MONTH CHINA
06
ENERGY STORAGE ALLIANCE
YEAR
2011
CNESA
Industry Trends this issue
Korea’s Energy Storage Investment P.1
Project Updates
Distributed Generation In China P.3 Golden and Field, Canada— BC
Tech Insights (Big, Cheap Batteries) P.5
Hydro and S&C Electric plan to build two 1MW NaS systems
New Policy Developments P.7 Catalina Island, CA—Southern Cali-
Important News P.9
fornia Edison and S&C Electric plan to build a 1MW NaS system
South Korea to Invest $5.9 Billion in Energy Storage
Stephentown, New York— Beacon Power has completed construction on its first 20 MW flywheel plant
Philadelphia, PA—Saft will build a trackside dual purpose ESS, which will provide both regenerative braking and regulation services
Nagasaki, Japan—Mitsubishi Heavy Industries has begun testing Japan’s first large-scale transportable ESS, a 1MW/.408MWh Li-ion system
New Jersey — Altairnano has been awarded a three-year lease from Energy Storage Holdings LLC for it’s new ALTI-ESS Advantage 1.8MW/.300MWh Li-ion system
On May 31st, the South Korean Ministry of Knowledge Economy (MKE) declared the largest government investment in energy storage to date. It will spend 6.4 trillion won ($5.4 billion USD) from now until 2020 to develop its domestic energy storage industry. One-third of this money will go towards research and development while the rest will go directly towards energy storage projects. This investment will not only ensure that the South Korean grid remains strong as it incorporates more renewable sources of energy but also establish South Korea as a global leader in the manufacturing of energy storage systems. South Korea hopes to capture 30% of global market share by 2020. While the Korean government has yet to declare specific programs and policies, a review of current energy storage projects affords insight. Along with the U.S. and Japan, South Korea has invested heavily in energy storage research over the last several years. The largest amount of funding has been directed towards a comprehensive smart grid demonstration project on Jeju Island, Korea’s
Status of Worldwide Projects Worldwide Energy Storage In Operation (2000– Present) 375 MW
As of June 1, 2011: (proposals not included) New Project Announcements: 5
NiCd 7%
Other 32% NaS 68%
Li-ion 9%
Flywheel 6% CAES, pumped hydro and thermal energy storage not included
Total MW to be Added: 5.875 MW Technologies to be used: Lithium ion and Sodium-sulfur batteries
Lead Acid 8%
Ultracapacitor <1% Flow 2%
Projects Beginning Operation: 1.2 Total MW added: 5 MW Technologies Used: Lithium Ion Battery, Flywheel
largest and southernmost island. It is known for its scenic tourist sites as well as its abundant wind resources. The $200 million demonstration project combines $50 million in public funding with $150 million in private investment from 168 companies, including those in power generation, power infrastructure, telecommunication, automotive, and electronics manufacturing sectors. Its ultimate goal is to develop smart grid technologies and business models that can be implemented throughout Korea beginning in 2013. Jeju Island Smart Grid Test-Bed The Jeju Island Smart Grid Test-Bed Project has been underway since December of 2009. It is centered around the town of Gujwa-eup, which has 6,000 households. The project incorporates smart grid controls, electric vehicle charging infrastructure, renewable sources of generation and energy storage. The most notable participating energy storage manufacturer is Samsung. Samsung’s lithium-ion battery technology has been installed at several points within the Jeju Island smart grid demonstration project. As of June 2011, it has installed 20 – 3kW/7kWh residential energy storage systems with another 30 set to begin operation in 2012. Samsung has also integrated a 600kW/150kWh grid stabilization/fast charging station, which has been in operation since November of 2010. Finally, it recently completed a 800kW/200kWh system that will provide wind peak smoothing and load shifting services.
CNESA Update 2011/11 CNESA IssueIssue 03 Month 06 Year 2011 CNESA Update 00 Month
Industry Trends
Year
South Korea to Invest $5.9 Billion in Energy Storage (cont.) Outside of the Jeju Island pilot project, Samsung has several energy storage systems under development, including a 2MW/0.5MWh frequency regulation system, a 25kW/25kWh community energy storage system and a 3kW/10kWh residential energy storage system. It is also working with several Korean companies to develop a 100 MW compressed air energy storage system in Samcheok, Gangwon Province.
Overhead view of Jeju Island
Samsung’s entry into the energy storage market is quite expected. According to the Japanese Institute of Information Technology, Samsung surpassed Sanyo in 2010 to become the world’s leading lithium-ion battery manufacturer. It also leads the world in new lithium ion battery patents. Samsung will look to maintain its market share by establishing itself as an early leader in Korea’s energy storage market.
Other Korean manufacturers have also shown considerable interest in the energy storage market. In April, Honam Petrochemical signed a joint development agreement with American zinc-bromide flow battery manufacturer ZBB Energy. As part of this agreement, Honam gained the exclusive rights to manufacture and sell ZBB’s energy storage systems in Korea as well as the nonexclusive rights to sell systems to other parts of Asia. Korea’s second largest lithium-ion battery manufacturer, LG Chem, is targeting the residential energy storage market. In April, LG Chem unveiled its 4kW/10kWh lithium-ion polymer battery system, which will be used in a smart grid demonstration project with electric utility Southern California Edison later this year. The Korean electric grid is already one of the strongest in the world. It has a power generation capacity of 73,470 MW, an annual average household blackout time of 16 minutes and an average 4% rate of transmission and distribution losses. Smart grid deployment, including energy storage, is expected to reduce overall power consumption by 3% by 2030. Although energy storage will allow Korea to incorporate more wind and solar power without compromising the integrity of its power system, it is quite clear that Korea’s interest in energy storage extends well beyond improving its domestic infrastructure. Energy storage is viewed as a growth engine for the Korean economy. In contrast, China has an estimated average transmission and distribution loss of 6% and has struggled to keep up with demand as its economy continues to expand at a rapid pace. On May 23, China State Grid warned that this year’s summer blackouts could be worse than 2004. State Grid’s executive vice president, Shuai Junqing, warned that rolling blackouts due to a projected 30 GW power shortage would likely lead to power outages in 26 provinces, including Beijing and Shanghai. These types of blackouts are often directed towards industrial users and result in economic losses totaling billions of dollars. Despite the Chinese government’s strong commitments towards building out the smart grid and reducing CO2 emissions, it has lent limited support to its domestic energy storage industry. China has the ability to compete with Korea in the worldwide energy storage market. Because the market is still relatively young, emerging companies have the opportunity to gain considerable market share. In addition, Chinese lithium battery manufacturers have drastically improved their product over the last several years and are gaining market share. While Korea has more developed technology and a head start in the energy storage race, China has one advantage – a domestic market that can reap greater benefits from energy storage. Energy storage can help mitigate some of the biggest problems facing the Chinese grid. By recharging during times of excess power and providing power during peak demand, energy storage systems can lower the total required generation capacity. Energy storage systems can also better utilize the power generated from wind and solar. This will make the Chinese grid less susceptible to power shortage resulting from various bottlenecks in the coal supply chain, ranging from insufficient coal shipping capacity to international price spikes. Despite the relative strength of its grid, the South Korean government has chosen to push the development of domestic energy storage solutions. The government’s ambition to capture 30% market share signals that it understands the energy storage market’s potential for growth. The Chinese government should consider a similar policy for growth to ensure that it does not fall behind the rest of the world in this emerging market.
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CNESA Update 2011/11 CNESA Issue 03 Month 06 Year 2011 Issue 01Issue Month Year 2011 CNESA Update 00 04 Month CNESA Year
Industry Industry Trends Trends
Issue 01 Month 04 Year 2011
Distributed Generation and Micro-grid Development in China Although the Chinese grid is strongly based on the central generation model, China State Grid recognizes the advantages in safety and reliability inherent to a distributed generation approach. As such, it is conducting several groundbreaking micro-grid and distributed generation demonstration projects. Through these projects, China State Grid will explore the distributed generation model and establish new designs and control systems that will aid it in the development of future distributed generation systems. Energy storage is playing a prominent role in these demonstrations and will likely be featured in resulting projects. In 2011, China entered into the nationwide construction phase of its smart grid deployment plan. According to China State Grid’s Smart Grid division, from 2011-2015 smart grid investments will reach 280 billion RMB ($43.2 billion) with an average annual expenditure exceeding 56 billion RMB ($8.6 billion). This is much greater than the 25 billion RMB ($38.6 billion) spent on smart grid development in 2010. Several smart grid demonstration projects incorporating energy storage are currently underway:
Storage Technology
Power Source
Start Date
Project Name
Participating Companies
China and Singapore Cooperation Tianjin Eco-city Smart Grid Demonstration Project
Lithium-ion 2MW
Solar, Wind
2010-4
China State Grid, Tianjin Electric Power Research Institute
Jiangxi Gongqing City Smart Grid Demonstration
Several
TBD
2011-5
China State Grid、CEPRI, Jiangxi Electric Power Design Institute
Dunhuang Renewables Integration Energy Storage Demonstration Project
Several
Solar, Wind
2011-4
Dongbei Power Grid Company, CNOOC, Datang Renewable Power
2011-4
Shanxi EV Charging and Renewable Integration Micro-grid Project
Lithium Iron Phosphate
Solar, Wind
China State Grid
2011-2
Weichang Bashang Distributed Generation and Micro-grid Control Project
Lead acid battery
Solar, Wind
Huabei Power Grid Company
2010-11
Dongfushan Island Comprehensive Smart Grid Project
Lead acid 2000Ah
Solar, Wind, Diesel
China State Grid、Zhoushan Offshore Wind Company
Distributed Generation and Micro-grid can be defined: Distributed Generation: A system containing several small sources of generation, often from wind and solar, that are located near the load center they are serving. In the event of excess power generation, energy is shared with the larger grid system. Micro-grid: A system consisting of distributed generation, power conversion systems, transmission lines, control systems and possibly energy storage that can operate in two modes: 1) Island mode: operating completely independent of the larger grid 2) Interconnected mode: operating in conjunction with the larger grid through the exchange of power. This type of system ensures power reliability in the event of massive failure of the larger grid. The role of energy storage within micro-grid and distribution generation systems:
Energy storage can stabilize the voltage on the local system by counteracting voltage drops and power outages resulting from variable generation and local faults on the grid. During unexpected periods of low generation, energy storage systems can supply extra power to meet demand. When switching from interconnected to island mode, energy storage can provide power to ensure that critical tasks can continue uninterrupted. Energy storage can provide peak shaving services to the local grid as well as the larger grid to minimize the generation capacity required. Energy storage gives grid operators a greater degree of control over micro-grid systems by allowing them to control when and where power is used. 3
CNESA Update 2011/11 CNESA Issue 03 Month 06 Year 2011 Issue 01Issue Month Year 2011 CNESA Update 00 04 Month CNESA Year
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Distributed Generation and Micro-grid Development in China (cont.) China and Singapore Cooperation Tianjin Eco-city Smart Grid Demonstration Project The China and Singapore Cooperation Tianjin Eco-city Smart Grid Demonstration Project is an example of a functioning distributed generation and micro-grid system. This project is also China’s first comprehensive smart grid demonstration project. It will shape China’s national smart grid development. The project is actually composed of twelve smaller demonstration projects, of which, two contain energy storage systems. Project Name Generation Sources
Animation Studio No. 2 Station Solar：0.5MW Natural gas generation：1.5MW
Jiyun River Wind Farm Wind：5.4MW
Energy Storage
0.5MW Li-ion system
1.5MW Li-ion system
Transmission Attachment
10kV primary connection
10kV secondary connection
Capable of Islanding?
Yes
No
Energy Storage Application
Micro-grid operation
Power output smoothing
In these projects, energy storage has two roles in the distributed generation and micro-grid system: 1) Stabilizing Output from Renewable Generation Within distributed generation systems the direction of the flow of electricity can change suddenly. This leads to drastic changes in voltage throughout the system, especially at the feeder end, where voltage spikes lead to over-voltage problems. Because the changes in flow are caused by changes in generation and load, systems incorporating variable sources like wind and solar are especially at risk. To address this problem, China State Grid has introduced “technical requirements for the integration of small-scale generation sources” and “technical requirements for wind integration.” These technical requirements stipulate acceptable voltage fluctuation ranges. Power producers looking to meet these requirements can use energy storage to mitigate voltage fluctuations, as exemplified in the Tianjin demonstration project. 2)
Micro-grid Controls
Micro-grids powered solely by wind and solar have difficulty maintaining constant frequency and voltage due to power output volatility. Energy storage can help maintain the frequency and voltage levels by serving to balance the generation and load. Given limited means to control power output from wind and solar, energy storage systems represent one of the few means of stabilizing micro-grids. Their role in optimizing micro-grid control operations is also of critical importance. Within the Animation Studio No. 2 Station project, the 500kW energy storage system is used during the transition from interconnected mode to island mode. It acts as a temporary power supply to ensure a seamless transition. During emergency situations, like the failure of the larger grid, the micro-grid can continue operating independently. This type functionality is very valuable to military bases and hospitals where a temporary interruption in power can be a matter of life and death. Conclusion Recent power shortages in China, the U.S. and Britain as well as the Fukushima disaster in Japan have exposed the fragility of electric grids built around central generation. When a large source of generation goes down, it is very difficult to maintain the stability of the power grid and ensure that load demands can be met. Distributed generation and micro-grid systems offer an alternative approach. By using smaller local sources of generation, the entire electric system becomes less susceptible to massive failure. However, operating a grid based around distributed sources of renewable generation requires complex control systems. Energy storage adds a new levels of control. It improves power quality while reducing the probability of blackouts. The Tianjin renewable integration and micro-grid demonstration projects are laying the foundations for China’s future smart grid projects. China State Grid will use the designs and control systems developed during this project as a model for future development.
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CNESA Update 2011/11 CNESA Issue 03 Month 06 Year 2011 Issue 01Issue Month Year 2011 CNESA Update 00 04 Month CNESA Year
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Big, Cheap Batteries The high energy density and relative safety of lithium ion batteries has made them ideal for use in portable consumer electronic devices. However, when it comes to grid-scale energy storage, their current production costs are simply too high to justify their use in all but a few high value applications. Two recent energy storage upstarts are taking a unique approach to this problem. Instead of concentrating on pushing the limits of lithium ion battery performance, these companies have sought out the some of the cheapest raw materials available in order to create energy storage systems that will be economical for a wide-range of applications. The following is a short review of the progress of Liquid Metal Battery and Aquion Energy in their quest to realize big, cheap batteries. Liquid Metal Battery Liquid Metal Battery is an MIT spinoff that was formed by Professor Donald Sadoway. Since its founding in 2009, the company has received a $6.9 million ARPA-E grant and a $4 million grant from French energy company Total. This money has been used to develop several small scale prototypes of its molten salt battery that uses liquid magnesium and antimony electrodes. Its raw materials are plentiful and cheap. Magnesium is the seventh most abundant element in the earth’s crust and costs around $3/kg. Antimony is rarer but sells for only $15/kg. Sadoway’s team estimates that this battery will have an energy density greater than lithium ion and will cost less than $100/kWh to produce commercially. Liquid Metal battery gets its inspiration from the electrolysis process used for large-scale aluminum smelting. During the aluminum smelting, a huge amount of electrical current is used to reduce molten aluminum oxide into aluminum and oxygen at the cathode. Then, an oxidation process at the carbon anode produces C02. Because the C02 escapes, this process is not reversible. Instead of creating a gas at the anode, Sadoway’s team found an oxidation process that actually creates a metal that will not evaporate away – effectively making the process reversible. In Sadoway’s battery, liquid antimony is used at the anode. This thin layer of antimony rests at the bottom of a crucible (container used for melting metals). A molten salt electrolyte which contains positively charged magnesium ions and negatively charged antimony ions rests on top of the antimony. Finally, a layer of magnesium which is in contact with an electrode rests on top. The whole mixture is then heated to melt the metals and electrolyte (500700oC). Liquid Metal Battery Charging Operation Charging
Fully Discharged
Fully Charged
Mg2+ + 2e- → Mg
Magnesium (Mg) Molten Salt w/ Magnesium and Antimony Ions
Mg2+
Sb3Sb3-→ Sb + 3e-
Antimony (Sb)
+
Figure 1: The charging process of Liquid Metal Battery’s innovative molten metal design.
As seen in Figure 1, during the charging process, the negatively charged electrode pulls the positively charged magnesium ions out of the electrolyte to create more liquid magnesium at the top while the positively charged electrode creates more antimony at the bottom. During discharge, this process is reversed, and current is generated as the metal atoms become ions once again. This type of system has many advantages. The manufacturing process is relatively simplistic because it does not rely on microscopic makeup of the electrodes. Additionally, the battery should be highly scalable. Because it takes its inspiration from aluminum smelting, it is hoped over one-hundred years of industry knowledge can be applied to create grid-scale systems. Finally, by using liquid electrodes and electrolytes, the battery can absorb electrical currents ten times higher than current high-end batteries. Sadoway’s team is currently working on a prototype of this battery that is around one-foot in diameter. One of the team’s near term goals is to build a system that is large enough to be “self-heating”, which means it has the ability to maintain operating temperatures without the aid of heaters. This will make the battery much more efficient. Despite the team’s progress thus far, Sadoway estimates that this system is still five to ten years away from commercialization. 5
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Big, Cheap Batteries (cont.) Aquion Energy Aquion Energy was founded in 2009 as a spin-off from Carnegie Mellon University. It was founded on the principle that “for energy storage to be viable, it must be low cost, long lasting and highly efficient and environmentally benign.” As of June 1, Aquion has received funding from venture capital firm Kleiner Perkins Caulfield & Byers as well as a $5 million grant from the DOE. Its batteries utilize a low cost activated carbon anode, a sodium manganese oxide cathode and an aqueous sodium ion based electrolyte. Aquion’s raw material costs are also quite low. As a result, Aquion estimates that the fully scaled production costs will be less than $300/kWh. Perhaps more importantly, the system will be extremely long lasting (>5000 cycles). Given its price and lifetime, it will be able compete with lead acid batteries in almost every application. Aquion’s battery can best be described as an asymmetric hybrid ultracapacitor that uses an aqueous sodium ion electrolyte. During the charging process, positively charged sodium ions are pulled from the sodium manganese oxide cathode to the negatively charged activated carbon capacitor anode. During the discharge process, the positively charged sodium ions return the manganese spinels where they generate a current as they intercalate. Aquion’s Battery Charging Operation Na+ Na+
-
+
+
Na Activated Carbon Anode
Separator
Manganese Oxide Cathode
Figure 2: The charging process of Aquion’s battery in which sodium ions are transported to the carbon anode.
By using an aqueous electrolyte, Aquion Energy can avoid several problems associated with lithium-ion batteries. First, the high purity solvent-based electrolytes used for lithium-ion batteries are expensive. Second, these solvents have a much lower conductivity than water. To make up for this shortcoming, lithium ion batteries are designed to minimize the distance ions travel through the electrolyte by using long sheets of thin electrode materials wound tightly together. This maximizes the surface area of the electrodes while decreasing the separation between them. It also substantially increases costs. In contrast, Aquion Energy uses thick electrodes and cuts costs by using less separator and current collector material.
Figure 3: Aquion uses stackable trays that can be connected in series or parallel to meet voltage and current needs. ( from Aquion Energy)
Aquion Energy has an ambitious commercialization timeline. It will begin sending samples to potential customers, including AES, later this year. It also plans to start high capacity production (500 MWh/yr) in 2013. To finance this, the company is hoping to raise $25-30 million in venture capital funding this summer in order to kick-start planning for a new manufacturing facility that will cost $70-80 million. Both Liquid Metal Battery and Aquion Energy have products with the potential to open up the energy storage market. By thinking outside the conventional battery design paradigms, the founders of these companies have created low cost systems specifically tailored for energy storage applications. These systems are capable of charging and discharging over several hours, making them ideal for peak shaving and renewable integration applications. Although commercial systems are still several years away, Liquid Metal Battery and Aquion Energy’s batteries represent some of the most exciting and innovative to date. 6
CNESA Update 2011/11 CNESA Issue 03 Month 06 Year 2011 Issue 01Issue Month Year 2011 CNESA Update 00 04 Month CNESA Year
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Energy Storage Policy Progress: AB2514 AB 2514 is a landmark energy storage bill – the first of its kind. After being signed into law on September 29, 2010, it empowers the California Public Utilities Commission (CPUC) to establish energy storage procurement targets for 2015 and 2020. Similar to a renewable portfolio standard, it will call for electric utilities to install energy storage systems that make up a fixed percentage of California’s peak load requirement. It has been lauded as a key enabler of California’s renewable energy goals. By increasing the amount of energy storage on the grid, it will enable grid operators to drastically reduce greenhouse gas emissions through more effective utilization of renewable sources of generation and decreased reliance on fossil-fuel based sources of generation. AB 2514 has been in development for several years. After being authored by Assembly member Nancy Skinner, the bill was formally introduced to the California Assembly in February of 2010. This original bill named specific portfolio standards (2.25% of peak load by 2015 and 5% by 2020). Over the next several months the original bill was modified - its specific standards were dropped in favor of allowing the CPUC to set its own goals after thorough review. In August 2010, it was passed by the California Senate. Finally, AB 2514 was signed into law by Governor Schwarzenegger on September 29, 2010. Throughout this process, lawmakers received considerable advice and support from the California Energy Storage Alliance (CESA). Although the CPUC has until January 1st, 2013 to establish specific targets, it has already begun the process and expects to reach a decision by the second quarter of 2012. After receiving feedback from California energy storage producers and utilities this January, the CPUC has launched a series of workshops aimed at determining how to best incorporate energy storage solutions into the California grid. It is not an easy task. The CPUC must confront local and federal regulatory barriers, limited performance data and the fact that energy storage has over ten applications, each of which carries a unique set of costs and benefits. While the CPUC can set the procurement targets at 0% - effectively nullifying AB2514 – its proactive attitude indicates that it will likely set high but achievable targets. AB 2514 is expected to have the following effects:
The development of energy storage technologies is expected to create more opportunities for producers of intermittent sources of renewable generation. Energy storage will stabilize power output from renewables and limit the need to the need to curtail excess power generation.
Energy storage will help to reduce peak demand. When combined with smart grid controls, energy storage systems can provide power during peak demand, which limits the need for new sources of generation to meet rising power demands. It can also lower electricity prices by avoiding the operation of expensive and inefficient fossil-fuel based plants during peak load.
Through minimizing the use of inefficient peaker plants during peak load and minimizing the amount of regulation provided by slow-responding fossil-fuel based generators, AB 2514 is expected to significantly lower greenhouse gas emissions.
When placed at congested nodes in the transmission system, energy storage systems can reduce transmission losses by as much as 50%. This will serve to improve the efficiency of California’s transmission systems.
Increased deployment of energy storage will create greater market certainty concerning the value and implementation of energy storage systems. Consequently, AB 2514 will push the adoption of similar policies worldwide.
California’s favorable policies will drive growth in its economy as more energy storage producers establish manufacturing facilities within the state.
California has led the charge in the adoption of renewable generation and energy storage technologies. It has the highest Renewable Portfolio Standard (RPS) in the country - California aims to get 33% of its energy from renewable sources by 2020. This will require a significant amount of energy storage to counteract the power fluctuations from solar and wind power. In recognizing this need, California is a hotspot for new energy storage demonstration projects. $74 million of the $185 million in ARRA funding for energy storage demonstration projects went to projects in California. The state’s support of this industry has helped stimulate its struggling local economy. In this regard, AB 2514 is expected to create 8,500 new jobs. California’s progressive policies have set the standard for other states and countries considering their own energy storage policies.
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Energy Storage Policy Progress: AB2514 Prior to AB 2514, energy storage has received limited government support, especially when compared to the solar and wind industries. In California, certain energy storage systems that are connected to fuel cell and wind sources of generation are eligible to receive purchase rebates under the Self-Generation Incentive Program (SGIP). However, the same rebates are not extended to standalone energy storage systems or those connected to PV panels, which has severely limited their adoption. In contrast, wind and solar producers have received generous support in the form of tax incentives, direct subsidies, feed-in tariffs and renewable portfolio standards. AB 2514 is expected to catalyze growth in the California energy storage market. If the CPUC chooses to adopt the original 2.25% standard, California will require 1.3 GW of energy storage by 2015 (based on California Energy Commission peak load growth estimates). This goal is very achievable. Not including pumped hydro storage, California already has over 20 MW of energy storage in operation, 400 MW slated to begin operation by 2015, and another 500 MW in the project pipeline. Energy storage procurement standards are expected to monetize certain benefits of energy storage that cannot be monetized by one user. One of the main problems confronting energy storage is that owner of an energy storage system is not compensated for the benefits provided to other stakeholders, such as transmission operators or power producers. By requiring utilities to incorporate a fixed amount of storage, AB2514 will ensure that the full value of energy storage can be captured. This essentially has the same effect as providing direct incentives, as illustrated in CESAâ&#x20AC;&#x2122;s graph. Monetizing Energy Storage Benefits Through Incentives
Figure 1 : This image from CESAâ&#x20AC;&#x2122;s policy presentation highlights how incentivizing energy storage helps to realize its total benefits.
There are many lessons to be learned from the development and implementation of AB 2514. From its inception till now, AB 2514 has received invaluable support from the California Energy Storage Alliance (CESA). The CESA worked closely with grid operators, energy storage producers and government officials to produce a policy that could capture the full value of energy storage in order to provide highly valuable grid stabilization services to Californiaâ&#x20AC;&#x2122;s rapidly changing grid. Their success in creating this policy illustrates the power that an industry alliance can wield. There are certain regions of China with high penetrations of wind and solar that are experiencing some of the same renewable energy integration problems as California. Grid operators in these regions could considerably benefit from policies similar to those advocated by the CESA. In order to reach a point where energy storage can play a serious role in resolving these issues, the CNESA believes that more demonstration projects must be conducted. This will allow grid operators to make better informed decisions concerning how to best integrate energy storage into the Chinese grid.
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Dong Fushan Island Completes Innovative Energy Storage Project Recently, a wholly-owned enterprise of China Guodian, Guodian Zhejiang Zhoushan Sea Wind Development Co., Ltd., completed construction on a wind, solar, energy storage and water desalination system integration project. This is China’s largest renewable energy project located within a remote and isolated grid. For this project, wind and solar are the primary sources of generation; they are supplemented by diesel generation during peak load.
pacity is 510 kW, including seven 30-kW wind turbines, one 100-kW PV system, several diesel generators totaling 200 kW, and 2000Ah worth of lead acid batteries. Power generated from this diverse set of generators passes through 10-kV transmission lines to the island’s inhabitants and armed forces. Power generated in excess of the inhabitant’s needs is used by the seawater desalination facility, which is capable of processing 50-tonnes of sea water per day. In remote locations like Dong Fushan Island, which rely on imported diesel to run generators, solar and wind generation offer a cheaper and more attractive alternative. However, controlling the power output from these variable sources of generation presents its own set of problems. Even though the Dong Fushan project’s energy storage system is relatively small, its significance lies in its ability to maximize the usage of generated power. During periods when generation exceeds the load of both the inhabitants and the desalination plant, the energy storage system absorbs power. This allows local grid operators to minimize the need for curtailment. This stored energy is later used to power the desalination plant during periods of low power generation.
Dong Fushan Island – located 50 km away from Zhoushan Main Island is China’s easternmost inhabited island. Because there are no connections to the main land or surrounding islands, the island’s inhabitants mainly depended on electricity produced by the island’s naval diesel generators. The island also has no fresh water resources. Residents relied on purified rainwater and water transported from Fushan Main Island. Thus, water and electricity usage became Dong Fushan Island’s most compelling problem in need of a solution. In December 2009, in order to guarantee local residents, tourists, and stationed soldiers water and electricity usage needs, China Guodian Zhejiang branch finalized a deal with the local government office.
Energy storage is extremely valuable in remote locations. Dong Fushan Island’s project is just one example of the many small scale projects that have been developed over the past few years. As energy storage technology prices continue to come down, more island communities and remote villages will be able to take advantage of energy storage’s unique capabilities in order to meet their power needs through the use This project broke ground in November 2010. Its total generation ca- of local, renewable sources of energy.
Zhangbei Energy Storage Project Names Lithium-ion ESS Providers The National Wind & Solar Renewable Integration Energy Storage Demonstration Project is the first of its kind under the “Golden Sun” program, a national policy aimed at increasing the use of solar generation advocated by the Ministry of Science and Technology. This project is organized and administered by the Huabei Electric Grid Co., Ltd. It aims to optimize generator control systems and unify system coordination. Through cohesively realizing the benefits of wind, solar and energy storage, it is hoped that this project will open the door for future large-scale renewable energy integration projects across the entire grid. This renewable integration demonstration project is located in Zhangbei, Hebei. In total, the project calls for 300-500 MW of wind generation, 100 MW of PV generation and 110 MW of energy storage. The total investment will amount to approximately 12 billion RMB (1.85 billion USD). After full installation, this project will become the world’s largest renewable integration test center that incorporates wind, solar energy storage. The first-stage of this project is currently underway. It calls for 100 MW of wind, 40 MW of solar, and 20 MW of energy storage. It will cost 3.3 billion RMB (460 million USD). Within the coming five months, the project is expected to enter into the centralization stage, with a focus on advancing civil engineering and construction. Energy storage providers for 14 out of the 20 MW have already been selected. A total of 12 lithium battery cell manufacturers
participated in the bidding process. The winning companies are expected to complete installation by August. Those companies are:
Storage Provider
Quantity
BYD Auto
6MW×6h
Dongguan New Energy Science & Technology Company
4MW×4h
China Aviation Lithium Battery Company
3MW×3h
Wanxiang Electric Car Company
1MW×2h
System Demands
Winning Bid (10,000元）
Energy storage system, two-way converter type according to the battery rated output power system’s 1.5 times configuration. Energy storage system, two-way converter type according to the battery rated output power system’s 1.5 times configuration.
14839.73
Power type energy storage system, two-way converter according to the battery rated output power system of 2 times configuration. Power type energy storage system, two-way converter according to the battery rated output power system of 2 times configuration.
6090.99
9
8456.0
1443.576
CNESA Update 2011/11 CNESA Issue 03 Month 06 Year 2011 Issue 01Issue Month Year 2011 CNESA Update 00 04 Month CNESA Year
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ABB Comissions First DynaPeaQ System ABB, the Swiss transmission and distribution technology specialist, announced the commissioning of its first DynaPeaQ energy storage system in Norfolk, England. This system is the first of what ABB hopes will form its flagship line of energy storage solutions. It is also rather unique. The system combines a static VAR compensator with a lithiumion battery system to provide dynamic voltage control and wind power stabilization services. This ABB DynaPeaQ system is located in an 11kV grid with a high penetration of wind power. ABB’s static VAR compensator, its SVC Light system, is used to provide near-instantaneous reactive power that stabilizes the voltage on the grid. When voltage drops due to a local fault or load change, it is possible for wind generators to trip in a cascading fashion, resulting in large amounts of wind generation dropping off the grid, which can lead to blackouts and other disturbances. The ability of wind farms to maintain operation during low voltage periods depends on their low-voltage ride-through capability. ABB’s SVC Light system provides reactive power that helps maintain voltage in order to avoid the cascading problem. When paired with a 600kW/200kWh Saft lithium-ion battery system, it creates a very versatile system capable of providing both active and reactive power, which ensures the stability of grids containing a large percentage of wind generation.
marks the first time that ABB has constructed its own energy storage system. Building upon the success of this 600kW/200kWh project, ABB plans to scale up its DynaPeaQ system. It claims the system can be scaled up to 50 MW for time periods ranging from 5 to 60 minutes. This will make it a strong competitor with other fast-response energy storage providers, including Beacon Power and Xtreme Power.
The relationship between ABB and China is quite close. In 2009, ABB earned $4.4 billion in revenues through business transactions in China, making China the largest market for ABB in the world. ABB is playing an integral role in State Grid’s plan to create high voltage power lines across the country. Considering that Chinese grid operators have strugAlthough ABB has participated in several energy storage demonstration gled with wind farm cascading, ABB’s DynaPeaQ system might just be projects prior to this, the commissioning of this DynaPeaQ system the innovative solution needed to fix this problem.
Nissan to Install Solar EV Charging Stations that Include Energy Storage Nissan announced that it will build 30 solar powered charging stations at its factory in Franklin, Tennessee. When completed this July, the charging stands, which feature energy storage, will be used to charge the company’s fleet of Nissan Leafs. This project is part of a larger $6.8 million project. By the end of 2012, Nissan plans to build 125 solar-powered charging stands in Tennessee. Thirty-six of these stations have already been built in the town of Oak Ridge. The project, which is being led by the Oak Ridge National Laboratory and partially funded by the U.S. Department of Energy, is a continuation is the charging infrastructure development program that began under the American Reinvestment and Recovery Act of 2009. The purpose of this project is to highlight the long-term opportunities for “second-life” electric vehicle battery applications. The charging stations will feature energy storage systems that use the same battery as those used on the Nissan Leaf - a manganese-type electrode lithium ion battery developed by AESC, a joint venture between Nissan and Japanese battery producer NEC. The Nissan Leaf’s battery pack features an 8-year 100,000 mile warranty, so applications for “second life” batteries are still several years away. Nissan has been investigating EV “second life” applications well before it released the Nissan Leaf. In 2009, Nissan set up a joint venture with Sumitomo Electric to explore “second life” applications for EV batteries. It is expected that EV batteries will start their “second life” when they can only be recharged to 70-80% of their original capacity. There are a variety of energy storage applications that can be filled by “second life” batteries including integration with residential and industrial solar systems, backup power, uninterruptible power supplies (UPS) and load shifting. The batteries used for pure electric vehicles have high energy density to power density ratios. This means that they are best suited to applications that require a constant flow of power over several hours as opposed to quick bursts of power of the course of several seconds. Systems built using “second life” batteries will most likely be competing with systems like NGK’s sodium-sulfur battery and large scale flow batteries. Some quick math reveals the massive market for “second life” applications. “Second life” batteries from 1 million electric vehicles with 24 kWh battery packs can provide 19.2 GWh of energy storage capacity (1,000,000 vehicles * 24 kW/h* 80% = 19.2 GWh). Given this massive potential, it makes sense to start planning early. This project is one many demonstrations being conducted over the next several years.
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CNESA Update 2011/11 CNESA Issue 03 Month 06 Year 2011 Issue 01Issue Month Year 2011 CNESA Update 00 04 Month CNESA Year
NewIndustry Developments Trends Industry Trends
Issue 01 Month 04 Year 2011
Primus Power Raises $11 Million Primus Power announced that is has raised $11 million to finance the further development of it zinc-chloride flow battery technology. This most recent financing round, which was led by I2BF Global Ventures and DBL Investors, also included existing investors Kleiner Perkins Caufield & Byers and Chrysalix Energy Venture Capital. Unlike traditional batteries, flow batteries operate by pumping liquid electrolytes through an electrochemical cell that react with one another to generate electrical current. Because the energy storage capacity depends largely on the size of the electrolyte storage tanks, flow batter- transmission and distribution investment deferral. The latest design ies are highly scalable and are ideal for applications that require long also boasts improved power output, 4-5 times higher than previous discharge cycles. They are also relatively expensive. generations. The high initial cost of flow battery demonstration systems has deterred investment. Primus Power is looking to remedy this by taking advantage of cheap, abundant materials and designing systems that can easily be mass-produced. It estimates that it will be able to produce its systems at a cost of $500/kWh, which is less than current flow battery systems. Primus Power’s latest generation of flow batteries takes a different approach from the behemoths of the past. Primus Power uses Energycells — small batteries which have an output of 20 kW. They are designed to be connected together to create large-scale energy storage systems. Primus Power hopes this modular approach will simplify the installation process and appeal to applications where transportability is a must, like
In 2009, Primus Power received a $14 million grant from the ARRA of 2009 to develop a 25MW/75MWh flow battery system in Modesto, California. The project, which will cost $46.7 million, will serve to solve the region’s wind power intermittency problems. This October, Primus plans to begin testing its EnergyPod, which will consist of 33 energy cells in a shipping container. If all tests go as planned, Primus Power will commission its 25MW/75MWh project sometime in 2013. Primus Power is one of over ten companies working on innovative flow battery systems that promise drastically reduced costs. Thus far, very few of these companies have brought their systems to market. This latest funding round reflects continued investor confidence in Primus’s unique approach.
Altairnano Leases New 1.8 MW ALTI-ESS Advantage System Altair Nanotechnologies announced that it has signed a threeyear lease agreement with U.S. energy company, Energy Storage Holdings LLC. Under this agreement, Altair Nanotechnologies will debut its new ALTI-ESS Advantage 1.8MW/300kWh system as part of a frequency regulation evaluation project in New Jersey. The system is expected to be installed by the end of 2011. Altair Nanotechnologies ALTI-ESS Advantage 1.8MW system is designed for high power applications. It delivers more power and has a smaller footprint than Altairnano’s previous ALTI-ESS system. The ALTI-ESS system delivered 1 MW of power for 15 minutes. In contrast, the new Advantage system delivers 1.8 MW for 10 minutes – this serves to reduce the cost per kilowatt of systems for frequency regulation service. Altairnano’s lithium-titanate batteries have far greater fast charge/discharge capability than other lithium ion batteries. It has an estimated 10 to 30 year lifetime for grid stabilization applications (16,000 full DOD cycles). This durability has made Altairnano batteries attractive for a variety of transportation and military applications Altairnano, which develops, manufactures and markets its proprietary lithium-titanate technology that has capacitor-like charge and discharge capabilities, was founded in 1999. Over the last several years, it has supplied its 1 MW ALTI-ESS for several demonstration projects with AES, including one at PJM headquarters that has been in continuous commercial operation since April 2009. However, AES has chosen A123 Systems for its most recent large-scale projects – most likely due to its lower price point. Despite this setback, Altairnano has several projects in the works. It will complete construction on a 1 MW wind integration project on Manoa, Hawaii later this year. It has also been working to resolve regulatory issues that have halted progress on an $18 million 10 MW frequency regulation project with INE in El Salvador. Since September, Zhuhai Yintong Energy has been working to purchase a 51% stake in Altairnano through Canon Investment Holdings Limited. However, the initial agreement has been amended several times. The end date for the current share subscription agreement is July 8th. If Zhuhai Yintong goes through with this deal, it is expected to manufacture Altairnano’s technology is China. This will not only serve to lower the production costs of Altairnano’s batteries but also boost Zhuhai Yintong’s position in the Chinese energy storage market.
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CNESA Update 2011/11 CNESA Issue 03 Month 06 Year 2011 Issue 01Issue Month Year 2011 CNESA Update 00 04 Month CNESA Year
NewIndustry Developments Trends Industry Trends
Issue 01 Month 04 Year 2011
ESA and AWEA Release Joint Principles One of the most promising results to emerge from this year’s Energy Storage Association Conference was a set of jointly agreed-upon principles from the Energy Storage Association (ESA) and the American Wind Energy Association (AWEA). These two organizations are the largest and most influential trade associations of their respective fields. Their agreed-upon principles recognize the symbiotic relationship between energy storage and wind energy. This pact will almost certainly lead to new policies encouraging the use of energy storage to complement wind integration. According to the CEO of AWEA, Dennis Bode: Large amounts of wind energy are being reliably and cost-effectively integrated onto the power system today. Energy storage can be a valuable resource for the power system in maximizing the efficient use of this resource, and add flexibility for electric utilities. We look forward to working closely with ESA on regulatory policy that will enable these growing industries to fully benefit both consumers and the economy of the U.S.
The joint principles include these statements: Wholesale energy markets and ancillary services markets should be created and expanded, and barriers to entry into those markets eliminated; Market and operating rules should be based around the type of service needed, and any technology that is able to reliably provide a needed service should be able to provide it. In many cases, previously bundled services should be disaggregated; and Low-cost grid operating reforms that will create more competition and make the grid operate more efficiently, such as greater balancing, should be implemented as soon as possible. These joint principles address the problem of asset classification within the US grid. Energy storage systems can simultaneously provide services to the generation, transmission and distributions systems, which make them subject to a range of limiting and often contradictory regulations. By classifying energy storage systems by the services provided instead of their location within the grid, they can provide wider range of services – not the least of which is to stabilize the power output of wind farms. With regard to the Chinese grid, these joint principles will lead to more wind integration projects in the US, which will subsequently serve as models for Chinese grid operators struggling to resolve their own wind integration issues.
General Compression Raises $54.4 Million On June 7th, compressed air energy storage technology developer, General Compression, announced that it raised $54.5 million during the first tranche of its Series B funding round, led by Northwater Capital Management. General Compression’s previous investors included the American utility company Duke Energy, and oil company ConocoPhillips - both whom are now collaborating with General Compression on its first demonstration project. This most recent round of funding will be used to further develop General Compression’s technology and boost its manufacturing capacity as it prepares for its first demonstration project as well as several others in its pipeline. According to General Compression CEO, Eric Ingersoll: The closing of the first tranche of our Series B Round leaves General Compression well-positioned to quickly ramp up our supply chain activity and to develop full-scale Dispatchable Wind™ projects. We’re very excited about the market opportunities we see, and thankful for the continued support of our investors.
Since 2006, General Compression has been developing its proprietary isothermal CAES technology. There are several features that separate General Compression’s technology from previous underground CAES systems. First and foremost, General Compression claims that its system can switch from ‘idle’ to ‘operational’ in less than six seconds and can switch between ‘compression’ and ‘expansion’ modes in less than a
second. This opens up a range of fast-responding energy storage applications, such as frequency regulation and other ancillary services. Second, the system does not use fuel. This should make it easier to permit and more environmentally friendly. Third, the system is modular – large systems will be composed of 2 MW units that are operated independently, which increases the reliability of the overall system and makes performing maintenance easier. General Compression is currently working on its first demonstration project. Later this year, it will deploy a prototype system for field testing in Texas with its development partner ConocoPhillips. The system is expected to have an efficiency of around 70%. It will lay the foundation for the commercialization of General Compression’s system – something it hopes to accomplish by the end of 2012. General Compression is an ARPA-E success story. In 2010, it received an ARPA-E grant of $750,000 to test an improved version of its technology. After receiving this grant, General Compression has attracted over $65 million in private investment and has added several projects to its pipeline. General Compression estimates that it will be able to produce its systems for $1,200/kW. Depending on the size of the underground cavern, this system may be as cheap as $10/kWh. If this low price point can be realized, it will make General Compression’s system one of the most affordable to date.
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CNESA CNESA Update Issue 03 Month2011/11 06 Year 2011
Industry Trends
Mitsubishi Develops Japan’s First Transportable Large-scale System On June 18th, Mitsubishi Heavy Industries announced that it has developed Japan’s first large-capacity transportable energy storage system. This 1 MW/.408MWh lithium-ion system, which includes power control systems, is contained within a 20-ft container mounted onto a trailer. By making the system transportable, Mitsubishi hopes to capture several high value applications, including emergency backup and renewable integration. Testing of the system will begin this July at Mitsubishi’s Nagasaki Shipyard and Machinery Works. This most recent energy storage project is part of an ongoing $76 million research and development project announced in May of 2010. As part of this program, Mitsubishi is conducting a solar integration project, which combines a 4 MW PV system with a 500 MW energy storage solution in Amagasaki, Japan. Mitsubishi is also developing household energy storage systems – its first project, an apartment building in Kokubunji, Tokyo is expected to be ready for occupancy in early 2012. These projects are the first step towards the commercialization of a wide range of energy storage solutions. While these systems were originally scheduled to reach commercialization by mid to late 2012, the power shortages resulting from the failure of Fukushima have motivated Mitsubishi to speed up its product development to meet Japan’s domestic demand. Mitsubishi’s systems will also be tailored to specific opportunities that it has identified in overseas markets. In Europe, Mitsubishi sees growth opportunities for solar and solar-integrated energy storage systems. In China and North America, Mitsubishi has identified transmission and distribution upgrades as a strong growth market. Finally, in South-east
Asia, Mitsubishi sees room for strong growth in comprehensive smart grid packages. It is unclear which markets Mitsubishi will target with this 1 MW transportable system. On one hand, transportable systems are ideal for transmission and distribution deferral, which has been identified by the U.S Electric Power Research Institute (EPRI) as the second most valuable energy storage application. By using energy storage systems to supply additional capacity at locations where load has exceeded the capabilities of the transmission equipment, grid operators can delay costly upgrades for several years. The avoided cost of the transmission equipment upgrade is substantial (~$1,700/kW-h). After several years, the upgrade can be performed and the storage system moved to a new location on the grid. On the other hand, the specifications of Mitsubishi’s system do not match the requirements for a T&D deferral system. T&D deferral systems effectively provide peak shaving service, which calls for energy storage systems that can provide power for several hours during peak demand. Mitsubishi’s system has a discharge time of less than 30 minutes, making it unsuitable. The high value applications targeted by Mitsubishi are difficult to discern.
S&C Electric Announces Two New Projects S&C Electric is ready to bring its energy storage solutions to market. This June, S&C announced two new projects totaling 3MW/18MWh. It will build two 1 MW systems in Golden and Field, Canada and a 1 MW system on Catalina Island, just off the coast of Los Angeles, California. These projects are part of S&C’s larger plan to install 12 MW of energy storage systems this year. For both of these projects, S&C is targeting markets with small, constrained grids that rely on expensive diesel generators. On June 11, BC Hydro and S&C Electric announced that they will partner to provide 1 MW energy storage systems to two remote towns in the Canadian Rocky Mountains. These systems will be used to supplement diesel generation during peak load, resulting in emissions reduction and fuel savings. They will also serve to increase the reliability of the local network by providing backup during power outages. The projects, which will cost $15 million, are expected to be completed by the Spring of 2012. On June 27, electric utility Southern California Edison awarded S&C Electric a contract to build a turnkey 1-MW S&C Smart Grid SMS™ Storage Management System on Catalina Island. Similar to the Canadian projects, this system will support diesel generation. When paired with energy storage, diesel generators can operate at constant RPMs, which can optimize performance and reduce emissions. It will also ensure power reliability for the island’s 3,000 residents and numerous visitors. Since 2006, global power systems provider, S&C Electric, has been conducting a range of energy storage demonstrations utilizing sodium-sulfur batteries from Japanese producer NGK Insulators. Through these projects, which also total 12 MW, S&C has fine-tuned its power control systems and control software. As a result, it has become a global expert in “islanding” and peak shaving applications using this technology. S&C’s latest projects clearly illustrate its intention to become the leading provider of turnkey sodium-sulfur energy storage system in the North American market. There are over 250 MW of NGK’s batteries installed worldwide, giving them the largest market share of the advanced energy storage market. S&C’s deep understanding of this technology gives it a distinct advantage over competitors pursuing similar projects.
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CNESA Update 2011/11 CNESA Issue 03 Month 06 Year2011 2011 Issue 01 Month Year CNESA Update Issue 00 04 Month CNESA Year
Industry Industry Trends Trends
Issue 01 Month 04 Year 2011
About Our Organization The China Energy Storage Alliance, CNESA, is the first and only energy storage industry association in China. It is a nonprofit member-based organization, that was founded in 2010 as a sub-committee under China New Energy Chamber of Commerce (CNECC), the largest renewable group in China. Our mission is to influence government policy in order to encourage healthy growth of renewable energy through the use of competitive and reliable energy storage systems. As part of this mission, we regularly track both technology development and policy directions to provide proposals and commentary to members of government and the state grid system. We also encourage cooperation between international and domestic market participants through publications, annual forums, and informal round-table discussions. We use our resources to communicate the most up-to-date market trends to our members, help them find market opportunities and provide a bridge to investors and government officials in China. This newsletter - published in both Chinese and English - is one of the services that we provide to our members. The first three issues will be provided free of charge in order to spread awareness. If you are interested in joining our alliance or learning more about our organization, please contact us. Sincerely,
Shore Lin Managing Director China Energy Storage Alliance
Contact Information:
For English, please call or email Kevin Popper, Industry Research Manager
China Energy Storage Alliance
Kevin.popper@cnesa.org
Suite 5 Floor 12B Tower B
(+86) 1065667066
No. 6 Jianhuanan Rd Chaoyang District, Beijing, China 100022
For Chinese, please call or email Liu Wei, Head of Member Relations Wei.liu@cnesa.org (+86) 1065667066
Disclaimer In the preparation of the information contained in this document, CNESA has endeavored to present information that is as accurate and current as possible from sources believed to be reliable. However, unintentional errors can occur. Therefore, the information is provided â&#x20AC;&#x153;as isâ&#x20AC;?, without any representation or warranty of any kind, expressed or implied. Should you discover any errors or misrepresentations, please contact us at the address provided above.
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