt hour (kWh), is relatively cheap. But the total cost (including building the plant, for example) would be about $500 per kWh to hook the batteries up to the grid. A 100MWh facility would cost $50m. Only when power prices reach stratospheric levels would that investment make sense for a utility. That’s why the government of South Australia is having to stump up instead. Eventually, practitioners hope that changes to the power market will make battery storage viable without public funding. “This is a short-term Band-Aid until the regulatory process catches up,” Mr Ottaviano says.

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