South Texas utility El Paso Electric Co. (EPE) has selected more than 600 MW of new generation capacity to help meet summer peak loads more than three years ahead.

EPE announced this week that it plans to add multiple cleaner emitting sources for capacity needed during the 2022-2023 summer peak season. The winning bids include expected purchases of 200 MW in utility-scale solar, 100 MW of battery storage and the construction of a 226-MW natural gas-fired combustion turbine unit at EPE’s Newman Power Station.

The $143 million Newman turbine addition is expected to be operational by 2023. In addition, EPE will seek another 50 to 150 MW of wind and solar power.

Kipp

“These technologies provide a mix of carbon-free renewable and clean burning natural gas generation that will enable us to meet the growing need for power in our region in a safe, clean, reliable, and cost-effective manner,” said Mary Kipp, El Paso Electric President and Chief Executive Officer. “This balanced combination of resources will work with our existing energy portfolio as we move to retire aging, less efficient plants while continuing to meet our customers’ changing energy needs.”

The El Paso utility, which serves some 425,000 customers in south Texas, reached coal-free generation status two years ago. EPE sold out its ownership stake in the coal-fired plant on the Navajo Indian Reservation in New Mexico for $32 million to Arizona Public Service.

The utility’s electricity output is primarily generated by natural gas units, most of those built in the 1960s, ‘70s or ‘80s. EPE also has a minority stake in nuclear-powered generation through the Palo Verde Generation Station near Phoenix, Arizona.

The future solar, gas and battery storage resource plan still needs Texas state Public Utility Commission approval.

(Rod Walton is content manager for PowerGen International and the Power Engineering website. He can be reached at 918-831-9177 and rod.walton@clarionevents.com).

New York manufacturing is poised for a job boom in 2019 and beyond.

That’s according to the American Jobs Project, which predicts that New York’s so-called “energy storage industry” could support 27,400 manufacturing and installation jobs by 2030.

The organization, in conjunction with the New York Battery and Energy Storage Technology Consortium (NY-BEST), published their findings in a new report.

American Jobs managing director Kate Ringness, who co-authored the report, explained that new policies are in place to help bolster this particular niche:

Amplifying the role of local manufacturing in New York’s energy storage industry could provide stable employment for thousands of middle-class workers while creating follow-on benefits for the broader labor market. New York’s leaders are creating strong policies to ensure there will be local demand for energy storage. We want to support these efforts by ensuring a healthy ecosystem that supports local job creation in manufacturing, as well as deployment.
New York’s job target is 30,000, according to a recent statement from Gov. Andrew Cuomo.

Currently, New York ranks fifth in the nation for energy storage patents. And while the report praises the Empire State for its testing facilities to support energy storage technology development, it suggested that early-stage startups are at a disadvantage.

They often face the “technological valley of death.”

“They require thorough performance data to build investor confidence in their prototypes, but often struggle to secure funding to pay for testing and validation resources,” Ringness wrote.

Among the players to keep an eye on due to their work in the “energy storage” sector, include General Electric Co. (NYSE: GE), Ioxus Inc., and Lockheed Martin Corp. (NYSE: LMT). Various startups are also driving growth, including C4V, Urban Electric Power, and NOHMs Technologies.

New York is also expanding critical capabilities in battery recycling, with investment in the new SungEel MCC Americas lithium-ion battery recycling plant, the report added.

China is poised to add a significant amount of battery storage to its utility grid next year. And it’s backing two horses in the energy storage race — both lithium-ion and flow batteries are part of the plan. China’s renewable energy portfolio now stands at 706 gigawatts according to Bloomberg but too much of that is wasted, or curtailed as they say in the utility industry. 7.7% of the electricity generated by wind turbines is curtailed as is 2.9% of electricity from solar panels.

Chinese regulators have approved a $174 million investment in the northwestern province of Gansu for the installation of a 720 MWh lithium-ion grid storage battery. It will be the first part phase of a new energy storage project in the region. When completed it will be able to store electricity for up to 4 hours, says Bloomberg.

The Gansu Provincial Development & Reform Commission says subsequent expansion of the project will depend on market conditions and the needs of the electrical grid. Once completed, it will be the country’s largest virtual power plant.

VRB Energy, a developer of vanadium flow batteries, says it plans to build a 100MW/500MWh storage system in Hubei province located in central China. It has begun commissioning a 250 kW/1 MW demonstration unit that it plans to expand to a 3 MW/12MWh battery later this year.

Jim Stover, vice president of business development at VRB Energy, tells TechCrunch, “The Chinese government I think in particular is happy to incentivize or call out vanadium like this. They want to push a number of technologies, but there is an awful lot of vanadium resources in China, both from mine sites and from steel slag recovery. They’re trying to seize that as a good and natural fit, they don’t have a lot of lithium. They have a lot of lithium manufacturers but not a lot of lithium itself, or cobalt, or nickel even.”

The China National Development and Reform Commission has issued a call for greater investment in flow batteries and set up programs to develop vast projects comprised of two or more 100MW installations. One such project — a 200MW / 800MWh vanadium energy storage project in Dalian Province — is already under way. Flow batteries potentially have the ability to provide electricity to the grid for longer than the 1 to 4 hours that is common with lithium-ion batteries. They also can support more charge/discharge cycles than lithium-ion batteries leading to longer life and lower total cost.

It’s been the biggest piece of bad news to hit UK solar for some time. Buried under waves and waves of Brexit procrastination, name-calling, indecision and confusion which appear to leave the country’s people, media and businesses alike scratching their heads and wondering what it was that anyone actually voted for in 2016’s EU referendum, the government announced its decision to end export tariff payments for solar PV.

Our UK news site Solar Power Portal reported at the beginning of this week that the export tariff will close to new applicants at the same time as the generation tariff, despite some 90%+ of respondents to a consultation expressing their opposition to the plans.

Britain’s feed-in tariff scheme will therefore now close in full to new applicants from 31 March 2019. While the government has accepted that there’s now need for market-based solutions for small-scale generators to make a difference to the UK’s energy mix in an economically rewarding way, the end of the present scheme without an explicit next step laid out is more than troubling for many in the renewable energy industries and those that care about energy security and climate change.

A somewhat dismal festive spread
“To not be taking care of the small actors in the system, which is so important, that just does not bode well for smart energy, especially given that Europe is steaming ahead,” Leonie Greene, policy director for the national Solar Trade Association says.

You can read all about how the STA and others plan to continue the fight for solar on Solar Power Portal, but let’s take a minute to consider what it might mean for battery energy storage.

While there might be a natural assumption that in the absence of payments for energy exported to the grid, households will at least – if they install a battery, or indeed hot water diverters or smart EV charging and other kit – be able to electrically store or otherwise ‘self-consume’ or ‘prosume’ the solar energy generated on their rooftops. Perhaps, but the economic equation for that is not so simple and neither are the industry or market dynamics.

At the beginning of this year, two battery storage systems went into operation in England which add up to 50MW of energy storage and deliver a significant percentage of total enhanced frequency response (EFR) contracts awarded in the UK through tenders by the transmission operator, National Grid.

Solar Media is proud to have been asked by technology provider NEC to publish a guide in the form of a case study, which goes in-depth on the 10MW Cleator and 40MW Glassenbury projects the company’s Energy Solutions division worked on for customer VLC Energy.

VLC Energy’s leadership includes prolific UK renewables developer Low Carbon and you can hear directly from the customer what was needed, what the challenges were and why NEC was the perfect fit, bringing in equipment and cutting-edge technology – both hardware and software – and choosing the right contractors for the grid connection and civil works portions of the project.

NEC Energy Solutions CEO Steve Fludder takes you through why he believes the energy industry is rapidly, through digitalisation and the growth of renewables and distributed energy resources (DERs), becoming a service-led proposition.

“The transformation of the electric power infrastructure all around the world is really unprecedented, because it impacts everyone and everyone will be engaged. The future is about multiple constituents and multiple flows of energy and multiple ways of really delivering cleaner, more reliable electricity through technologies and digital platforms, managed as an enterprise as opposed to managing a one-way flow of electrons,” Fludder says in the guide.

“We’re focused on all of the new technologies and solutions that will make this transformed grid that’s going to be majority renewable, in some cases totally renewable…I see storage as a central part of many types of energy system that allow other things to happen.”

Enel, through its Enel X energy services division, has won a contract to deploy energy storage to cut energy costs for US packaging producer Berry Global.

The behind-the-meter lithium ion battery installations, totalling 5MW/10MWh, will provide the Berry Global with 20% to 30% energy bill savings annually.

Under the terms of the agreement, Enel X will purchase, install and operate four battery systems for Berry Global at its Ontario operations in Canada. The batteries will be operational by summer 2019.
The energy services provider will also provide peak prediction services and enrol the batteries in Ontario’s Independent Electricity System Operator’s (IESO) demand response programme.

The project will use Enel X’s distributed energy resources (DER) optimization software.

Enel X North America head Michael Storch said: “This agreement underscores the benefits our storage systems and software can bring to businesses, helping them improve their energy cost-savings potential and supporting their sustainability goals related to energy efficiency.

“Enel X collaborates with customers to unlock new opportunities and deliver even greater value, including by making energy storage systems more accessible through the availability of flexible financing options.”

Enel X’s DER platform will analyse Berry Global’s energy consumption patterns and optimise the battery use, with the aim to boost financial savings from managing Ontario’s system charges and to enhance Berry Global’s participation in IESO’s demand response programme.

An energy storage startup that found its footing at Alphabet’s X “moonshot” division announced last week that it will receive $26 million in funding from a group of investors led by Breakthrough Energy Ventures, a fund that counts Jeff Bezos and Michael Bloomberg as investors, and whose chairman is Bill Gates. The startup, called Malta, uses separate vats of molten salt and antifreeze-like liquid to store electricity as thermal energy and dispatch it to the grid when it’s needed.

Malta’s system stores electricity by taking that electricity, using a heat pump to convert the electricity to heat, and storing that heat in molten salt. Then, when electricity is needed again, the system reunites the molten salt with the cold fluid, using a heat engine to reconvert the thermal energy to electricity, which can be sent back to the grid.
The concept is outlined in a July 2017 paper in the Journal of Renewable and Sustainable Energy, which states that “Round-trip efficiency…is found to be competitive with that of pumped hydroelectric storage.” Pumped hydroelectric storage is one of the oldest forms of electricity storage, using electricity when it’s cheap and plentiful to pump water up a hill, and then releasing that water through hydroelectric turbines when electricity is expensive and scarce.

In fact, lots of parallels can be drawn between Malta’s system and other forms of energy storage. A liquid-air energy storage system in the UK uses temperature differentials (like Malta does) to expand condensed air and put more electricity back on the grid when it’s needed. Solar thermal systems direct concentrated sunlight to a central tower to heat molten salt, which can store that heat for a long time before it’s used. This allows solar thermal systems to keep sending energy to the grid well after the sun goes down.

Malta’s business pitch is that its thermal pumped storage system can be located anywhere (unlike hydroelectric pumped storage, which requires elevation changes, or compressed air energy storage, which has been primarily deployed near natural underground caverns). It can be expanded easily, and unlike chemical batteries, such a system is made of common and cheap industrial materials that have 20-year lifespans.

Centrica has formally announced the completion of its 49MW Roosecote battery storage project, 18 months after construction started.

The energy major said construction of the project, one of Europe’s largest battery storage facilities, started in March 2017 and had now been fully unwrapped, just in time for Christmas.

The 49MW project is able to provide sub-second respond to fluctuations in demand and was among the 500MW of battery storage projects to have received a 15-year Capacity Market contract in December 2016 for the 2020/21 winter period.

Mark Futyan, distributed power systems director at Centrica Business Solutions, said: “The Roosecote site is truly unique, having been home to the latest technology of its time and is an exemplar of the transition we’ve made from dirty coal to cleaner, more flexible power. Christmas has indeed come early for our team!”

The site in Cumbria used to be home to a coal-fired power station that was later replaced by the country’s first combined cycle gas turbine.

It forms part of a £180 million (US$227.92 million) investment in flexible power on the part of Centrica, comprising a refurbishment and addition of a new gas turbine at the company’s King’s Lynn power station and two fast response gas-fired power stations.

Malta Inc., which started as “Project Malta” at the Moonshot Factory, but is now an independent company, announced Wednesday that it has raised $26 million in a round of funding led by Breakthrough Energy Ventures with participation from other investors including Concord New Energy Group, a wind and solar power developer,  and Alfa Laval, a Swedish industrial company.

Bloomberg, of Bloomberg News fame, and Bezos, the founder of Amazon, are among Breakthrough Energy Ventures investors.

Microsoft founder Gates is the chairman of the fund, which also counts Masayoshi Son, the Japanese business magnate, and Ray Dalio, founder of Bridgewater Associates, one of the world’s largest hedge funds, as investors.

In a statement, Ramya Swaminathan, CEO of Malta Inc., said “Our investors share our vision to create a scalable storage solution that will facilitate further expansion of renewable energy while improving grid stability and resilience across the globe.

“Beyond capital investment, they are truly partnering with us to build a first-of-a-kind product. We appreciate their confidence in our strategy and in our team’s ability to execute on it,” Swaminathan said.

The infusion of funds will allow Malta to further develop a system that uses large containers of molten salt and cooler liquid to store electricity generated from variable sources such as solar and wind.

The system is based on well-established principles in thermodynamics for a system that stores electricity as heat in high temperature molten salt and cold in a low temperature antifreeze liquid.

While incubated at Alphabet’s Moonshot Factory, the project underwent a rigorous evaluation and de-risking process.

Swaminathan, who previously ran Rye Development, a Boston-based developer of renewable energy projects, said Malta will now work with industry partners to turn the detailed designs developed and refined at X into industrial-grade machinery for its first pilot system.

As currently designed, Malta’s system can store electricity for days or even weeks, until it’s needed. The electricity can come from any source (i.e. wind, sun, or fossil fuels) in any location.

Rooftop solar communities may soon become the latest line of cybersecurity defense for America’s vulnerable electric utility industry, providing emergency power for local consumers while supporting the grid in the event of an attack-based outage. Indeed, a key recommendation in a recent President’s National Advisory Infrastructure Council report on cybersecurity and the grid is that solar and other renewable energy-based microgrids be developed for emergency preparedness.

At the same time that solar microgrids can provide refuge from electric grid hacking, the microgrids themselves need to implement security protocols to avoid the same sort of hacking, some experts point out.

In a draft version of the NAIC report, “Surviving a Catastrophic Power Outage,” released in December, one recommendation is to “Support demonstrations of community enclaves design approaches, which may range from traditional hardening of infrastructure to microgrids that combine distributed energy resources, energy storage, and innovative consumer technologies.”

The NAIC report suggests that this can be achieved by “Deliver(ing) peer-reviewed results and lessons learned from demonstrations to provide utilities and communities with effective approaches to design, manage, operate, and fund microgrid and energy resilience capabilities.”

Some funding for such activity has already taken place. New Orleans, for example, won a grant from from the US Department of Housing and Urban Development for $141 million in unused Hurricane Sandy recovery funds “to undertake the highest priority upgrades and implement advanced microgrid pilot projects in critical sections of the city.”

Rooftop solar and larger solar arrays are vulnerable to hacking through the inverter, which often has a web link to the equipment manufacturer, which provides a monitoring service to the customer, if not a link to a community solar or community aggregation operation center. This was recently highlighted in a November report by Ridge Global, a consulting firm founded by former Homeland Security Secretary Tom Ridge.