After another record-breaking year, in which the US surpassed 1GW of deployed energy storage and China began its programme of building flow batteries several hundred megawatts in size each, we canvassed opinion on what 2018’s biggest challenges and successes were. In doing so we also look ahead to what this year, 2019, will hold, from the strategies our industry will utilise to meet those big challenges and what the expected direction of travel will be in some of the world’s leading markets.

In this first part, we look at the challenges faced by the industry in 2018 and we’ll move on to those other aspects of energy storage in 2018-2019 and beyond in the coming instalments.

Lithium-ion cell supply

Physically getting hold of batteries for use in energy storage systems was a constraining factor in 2018 for many. Respondents Roger Lin, VP of marketing at the Energy Solutions division of NEC Corporation, said electricity policy in South Korea has “spurred an avalanche of local demand there, making it difficult to secure supply for other parts of the world,” and the only unaffected companies were those with long-term supply agreements in place. Karim Wazni, managing director of Aggreko (which bought up storage system integrator Younicos earlier this year) agreed that “the sourcing of lithium-ion cells” in particular was a supply chain challenge in 2018.

Policy uncertainty
Déjà vu for anyone making the sideways move into energy storage from the solar PV industry: politicians aren’t ever sure how to treat new technologies and environmentally-friendly energy sources are among the least understood.

Almost every one of our recipients said that while energy storage markets have grown significantly around the world, policy uncertainty remains one of the biggest challenges. Aggreko’s Karim Wazni said that rule changes have increased market risk and uncertainty – “particularly in the UK and in Germany”. NEC’s Roger Lin said that in the UK, changes to Capacity Market conditions and changes to grid services contracts and peak demand pricing mechanisms – still a work in progress – created “shifting market conditions” and uncertainty.

While a recent study said 10GW of energy storage by 2030 would offer overall benefit to Nevada, NV Energy will move forward with an Integrated Resource Plan: 1,000MW of renewables including 100MW of storage – by 2021.

NV Energy, a Nevada utility owned by billionaire investor Warren Buffet’s Berkshire Hathaway vehicle, serves around 1.2 million customers in north and south Nevada, with electricity, as well as millions more tourists.

Just before the Christmas Holiday period in the last two weeks of 2018, regulators in the US state approved NV Energy’s proposal, which had been tabled in June. The plan would double NV Energy’s renewables deployment by 2023, green-lit by the Nevada Public Utilities’ Commission (PUC). NV Energy confirmed in a release that the plan will entail US$2 billion of investment, creating 80 long-term jobs and 1,700 roles during construction.

By the time the projects are completed, expected during 2021, NV Energy would have 3,000MW of renewable energy resources in operation. Wholesale electricity costs are expected to fall as a consequence of the investment in clean energy. The plan includes six projects in the state, while the company also has out a 350MW request for proposals (RFP) for large-scale solar projects.

The utility, one of only two regulated public utilities serving retail customers in the state, already offers incentives for eligible homeowners and businesses to deploy home or commercial & industrial battery storage systems from 4kW to 1,000kW. Depending on system size, up to US$2,000 or US$3,000 could be applied for, with payments capped at US$1,000,000 for every step of the programme.

From a bigger picture perspective, it’s not quite what the energy storage industry might have hoped for in the best case scenario but is certainly a big step forward. A recent study by consultancy The Brattle Group (commissioned by the PUC) determined that certain levels of energy storage deployment: 200MW by 2020, 1,000MW by 2030, along with 40MW of behind-the-meter resources would give a net benefit for the state.

Electricity from 100MW of energy storage facilities will be purchased by US public utility company El Paso Electric, following a competitive solicitation process.

Headquartered in Texas and serving more than 400,000 customers in that state and in New Mexico, the utility determined that it required additional generation and energy management resources in place by the time the 2022 and 2023 summer peaks in electricity demand happen. The utility currently owns around 2,153MW of generation facilities.

El Paso Electric put out its 2017 “All Source Request for Proposals for Electric Power Supply and Load Management Resources” as a consequence, competitively tendering for both the construction of new projects including solar, storage and natural gas and for the purchase of power from third-party owned generation facilities.

Winning proposals remain subject to their obtaining required environmental and construction permits as well as gaining approval from the respective Public Utility Commission of Texas and New Mexico’s Public Regulation Commission. El Paso Electric said the projects chosen and the mix of diverse choices is in line with the need to deploy “cost-effective, diverse and competitive-based energy resources for its customers” in expanding its portfolio, as well as advancing a strategic goal to “remain at the forefront in advancing renewable energy”.

The utility selected:

200MW of utility-scale solar

100MW of energy storage

226MW new natural gas combustion turbine unit at existing power station

50MW to 150MW of wind and solar power purchases

The burgeoning as-a-service model, offering greater user flexibility and attractive economics, is now a viable option for energy storage. As with transportation, office equipment, and other capital-intensive assets, large-scale energy users both on and off the grid can leverage the benefits of battery storage on a use-only-what-you-need-when-you-need-it basis. What is the main driver behind this new offering? Flexibility.

Removing the Risks

There are several reasons why storage-as-a-service makes sense in today’s fast-evolving energy landscape. First, long-term ownership commitments may lead to stranded assets and tied-up capital (especially with relatively new technology). In certain cases, it might be better to rent a system and see if it proves valuable. Second, as-a-service solutions provide maximum flexibility when market conditions shift. For example, when regulations or the value of ancillary services change, users can more easily adapt. Third, rental customers can generally contract with one supplier who takes responsibility for system design, performance, and maintenance—a “one-stop shop.” These new approaches to system deployment offer a virtually risk-free, 100% reliable solution.

There are also compelling arguments for the as-a-service model that apply in particular to batteries. For example, potential customers may have concerns about battery life and whether their investment will be compromised. New technology is continually coming on the market, which could render their newly acquired asset obsolete. As with solar photovoltaic technology, there’s a perception that prices will continue to decline. Why buy now if it’ll be cheaper tomorrow? Faced with a purchase decision, these concerns can lead to hesitation, limiting a customer’s ability to capture energy storage benefits immediately. The more-flexible as-a-service alternative eliminates these risks.

A final point worth mentioning is that batteries typically have long lead times, ranging from nine to 18 months, depending on market conditions. Most established providers that offer storage-as-a-service have inventory available that can be delivered on short notice (typically less than three months), enabling customers to realize the benefits faster.

Convenient Contracts and Configurations

Storage-as-a-service contracts start with periods as short as a few months (although multi-year terms are far more economical). Typically, agreements are based on a regular monthly or annual fee. Terms can be easily adapted to fit changing business needs. Customers receive guaranteed 24/7 system reliability for zero asset investment and with low implementation costs, including 100% service coverage. All operations and maintenance costs, remote monitoring, performance guarantees, and warranties are covered under one contract and fee.

From both a regulatory and development perspective, 2018 was a significant year for the expansion of energy storage resources (ESRs). From a significant ruling of the Federal Energy Regulatory Commission (FERC), to the presentation and implementation of aggressive state initiatives, rapid ESR deployment continues unabated while ESR technology costs continue to decline precipitously.

Undeniably, ESRs have arrived as a credible, useful component of a resilient and efficient grid. This article explores common ESRs and how they contribute to grid stability, the FERC’s impact on the development of markets to compensate ESRs, and how states are playing a pivotal role in advancing the development of ESRs.

ESRs and the Grid
An electric storage resource is defined by FERC as “a resource capable of receiving electric energy from the grid and storing it for later injection of electricity back to the grid regardless of where the resource is located on the electrical system.” Common examples of ESRs include batteries, pumped storage facilities, and compressed air energy storage.

Because ESRs have the flexibility to consume or inject electricity, they can be used by grid operators and market administrators to balance supply and demand efficiently. Generally, grid operators identify the ability of ESRs to shift load as a consumer when load is low and as a supplier when load is high. ESRs can help manage peak demand, manage the integration of intermittent resources (such as solar and wind facilities), and defer distribution and transmission upgrades.

Because of their ability to store energy for later deployment, ESRs have the capability to mitigate demand during peak consumption periods. Additionally, because certain ESRs have the ability to ramp up and down rapidly in response to grid requirements, they are particularly useful in assisting grid operators in integrating increasing levels of intermittent, renewable sources of power.

Resources such as solar and wind do not have defined production patterns, and often they need to be curtailed for economic reasons. ESRs have the capability to flatten the production curve for such resources, thereby enhancing grid reliability.

Finally, ESRs can help operators manage transmission congestion. Grid operators are often confronted by congestion in areas of the grid that lack sufficient transmission infrastructure, particularly during peak periods. During such periods, lower-cost resources may not be able to be dispatched to serve load. ESRs strategically located on the uncongeste

Ørsted’s first standalone battery energy storage system has now entered operation.

The 20MW battery, located in Carnegie Road, Liverpool, consists of three battery units as well as a power conversion system.

The firm said infrastructure of this kind is vital to help balance the UK’s electricity grid by ensuring consumption matches the amount of power generated at any given moment.

Highly flexible batteries can quickly respond to grid requirements and are seen as a valuable component of a modern, decarbonised energy system.

Matthew Wright, UK Managing Director at Ørsted, said: “Climate change is a real and pressing threat to our planet and in order to minimise its effects, we urgently need to decarbonise our electricity system.

“Batteries and other innovative storage technologies will form a critical part of an integrated green energy system required to ensure we keep the lights on without harming our planet.”

The project is the first large energy storage facility built by EMC Lendlease, the joint venture between Energy Made Clean, a wholly-owned subsidiary of Carnegie, and Lendlease, an engineering, procurement and construction (EPC) provider. As the module supplier, Risen Energy provided more than 30,000 mono-crystalline modules to the facility.

The modules have been tested by Clean Energy Associates, an American owned and operated global solar PV engineering and quality assurance technical services advisory firm, and are highly adaptable to the local climate conditions in Western Australia in that they can maintain stable power output in hot and dry environments and ensure a high ROI by reducing costs.

The 25-hectare PV power station has now been fully connected to the grid and is estimated to be capable of generating 24 GWh of clean electricity over the next 25 years.

According to the latest data from the China Photovoltaic Industry Association (CPIA), module exports by Chinese PV manufacturers maintained growth during the first ten months of 2018, with the proportion of exports to Australia climbing from 6.0 in 2017 to 10.7 percent. Risen Energy has successfully exported its modules to Australia but also participated in the construction of many large power stations across the country, in full compliance with local standards for project design and development. Among the several projects, Yarranlea, in which Risen Energy played an important role, was specifically pointed out for praise by Dr. Anthony Lynham, Queensland Minister for Natural Resources, Mines and Energy.

Li Bin, general manager of Risen Energy Australia, said, “Our steady expansion in Australia is driven by the company’s innovative products and technologies which can meet the needs of consumers in different regions. Looking ahead, our company plans to invest in renewable energy projects totaling over 2GW in Australia and will continue to expand in the energy storage sector. As for some upcoming acquisitions, we are in the process of seeking financing or EPC partners as well as looking for co-developers.”

2018 is over, and a new year of energy evolution is upon us.

The past year laid a robust foundation for growth in 2019. It ended with six states and territories, including two of the three largest state economies, committing to 100 percent clean electricity. The solar industry weathered the much-feared tariffs without excessive bleeding. The list of cleantech failures was much shorter than in previous years.

There’s still plenty of room to grow. Solar only accounts for 1.3 percent of U.S. electricity generation, and wind produces 6.3 percent. Grid edge technologies are helping the grid adapt, but they’re still in limited real world use.

Keeping in mind that contrast between heady potential and modest achievement so far, we shall venture into the prediction game to identify key clean energy developments to come over the new year.

More states commit to clean
GTM’s Emma Foehringer Merchant dubbed 2018 the year of 100 percent clean energy. Watch for another waves of jurisdictions to follow the past year’s trailblazers.

In 2018, California joined Hawaii in legislatively committing to a carbon-free electricity system. Governors in New Jersey, New York and Puerto Rico made their own executive commitments to that end. Washington, D.C.’s city council passed a target of 100 percent renewables by 2032.

For a while, debates over 100 percent clean energy policy broke down into intellectual tribalism, as different factions jostled over who had the better vision for a clean energy future. Meanwhile, skeptics could dismiss the whole exercise as a folly.

Once economic and demographic powerhouses like California and New York got on board, it became exceedingly difficult to dismiss the policy as a fairy tale. Suddenly, passing the target switched from seeming intractably difficult to eminently achievable; following through is now the hard part.

December13, 2018: Academics at University of California San Diego have developed a suite of tools using a combination of chemistry and economic know-how to predict the best battery technology for an energy storage project, the university announced on December 3.

The tools take into account a region’s energy markets and the operating characteristics of the battery to predict if a storage project will be financially viable.

Shirley Meng from UC San Diego nano-engineering, and co-author of the paper, says the research was the first step towards re-thinking how battery storage should be viewed by energy storage system practitioners.

She also urged people to look at new chemistries such as sodium ion batteries.

The tools take into account the battery type, its task (such as frequency response, load shifting), price, and market rules of the specific region to help project developers select the appropriate grid-connected battery storage.

The study titled Combined economic and technological evaluation of battery energy storage for grid applications was published in the peer reviewed scientific journal Nature Energy on December 3.

Meng told ESJ: “We are using real California grid (energy market) data to do revenue projection, and the focus is really on understanding how different chemistries can deliver different efficiency under different duty cycles.

“Most of the batteries that have been commercialized have optimum operation temperatures in the range of 0°C to 40°C. From this aspect, lead acid and lithium ion are the same.

“For this reason, most of the grid storage units have temperature control (cooling unit); lead acid batteries still occupy the majority of the grid storage market, but in terms of new storage units (coming up online) lithium ion batteries definitely dominate.

“This is because some lithium ion battery chemistries such a LFP are robust at cycling at 40°C. LFP based batteries have demonstrated over 10,000 cycles at 25°C, making it ideal for grid storage.”