Renewable Energy

Utilities are starting to invest in big batteries instead of building new power plants

By Jeremiah Johnson and Joseph F. Decarolis
View the original article here.

This is what a 5-megawatt, lithium-ion energy storage system looks like. Credit: Pacific Northwest National Laboratory

This is what a 5-megawatt, lithium-ion energy storage system looks like. Credit: Pacific Northwest National Laboratory

Due to their decreasing costs, lithium-ion batteries now dominate a range of applications including electric vehicles, computers and consumer electronics.

You might only think about energy storagewhen your laptop or cellphone are running out of juice, but utilities can plug bigger versions into the electric grid. And thanks to rapidly declining lithium-ion battery prices, using energy storage to stretch electricity generation capacity.

Based on our research on energy storage costs and performance in North Carolina, and our analysis of the potential role energy storage could play within the coming years, we believe that utilities should prepare for the advent of cheap grid-scale batteries and develop flexible, long-term plans that will save consumers money.

Peak demand is pricey

The amount of electricity consumers use varies according to the time of day and between weekdays and weekends, as well as seasonally and annually as everyone goes about their business.

Those variations can be huge.

For example, the times when consumers use the most electricity in many regions is nearly double the average amount of power they typically consume. Utilities often meet peak demand by building power plants that run on natural gas, due to their lower construction costs and ability to operate when they are needed.

All of the new utility-scale electricity capacity coming online in the U.S. in 2019 will be generated through natural gas, wind and solar power as coal, nuclear and some gas plants close. Credit: U.S. Energy Information Administration

All of the new utility-scale electricity capacity coming online in the U.S. in 2019 will be generated through natural gas, wind and solar power as coal, nuclear and some gas plants close. Credit: U.S. Energy Information Administration

However, it’s expensive and inefficient to build these power plants just to meet demand in those peak hours. It’s like purchasing a large van that you will only use for the three days a year when your brother and his three kids visit.

The grid requires power supplied right when it is needed, and usage varies considerably throughout the day. When grid-connected batteries help supply enough electricity to meet demand, utilities don’t have to build as many power plants and transmission lines.

Given how long this infrastructure lasts and how rapidly battery costs are dropping, utilities now face new long-term planning challenges.

Cheaper batteries

About half of the new generation capacity built in the U.S. annually since 2014 has come from solar, wind or other renewable sources. Natural gas plants make up the much of the rest but in the future, that industry may need to compete with energy storage for market share.

In practice, we can see how the pace of natural gas-fired power plant construction might slow down in response to this new alternative.

Grid-scale batteries are being installed coast-to-coast as this snapshot from 2017 indicates. Credit: U.S. Energy Information Administration, U.S. Battery Storage Market Trends, 2018.

Grid-scale batteries are being installed coast-to-coast as this snapshot from 2017 indicates. Credit: U.S. Energy Information Administration, U.S. Battery Storage Market Trends, 2018.

So far, utilities have only installed the equivalent of one or two traditional power plants in grid-scale lithium-ion battery projects, all since 2015. But across California, Texas, the Midwest and New England, these devices are benefiting the overall grid by improving operations and bridging gaps when consumers need more power than usual.

Based on our own experience tracking lithium-ion battery costs, we see the potential for these batteries to be deployed at a far larger scale and disrupt the energy business.

When we were given approximately one year to conduct a study on the benefits and costs of energy storage in North Carolina, keeping up with the pace of technological advances and increasing affordability was a struggle.

Projected battery costs changed so significantly from the beginning to the end of our project that we found ourselves rushing at the end to update our analysis.

Once utilities can easily take advantage of these huge batteries, they will not need as much new power-generation capacity to meet peak demand.

Credit: The Conversation

Credit: The Conversation

Utility planning

Even before batteries could be used for large-scale energy storage, it was hard for utilities to make long-term plans due to uncertainty about what to expect in the future.

For example, most energy experts did not anticipate the dramatic decline in natural gas prices due to the spread of hydraulic fracturing, or fracking, starting about a decade ago – or the incentive that it would provide utilities to phase out coal-fired power plants.

In recent years, solar energy and wind power costs have dropped far faster than expected, also displacing coal – and in some cases natural gas – as a source of energy for electricity generation.

Something we learned during our storage study is illustrative.

We found that lithium ion batteries at 2019 prices were a bit too expensive in North Carolina to compete with natural gas peaker plants – the natural gas plants used occasionally when electricity demand spikes. However, when we modeled projected 2030 battery prices, energy storage proved to be the more cost-effective option.

Credit: The Conversation

Credit: The Conversation

Federal, state and even some local policies are another wild card. For example, Democratic lawmakers have outlined the Green New Deal, an ambitious plan that could rapidly address climate change and income inequality at the same time.

And no matter what happens in Congress, the increasingly frequent bouts of extreme weather hitting the U.S. are also expensive for utilities. Droughts reduce hydropower output and heatwaves make electricity usage spike.

The future

Several utilities are already investing in energy storage.

California utility Pacific Gas & Electric, for example, got permission from regulators to build a massive 567.5 megawatt energy-storage battery system near San Francisco, although the utility’s bankruptcy could complicate the project.

Hawaiian Electric Company is seeking approval for projects that would establish several hundred megawatts of energy storage across the islands. And Arizona Public Service and Puerto Rico Electric Power Authority are looking into storage options as well.

We believe these and other decisions will reverberate for decades to come.If utilities miscalculate and spend billions on power plants it turns out they won’t need instead of investing in energy storage, their customers could pay more than they should to keep the lights through the middle of this century.

The United States is headed for a battery breakthrough

By Tim Sylvia
View the original article here.

A new report by the Energy Information Administration projects U.S. installed battery storage capacity will reach 2.5 GW by 2023. Florida and New York are set to pave the way as massive projects in each state will account for almost half the coming capacity.

Storage is ready to take off in a big way. Image: Tesla

Storage is ready to take off in a big way. Image: Tesla

Symbiosis is one of life’s most beautiful phenomena. Certain things just work perfectly together and the energy revolution is no different, as renewable energy resources and battery storage go together like peas in a pod.

However, the United States has an operating battery storage capacity of only 899 MW to date. And while that figure is expected to reach 1 GW this year that would still only represent 1/67th of the nation’s cumulative solar generation capacity, and an even smaller percentage of the overall renewables capacity.

That could all be about to change dramatically though, as the U.S. Energy Information Administration(EIA) has released a report predicting battery storage capacity will almost treble by 2023, to 2.5 GW.

Past, current and predicted U.S. battery storage capacity levels. Image: EIA

Past, current and predicted U.S. battery storage capacity levels. Image: EIA

 

The projections were made based on proposed utility scale battery storage projects scheduled for initial commercial operation within five years. The EIA tracks data with its Preliminary Monthly Electric Generator Inventory survey, which updates the status of projects scheduled to come online within 12 months.

As drastic as a prediction of 2.5 GW appears, there is a precedent. Between late 2014 and March, installed battery storage capacity rose more than four times over, from 214 to 889 MW.

A look at the states that brought the U.S. to its current storage reality offers surprising results. Leading the way was California, unsurprisingly. However, of the six states known to pv magazine to have energy storage mandates, California is the only one in the top 10 for installed capacity. The others: Arizona, Nevada, New York, Massachusetts and Oregon; each have less than 50 MW of installed battery storage capacity.

The top 10 states in terms of current installed battery storage capacity. Image: EIA

The top 10 states in terms of current installed battery storage capacity. Image: EIA

Texas, Illinois and Hawaii are relatively unsurprising storage pioneers as all three states have strong solar industries and Hawaii especially has been pushing battery storage deployment. Right away, however, the names that stand out on the list are West Virginia, Pennsylvania and Ohio. None of those is known as a solar pioneer; they have just under 650 MW of generation capacity installed between them. Special recognition goes to West Virginia on that score, with its 8.5 MW.

So what’s with all the storage? Independent of renewables West Virginia, Pennsylvania and Ohio – plus New Jersey, the seventh state on the list – are all members of the PJM Interconnection. PJM was the first large market for battery storage, and uses the technology for frequency regulation.

That list is likely to look different by 2023, however. Of the 1,623 MW expected to come online by 2024, 725 MW will come courtesy of two projects – both in states outside the current top 10.

Two mammoth projects

The first of those is Florida Power and Light’s (FPL) planned battery system for its Manatee Solar Energy Center in Parrish. The battery is set to clock in at 409 MW, which would make it the largest solar powered battery system in the world.

In that project’s shadow, but nevertheless considerable is the Helix Ravenswood facility, planned in Queens, New York. Almost more impressive than the project’s anticipated 316 MW of capacity is the idea of having a storage project of such magnitude in NYC.

FPL’s Manatee battery is anticipated to begin commercial operation in 2021, as is the first stage of Helix Ravenswood. That initial phase in New York will represent 129 MW of capacity, with the remaining 187 MW following via a 98 MW second phase and 89 MW final stage. The anticipated commercial operation dates of those expansions have not yet been announced.

We have seen the future and there are batteries, lots of them, demonstrating symbiosis extends beyond the natural world.

Israel Completes World‘s Largest Solar & Thermal Electric Facility

By David Lazarus
View the original article here.

The state-of-the-art thermal electric power plant in Israel’s Negev Desert is equipped with more than 50,000 computer-controlled heliostats that produce enough power for 150,000 homes, keeping 110,000 tons of CO2 emissions out of the air per year.

The Ashalim solar and thermal electric power plant in Israel’s Negev Desert is up and running. The state-of-the-art facility is equipped with more than 50,000 computer-controlled heliostats or mirrors, which can track the sun in two dimensions and reflect the sunlight onto a boiler placed on top of a tower measuring 240 m-high (787.4 ft). That’s higher than some of the tallest sky scrapers in the world and by far the tallest solar tower ever built.

How does it work? All those tens of thousands of mirrors are hooked up to a computer operated tracking system so that they all move precisely with the orbit of the earth around the sun throughout the day and direct the heat from the sunlight to a spot on the boiler on top of the tower to within 0.0015499969 of an inch. The super hot water in the boiler produces superheated steam, which is then conveyed through pipes down below with enough pressure to spin a steam turbine-generator at astronomical speeds needed to produce electricity. The solar run generator can put out 300 megawatts of clean electricity every day, or enough to power about 150,000 homes.

Ashalim construction in 2016 – BrightSource Energy website

Ashalim construction in 2016 – BrightSource Energy website

Another feature of the Ashalim project is the use of solar thermal technology that can store energy for use at night in order to provide consistent and reliable output of electricity. This is one of the largest renewable energy projects in the world. The facility covers an area of over 3 sq. km (2 sq. miles).

Israel’s climate is ideal for solar power, particularly in the Negev which enjoys more than 300 sunny days a year. Israel has been home to many solar technology breakthroughs, but the government has been slow in getting away from using fossil fuels for power. But that is definitely starting to change with a goal getting 10 percent of its energy needs from renewable sources by 2020 with the new solar project. Once the project is proven fully successful, Israel plans to move ahead rapidly towards renewable energy sources.

Together with the recent discovery of huge deposits of natural gas along Israel’s Mediterranean Coast, the Ashalim plant will contribute to Israel’s security by reducing dependence on fossil fuel imports. It will also keep us safe by keeping 110,000 tons of CO2 emissions per year out of the air we breathe.

Solar Energy Isn’t Just for Electricity

It can also provide carbon-free heat for a wide variety of industrial processes

By Steven Moss
View the original article here.

Part of the Miraah soler thermal project in Oman. Credit: GlassPoint Solar

Part of the Miraah soler thermal project in Oman. Credit: GlassPoint Solar

The industrial processes that underpin our global economy—manufacturing, fuel and chemical production, mining—are enormously complex and diverse. But they share one key input: they, as well as many others, require heat, and lots of it, which takes staggering amounts of fuel to produce. Heat and steam generation is critical to the global economy, but it’s also an overlooked and growing source of greenhouse gas (GHG) emissions.

The good news is that innovative solar technologies can produce steam at industrial scale—reducing emissions and, increasingly, cutting costs. And given the current climate outlook, it’s urgent that industry adopt these new technologies.

Despite enormous progress around the world to ramp up renewables and increase energy efficiency, global GHG emissions reached an all-time highin 2018. In a report released in January, the Rhodium Group found that even though renewable energy installations soared and coal plants shut down, carbon emissions in the U.S. rose sharply last year. Emissions from industry shot up 5.7 percent—more than in any other sector, including transportation and power generation. The authors of the Rhodium Group study concluded that despite increased efforts from policymakers and the business to tackle emissions, “the industrial sector is still almost entirely ignored.”

This must change, at the global level. Worldwide industry is responsible for a quarter of total emissions. And while those from transportation and residential segments are trending down, the International Energy Agency (IEA) projects that industrial emissions will grow some 24 percent by 2050.

As people around the world continue to transition from living off the land to moving to cities and buying and consuming more things, industrial activity will continue to increase—and the need to reduce corresponding emissions will become all the more urgent.

Credit: GlassPoint Solar

Credit: GlassPoint Solar

This brings us back to heat. Industry is the largest consumer of energy, and a surprising 74 percent of industrial energy is in the form of heat, mostly process steam. Solar steam—making the sun’s heat work for industry—is a largely unexplored but promising avenue for reducing emissions.

While photovoltaic (PV) panels that convert sunlight into electricity are more common, thermal solutions are what’s needed to meet industry’s growing demand for heat. In a solar thermal system, mirrors focus sunlight to intensify its heat and produce steam at the high temperatures needed for industry. Another key advantage is the ability to store the heat using simple, proven thermal energy storage in order to deliver steam 24 hours a day, just like a conventional fossil fuel plant. With the right technology, solar thermal can be a reliable, efficient and low-cost energy source for industrial steam generation.

So-called "enclosed trough technology" uses sunshine to produce zero-carbon steam. Credit: GlassPoint Solar.

So-called “enclosed trough technology” uses sunshine to produce zero-carbon steam. Credit: GlassPoint Solar.

For example, renewable process heat provider Sunvapor is partneringwith Horizon Nut to build a 50-kilowatt solar thermal installation at a pistachio processing facility in the Central Valley of California. The companies are working to expand solar steam production for food industry processes, such as pasteurization, drying and roasting.

In Oman and California, GlassPoint Solar is operating and developing some of the world’s largest solar projects for industry. GlassPoint’s greenhouse-enclosed mirrors track the sun throughout the day, focusing heat on pipes containing water. The concentrated sunlight boils the water to generate steam, which is used by Oman’s largest oil producer to extract oil from the ground. The capacity of GlassPoint’s Miraah plant, which can currently deliver 660 metric tons of steam every day, will top 1 gigawatt of solar thermal energy when completed. This same technology is also being deployed in California to reduce emissions from one of the country’s largest and oldest operating oilfields.

Meanwhile, to meet the needs of extremely high-temperature (800-1,000degreesC) industrial processes, the European Union is developing SOLPART, a research project to develop solar thermal energy that can be used to produce cement, lime and gypsum.

While fossil fuels remain the dominant source of heat for industry across all sectors and regions, industry is beginning to explore cleaner alternatives—and in some cases, industry is leveraging solar steam on a significant scale. As technology advances, more and more companies will find that switching to solar steam can simultaneously reduce costs and emissions, improving business operations while shrinking its carbon footprint.

When it comes to mitigating climate change, most attention has been directed to the things we see, buy, or use on a daily basis—the cars we drive, the food we eat, the power plants that keep our lights on. But behind all these activities is process heat, an emissions source that has been largely ignored.

Now we must turn our attention to industry—the sleeping giant of climate action. Process heat is an overlooked opportunity to slash GHG emissions, and solar technologies operating at the scale needed by industry are currently available. It’s time to embrace them and stop industrial heat from heating up our planet.

The Price of Large-Scale Solar Keeps Dropping

JOHN ROGERS, SENIOR ENERGY ANALYST, CLEAN ENERGY | SEPTEMBER 13, 2018, 11:49 AM EST
View the original article here.

PV modules at the Kerman site near Fresno, California
The latest annual report on large-scale solar in the U.S. shows that prices continue to drop. Solar keeps becoming more irresistible.

The report, from Lawrence Berkeley National Laboratory (LBNL) and the US Department of Energy’s Solar Energy Technologies Office, is the sixth annual release about the progress of “utility-scale” solar. For these purposes, they generally define “utility-scale” as at least 5 megawatts (three orders of magnitude larger than a typical residential rooftop solar system). And “solar” means mostly photovoltaic (PV), not concentrating solar power (CSP), since PV is where most of the action is these days.

Here’s what the spread of large-scale solar looks like:

Solar Drop 2

In all, 33 states had solar in the 5-MW-and-up range in 2017—four more than had it at the end of 2016. [For a cool look at how that map has changed over time, 2010 to 2017, check out this LBNL graphic on PV additions.]

Watch for falling prices

Fueling—and being fueled by—that growth are the reductions in costs for large-scale projects. Here’s a look at power purchase agreements (PPAs), long-term agreements for selling/buying power from particular projects, over the last dozen years:

Solar Drop 3

And here’s a zoom-in on the last few years, broken out by region:

Solar Drop 4

While those graphs show single, “levelized” prices, PPAs are long-term agreements, and what happens over the terms of the agreements is worth considering. One of the great things about solar and other fuel-free electricity options is that developers can have a really good long-term perspective on future costs: no fuel = no fuel-induced cost variability. That means they can offer steady prices out as far as the customer eye can see.

And, says LBNL, solar developers have indeed done that:

Roughly two-thirds of the contracts in the PPA sample feature pricing that does not escalate in nominal dollars over the life of the contract—which means that pricing actually declines over time in real dollar terms.

Imagine that: cheaper over time. Trying that with a natural gas power plant would be a good way to end up on the losing side of the contract—or to never get the project financed in the first place.

Here’s what that fuel-free solar steadiness can get you over time, in real terms:

Solar Drop 5

What’s behind the PPA prices

So where might those PPA price trends be coming from? Here are some of the factors to consider:

Equipment costs. Solar equipment costs less than it used to—a lot less. PPAs are expressed in cost per unit of electricity (dollars per megawatt-hour, or MWh, say), but solar panels are sold based on cost per unit of capacity ($ per watt). And that particular measure for project prices as a whole also shows impressive progress. Prices dropped 15% just from 2016 to 2017, and were down 60% from 2010 levels.

Solar Drop 6

The federal investment tax credit (30%) is a factor in how cheap solar is, and has helped propel the incredible increases in scale that have helped bring down costs. But since that ITC has been in the picture over that whole period, it’s not directly a factor in the price drop.

Project economies of scale. Bigger projects should be cheaper, right? Surprisingly, LBNL’s analysis suggests that, even if projects are getting larger (which isn’t clear from the data), economies of scale aren’t a big factor, once you get above a certain size. Permitting and other challenges at the larger scale, they suggest, “may outweigh any benefits from economies of scale in terms of the effect on the PPA price.”

Solar resource. Having more of the solar happen in sunnier places would explain the price drop—more sun means more electrons per solar panel—but sunnier climes are not where large-scale solar’s growth has taken it. While a lot of the growth has been in California and the Southwest, LBNL says, “large-scale PV projects have been increasingly deployed in less-sunny areas as well.” In fact:

In 2017, for the first time in the history of the U.S. market, the rest of the country (outside of California and the Southwest) accounted for the lion’s share—70%—of all new utility-scale PV capacity additions.

The Southeast, though late to the solar party, has embraced it in a big way, and accounted for 40% of new large-scale solar in 2017. Texas solar was another 17%.

But Idaho and Oregon were also notable, and Michigan was one of the four new states (along with Mississippi, Missouri, and Oklahoma) in the large-scale solar club. (And, as a former resident of the great state of Michigan, I can attest that the skies aren’t always blue there—even if it actually has more solar power ability than you might think.)

Capacity factors. More sun isn’t the only way to get more electrons. Projects these days are increasingly likely to use solar trackers, which let the solar panels tilt face the sun directly over the course of the day; 80% of the new capacity in 2017 used tracking, says LBNL. Thanks to those trackers, capacity factors themselves have remained steady in recent years even with the growth in less-sunny locales.

What to watch for

This report looks at large-scale solar’s progress through the early part of 2018. But here are a few things to consider as we travel through the rest of 2018, and beyond:

  • The Trump solar tariffs, which could be expected to raise costs for solar developers, wouldn’t have kicked in in time to show up in this analysis (though anticipation of presidential action did stir things up even before the tariff hammer came down). Whether that signal will clearly show in later data will depend on how much solar product got into the U.S. ahead of the tariffs. Some changes in China’s solar policies are likely to depress panel prices, too.
  • The wholesale value of large-scale solar declines as more solar comes online in a given region (a lot of solar in the middle of the day means each MWh isn’t worth as much). That’s mostly an issue only in California at this point, but something to watch as other states get up to high levels of solar penetration.
  • The investment tax credit, because of a 2015 extension and some favorable IRS guidance, will be available to most projects that get installed by 2023 (even with a scheduled phase-down). Even then it’ll drop down to 10% for large-scale projects, not go away completely.
  • Then there’s energy storage. While the new report doesn’t focus on the solar+storage approach, that second graphic above handily points out the contracts that include batteries. And the authors note that adding batteries doesn’t knock things completely out of whack (“The incremental cost of storage does not seem prohibitive.”).

And, if my math is correct, having 33 states with large-scale solar leaves 17 without. So another thing to watch is who’s next, and where else growth will happen.

Many of the missing states are in the Great Plains, where the wind resource means customers have another fabulous renewable energy option to draw on. But solar makes a great complement to wind. And the wind-related tax credit is phasing out more quickly than the solar ITC, meaning the relative economics will shift in solar’s favor.

Meanwhile, play around with the visualizations connected with the new release (available at the bottom of the report’s landing page), on solar capacity, generation, prices, and more, and revel in solar’s progress.

Large-scale solar is an increasingly important piece of how we’re decarbonizing our economy, and the information in this new report is a solid testament to that piece of the clean energy revolution.

Eggshells May Power The Renewable Energy Revolution

View the original article here.

Ready for some happy news among all the gloom surrounding government shutdowns, border security, and malfeasance in high places? Here’s something that may put a smile on your face. According to researchers in Western Australia, eggshells may be the key to abundant, inexpensive energy storage.
Eggshell_001

Dr Manickam Minakshi and his colleagues began experimenting with eggshells in 2017 using eggs purchased at the local supermarket. “Eggshells have a high level of calcium carbonate, which can act as a form of replenishing energy,” he tells the Canberra Times.

“What’s interesting is that the egg membrane around the yolk allowed us to cook it at a high temperature, crush it into powder and bake it at 500 degrees Celsius with the chemical still present.The final baking process changes the chemical composition from calcium carbonate to calcium oxide and allows it to become a conduit for electricity.

For Dr Minakshi’s team, this represents a first step towards work on an alternative battery to store energy from renewable energies such as solar panels and wind turbines. “Renewable energy resources are intermittent as they depend on the weather,” he says. “When we have an excess, we need a battery to store it. Ground egg shells serve as the electrode to store this.” Before being heated, the eggshell is a positive electrode but when heated it changes to be a negative electrode, he explains.

Dr Minakshi says he hopes his research will attract the attention of renewable energy companies. Assuming further tests prove the validity of his preliminary results, abundant and affordable materials like eggshells have the potential to provide energy storage from items that would otherwise be little more than bio-waste.

“You can buy them at a 12-pack from Coles for $4 or pick them up from the food court,” he says. “What’s even more important is that you can use the eggshells that are thrown into landfills. This brings in the potential to reduce the amount of bio-waste we produce.”

The research in the laboratory will continue to determine how much electricity the eggshell powder can store and for how long. Minakshi even has plans to test free range eggshells to see if they have better conductive properties, although why that would be is not clear. Perhaps free range chickens have higher levels of self esteem which lead to chemical changes in their eggs.

If anyone can peck out the answers, it is Dr. Manakshi, who may or may not have watched the adventures of Henry Cabot Henhouse III — a/k/a Super Chicken — as a boy. (There is a slight possibility I am not treating this topic with the seriousness is deserves.)

Warren Buffet’s MidAmerican Energy puts in Iowa’s latest big battery project

Grand Ridge, an existing Invenergy project that combines wind power and energy storage, in Illinois. Image: Invenergy.

Grand Ridge, an existing Invenergy project that combines wind power and energy storage, in Illinois. Image: Invenergy.

View the original article here.
The US state of Iowa got its first grid-scale solar-plus-storage system at the beginning of this year, and this has already been followed by the completion of another, larger battery project in the US state this week.

Energy-Storage.news reported last week on the completion of a solar PV system at Maharishi University of Management equipped not only with solar trackers but also with a 1.05MWh flow battery.

This week, project developer Invenergy said a four month “construction sprint” had been successfully undertaken and the company has begun commercial operations of a 1MW / 4MWh lithium iron phosphate battery energy storage system.

Located at a substation in Knoxville, Iowa, the project has been executed for utility MidAmerican Energy, one of billionaire investor Warren Buffet’s companies as a subsidiary of Berkshire Hathaway Energy. MidAmerican serves just under 800,000 electricity customers.

In a November press release, MidAmerican’s VP of resource development said the utility-scale storage system would teach lessons about “how best to use an energy storage system, and how it can serve our customers in the future,” adding that the primary purpose of the system will be to help manage peak loads on the utility’s network.

“Energy storage has the potential to allow us to retain energy when customer demand is low and release it during peak usage times. That would give us new options to manage peak loads, enhance overall reliability and help keep electric costs low and affordable for our customers,” Mike Fehr of MidAmerican Energy said.

The utility highlighted four of the main benefits of energy storage that it will explore through the application of the lithium system: flattening and managing peaks in electricity demand through storing off-peak energy for later use, reducing the required run times and capacities of natural gas peaker plants with energy storage, enhancing the value and usefulness of renewable energy through smoothing the output of solar farms before it enters the grid and improving power quality and extending the life of transformers and other grid infrastructure.

“Energy storage is still in the development stages and the economic feasibility on a larger scale is being assessed as well; however, prices are trending downward,” Mike Fehr said.

“MidAmerican Energy wants first-hand experience with the technology so we’re positioned to quickly and efficiently add it to our system in ways that benefit our customers when the price is right.”

For Invenergy, which already owns and operates four other large-scale battery systems it developed, this has been its first project as an EPC (engineering, procurement and construction) partner.

“We are excited by the new opportunities for battery storage that we are seeing around the country. We are grateful for partners like MidAmerican Energy who are seeking innovative ways to deliver value to their customers and are proud to have provided them with this solution in such a short time,” Invenergy senior VP Kris Zadlo said.

Siemens Gamesa Pursues Hybrid Wind and Solar Projects With Energy Storage

The company confirms hybrid systems are a growing focus area.

By Jason Deign
View the original article here.

Siemens Gamesa Pursues Hybrid Wind and Solar Projects With Energy Storage

Siemens Gamesa Pursues Hybrid Wind and Solar Projects With Energy Storage

Siemens Gamesa, the leading turbine manufacturer, is looking to go beyond wind — into hybrid systems with solar and storage.

The company’s chief technology officer, Antonio de la Torre Quiralte, told GTM that Siemens Gamesa remains committed to the wind market. However, it is increasingly interested in other technologies to reduce renewable energy intermittency.

“Following the merger about one year ago, we realized that our two former companies were quite interested in resolving the renewable problem, which is discontinuity,” he said.

“As part of our business strategy, there is a clear mandate from our CEO and our board that we will resolve, with a huge investment in new technologies, solutions for the market that will allow, quite soon, stable renewable procurement of energy.”

The development of systems that can provide baseload or near-baseload capacity could involve the hybridization of potentially complementary generation technologies such as wind and solar. But storage is a big part of the equation.

“It definitely is in our roadmap,” de la Torre said.

De la Torre said the manufacturer is focused on solutions rather than products, integrating energy storage with renewable plants at the project level.

He also said Siemens Gamesa is looking beyond today’s existing utility-scale battery storage capacities, which typically run to tens of megawatt hours, to gigawatt-hour levels of storage.

Batteries will remain the company’s technology of choice for standalone hybrid and off-grid systems, which demand storage capacities of between 500 kilowatt-hours and 50 megawatt-hours for onshore wind and PV plant balancing.

But Siemens Gamesa is also investigating a thermal storage system called the Future Energy Solution, which could boast much higher capacities. A demonstration plant currently under construction in Hamburg will be able to deliver 1.5 megawatts of power for 24 hours.

Siemens Gamesa hopes to use this kind of technology for round-the-clock renewable energy generation. “We have to integrate several renewable sources,” said de la Torre. “Currently we are investigating all relevant sorts of storage.”

Recently, for example, Siemens Gamesa started testing a 120-kilowatt, 400-kilowatt-hour redox flow battery at its La Plana test center near Zaragoza in Spain.

The test center had previously been used by Gamesa to put together a hybrid system combining traditional gensets with wind, solar and storage in 2016. Customer interest in hybrid systems with storage has grown in the last six to nine months, de la Torre said.

One example is the Bulgana Green Power Hub project owned by Neoen in Australia, where Siemens Gamesa will be acting as an engineering, procurement and construction contractor, and will be integrating a 194-megawatt wind farm with 34 megawatt-hours of Tesla storage.

Hong Zhang Durandal, a business analyst with MAKE Consulting, said Siemens Gamesa’s growing interest in hybrid systems reflects a wider trend within the wind industry. OEMs are not interested in having storage as a product, he said, but see value in adding other technologies to wind farms, for example to help avoid curtailment or smooth out imbalances.

It also makes sense for Siemens Gamesa to explore thermal or redox flow technologies for bulk, long-duration storage, he said. “For lithium-ion, getting to gigawatt-hours is just cost-ineffective,” he said. “It’s too large a system to justify the cost of the batteries.”

In a recent question-and-answer session published by Wood Mackenzie, Durandal said wind-plus-storage could offer new opportunities for energy production in the U.S.

“Wind farms paired with energy storage can shift energy from periods of low prices to take advantage of spikes and shift energy in bulk when it is most needed,” he said.

Pairing wind with energy storage also helps with ramp-rate control, can avoid curtailment and could open the door for project owners to compete for ancillary services revenues.

“We are seeing increased interest by wind turbine OEMs across the globe in exploring and developing utility-scale wind-plus-storage systems,” Durandal said. “Not only can the development of such systems strengthen the portfolio of the OEMs in key markets, [but] hybrid systems can also play a significant role in the deployment of more wind energy in the future.”

How Energy Storage Can Limit the Impact of Extreme Weather

John Jung, President & CEO, Greensmith Energy
View the original article here.

energy storage weather

Photo Credit: Howard Scott

Last month, the National Hurricane Center reported that Hurricane Maria, the sixth fastest hurricane on record, caused an estimated $90 billion in damage in Puerto Rico and the U.S. Virgin Islands. This would make it the third costliest hurricane in history, following Katrina and Harvey.

Now seven months later, there are still parts of Puerto Rico that are still without power. I can only imagine how this prolonged outage is making relief and recovery efforts difficult.

For those of us in the energy business, we see a better pathway for communities to avoid prolonged outages that hinder relief and recovery efforts.

One solution – already in the marketplace and in use around the world – is the combination of energy storage and islanded grid systems.

Islanded systems, also known as microgrids, can operate with or without a connection to grid. When you add energy storage, communities benefit from a more flexible, versatile distributed energy resource.

What exactly does that mean?

Traditional grid operators, without adequate energy storage, follow conservative limits on the deployment of distributed energy resources to maintain reliability.

Energy storage enables integration of more renewable energy sources so that grid systems can better respond to dynamic fluctuations in electricity consumption, and lessen greenhouse gas emissions. As solar, wind and hydro become the world’s main energy sources, renewables are no longer an incremental component in energy production.

And, renewable energy costs are the lowest ever. So, with islanding and storage combined, microgrids can safely lift limits on renewables, bringing a substantial benefit in places where electricity prices exceed the cost of electricity for renewables.

The Graciosa Hybrid Renewable Power Plant, located on the island of Graciosa in the northern part of the Azores, an autonomous region of Portugal, is a recent example of a Greensmith microgrid project that will combine solar and wind generation, together with energy storage using lithium-ion batteries. When completed, the Graciosa plant will enable 1 MW of solar and 4.5 MW of wind power to be supplied to the grid, reducing the region’s reliance on imported fossil fuels and significantly reducing GHG emissions.

Credit: Howard Scott

Credit: Howard Scott

Beyond the advanced energy storage technology Greensmith is known for, we help a growing number of power companies and developers integrate and maximize a diverse mix of grid resources using our industry-leading GEMS software platform. Our suite of proven grid-scale and microgrid energy storage solutions delivers renewables integration, reliability and resilience. In fact, more than one-third of all energy storage capacity installed in the United States is running on Greensmith’s GEMS software platform, which provides full visibility into a grid system operation and can pinpoint and isolate any malfunctions.

Faster response time means a greater chance of avoiding power outages. And, as we have seen in Puerto Rico, and the bomb cyclones that hit the northeast in March, extreme weather events were happening much more frequently across the country and the world.

The frequency of natural disasters is an important reason that more of us should look at energy storage and microgrids as a necessary infrastructure improvement for customers and utilities.

It’s clear that, while microgrids are complex systems, when deployed with energy storage solutions, they are essential to the evolution of our power grid.

Mapping the Boom in Global Solar Power

By Molly Lempriere
View the original article here.

Solar power is growing faster than any other renewable energy in the world, according to new research by the IEA. But where in the world is the technology booming the most?

Solar is growing at speed in several states, including Utah, Arizona, and Nevada, and looks set to continue this trend through this year and beyond.

Solar is growing at speed in several states, including Utah, Arizona, and Nevada, and looks set to continue this trend through this year and beyond.