Case Study - Redflow · REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page v The use of RedFlow’s ESS reduces the traditional peak seen by the grid by 10-15%

Case Study

Utility-Owned Smart Grid Smart Grid, Smart Cities

Trial 1 March – 31 May 2012

11 July 2012

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page ii

Background

The Australian Government has chosen Ausgrid to lead a $100 million initiative across five sites in

Newcastle, Sydney and the Upper Hunter regions (see Figure 1). Smart Grid, Smart City creates a

testing ground for new energy supply technologies. At least 30,000 households will participate in

the project over three years.

The demonstration project gathers information about the benefits and costs of different smart grid

technologies in an Australian setting. Building a smart grid involves transforming the traditional

electricity network by adding a chain of new, smart technology. It includes smart sensors, new back-

end IT systems, smart meters and a communications network.

RedFlow has won the bid to supply 61 energy storage systems (ESS) to Ausgrid for installation in

Newcastle, Scone and Newington in Sydney. 40 of these were installed in Newcastle in late 2011

and early 2012, with the other 20 ESS installed in Scone in April 2012. One ESS has also been

operational in Newington since 2010 as part of the ongoing Smart Home sub-project. The 40

systems in Newcastle have been operating since February 2012 and have been feeding into the grid

during peak demand periods. The 20 systems in Scone have been operational since mid-May 2012.

Figure 1: The locations and highlights of the Smart Grid, Smart City Trial [1]

RedFlow’s ESS are based on its core zinc bromide module (ZBM) flow battery technology. Each ESS

contains one ZBM, battery management system (BMS), remote terminal unit (RTU), inverter and 3G

modem for communications. All components are housed in a metal enclosure installed near

customer houses on private property.

40 RedFlow ESS

20 RedFlow ESS

1 RedFlow ESS

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page iii

Summary

Increases in both general and peak electricity demand, the integration of intermittent and

distributed generation, and developments in communications technology have all enabled, as well

as necessitated a more advanced electricity network. This moves away from the traditional uni-

directional grid, with central generation and one-way communications. As such, utilities have seen

Smart Grids as an answer to the need for greater grid capacity, as well as allowing transmission and

distribution infrastructure upgrade deferral. According to the Electric Power Research Institute

(EPRI), a Smart Grid “integrates and enhances other necessary elements including traditional

upgrades and new grid technologies with renewable generation, storage, increased consumer

participation, sensors, communications and computational ability” [2].

The use of energy storage in Smart Grids can provide utilities with many benefits, including

improved operational efficiency and increased value of distributed generation, thereby improving

customer satisfaction [3]. This is done through the time-shifting of electricity from low demand, as

well as times of high distributed generation output, to high demand times.

However, despite the many benefits of energy storage, existing proven technologies are either

inappropriate for Smart Grid applications (in the case of lead acid batteries), or are physically

impossible to implement on a large scale in a variety of areas (in the case of pumped hydro or

compressed air energy storage (CAES)). As such, new and advanced technologies are emerging to

satisfy this new market. These must be trialed and tested to ensure that they are both reliable and

align with the needs of utilities.

As such, the Australian Government has initiated, and is currently funding the Smart Grid, Smart

Cities (SGSC) Trial. It aims to test several hypotheses about many types of Smart Grid technology. In

particular, the Trial aims to quantify the following seven benefits of energy storage:

1. Reduction in peak demand – energy storage as a cost-effective and reliable alternative to

network capacity expansion

2. Improvement in network reliability/voltage/power factor/power quality – cost-

effectiveness and value of energy storage

3. Energy supply during peak price events – net benefit to retail sector

4. Minimisation of customers’ energy bills – with innovative tariffs e.g. time of use together

with energy storage.

5. Combined benefit between consumer, retail and network sectors

6. Investigation of large capacity (~1MVA) storage – extra cost and other benefits compared

to smaller capacity storage

7. Intermittent generation support – optimisation of renewable energy sources value

RedFlow has been selected as one of several advanced energy storage companies to supply energy

storage systems (ESS) for the trial to test these seven benefits of energy storage to Smart Grids. The

ESS supplied for the Trial by RedFlow are the zinc-bromide module (ZBM)-based R510 model (see

Appendix B – R510 Product Brochure). These systems are rated at 5kW, 10kWh, and comprise one

ZBM, inverter, 3G modem for communications, battery management system (BMS), remote terminal

unit (RTU) and other power electronics housed in a metal enclosure (see Figure 8).

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page iv

Figure 2: Components of RedFlow's R510 ESS

61 R510 ESS have been installed and commissioned on separate residential properties as part of the

SGSC Trial. The ESS have been staggered in their installations, with all systems operational since

mid-May 2012. The operational results and benefits of RedFlow’s ZBM-based ESS were analysed,

and the lessons learnt presented. This produced the following key conclusions:

Over the period between 1 March and 31 May 2012, the R510 ESS installed for the SGSC trial

have outputted a total of 14.334MWh to the grid at an average efficiency of 58.03%. This is

shown in the graph below in Figure 12.

Figure 3: Total grid import and export over the trial period with average monthly efficiency

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ZBM

Inverter

SMA Sunny Backup

Enclosure

1850 H x 971 L x 567 W

Power Electronics

Including BMS, RTU,

3G Modem

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page v

The use of RedFlow’s ESS reduces the traditional peak seen by the grid by 10-15% when used

in a ratio of approximately 1 ESS for 16 customers during cooler months (see Figure 4).

Figure 4: Results from the Melinda Avenue feeder in Newcastle show a reduction in peak demand of over 15% with the

use of RedFlow's ESS during traditional peal times

The use of RedFlow’s ESS transforms the traditional evening peak seen by the grid to a

trough when used in a ratio of approximately 1 ESS for 1 customer during cooler months

(see Figure 5).

Figure 5: Results from the Scone feeder in mid-June show a transformation from peak to trough with the use of

RedFlow's ESS during traditional peak times

Research and Development already undertaken by RedFlow shows that its kW-scale ESS can

be scaled up to MW-scale systems (see Figure 6).

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Grid-Feed

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Grid Charge Period 28kW

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Grid-Feed Period – Monday 9 April 2012

Real Power (kW) with Storage Real Power (kW) without Storage

Peak Reduction

15.19%

65 Residential Customers 4 R510 ESS


13 Residential Customers

15 R510 ESS

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page vi

Figure 6: RedFlow's M90 90kW, 180kWh ESS was installed at the University of Queensland in late May 2012

RedFlow’s ESS perform well when integrated with intermittent solar generation, as well as

more reliable fuel cell distributed generation

Figure 7: The SGSC trial in Newcastle has integrated a total of 200kW of solar and 50kW of Blue Gen fuel cell generation

with 40 RedFlow ESS

3 Solar

12 Solar

2 Solar

15 Solar

5 Solar

3 Solar

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page vii

Contents

Background ............................................................................................................................................. ii

Summary ................................................................................................................................................ iii

Contents ................................................................................................................................................ vii

List of Figures ....................................................................................................................................... viii

1 Introduction .................................................................................................................................... 1

2 Operation ........................................................................................................................................ 5

2.1 Newcastle ................................................................................................................................ 5

2.2 Scone ....................................................................................................................................... 5

2.3 Newington ............................................................................................................................... 5

3 Results ............................................................................................................................................. 6

3.1 Newcastle ................................................................................................................................ 6

3.1.1 Peak Demand Reduction ................................................................................................. 6

3.1.2 Reliability ......................................................................................................................... 8

3.2 Scone ....................................................................................................................................... 9

3.2.1 Peak Demand Reduction ................................................................................................. 9

3.2.2 Reliability ....................................................................................................................... 10

3.3 Newington ............................................................................................................................. 10

3.3.1 Load Following .............................................................................................................. 10

3.3.2 Reliability ....................................................................................................................... 11

4 Lessons Learnt ............................................................................................................................... 12

4.1 Newcastle .............................................................................................................................. 12

4.2 Scone ..................................................................................................................................... 12

4.3 Newington ............................................................................................................................. 13

5 Conclusions ................................................................................................................................... 14

6 References .................................................................................................................................... 15

Appendix A – List of Abbreviations ....................................................................................................... 16

Appendix B – R510 Product Brochure ................................................................................................... 17

Appendix C– List of Trial Sites ............................................................................................................... 20

Appendix C1 – List of Newcastle Sites .............................................................................................. 21

Appendix C2 – List of Scone Sites ..................................................................................................... 23

Appendix D – Cycle Profiles .................................................................................................................. 24

Appendix E – Newcastle Reduction in Peak Demand ........................................................................... 25

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page viii

List of Figures

FIGURE 1: THE LOCATIONS AND HIGHLIGHTS OF THE SMART GRID, SMART CITY TRIAL [1] II

FIGURE 2: COMPONENTS OF REDFLOW'S R510 ESS IV

FIGURE 3: TOTAL GRID IMPORT AND EXPORT OVER THE TRIAL PERIOD WITH AVERAGE MONTHLY EFFICIENCY IV

FIGURE 4: RESULTS FROM THE MELINDA AVENUE FEEDER IN NEWCASTLE SHOW A REDUCTION IN PEAK

DEMAND OF OVER 15% WITH THE USE OF REDFLOW'S ESS DURING TRADITIONAL PEAL TIMES V

FIGURE 5: RESULTS FROM THE SCONE FEEDER IN MID-JUNE SHOW A TRANSFORMATION FROM PEAK TO

TROUGH WITH THE USE OF REDFLOW'S ESS DURING TRADITIONAL PEAK TIMES V

FIGURE 6: REDFLOW'S M90 90KW, 180KWH ESS WAS INSTALLED AT THE UNIVERSITY OF QUEENSLAND IN LATE

MAY 2012 VI

FIGURE 7: THE SGSC TRIAL IN NEWCASTLE HAS INTEGRATED A TOTAL OF 200KW OF SOLAR AND 50KW OF

BLUE GEN FUEL CELL GENERATION WITH 40 REDFLOW ESS VI

FIGURE 8: COMPONENTS OF REDFLOW'S R510 ESS 2

FIGURE 9: INSTALLATION OF AN ESS IN NEWCASTLE 2

FIGURE 10: THE LOCATIONS OF THE REDFLOW ESS IN NEWCASTLE, WITH THE FUEL CELL GENERATION

CONNECTED TO EACH FEEDER 3

FIGURE 11: THE R510 ESS INSTALLED AT THE SMART HOME IN NEWINGTON, SYDNEY 4

FIGURE 12: TOTAL GRID IMPORT AND EXPORT OVER THE TRIAL PERIOD WITH AVERAGE MONTHLY EFFICIENCY

6

FIGURE 13: A TYPICAL FEED-IN CURVE FOR THE 4 ESS ON THE MELINDA AVENUE FEEDER 6

FIGURE 14: THE REDUCTION IN PEAK DEMAND SEEN BY THE GRID (4PM-10PM) IN MAY ON THE MELINDA

AVENUE FEEDER 7

FIGURE 15: REDUCTION IN PEAK DEMAND SEEN BY THE MELINDA AVENUE FEEDER DURING TRADITIONAL

PEAK TIMES 7

FIGURE 16: THE PEAKS CAUSED BY AUTOMATIC HOT WATER SYSTEMS ON THE MELINDA AVENUE FEEDER 8

FIGURE 17: AVAILABILITY OF ZBMS AND ESS IN NEWCASTLE 8

FIGURE 18: AVERAGE POWER ON THE SCONE RECLOSER 14 TO 18 MAY (BEFORE REDFLOW ESS COMMENCED

FULL OPERATION) 9

FIGURE 19: AVERAGE POWER ON THE SCONE RECLOSER 18 TO 22 JUNE (WITH REDFLOW ESS OPERATIONAL) 9

FIGURE 20: AVAILABILITY OF ZBMS AND ESS IN SCONE 10

FIGURE 21: THE ESS CAN DYNAMICALLY FOLLOW THE LOAD, AND ANY SUDDEN CHANGES TO GENERATION 10

REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page 1

1 Introduction

Increases in both general and peak electricity demand, the integration of intermittent and

distributed generation, and developments in communications technology have all enabled, as well

as necessitated a more advanced electricity network. This moves away from the traditional uni-

directional grid, with central generation and one-way communications. As such, utilities have seen

Smart Grids as an answer to the need for greater grid capacity, as well as allowing transmission and

distribution infrastructure upgrade deferral. According to the Electric Power Research Institute

(EPRI), a Smart Grid “integrates and enhances other necessary elements including traditional

upgrades and new grid technologies with renewable generation, storage, increased consumer

participation, sensors, communications and computational ability” [2].

The use of energy storage in Smart Grids can provide utilities with many benefits, including

improved operational efficiency and increased value of distributed generation, thereby improving

customer satisfaction [3]. This is done through the time-shifting of electricity from low demand, as

well as times of high distributed generation output, to high demand times.

However, despite the many benefits of energy storage, existing proven technologies are either

inappropriate for Smart Grid applications (in the case of lead acid batteries), or are physically

impossible to implement on a large scale in a variety of areas (in the case of pumped hydro or

compressed air energy storage (CAES)). As such, new and advanced technologies are emerging to

satisfy this new market. These must be trialed and tested to ensure that they are both reliable and

align with the needs of utilities.

As such, the Australian Government has initiated, and is currently funding the Smart Grid, Smart

Cities (SGSC) Trial. It aims to test several hypotheses about many types of Smart Grid technology. In

particular, the Trial aims to quantify the following seven benefits of energy storage:

8. Reduction in peak demand – energy storage as a cost-effective and reliable alternative to

network capacity expansion

9. Improvement in network reliability/voltage/power factor/power quality – cost-

effectiveness and value of energy storage

10. Energy supply during peak price events – net benefit to retail sector

11. Minimisation of customers’ energy bills – with innovative tariffs e.g. time of use together

with energy storage.

12. Combined benefit between consumer, retail and network sectors

13. Investigation of large capacity (~1MVA) storage – extra cost and other benefits compared

to smaller capacity storage

14. Intermittent generation support – optimisation of renewable energy sources value

RedFlow has been selected as one of several advanced energy storage companies to supply energy

storage systems (ESS) for the trial to test these seven benefits of energy storage to Smart Grids. The

ESS supplied for the Trial by RedFlow are the zinc-bromide module (ZBM)-based R510 model (see

Appendix B – R510 Product Brochure). These systems are rated at 5kW, 10kWh output, and

comprise one ZBM, inverter, 3G modem for communications, battery management system (BMS),

remote terminal unit (RTU) and other power electronics housed in a metal enclosure (see Figure 8).


Figure 8: Components of RedFlow's R510 ESS

61 R510 ESS have been installed (see Figure 9) and commissioned on separate residential properties

as part of the SGSC Trial. This includes 40 systems in Newcastle (see Figure 10), which were installed

throughout late 2011 and early 2012. All systems were operational by February 2012, and operate

on four different charge/discharge cycles with the aim of reducing the peak load seen by the grid in

these suburban areas. They are also integrated with solar and fuel cell distributed generation.

Figure 9: Installation of an ESS in Newcastle

ZBM

Inverter

SMA Sunny Backup

Enclosure

1850 H x 971 L x 567 W

Power Electronics

Including BMS, RTU,

3G Modem


Figure 10: The locations of the RedFlow ESS in Newcastle, with the fuel cell generation connected to each feeder

Twenty systems were installed in Scone (a map cannot be given for privacy reasons) in early 2012,

and were operational by May 2012. These systems are located at fringe-of-grid areas, and are being

used to test islanding aspects of a Smart Grid, as well as integration with wind turbines.


One R510 ESS (see Figure 11) has also been in operation since October 2011 in Ausgrid’s Smart

Home, located in the suburb of Newington in Western Sydney. It was installed as an upgrade to an

existing RedFlow lead-acid system that was installed in mid-2010, with a ZBM installed in late 2010

to augment the lead acid storage. This ESS originally operated on a daily charge/discharge cycle,

which was followed by a zero import/export from the grid mode with the installation of the R510.

This has recently been modified to a hybrid cycle including both forced charge/discharge, as well as

dynamic load following.

Figure 11: The R510 ESS installed at the Smart Home in Newington, Sydney

This Case Study provides an overview and analysis of the performance of RedFlow’s R510 ESS in their

Smart Grid applications. It will cover the period of 1 March to 21 May 2012. It has been divided into

the sections of Operation, Results and Lessons Learnt. Each section addresses the three locations of

Newcastle, Scone and Newington separately.

Appendix A contains a list of abbreviations used in this Case Study.

Appendix B contains a Product Brochure for RedFlow’s R10, outlining key specifications of the ESS.

Appendix C contains a list of all sites testing energy storage in the SGSC trial (see Appendix D for an

explanation of schedule profiles).

Appendix D contains a list of charge and discharge schedule profiles.

Appendix E contains a large graph of peak reduction data from Newcastle.


2 Operation

2.1 Newcastle The 40 R510 ESS installed in Newcastle were located in suburban areas, which generally experiences

a very high standard of power quality. However, in relation to the installation of further embedded

generation (e.g. fuel cells and extra solar panels), the value and capabilities of energy storage in

meeting these non-traditional challenges to the grid were tested.

As such, the ESS were set to charge from and discharge into the grid at set times every weekday.

The ESS did not operate at all (apart from discharging in the early hours of each Saturday) on

weekends. This time schedule was varied between four different profiles: Profile A, Profile B, Profile

C and Profile D (see Appendix D). 10 ESS operated on each profile (see Appendix C1).

The efficiency and reliability of the R510 ESS in reducing the peak demand seen by the grid was

tested. The results of this are presented in Section 3.1.

2.2 Scone The 20 R510 ESS installed in Scone were located in fringe of grid areas, which generally experiences a

lesser standard of power quality than those areas in Newcastle. As such, the islanding abilities of the

ESS were tested, as well as their ability to limit peaks seen by the grid.

The ESS did not operate at all (apart from discharging in the early hours of each Saturday) on

weekends. This time schedule was varied between two different profiles: Profile E and Profile F, (see

Appendix D). 6 ESS operated on Profile E, and 14 ESS operated on Profile F (see Appendix C1).

2.3 Newington The R510 ESS installed in Newington is located in a suburban area, which generally experiences a

very high standard of power quality. While the ESS at Newington has operated under several types

of cycles, it is currently operating under Profile G (see Appendix D). When it is in the load following

mode, the ESS discharges power to the household load if the generation from the solar panels and

the fuel cell in insufficient, and charges from any excess generation that exceeds the household load.

The efficiency and reliability of the R510 ESS in reducing the peak demand of the Smart Home seen

by the grid was tested. The results of this are presented in Section 3.3.


3 Results Over the period between 1 March and 31 May 2012, the R510 ESS installed for the SGSC trial have

outputted a total of 14.334MWh to the grid at an average efficiency of 58.03%. This is shown in the

graph below in Figure 12.

Figure 12: Total grid import and export over the trial period with average monthly efficiency

3.1 Newcastle

3.1.1 Peak Demand Reduction The ESS installed in Newcastle have had significant impact on the peak demand seen by the grid.

Analysis has shown that during the cooler Autumn months, a ratio of 4 ESS to 65 residential

customers produced reductions of peak demand seen by the grid during the traditional peak period

(between the hours of 4pm and 10pm on weeknights) by an average of 5.39% in May. This is with 4

ESS operational for most of the month (1 ESS recommenced operation on 10 May after being out of

service since the start of the month), and therefore a ratio of approximately 1 ESS for 16 customers.

A typical output curve of the cumulative ESS is shown in Figure 13.

Figure 13: A typical feed-in curve for the 4 ESS on the Melinda Avenue feeder

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3 ESS on Profile A

feed in 9kW total 1 ESS on Profile B

feeds in 3kW

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are almost flat


However, the irregularity of this curve results in only very small peak reductions when peaks occur

around 7pm, or after 9pm. The variability in peak reduction can be seen in Figure 14.

Figure 14: The reduction in peak demand seen by the grid (4pm-10pm) in May on the Melinda Avenue feeder

Despite this, the ESS have been capable of achieving peak reduction of about 15% (see Figure 15). A

grid peak demand graph for the week of Monday 9 April 2012, showing similar results, is given in

Appendix E.

Figure 15: Reduction in peak demand seen by the Melinda Avenue feeder during traditional peak times

However, in this particular area of Newcastle, many homes are fitted with automatic hot water

systems that are set to charge at 11pm. As can be seen in Figure 16, this causes a much larger peak

than that seen during traditional peak periods, when the ESS are discharging into the grid.

Therefore, while the ESS are effectively reducing the traditional evening peak, they are not

addressing the actual peaks see by the grid.

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Grid-Feed Period – Monday 9 April 2012


Peak Reduction

15.19%


4 R510 ESS

Peak occurs at

times of low ESS

feed-in power


Figure 16: The peaks caused by automatic hot water systems on the Melinda Avenue feeder

This highlights the importance of thorough load profiling prior to setting charge/discharge profiles

for residential ESS aimed at reducing peaks in demand seen by the grid. In the case of the Newcastle

ESS involved in the SGSC trial, this would have raised two main issues. Firstly, the ESS should be

discharging between about 11pm and 2am to reduce the true peak caused by the hot water systems.

Furthermore, the discharge profiles should be more appropriately staggered to achieve a smoother

collective output curve, that discharges more power during times when the load curve is normally

highest. These measures would aid in reducing the peak demand seen by the grid even more than

the significant reductions already provided by the ESS.

3.1.2 Reliability As the ZBM is still an emerging technology, the reliability of the R510 is an important aspect of

evaluating its value in Smart Grid applications of energy storage. As can be seen in Figure 17, the

vast majority of ZBMs were available for operation throughout the study period, showing that ZBM

failure is not the main cause for making ESS unavailable.

Figure 17: Availability of ZBMs and ESS in Newcastle

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Newcastle ZBM Available Newcastle ESS Available

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Effect of Hot Water Systems


Peak Reduction shown in Figure 15


4 R510 ESS

43.29% increase of traditional

evening peak

Monday 9 April Tuesday 10 April


3.2 Scone

3.2.1 Peak Demand Reduction The ESS installed in Scone have had significant impact on the peak demand seen by the grid. This is

due in part to the high ratio of ESS to customers (just over 1 ESS per customer) in this semi-rural

area. Analysis has shown that during the cooler Autumn and Winter months, the usual evening peak

seen by the grid (see Figure 18) is transformed into a noticeable trough with the use of RedFlow’s

ESS (see Figure 19).

Figure 18: Average power on the Scone recloser 14 to 18 May (before RedFlow ESS commenced full operation)

Figure 19: Average power on the Scone recloser 18 to 22 June (with RedFlow ESS operational)

However, it can also be seen that peaks occur very late at night, and in the early morning due to

automatic off-peak hot water systems turning on. However, these hot water system peaks are not

significantly larger in magnitude than the traditional morning and evening peaks.

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Period 45kW




15 R510 ESS



3.2.2 Reliability As the ZBM is still an emerging technology, the reliability of the R510 is an important aspect of

evaluating its value in Smart Grid and islanding applications of energy storage. As can be seen in

Figure 20, the vast majority of ZBMs were available for operation throughout the study period,

showing that ZBM failure is not the main cause for making ESS unavailable.

Figure 20: Availability of ZBMs and ESS in Scone

3.3 Newington

3.3.1 Load Following Results, such as those presented in Figure 21, show that the R510 ESS can charge and discharge

according to the needs of the load, as well as discharge when interruptions to normal generation

occur. This is known as load following.

Figure 21: The ESS can dynamically follow the load, and any sudden changes to generation

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Percentage of Scone ZBM and ESS Available

Scone ZBM Available Scone ESS Available

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Blue Gen Fuel Cell Outage Performance

InvPwrAt [kW] Blue Gen Power Total Usage

Fuel cell

outage

ZBM discharges

to satisfy load

ZBM discharges in preparation to strip


3.3.2 Reliability The R510 at Newington was installed on 5 October 2011. It engaged in daily operation until 20

December, when it was shut down because its ZBM’s health was deteriorating and a fault was

expected to soon occur. Soon after, the resident family moved out of the Smart Home and Ausgrid

suspended the operation of most of the Smart Home’s elements while it underwent upgrades and

maintenance. The R510 ESS was kept shut down until late March when the ZBM was replaced. After

a series of calibration and test cycles, the ESS was shut down again until the new resident family

moved into the Smart Home on 28 April, at which point the ESS recommenced operation. It has not

experienced a fault since this time.

At the end of May 2012, the new ZBM installed at the Smart Home had undertaken 48 cycles (of less

than 100% depth of discharge due to the shortage of excess generation from the Smart Home to

charge the ZBM), and outputted 87.23kWh.


4 Lessons Learnt

4.1 Newcastle The 40 systems in Newcastle were the first R510s to be installed on a large scale for RedFlow. As a

result of this, and early operation, the following important points were observed for future work in

the area.

The use of specialist installers, O’Donnell Griffin (ODG), has been highly beneficial in the roll-

out of ESS to Newcastle. This brought expertise to the project that RedFlow did not have,

and will be used in future large-scale trials. Small issues with Newcastle installations shaped

changes to the process during Scone installations.

RedFlow needs to have unlimited access to data sent from each ESS. In the case of the SGSC

project, Ausgrid kept data on their machines, which made it highly difficult and time-

consuming for RedFlow to acquire and analyse data from systems for both monitoring and

improvement purposes.

An average of 76.14% of the ESS installed for the SGSC Trial were available for operation

over this study period. While this can be improved, the average of 96.65% availability of

ZBMs over the same time period means that most ESS faults were not due to ZBM failures.

Instead, it was elements of the ESS, and in particular the analogue looms that caused most

ESS faults.

This shows the reliability of the core ZBM product, as well as the need for specialist system

integrators to be involved in the design and manufacturing of future ESS.

It is important to carry out appropriate load and distributed generation analyses prior to

project commencement. In the case of Newcastle, this would have shown the large peaks

caused by the automatic hot water systems. In response to this, and in addressing the true

peaks in the Newcastle area, the discharge period of the ESS should be shifted, or hot water

systems should begin charging at staggered times.

The ESS have been installed at suitable ratios (1 ESS for every 16 customers) to the number

of customers in respective areas to achieve reductions in peak demand seen by the grid by

about 5-10%. However, reductions could be improved with different discharge profiles.

Regardless, the number of ESS may need to be increased to see the same peak reduction

results during the summer months.

4.2 Scone The following lessons were also noted for the installation and operation of the 20 ESS in Scone.

The use of specialist installers, O’Donnell Griffin (ODG), has also been highly beneficial in the

roll-out of ESS to Scone.

RedFlow needs to have unlimited access to data sent from each ESS. In the case of the SGSC

project, Ausgrid kept data on their machines, which made it highly difficult and time-

consuming for RedFlow to acquire and analyse data from systems for both monitoring and

improvement purposes.


An average of 79.57% of the ESS installed for the SGSC Trial were available for operation

over this study period. While this can be improved, the average of 92.24% availability of

ZBMs over the same time period means that most ESS faults were not due to ZBM failures.

This shows the reliability of the core ZBM product, as well as the need for specialist system

integrators to be involved in the design and manufacturing of future ESS.

4.3 Newington The R510 ESS, as well as previous ESS, installed at the Newington Smart Home have produced the

following lessons learnt from installation and operation.

The 5kW, 10kWh rating of the R510 ESS is appropriate for the needs of the Smart Home

household load (approximately 15kWh/day), and would still be suitable for slightly higher

loads.

Large and continuous loads, such as the EV, are often too large for the ESS to sustain without

requiring power from the grid.

There is a need for a fuel cell or other similar reliable form of embedded generation to back-

up solar generation in off-grid or minimum grid import Smart Grid applications.

The effectiveness of the R510 in conjunction with embedded generation to load follow and

greatly reduce grid import to below 8% of the time.


5 Conclusions

Overall, this project has shown that ZBMs in R510 ESS are a suitable type of energy storage to use in

Smart Grid applications. The ZBM is reliable and effective in reducing peak demand seen by the grid,

as well as in islanding applications.

Overall, RedFlow has learnt many valuable lessons over the course of the SGSC Trial, and will use

these to improve upon their technology and installation procedures for future Smart Grid ESS

designs. These have included:

The benefits of using specialist installers to carry out large-scale installations of ESS.

The importance of complete access to trial data for monitoring and analysis.

The ZBM is a reliable product, and was by far not the main cause of ESS failures.

The subsequent need for specialist system integrators to be involved in the design and

manufacturing of future ESS.


6 References

[1] Ausgrid. (2011) “Program Trial Areas,” Ausgrid. [Online]. Available: http://www.smartgridsmartcity.com.au/About-Smart-Grid-Smart-City/~/media/Microsites/SGSC/Files/PDFs/Smart%20Grid%20Smart%20City%20project%20trial%20map.pdf

[2] Electrical Power Research Institute (EPRI), “Estimating the Costs and Benefits of the Smart Grid: A Preliminary Estimate of the Investment Requirements and the Resultant Benefits of a Fully Functioning Smart Grid,” EPRI, Palo Alto, CA, Final Report 1022519, Mar. 2011.

[3] M. Dean. (2012, Jun. 20). Smart Grid growth to spur demand for energy storage [Online]. Available: http://www.pennenergy.com/index/power/display/3319716882/articles/pennenergy/power/grid/2012/june/-smart_grid_growth.html


Appendix A – List of Abbreviations

BMS - Battery Management System

CAES - Compressed Air Energy Storage

EPRI - Electric Power Research Institute

ESS - Energy Storage System

RTU - Remote Terminal Unit

SGSC - Smart Grid, Smart Cities

ZBM - Zinc Bromide Module


Appendix B – R510 Product Brochure




Appendix C– List of Trial Sites


Appendix C1 – List of Newcastle Sites Site

Number ZBM # (Class)

Cabinet ID Date of

Commissioning Schedule Status Comments

159 195 R510-A1-DE13-159 17 November 2011 Profile A Operational Leak 1 Trip

160 184 R510-A1-DE14-160 17 November 2011 Profile A Operational

161 319(A+) R510-A1-DE15-161 17 November 2011 Profile A Operational 2 ZBM Replacements

162 194 R510-A1-DE22-162 17 November 2011 Profile A Not Operational

163 318 (A+) R510-A1-DE17-163 17 November 2011 Profile A Operational ZBM Replacement

164 339 (A+) R510-A1-DE18-164 17 November 2011 Profile A Operational ZBM Replacement Previous SMA Fault

165 346 (A+) R510-A1-DE19-165 17 November 2011 Profile A Unknown Fault ZBM Replacement

Q4 Switching

166 304 (A+) R510-A1-DE20-166 17 November 2011 Profile A Not Operational System Noise

ZBM Replacement

167 300 (A+) R510-A1-DE21-167 17 November 2011 Profile A Operational ZBM Replacement

168 311 (A+) R510-A1-DE22-168 17 November 2011 Profile A Operational Analog Loom Fixed ZBM Replacement

169 341 (A+) R510-A1-DE23-169 17 November 2011 Profile B Not Operational System Noise

ZBM Replacement

170 301 (A+) R510-A1-DE24-170 17 November 2011 Profile B Operational ZBM Replacement

171 297 (A+) R510-A1-DE25-171 17 November 2011 Profile B Not Operational ZBM replacement



174 226 (B) R510-A1-DF01-174 21 December 2011 Profile B Operational

175 317 (A+) R510-A1-DF02-175 21 December 2011 Profile B Operational ZBM Replacement

176 238 (A) R510-A1-DF03-176 21 December 2011 Profile B Operational Leak1 Trip and Battery Voltage Fail

177 240 (A) R510-A1-DF04-177 12 December 2011 Profile B Not Operational BC Firmware Upgrade Required

178 233 (A) R510-A1-DF05-178 12 December 2011 Profile B Operational Incorrect Installation

179 329 (A+) R510-A1-DF06-179 12 December 2011 Profile C Not Operational Previous RTU Fault ZBM Replacement


Site Number

ZBM # (Class)

Cabinet ID Date of

Commissioning Schedule Status Comments

180 235 (A) R510-A1-DF07-180 21 December 2011 Profile C Not Operational System Noise

181 244 (A) R510-A1-DE08-181 12 December 2011 Profile C Operational Previous Analog Loom Failure

182 237 (A) R510-A1-DF09-182 12 December 2011 Profile C Operational Incorrect Installation

183 234 (A) R510-A1-DF10-183 12 December 2011 Profile C Not Operational

184 295 (A+) R510-A1-DF11-184 21 December 2011 Profile C Operational Incorrect Installation

ZBM Replacement Previous Analog Loom Fault

185 186 (A) R510-A1-DF12-185 12 December 2011 Profile C ZBM Fault RTU Lost Comms with BC

186 305 (A+) R510-A1-DE13-186 12 December 2011 Profile C Operational ZBM Replacement

187 239 (A) R510-A1-DF14-187 21 December 2011 Profile C Operational

188 245 (B) R510-A1-DF15-188 12 December 2011 Profile C Operational Previous Analogue Loom Fault

189 257 (A) R510-A1-DG01-189 21 December 2011 Profile D Not Operational

190 349 (A+) R510-A1-DG01-190 21 December 2011 Profile D Operational ZBM Replacement

191 264 (A) R510-A1-DG01-191 21 December 2011 Profile D Operational

192 350 (A+) R510-A1-DG01-192 21 December 2011 Profile D Not Operational ZBM Replacement

193 249 (A) R510-A1-DG01-193 21 December 2011 Profile D Unknown Fault Mains Fail, Needs AS Board

Replacement



196 330 (A+) R510-A1-DG01-196 21 December 2011 Profile D Battery Controller

Fault Amp Lockout Failure ZBM Replacement




Appendix C2 – List of Scone Sites Site

Number ZBM # (Class)

Cabinet ID Date of Commissioning Schedule Status Comments

199 261 (A+) R510-A1-DG01-199 29 March 2012 Profile F Operational

200 262 (A+) R510-A1-DG01-200 29 March 2012 Profile E Operational ZBM Replacement

201 348 (A+) R510-A1-DG01-201 29 March 2012 Profile F Operational ZBM Replacement

202 265 (A+) R510-A1-DG01-202 4 April 2012 Profile F Operational

203 343 (A+) R510-A1-DH01-203 28 March 2012 Profile F Operational ZBM Replacement

204 271 (A+) R510-A1-DH01-204 29 March 2012 Profile E Operational

205 258 (A+) R510-A1-DH01-205 4 April 2012 Profile F Operational

206 272 (A) R510-A1-DH01-206 4 April 2012 Profile F Operational Previous Analog Loom Fault

207 342 (A+) R510-A1-DH01-207 29 March 2012 Profile E Operational ZBM Replacement

208 267 (A+) R510-A1-DH01-208 4 April 2012 Profile F Operational

209 340 (A+) R510-A1-DH01-209 29 March 2012 Profile E Operational ZBM Replacement

210 185 (A) R510-A1-DH01-210 30 March 2012 Profile F Operational Previous ZBM Fault


212 282 (A) R510-A1-DH01-212 28 March 2012 Profile F Operational Previous Battery Controller Fault


214 284 (A) R510-A1-DH01-214 29 March 2012 Profile E Operational

215 347 (A+) R510-A1-DH01-215 28 March 2012 Profile F Not Operational ZBM Replacement

Grid Fault

216 281 (A) R510-A1-DH01-216 28 March 2012 Profile F Operational Previous Battery Controller Fault

217 278 (A) R510-A1-DH01-217 29 March 2012 Profile E Operational

218 276 (A) R510-A1-DH01-218 30 March 2012 Profile F Operational


Appendix D – Cycle Profiles

Profile Days of the Week Active Time Power

Profile A Charge

Monday to Friday 2am to 8am 2kW

Discharge 4pm to 2am 3kW

Profile B Charge



Profile C Charge



Profile D Charge



Profile E Charge

Monday to Friday 8am to 2pm 2kW


Profile F Charge



Profile G

Charge Monday, Wednesday, Friday,

Sunday

2am to 7am 2kW

Load Follow 7am to 11pm Load Following

Discharge 11pm to 2am 4.5kW


Appendix E – Newcastle Reduction in Peak Demand

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Effect of Storage on Peak Reduction - April 2012


Friday 6 April

Peak Reduction 17.78%





Saturday

7 April

Sunday

8 April

Monday

9 April

Tuesday

10 April

Wednesday

11 April

Thursday

12 April

Friday

13 April


4 R510 ESS Operating

Documents

Case Study - Redflow · REDFLOW LTD. – Smart Grid, Smart Cities Trial Case Study 11/10/2012 Page v The use of RedFlow’s ESS reduces the traditional peak seen by the grid by 10-15%