Chemring CM Renewable Energy Report

7/30/2019 Chemring CM Renewable Energy Report

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y:\usb3 drive\other\chemring countermeasures solar files\chemring cm renewable energy report.doc

Study Report for

Chemring CountermeasuresHigh Post Salisbury

Renewable Energy Review

Solar Energy Opportunities


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Contents

1. Executive Summary 4

2. Introduction 6

2.1 Previous PROjEN Involvement 6

2.2 Site Location and Orientation 7

3. Solar Energy Background 8

4. PVGIS Resource Data and Analysis 9

4.1 PVGIS Database 10

5. Photovoltaic 11

5.1 PV Technology 11

5.2 Planning 12

5.3 Fixed or Tracking PV Collectors 13

6. PV Installations at Chemring Countermeasures 14

6.1 Integrated PV Solution 146.1.1 Building 207 Evaluation 15

6.1.2 Determination of Required Panel Numbers 166.1.3 Financial Model and Budgetary Costings 17

6.2 Stand Alone Modular System (100kW) 206.2.1 Determination of Required Panel Numbers 216.2.2 Financial Model and Budgetary Costings 21

7. Solar Thermal 24

7.1 Solar Thermal Panel Performance 24

7.2 Solar heating of HWS and heating circuits for the Spectral Building 25

8. Appendix A Solar Irradiance Data 298.1 Average Solar Irradiance for Chemring Countermeasures (SP4 6AS) 30

8.1.1 Solar Irradiance across time of day (W/m2) 31

9. Appendix C Renewable Energy Support 33

9.1 Micro-generation Certification Scheme (MCS) 33

9.2 Feed in Tariff (FiT) 339.2.1 Feed In Tariff Rates 33

9.3 Renewable Heat Incentive (RHI) 349.3.1 RHI Proposed Rates 35

9.3.2 Deeming 35

10. Appendix D Solar Thermal Collectors 36


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11. Appendix E Solar Panel Data 38

12. Appendix F - Photovoltaic Array Installed Cost 44

13. Appendix G Solar Collector Factsheet 46


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1. Executive Summary

Chemring Countermeasures are currently reviewing the use of renewable energytechnologies to reduce their dependence on conventional fossil fuels used on the site. In linewith current site expansion plans for two new production buildings PROjEN have beenrequested to carry out a study on Solar Energy opportunities on the site.

The two technologies under review are Solar Thermal, providing thermal energy directly tohot water services, and Photovoltaic, where electrical power is generated for use in offsettingimported electricity from the grid.

In both these cases, previous involvement with the site has been utilised to reflect knownbuilding consumption and operation to evaluate these technologies. A brief site survey of thenew facilities along with review of design documents has also been conducted.

Photovoltaic Solutions

Photovoltaic Solutions included the electrical supply to Building 207 and a modular approachto a larger 100kW standalone array.

The simple payback of these schemes equate to 8-9 years when governmental supportthrough Feed in Tariffs are considered. With a potential equipment life of 25 years, thecumulative savings of these schemes show a considerable benefit to the site. The modularsolution can be ramped up to provide 400-500kW output offering considerable benefits at thecost of tying up capital investment for a number of years.

PV systems provide a simple clean solution of reducing imported electricity and allows carbonreductions to be realised for both company and legislative targets.

Solar Thermal Solutions

Solar Thermal solutions proved to be much harder to apply across the site with knowninformation about consumption. It was found that heating hot water above 50oC was notpossible, and therefore any application requiring a supply and return above this range couldnot benefit from Solar Thermal.

Production of Hot Water can be applied as the water required heating from a lowertemperature of 5oC-10oC. Known applications across the site are limited but as an exampleof what could be achieved the HWS load of the existing Spectral Building was modelledusing a large solar thermal array. In order to meet demand for hot water required the storageof approximately 12m3 of heated water to balance out night time demand.

Solar Thermal systems require greater engineering to provide an acceptable solution. The capitalcosts are estimated at 1,500/kWt for a standard solar panel installation, where complex heatexchangers and or self-syphoning systems are required, these cost will increase.


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A simple payback of 2-3 years was found for the building reviewed, although the variables are much

greater than that known for PV due to demand profiles, conformation of the HWS load and fundingoptions etc.

The Renewable Heat Incentive (RHI) has not yet been ratified, and although rates for solar thermalhave been published, there is still scope for changes to be made. One such area is in therequirement for Deeming or modelling the thermal demand for a given building. Where full benefitshave been calculated in the example within this report, this ma be subject to change.

This study on solar energy provides the first part of a structured approach to review renewableenergy solutions for the Chemring Countermeasure site. Ground source heating & cooling, Biomassand Anaerobic Digestion and Wind Power are all technologies that could be beneficial to the site toassist in reducing fossil fuel consumption, reduce carbon emissions and reduce operational costs.


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2. Introduction

PROjEN have been asked to provide a study on the opportunities of utilising solar energy asa renewable energy source for Chemring Countermeasures in line with their current drive toreduce their use of conventional fossil fuels, and support the on-going expansion program ofthe site in the manufacture of countermeasure products.

This study is the first part of a proposed range of technologies that is recommended to beevaluated within a range of renewable energy solutions available.

The outlined objectives of the study are:

Determine solar energy data for site location

Review Photovoltaic and Solar Thermal technologies

Evaluate technologies against site applications

Determine budget costs for recommended options

2.1 Previous PROjEN Invo lvement

During the summer 2008 PROjEN were commissioned to undertake a site energy study ofthe Chemring Countermeasures, High Post facilities. The purpose of undertaking this workwas allow the continued site operations against an on-going limitation over the agreed 1MVAelectrical supply capacity the site were able to take from Scottish & Southern DistributionNetwork. The study looked at opportunities to reduce both the electrical demand andconsumption of the site, along with other energy and carbon reduction opportunities.

During this period of time the site was due to undertake expansion works in the nature of twonew production buildings to be located in green belt area to the northeast sector of the site.The new production facilities were to accommodate automated production plant, and thatwould also allow the rationalisation of a number of other existing poor performing buildings

around the site that were up to 30 years old.

Since 2008, agreement has been made to lay a new secure 8MVA supply into the site tosupply both the existing buildings and new production buildings. This works will allow thedependency on existing diesel generation capacity to be removed, namely in EM8 area andprovide the increase capacity required for the production automation plant and heating withancillary areas. A single 970kVA standby generator will remain on site to support the newproduction facilities during local loss of supply.

The new production facilities comprise of two purpose built buildings of approximately1,200m2 each with additional separate control/services buildings and ovens of smallerfootprints. Both building shells have been constructed but the first to be fitted out forproduction will be the MTV building leavings the Spectral Building to be completed at a laterdate.


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2.2 Site Loc at ion and Orientat ion

Chemring Countermeasures (CCM) has a large 100 acre estate comprising in excess of 180buildings and structures. The site is serviced by mains electricity which is metered through asingle half hour meter. Due to the sites location, there are no mains gas services on site andthe predominant source of energy use is through electricity for heating, lighting andcompressed air services in addition to site process activities. The site also uses light fuel oilfor low pressure hot water space heating and diesel fuel for electricity generation in a numberof smaller production areas.

The site is located in an open and exposed position at the top of Salisbury plain, and

experiences high winds and gains very little protection from the elements. There is no overshadowing from other buildings or facilities.

The location and grid reference coordinates for Chemring Countermeasure site are asfollows:

OS X (Eastings) 414304OS Y (Northings) 136810Post Code: SP4 6ASLatitude N51:07:49 (51.130391)Longitude W1:47:49 (-1.796962)

126m above sea level

The site runs predominantly east to west with open plain land currently being developed fornew process facilities to the north-east sector of the site.

The approximate area of the development land is 71,000m2 (17.2 Acres) of which the

physical buildings and ancillary areas account for approximately 3,000-4,000m2 providingsignificant areas of open land available for the installation of renewable energy services.


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3. Solar Energy Background

Solar energy, radiant light and heat from the sun, has been harnessed by humans sinceancient times using a range of ever-evolving technologies. The earth continually receivesradiation from the sun in the form of ultra violet, visible and infra-red light. This light energyfalls on the surface of the earth and dependant on your location, distance from the equator,and time of day will vary the amount of energy available.

The amount of instantaneous energy available at the earths distance from the sun isapproximately 1,366W/m2, after passing through the earths atmosphere this value drops to

around 1,000W/m2

. This is the theoretical maximum amount of energy that would fall at theequator.

Dependant of the location on the earths surface in relation to the latitude above or below theequator, the amount of energy available per square meter will vary accordingly. As can beseen in the figure below, the effect of the angle will reduce the density of energy across theactual surface area.

Energy will always be available even with cloudy or overcast skies due to diffused insolation.

For clarification of the terms used within this report, and to assist in understanding therelationship between each term, the following explanations are provided below:

Irradiance - The direct, diffuse, and reflected solar radiation that strikes a surface,usually expressed in kilowatts per square meter (kW/m2). Irradiance multiplied by timeequals insolation.

Insolation - The solar power density incident on a surface of stated area andorientation, usually expressed as Watts per square meter per hour (Wh/m2) or Btu persquare foot per hour (BTUh/ft2).

Direct Insolation - Sunlight falling directly upon a collector.

Diffuse Insolation - Sunlight received indirectly as a result of scattering due toclouds, fog, haze, dust, or other obstructions in the atmosphere.

The different technologies employed for solar collectors, their performance data, and costscan be found in the relevant appendices of this report.

Energy Density@ 51

0N= 230-890W/m

2

Energy Density@ 0

0N= 1,000W/m

2

SUN

Earth

1,366W/m

above the

atmosphere


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4. PVGIS Resource Data and Analysis

This study utilises solar data available from a reliable source of the PVGIS, as used for themajority of European solar evaluation schemes. The Photovoltaic Geographical InformationSystem (PVGIS) is a web based resource available to engineers and research bodiesprovided by the EU and provides a map-based inventory of solar energy resource andassessment of the electricity generation from photovoltaic systems in Europe, Africa, andSouth-West Asia. It is a part of the SOLAREC action that contributes to the implementationof renewable energy in the European Union as a sustainable and long-term energy supply.

The data made available is provided as a means to evaluate both Photovoltaic and Solar

Thermal energy opportunities throughout Europe, Africa, and South-West Asia.

The database contains solar irradiance data on the following factors at a resolution of 1 km x1 km:

[1] Geographical data: digital elevation model, administrative boundaries, landcover and cities, etc.

[2] Spatially continuous climatic data series representing monthly and annualmeans of:

Daily sum of global irradiation for horizontal plane [Wh/m2] Linked atmospheric turbidity [dimensionless]

Ratio of diffuse to global irradiation [dimensionless]

Optimum inclination angle of solar collector modules to maximise energy yield[degrees]

[3] Regional averages for built-up areas:

Yearly total of global irradiation (horizontal, vertical and optimally- inclinedplanes) [kWh]

Yearly total of estimated solar electricity generation (for horizontal, vertical,optimally-inclined planes) [kWh]

Optimum inclination angle of the solar collector modules to maximise energyyield over a year (degrees]

A second resource; RETScreen Clean Energy Project Analysis software, was also madeavailable to verify the figures used in this report as a comparison. RETScreen is provided bythe Government of Canada as part of Canadas recognition of the need to take an integratedapproach in addressing climate change and reducing pollution. Data used in the software isderived from NASA climate sources. Although figures from RETScreen have not beenincluded in this report, a comparison has been made for the site location to ensure

robustness of the figures.


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4.1 PVGIS Database

The screen shot below shows the data presented by the PVGIS system. A data entry screenalso allows site specific information regarding proposed system to be entered and certain keyinformation about the system to be determined; e.g. type of chemistry/construction of thepanel, mounting position and slope and azimuth of the array.

The database can also indicate the optimal slope and azimuth for peak performance of thesystem across the year.

From the main screen the site location can be entered and the relevant data specific to thatlocation is presented by the software. Other data is able to be drilled down from the softwareto provide; Monthly Radiation and Daily Radiation, the results of which are shown inAppendix 8 Solar Irradiance Data.


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5. Photovoltaic

5.1 PV Technolo gy

Generating electricity from the suns energy is possible using Photovoltaic cells. Cells arearranged in multiple units to form a panel. Panels are then connected together to provide aPV Array. The size and power output of any array is limited by only the space required toinstall them and the insolation level applicable to their installation.

The key components within a PV system are PV array, Inverter and Distribution cabling.Within each element there are inherent efficiency values that need to be considered in orderto fulfil the electrical power supply to the load.

PV Array

The selection of photovoltaic material and its ability to generate electricity is discussed inAppendix B. Generally, consideration of Watt/ is the primary driver to a selection of thearray as it is intended to get the most amount of energy out of a system for as little capital

investment as possible. The power output data presented in Appendix B is for a standardisedinsolation of 1,000W/m2 across all panels thereby allowing fair comparison when consideringperformance data.

Most photovoltaic panels are guaranteed by the manufacturers to generate power for aperiod of 20-25 years. Whilst this may be taken as original peak output under optimumconditions, certain technologies have a varying degradation of the materials that prevent fullpower capability being maintained over the life of the panel. A 10-15% reduction in output iscommon for most panels due to deterioration.

Increased operating temperature of the panel decreases performance of the panel.

Dependant on the ambient air temperatures around the panel, the output performance willvary accordingly. e.g. higher ambient air temperatures equates to lower performance of thesame panel.


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Inverter

The function of an inverter is to convert Direct Current (DC) power into Alternating Current(AC) power for use in supply at the same conditions as would be expected at the mainsincomer for the building or site. Due to the inherent conversion efficiency of the electronicsinvolved energy is lost from the process in the form of heat. The performance of an invertervaries across the range it is designed to provide power for. If an inverter is significantlyoversized and operates at say 10% of its full capacity, its efficiency will be much lower than ifoperating at 90-100% of its capacity. Consideration should therefore be taken to employmultiple inverters where the load varies significantly.

Grid Tie In Inverters - As with all inverters, a grid-tie or grid-interactive inverter converts thedirect current (DC) power from the renewable energy source into the alternating current (AC)used within domestic and commercial properties. These inverters are intended specifically forgrid-tied applications where they will be tied into the local distribution system or utility grid.

While it is possible to completely eliminate your imported electricity with a grid-tie system, itis generally required to supplement energy usage by using a combination of both their utilitygrid and solar array (i.e. 70% solar, 30% utility grid). This can due to factors such as powerrequirements outside of natural daylight, and when power demand is higher than installedgeneration capacity.

One of the major benefits of a grid-tie system is net metering, where unused energy is fedback into the local distribution or utility grid. When no power is being generated by the solararray, the buildings power is drawn from the utility supply. The energy the site pays for is thedifference between the power drawn from the grid and the power fed into the local grid.

Distribution Cabling

Low voltage cabling (12-50V) is much more susceptible to resistance issues whether fromcable resistance or terminal resistance. To lose 1,000W of power in a 12V system onlyrequires a line resistance of only 0.145 Ohms compared the 62.5 Ohms resistance required

to lose the same power in a 240V system. Therefore it is important to ensure that cableresistance, cable length and terminations are minimised throughout the system design priorto inverter connection.

For the purposes of this study the most commonly available and higher power/m2 collectorhas been considered for a suitable solution. Where space is a premium getting the most outof a favourable location is usually the limiting factor.

5.2 Planning

In many cases fixing solar panels a roof is likely to be considered 'permitted development'under planning law with no need to apply for planning permission. There are, however,important exceptions and provisos which must be observed.


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Under normal planning regulations all solar installations are subject to the followingconditions:

Panels on a building should be sited, so far as is practicable, to minimise the effect onthe appearance of the building.

They should be sited, so far as is practicable, to minimise the effect on the amenity ofthe area.

When no longer needed for micro generation they should be removed as soon aspossible.

It would be expected that the local planning body would be advised and would make specificcomments on local site regulations. Therefore it should not be assumed that planning shouldnot be sought when considering large scale installations. The aspects of planningrequirements will need to be addressed during the design stage, once commitment has beengiven to take solar energy opportunities further.

5.3 Fixed or Trackin g PV Collectors

The sun passes through a known variable path across the sky thereby varying the peak

power available dependant on the inclination and azimuth of the earth. Allowing the solararray to track the sun through this path maximises the collection of available energy. Whilst itis possible to design solar arrays to track the suns path, it is considered outside the scope ofthis study to evaluate the technical parameters and costs. This study will therefore onlyconsider a fixed array designed to be mounted at the optimum angle.


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6. PV Installations at Chemring Countermeasures

From the site location and data identified in Appendix A: Solar Irradiance Data, the annualirradiance figure for Chemring Countermeasures site equates to 1030kWh/m2/annum for ahorizontal surface.

For the purpose of this study two scenarios have been considered for review;

Integrated PV array designed to utilise the building characteristics of the existingbuilding types for which known consumption patterns can be associated. In this

scenario the physical area of the roof will be the limiting factor on how much electricitycan be generated through a suitably designed PV system in addition to the buildingown electricity demand profile. It is also expected that a solution will be below 50kWpand fall within a MCS certified registration process.

A stand-alone modular PV array designed to provide 100kW of electricity. The modelcan then be built up in multiples to meet the required supply requirements. Thepotential benefits of a PV installation will be limited firstly what area will besurrendered for a large scale PV array, and more importantly on capital investmentagainst Internal Rate of Return, or simple payback required.

This data is used within the PVGIS analysis sheet as below. The selection of a suitable solararray has been chosen for this study to be based around the current range of UK availablesolar panel manufactures, and the most commonly available highest efficiency unit.The Suntech STP195S-24-Ad+ panel was chosen with a peak output of 195Wand panelsurface area of 1.28m2.This panel has an equivalent output of 152W/m2 at a surfaceinsolation of 1,000W/m2 equating to an efficiency of 15.2%

6.1 Integrated PV Solu tion

From building data from the original energy study building type Building 207 has beenconsidered due their use of electricity for both lighting and/or production equipment.

From the previous study Building 207 used showed a peak demand of 6-7kW during theperiod of (08:00-17:30) over Monday-Friday working pattern although working out of thesehours was noted. This would be expected to increase to a maximum of 9-10kW during winteroperation when the boiler pumps were in operation.

Building 207 has a floor area of approximately 494m2 but with its (SSW) South South Westfacing pitched roof the available roof mounted area is approximately 284m2. A roof pitch of30o is assumed in these calculations.

When we consider an array to support 7kW during summer selection of a suitable panel isrequired. Panel efficiency is set out in Appendix B. In order to fulfil the summer time peak


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load of 7kW a system that incorporates collector, invertor and distribution components will

need to be established.

6.1.1 Building 207 Evaluation

For the location and orientation of the required array, an inclination of 30o and SSEorientation (+30o) gives the following data. Based on a combined loss of 23.1% output fromthe array to point of use, a 9kWp array is required to produce the required 7kW of power forthe building.

Nominal power of the PV system: 9.0 kWp (crystalline silicon)Estimated losses due to temperature: 7.7% (using local ambient temperature)Estimated loss due to angular reflectance effects: 3.1%Other losses (cables, inverter etc.): 14.0% (Inverter 10% Cables 4%)Combined PV system losses: 23.1%

Where:Ed: Average daily electricity production from thegiven system (kWh)Em: Average monthly electricity production fromthe given system (kWh)

Hd: Average daily sum of global irradiation persquare meter received by the modules of thegiven system (kWh/m2)Hm: Average sum of global irradiation per squaremeter received by the modules of the givensystem (kWh/m2)

When we consider the performance with the ideal orientation and slope of the same power

output panel the following data is provided:

Fixed system: inclination=30o,orientation=30o

Month Ed Em Hd Hm

Jan 8.05 250 1.10 33.9

Feb 13.90 388 1.89 53.0Mar 20.10 623 2.81 87.0

Apr 30.30 909 4.34 130

May 33.60 1040 4.91 152

Jun 34.30 1030 5.09 153

Jul 34.60 1070 5.17 160

Aug 30.90 959 4.62 143

Sep 24.20 726 3.53 106

Oct 15.40 479 2.19 67.9Nov 9.87 296 1.36 40.8

Dec 6.27 194 0.85 26.4

Yearlyaverage

21.8 664 3.16 96.2

Total foryear

7960 1150


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Nominal power of the PV system: 9.0 kWp (crystalline silicon)

Estimated losses due to temperature: 7.7% (using local ambient temperature)Estimated loss due to angular reflectance effects: 2.9%Other losses (cables, inverter etc.): 14.0% (Inverter 10% Cables 4%)Combined PV system losses: 23.0%

Where:Ed: Average daily electricity production from thegiven system (kWh)

Em: Average monthly electricity production fromthe given system (kWh)Hd: Average daily sum of global irradiation persquare meter received by the modules of thegiven system (kWh/m2)Hm: Average sum of global irradiation per squaremeter received by the modules of the givensystem (kWh/m2)

Here the ideal orientation is 2

o

to the West and 36

o

inclination from the horizon. Theadditional calculated energy generated between the location of the roof and the ideal is only220kWh or 2.6% of the maximum therefore siting the panel onto the existing roof of building207 does not significantly affect the power available.

6.1.2 Determination of Required Panel Numbers

The selected panel Suntech STP195S-24-Ad+ has an area of 1.28m2/panel and peakcapacity of 152W/m2.

Therefore; 9,000Wp / 152W/m2 = 59.2m2 of solar array

and; 59.2m2 / 1.28m2/panel = 46.3 panels

Fixed system: inclination=36o,

orientation=-2o

Month Ed Em Hd Hm

Jan 9.09 282 1.22 37.9

Feb 15.20 427 2.07 58.0

Mar 21.20 657 2.96 91.6

Apr 30.90 927 4.43 133

May 33.30 1030 4.87 151

Jun 33.60 1010 5.00 150

Jul 34.10 1060 5.10 158

Aug 31.20 966 4.66 144

Sep 25.30 759 3.69 111

Oct 16.70 518 2.37 73.3Nov 11.10 333 1.52 45.5

Dec 7.11 220 0.95 29.6

Yearlyaverage

22.4 682 3.24 98.6

Totalfor year

8180 1180


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Using the selected Suntech STP195S-24-Ad+ panel as previously discussed an arraycomprising of 59.2 m2 can be provided in 47 panels.

A total array area of 60m2 over a roof area of 284m2 can be accommodated without anyspace issues although consideration over additional loading of the roof must be taken intoaccount and structural advice obtained.

6.1.3 Financial Model and Budgetary Costings

It was noted that Building 207 is used during weekdays only; therefore the demand solely forthe building for electricity will only be apparent during these times. It should therefore bepossible that any excess power generated is effectively fed back into the local distributiongrid offsetting power drawn elsewhere.

Therefore as the site has a higher demand than can be met with the suggested solar array,all electricity generated will be used and be counted as offsetting imported electricity.

Offset SavingsCalculated generated power 7,960kWh/annumCost of current electricity = 6.33p/kWh (Night time rate is not applicable)

Annual offset savings = 7960kWh x 0.0633 = 503.87/annum

Feed In TariffFeed in tariff is based on the installed power load (4-10kW) for April 2012 onwards =33p/kWhAnnual FIT income = 7,960kWh x 0.33 = 2,626.80/annum

Total Financial savings = 503.87 + 2,626.80 = 3,130.67

Cost of System

For an estimate cost per kWp installed Segen have provided costs for smaller type systemsas shown in Appendix F.

An average cost of a 9kWp system is expected to be in the region of 31,500 based on3,500/kWp installed system.

Therefore the simple payback of this scheme would be 11.4 years at todays rates. It isimportant to note that the Feed in Tariff will be index linked to RPI for a guaranteed 25 yearsTherefore when this data is taken into account along with a conservative fuel costs rises of3% then the following cost model can be determined.


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YearkWh

GeneratedDegradation

%

Expected

GenerationkWh /kWh

FITRate

AnnualSavings

CapitalExpenditure

CumulativeSavings

0 0 0.063 0.330 0 -31,500 -31,500

1 7960 0.00% 7960 0.065 0.340 3,225 -28,275

2 7960 0.40% 7928 0.067 0.350 3,308 -24,967

3 7960 1.20% 7864 0.069 0.361 3,380 -21,587

YearkWh


%

ExpectedGeneration

kWh /kWhFIT

RateAnnualSavings

CapitalExpenditure

CumulativeSavings

4 7960 1.60% 7833 0.071 0.371 3,467 -18,120

5 7960 2.00% 7801 0.073 0.383 3,557 -14,564

6 7960 2.40% 7769 0.076 0.394 3,648 -10,915

7 7960 2.80% 7737 0.078 0.406 3,743 -7,173

8 7960 3.20% 7705 0.080 0.418 3,839 -3,334

9 7960 3.60% 7673 0.083 0.431 3,938 604

10 7960 4.00% 7642 0.085 0.443 4,039 4,643

11 7960 4.40% 7610 0.088 0.457 4,143 8,786

12 7960 4.80% 7578 0.090 0.471 4,249 13,035

13 7960 5.20% 7546 0.093 0.485 4,358 17,394

14 7960 5.60% 7514 0.096 0.499 4,470 21,864

15 7960 6.00% 7482 0.099 0.514 4,585 26,449

16 7960 6.40% 7451 0.102 0.530 4,702 31,151

17 7960 6.80% 7419 0.105 0.545 4,823 35,974

18 7960 7.20% 7387 0.108 0.562 4,946 40,92019 7960 7.60% 7355 0.111 0.579 5,072 45,992

20 7960 8.00% 7323 0.114 0.596 5,202 51,194

21 7960 8.40% 7291 0.118 0.614 5,335 56,529

22 7960 8.80% 7260 0.121 0.632 5,471 62,000

23 7960 9.20% 7228 0.125 0.651 5,610 67,610

24 7960 9.60% 7196 0.129 0.671 5,753 73,363

25 7960 10.00% 7164 0.133 0.691 5,899 79,263

The payback once RPI and fuel price increases have been evaluated indicates that thescheme would look to pay within 9 years, with a cumulative gain over the life of the scheme

of over 79,000.


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Graph of Cumulative Savings over Life of System (9kWp)

-40,000

-20,000

0

20,000

40,000

60,000

80,000

100,000

0 5 10 15 20 25Years

Cumulative Savings

Based on 3% RPI & 3% Increase fuel costs


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6.2 Stand Alon e Modu lar System (100kW)

In this instance a stand-alone fixed solar array with a useful peak power output of 100kW isconsidered. The orientation and slope will be maximised to provide the greatest benefit to thescheme in the available land surrounding the newly constructed production buildings.

Using PVGIS model, with the assumed power loss figures and optimum alignment thefollowing data has been determined:

Nominal power of the PV system: 130.0 kW (crystalline silicon)Estimated losses due to temperature: 7.7% (using local ambient temperature)Estimated loss due to angular reflectance effects: 2.9%Other losses (cables, inverter etc.): 14.0% (Inverter 10% Cables 4%)Combined PV system losses: 23.0%

Where:

Ed: Average daily electricity production from the

given system (kWh)Em: Average monthly electricity production fromthe given system (kWh)Hd: Average daily sum of global irradiation persquare meter received by the modules of thegiven system (kWh/m2)Hm: Average sum of global irradiation per squaremeter received by the modules of the givensystem (kWh/m2)

Fixed system: inclination=36o,orientation=-2o

Month Ed Em Hd Hm

Jan 131.00 4070 1.22 37.9

Feb 220.00 6170 2.07 58.0

Mar 306.00 9490 2.96 91.6

Apr 446.00 13400 4.43 133

May 480.00 14900 4.87 151

Jun 485.00 14600 5.00 150

Jul 492.00 15300 5.10 158

Aug 450.00 14000 4.66 144

Sep 365.00 11000 3.69 111

Oct 242.00 7490 2.37 73.3

Nov 160.00 4810 1.52 45.5

Dec 103.00 3180 0.95 29.6

Yearlyaverage

324 9850 3.24 98.6

Totalfor year

118000 1180


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6.2.1 Determination of Required Panel Numbers

The selected panel Suntech STP195S-24-Ad+ has an area of 1.28m2/panel and peakcapacity of 152W/m2.

Therefore; 130,000Wp / 152W/m2 = 855.2m2 of solar array

and; 855.2m2 / 1.28m2/panel = 668 panels

Using the selected Suntech STP195S-24-Ad+ panel as previously discussed an arraycomprising of 855.2 m2 can be provided in 670 panels.

A total array area of 855m2 will be required for every 100kW of peak power required. Thefootprint of a scheme would typically require an area of 30m x 30m..


It was noted that site demand has previously been a minimum of 400kW during the past 12months. With the phasing in of the production plant and upgrade of the electricity supply, thisdemand is expected to increase significantly over the next 6 months. In reality the site couldbenefit from a number of 100kW arrays in order to offset site demand and consumption and

the following calculations will provide support to investigate this further if found acceptable.

In this scenario, all of the electricity is expected to be used within the site, there is no plansfor exporting generated power to the grid (i.e. export to the national grid).

Therefore as the site has a higher demand than can be met with the suggested solar array,all electricity generated will be used and be counted as offsetting imported electricity.

Offset SavingsCalculated generated power 118,000kWh/annumCost of current electricity = 6.33p/kWh (Night time rate is not applicable)

Annual offset savings = 118,0000kWh x 0.0633 = 7,469.40/annum

Feed In TariffFeed in tariff is based on the installed power load (100kW>5MW) for April 2012 onwards =26.8p/kWhAnnual FIT income = 118,000kWh x 0.268 = 31,364/annum

Total Financial savings = 7,469 + 31,624 = 39,093

Cost of System

For an estimate cost per kWp installed Segan have provided costs for smaller type systemsas shown in Appendix F..


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An average cost of a 130kWp system is expected to be in the region of 390,000 based on

3,000/kWp installed system.

Therefore the simple payback of this scheme would be 9.9 years at todays rates. It isimportant to note that the Feed in Tariff will be index linked to RPI for a guaranteed 25 yearsTherefore when this data is taken into account along with a conservative fuel costs rises of3% then the following cost model can be determined.

YearkWh


%

ExpectedGeneration

kWh /kWhFIT

RateAnnualSavings

CapitalExpenditure

CumulativeSavings

0 0 0.063 0.268 0 -390,000 -390,000

1 118000 0.00% 118000 0.065 0.276 40,266 -349,734

2 118000 0.40% 117528 0.067 0.284 41,308 -308,426

3 118000 1.20% 116584 0.069 0.293 42,206 -266,220

4 118000 1.60% 116112 0.071 0.302 43,296 -222,924

5 118000 2.00% 115640 0.073 0.311 44,414 -178,510

6 118000 2.40% 115168 0.076 0.320 45,559 -132,951

7 118000 2.80% 114696 0.078 0.330 46,734 -86,217

8 118000 3.20% 114224 0.080 0.339 47,938 -38,280

9 118000 3.60% 113752 0.083 0.350 49,172 10,892

10 118000 4.00% 113280 0.085 0.360 50,437 61,329

11 118000 4.40% 112808 0.088 0.371 51,733 113,062

12 118000 4.80% 112336 0.090 0.382 53,062 166,125

13 118000 5.20% 111864 0.093 0.394 54,425 220,549

14 118000 5.60% 111392 0.096 0.405 55,821 276,370

15 118000 6.00% 110920 0.099 0.418 57,252 333,622

16 118000 6.40% 110448 0.102 0.430 58,718 392,341

17 118000 6.80% 109976 0.105 0.443 60,222 452,562

18 118000 7.20% 109504 0.108 0.456 61,762 514,324

19 118000 7.60% 109032 0.111 0.470 63,341 577,665

20 118000 8.00% 108560 0.114 0.484 64,958 642,623

21 118000 8.40% 108088 0.118 0.499 66,616 709,240

22 118000 8.80% 107616 0.121 0.514 68,315 777,555

23 118000 9.20% 107144 0.125 0.529 70,056 847,611

24 118000 9.60% 106672 0.129 0.545 71,840 919,45125 118000 10.00% 106200 0.133 0.561 73,668 993,118

The payback once RPI and fuel price increases have been evaluated indicates that thescheme would look to pay within 9 years, with a cumulative gain over the life of the schemeof over 993k.


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Graph of Cumulative Savings over Life of System (100kW)

-400,000

-200,000

0

200,000

400,000

600,000

800,000

1,000,000

1,200,000

0 5 10 15 20 25Years

Cumulative Savings

6.3 Photov oltaic Conclu sion s

Due to the large dependency on electricity for the site for existing space heating, lighting andproduction power, there is a benefit to the site to reduce its dependency on fossil fuel derivedelectricity and utilise renewable Green electricity. This can be realised in a number of ways. Ascheme to provide electricity independent to the grid will give increased security of supply, affordsome protection from price rises in fossil fuels, and assist in meeting the companys drive to reducetheir carbon emissions either through internal targets or as part of a Governmental scheme, such asCarbon reduction Commitment (CRC) or European Union Emissions Trading Scheme (EUETS)

The two example scenarios chosen give an indication of the potential that is available throughPhotovoltaic. The simple payback for both the stand alone single building and large scale centralmodular array provide a payback of around 8-9 years with the current Feed in Tariff rates guaranteedfor the next 25 years.

Whilst this may be considered too long for many projects the full benefit of a scheme will need to beevaluated in order to define the true costs and savings in light of future legislation and companydrivers.

It is important to note that a fixed 3% annual increase in fuel costs has been assumed, this may infact be much higher over the next 5-10 years. Also the overall savings from the scheme during the lifeof the equipment will be positive, indicating 50k-80k and 600k-1M lifetime savings between thestand alone and modular solutions respectively.

One area that has been ignored during this study has been the maintenance of the equipment. Dueto the fit and forget nature of the PV panels and inverters, there is very little maintenance requiredother than usual periodic electricity certification and possible some cleaning of the arrays dependanton fouling by birds and local atmospheric conditions.


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7. Solar Thermal

7.1 Solar Thermal Panel Perform ance

The solar energy available for solar thermal is common to that for PV systems. For anoptimised collector the available thermal energy that can be collected will be dependent onthe following efficiency coefficients.

The ability for the panel to collect and transfer the solar energy to the working fluid will bedependent on a number of factors. The raw conversions factor, the losses from the panel

due to radiation or re-radiation and conduction, and the ambient air temperature and requiredoff water temperature the panel is operating within. Each panel will have known efficiencycoefficients as part of its specification. The efficiency coefficients will be related to theaperture area of the collector: These parameters describe the efficiency of the collectorunder certain conditions of irradiation and temperatures.

The efficiency at an irradiation G, a mean collector temperature Tm and the ambienttemperature Ta can be computed as follows:

True Panel efficiency T= 0 (a1 * x) (a2 * G * x)Where: x = (Tm Ta) / G

0 = Conversion factorLoss coefficient a1 W/(mK)Loss coefficient a2 W/(mK)

For a typical flat plate collector example, panel model Caotec CAO TLP, has been selectedbased on a designed to provide 50oC supply off temperature. The following table can beestablished to determine performance for the selected location.

Month G Ta 0 Tm a1 a2True Panel

EffT

Jan 1220 5.3 0.802 50 3.8 0.0067 65.2%

Feb 2070 5.8 0.802 50 3.8 0.0067 71.5%

Mar 2960 7.1 0.802 50 3.8 0.0067 74.3%

Apr 4430 9.0 0.802 50 3.8 0.0067 76.4%

May 4870 12.2 0.802 50 3.8 0.0067 77.1%

Jun 5000 15.1 0.802 50 3.8 0.0067 77.4%

Jul 5100 17.3 0.802 50 3.8 0.0067 77.6%

Aug 4660 17.6 0.802 50 3.8 0.0067 77.4%

Sep 3690 15.1 0.802 50 3.8 0.0067 76.4%

Oct 2370 12.0 0.802 50 3.8 0.0067 73.7%

Nov 1520 8.0 0.802 50 3.8 0.0067 68.9%Dec 955 5.4 0.802 50 3.8 0.0067 61.1%

Year 3240 10.8 0.802 50 3.8 0.0067 75.3%


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Therefore it is possible to determine the seasonal efficiency of the panel based on localclimatic and insolation data.

The application of solar heating appear to be beneficial for instances of heating water that issupplied at low ambient conditions (5oC-10oC) prior to any additional heating for point of useconsumption. In cases where process or space heating is required, the design of the systemis normally required to heat the working fluid a maximum range between flow and return of10-20oC differential once the system is at operating temperature.

The sizing of conventional space heat exchangers/radiators etc. would normally require atemperature flow of say 82oC, and 72oC return, thereby giving the designed temperaturedrop. The temperatures available from the solar collector fall too low to be of benefit to theheating effect for conventional heating i.e. generally using flat plate panel technology it wouldnot normally be expected to increase the off panel temperature above 50oC. In someinstances where under floor heating has been installed a designed flow temperature of 50oCwill be suffice, but only useful during periods when ambient air temperature is low.

Consideration has been made into the supply of the MTV Production Building ProcessHeating. A review of the system design indicates that both space heating, by means of airhandling plant, and process heating of the fluidised bed dryer is required.

The two kerosene oil fired boilers are rated at 120kW each and provide hot water to closedcircuit heating coils within a number of air handling units for space heating around the facility.In addition to the heating circuits, there is a non-storage calorifier used to provide hot waterto the drying table. As the design of these circuits are based around a flow temperature of90oC and return of 70oC this is outside the useful range of solar thermal systems. SolarThermal therefore cannot be considered to assist in heating the hot water used forproduction.

Solar heating of HWS system for the Spectral Building

This building has been chosen as an example due to the previously known data regardingits thermal oil usage from the previous energy site study. It is believed that this buildingsactivities will be replaced over time within the new Spectral production building but hasbeen chosen as a typical example to evaluate a solar thermal solution.

7.2 Solar heat ing of HWS and heat ing circu its for the Spectral Build ing

The spectral building was reported to have used 497,111kWh of thermal oil during the 12month period of June 2007 May 2008. Summer consumption accounted for an estimated

963kWh/day presumed for HWS production. Comments cannot be made regarding thesignificance of the summer load compared to the winter consumption, but it is assumed forthe purpose of this study to be for HWS production.


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The HWS production is therefore assumed to be constant across the year and will be used

as the basis for this evaluation.

Annual HWS load = 50Wks x 7days x 963kWh/day x 65% seasonal boiler efficiency =219,082kWh/annum hot water consumption.

Annual cost of production of HWS = (219,082kWh / 0.65 Boiler Eff) x 0.728p/litre* x10.7kWh/litre = 22919/annum (*Cost of Fuel from previous survey)

In order to fulfil this supply of production the daily consumption will be spread over the 24hours and the design of a suitable HWS storage vessel capable of holding the daily usage ofhot water will be considered.

0.65 x 963 = 635kWh/day equivalent to 26kW demand.

There are several options that can be taken to size the array;

Design Array for 100% HWS daily production based on highest monthly irradiance

Design Array for 100% HWS daily production based on lowest monthly irradiance

The chosen option to provide a solution to provide hot water production will be todesign the Array for 100% HWS daily production based on average yearly irradiance.

From the solar thermal panel efficiency table above, an average seasonal conversionefficiency of 75.3% can be determined for the location and panel chosen.

From the previous PV solar irradiance data it can be seen that the average insolationequates to 5.10kWh/m2/day. Therefore based on 75.3% efficiency the solar thermal arraywould need to be:

635kWh/day / (5.10kWh/m2/day x 0.753 Conversion Eff) = 165m2

Therefore given the specification of the example panel Caotec CAO TLP with an aperture of

1.818m2

and Gross area of 2.095m2

this will require 91 panels covering a gross total arrayarea of 191m2.

To provide the load of 26kW at peak irradiance levels during highest irradiance day wouldonly require the following size panel:

Load of 26,000W / (Panel Peak Power *801W/m2 x June Seasonal Eff of 0.774) = 37.9m2 ofnet collector area (21 panels equating to an array of 44m2). (* Taken from PanelSpecification sheet)

Thermal Energy Storage

The storage requirements to contain hot water for 635kWh of energy equates to:


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(635 x 1000W x 3600 sec) / (4.19kJ/kgoC x (50oC 5oC)) = 12,012kg of water

As 1 litre = 1kg this will equate to 12m3 volume water tank. This could be contained in aninsulated tank approximately 2.2m long x 2.2m wide x 2.2m high.


Offset SavingsCalculated hot water production = 219,082kWh/annumCalculated offset thermal energy for Hot Water = 337,050kWh/annumCost of current fuel = 0.728/litre * 10.7kWh/litre = 6.8p/kWh

Annual Offset Savings = 337,050kWh x 0.068 = 22,919/annum

The cost of running Solar Thermal circulation pump will need to be determined:

For a 1kW pump operating 50% of the year (daylight hours) will be

1kW x 4350 hours x 6.8p/kWh = 295.00 which is a small proportion against the overallsavings of the scheme.

Renewable Heat IncentiveRHI is based on the installed thermal load (20kW-100kW) for April 2012 onwards =17.0p/kWh

Annual RHI income = 219,082kWh x 0.17 = 37,243/annum

Total Financial savings = 22,919 + 37,243 - 295 = 59,867/annum

Cost of System

For an estimate cost per kW thermal installed an estimated costs of 1500/kWt installed has

been used. The costs of the collectors,

From above with the array size of 165m2 and for the example panel with requires 91 panels.Each panel has a peak output of 801W which equates to 72,891Wt peak output for an annualaverage output of 26,000W or 35% seasonal loading.

72.9kW x 1,500 = 109,000 estimated capital cost

An average cost of a 73kWt system is expected to be in the region of 110,000 based on1,500/kWt installed system. The cost of the storage system is not included, and therefore anestimated additional cost of say 30,000 may be required raising te capital cost to 140,000.

It is also noted that the existing system for heating the water may still be required due to theinability to keep the hot water above required safety standards e.g. legionella protection.


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Therefore the simple payback of this scheme would indicate 2-3 years at todays rates. The

RHI is currently under review, current indications show its application in the domestic arenaand there is little information on commercial/industrial applications. Therefore the publishedrates have been used but these have been issued under the requirements for Deeming (seeAppendix 9.3.2 Deeming) and therefore until the full regulations are issued, the support ofthe RHI will not be truly known until at earliest the end of 2011. It is important to note that theRHI will be index linked to RPI for a guaranteed 20 years.

7.3 Solar Thermal Conclu sion s

It is evident that solar thermal heating is limited in schemes where the design hot watertemperature is above 50oC and does not involve the heating of water below this temperature.

The selection of the example site was based on previous survey information. If a building orprocess is found to have hot water production requirements as opposed to space heatingloads, then this technology may prove beneficial in those instances.

There are currently a number of factors that will determine whether the financial modelprovides a benefit to Chemring for the limited number of applications around the site. Thegreatest impact comes in the determination of the Deeming criteria. Where the assumptionhas been that all thermal energy will be provided and offset from the solution, the RHI benefit

may be substantially lower for the scheme when it finally is rolled out. Maintenance of a SolarThermal system will be higher than that of the existing fossil fuel heated system. Potentiallydraining of the system in winter, more pumps and valves to operate and maintain, andperiodic checks will be required during its operation in addition to the original system. For thisreason care should be taken when looking at the lower payback period of the solar thermalopportunities compared to that of PV unless all factors are known..


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8. Appendix A Solar Irradiance Data

Chemring

Countermeasures


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8.1 Average Solar Irradiance for Chemring Coun termeasures (SP4 6AS)

20 Year Average Daily Solar Irradiance Values [W/m2] (CIBSE Guide J)

It is important to recognise that the availability of insolation will vary across the year,dependant on the month of the year and time of day will determine when to expect insolationand when peak values occurs.

In the case of PV, unless the system has a means to store the energy, the use of solar powerwill be required to be utilised instantaneously. Certain installation will utilise battery banks to

store the power for use at a later period. Due to the additional cost and maintenancerequirements for these battery systems they have not been considered within this study.

Where solar thermal is concerned, it is often possible to store the heat gained during the dayfor use outside normal irradiance periods. The thermal energy can be captured in asubstance of high specific heat capacity. Water as a working within a solar thermal system isoften used due to its moderate thermal capacity, stored in large tanks where it can be usedto supplement conventional hot water services.

The table and graph below show the solar Irradiance for a site in similar coordinates toChemring Countermeasures facility. The variation on availability as well as peak irradiance

values can be easily identified across the 12 months.

MonthkWh/m

2/

Day

kWh/m2/

Month

Jan 0.73 22.6

Feb 1.38 38.6

Mar 2.34 72.5

Apr 3.9 117

May 4.79 149

Jun 5.14 154

Jul 5.12 159

Aug 4.31 134

Sep 2.98 89.4

Oct 1.67 51.9

Nov 0.92 27.5

Dec 0.56 17.2

Yearly

average2.83 86

Total

for year1030


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8.1.1 Solar Irradiance across time of day (W/m2)

Time Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

00:00 0 0 0 0 0 0 0 0 0 0 0 0

01:00 0 0 0 0 0 0 0 0 0 0 0 0

02:00 0 0 0 0 0 0 0 0 0 0 0 0

03:00 0 0 0 0 0 17 13 0 0 0 0 0

04:00 0 0 0 19 43 54 45 27 0 0 0 0

05:00 0 0 23 70 144 162 143 91 30 0 0 0

06:00 0 19 78 199 276 318 281 211 117 32 0 0

07:00 22 68 197 352 429 482 435 366 263 119 29 0

08:00 75 172 343 515 585 625 579 519 409 253 111 37

09:00 171 293 469 626 717 750 697 639 530 386 227 122

10:00 257 391 562 721 805 835 781 738 605 466 312 204

11:00 300 447 623 775 847 879 820 771 642 486 357 24312:00 300 440 617 779 846 884 830 764 657 481 341 236

13:00 245 389 568 721 802 825 779 719 613 442 286 190

14:00 156 302 476 643 715 739 695 643 522 357 198 115

15:00 73 181 348 505 584 611 576 502 393 227 102 36

16:00 24 69 199 356 439 470 437 344 239 111 30 0

17:00 0 19 76 190 277 312 287 194 111 31 0 0

18:00 0 0 21 68 142 164 140 85 31 0 0 0

19:00 0 0 0 19 39 56 43 25 0 0 0 0

20:00 0 0 0 0 0 17 12 0 0 0 0 0

21:00 0 0 0 0 0 0 0 0 0 0 0 0

22:00 0 0 0 0 0 0 0 0 0 0 0 0

23:00 0 0 0 0 0 0 0 0 0 0 0 0


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Appendix B Photovoltaic Panels

PV panels can come in a number of different compositions utilising different manufacturingprocesses and offering varying conversion efficiencies. The three main types areMonocrystalline, Polycrystalline, and Amorphous Silicon cells.

Monocrystalline Silicon PV (Mono-Si)

To produce Monocrystalline silicon a crystal of silicon is grown from highly puremolten silicon. This single crystal cylindrical ingot is cut into thin slices between 0.2and 0.3mm thick- this is the basis of a solar PV cell. The edges are cut off to give a

hexagonal shape so more can be fitted onto the module. These PV cells haveefficiencies of 13-17% and are the most efficient type of the three types of silicon PVcell. However, they require more time and energy to produce than polycrystallinesilicon PV cells, and are therefore slightly more expensive.

Polycrystalline Silicon PV (Poly-Si)

Polycrystalline silicon is also produced from a molten and highly pure molten silicon,but using a casting process. The silicon is heated to a high temperature and cooledunder controlled conditions as a mould. It sets as an irregular poly- or multi-crystalform. The square silicon block is then cut into 0.3mm slices. The typical blue

appearance is due to the application of an anti-reflective layer. The thickness of thislayer determines the colour- blue has the best optical qualities. It reflects the least andabsorbs the most light. More chemical processes and fixing of the conducting grid andelectrical contacts complete the process. Mass-produced polycrystalline PV cellmodules have an efficiency of 11-15%.

Amorphous Silicon PV (a-Si)

Amorphous silicon is non-crystalline silicon. Cells made from this material are found inpocket calculators etc. The layer of semi-conductor material is only 0.5-2.0um thick,where 1um is 0.001mm. This means that considerably fewer raw materials arenecessary in their production compared with crystalline silicon PV production. The filmof amorphous silicon is deposited as a gas on a surface such as glass. Furtherchemical processes, the fixing of a conducting grid and electrical contacts follow.These PV cells have an efficiency of between 6-8%. Multi-junction amorphous thin filmPV cells with each layer sensitive to different wavelengths of the light spectrum arealso available. These have slightly higher efficiencies. This type of PV cell is notcurrently suitable for use on residential or commercial developments due to the lowgeneration density.


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9. Appendix C Renewable Energy Support

9.1 Micr o-generation Certif ication Scheme (MCS)

The Micro-generation Certification Scheme was set up to ensure that the public is protectedfrom rogue renewable energy installers. Each product to be eligible for the FiT or RHIschemes must be MCS registered, and each installation done by a MCS registered installer.As long as a product is listed on the MCS product list and is installed by a registered installerthen there should be no issues in eligibility. MCS are responsible for renewable installations

between 0kW and 50kW.

Where renewable installations are between 50kW and 5MW in capacity, they will need toapply to Ofgem for accreditation through Ofgems Renewable and CHP Register(www.ofgem.gov.uk/Sustainability/Environment/RCHPreg). Upon completion of this process,applicants will need to contact a supplier with the accreditation details in order to receive thecredits for all renewable energy generated.

9.2 Feed in Tariff (FiT)

In April 2010 the UK Government introduced Feed In Tariffs to encourage the installation ofrenewable electricity generating technology in all types of buildings across the UK. Under thisscheme the system owner is paid a fixed rate for every kilowatt hour (kWh) of renewableelectricity that is generated, regardless of whether it is use within the site or exported. Forelectricity that is not use within the site will be paid an additional rate for every KWh that isfeed back into the national grid. This will result in reduced electricity costs as the site willpurchase less electricity from its supplier.

9.2.1 Feed In Tariff Rates

FIT (Feed In Tariffs)

Technology ScaleTariff level for new installations in period

(p/KWh)(Tariffs RPI Indexed annually)

TariffLifetime(years)

Year 1 Year 2 Year 3

01/04/2010 01/04/2011 01/04/2012

31/03/2011 31/03/2012 31/03/2013

Anaerobic digestion 500kW 11.5 11.5 11.5 20

Anaerobic digestion 500kW 9.0 9.0 9.0 20

Hydro 15 kW 19.9 19.9 19.9 20

Hydro 15 - 100kW 17.8 17.8 17.8 20

Hydro 100 - 2MW 11.0 11.0 11.0 20

Hydro 2MW - 5MW 4.5 4.5 4.5 20Micro CHP pilot 2 KW 10.0 10.0 10.0 10

Photo-Voltaic (PV) 4 Kw (new

build)36.1 36.1 36.1 25

Photo-Voltaic (PV) 4 Kw (retrofit) 41.3 41.3 37.8 25


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Technology ScaleTariff level for new installations in period

(p/KWh)(Tariffs RPI Indexed annually)

TariffLifetime(years)

Year 1 Year 2 Year 3

01/04/2010 01/04/2011 01/04/2012

31/03/2011 31/03/2012 31/03/2013

Photo-Voltaic (PV) 4 10kW 36.1 36.1 33.0 25

Photo-Voltaic (PV) 10 10kW 31.4 31.4 28.7 25

Photo-Voltaic (PV) 100 - 5MW 29.3 29.3 26.8 25

Photo-Voltaic (PV)Standalone

system29.3 29.3 29.3 25

Wind 1.5kW 34.5 34.5 32.6 20

Wind 1.5 - 15kW 26.7 26.7 25.5 20

Wind 15 - 100kW 24.1 24.1 23.0 20

Wind 100 - 500kW 18.8 18.8 18.8 20

Wind 500 - 1.5MW 9.4 9.4 9.4 20

Wind 1.5 - 5MW 4.5 4.5 4.5 20

Existing micro generatorstransferred from the RO

9.0 9.0 9.0 to 2027

9.3 Renewab le Heat Incentiv e (RHI)

As set out in the UK Governments UK Low Carbon Transition Plan and Renewable EnergyStrategy, July 2009, the Government planned to introduce a Renewable Heat Incentive(RHI) in June 2011 to encourage the installation of renewable heat technologies throughout

the economy. The RHI is very similar to the FIT scheme for renewable electricity, but appliesto technologies that generate heating in a renewable fashion. The RHI is now due to comeinto effect in November 2011 (delayed from June 2011). The RHI is being put in place toencourage the take-up of renewable heat technologies that remain more expensive to installand run than traditional fossil-fuel heating systems. It is for this reason that the Governmentis setting up a cash incentive scheme whereby under the RHI you will be paid annually onthe total amount of heat generated, expressed in kWh. The scheme aims to generate areturn on investment of 12% for all technologies and 6% for Solar thermal. This is more thanthe investment return the FIT scheme attempts to achieve and this is because thetechnologies available are less well known, more expensive to purchase and run on astandalone basis (i.e. there is no grid connectivity to allow the generator to sell excess

production). Solar thermal gets a lower rate of return as it is a widely known technology withlower barriers to entry and cheaper installation costs.

Solar Thermal: Collects heat from the sun which transfers the heat to the building. All solarsystems contain a storage element in the form of a hot water tank that ensures the hotwater/heat can be supplied at the desired time rather than just when the sun is shining.


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9.3.1 RHI Proposed Rates

RHI (Renewable Heat Incentives)

Technology ScaleProposed

tariff (p/kWh)Deemed or

MeteredTariff lifetime

(years)

Small installations

Solid biomass Up to 45kW 9.0 Deemed 15

Bioliquids Up to 45kW 6.5 Deemed 15

Biogas on - site combustion Up to 45kW 5.5 Deemed 10

Ground source heat pumps Up to 45kW 7.0 Deemed 23

Air source heat pumps Up to 45kW 7.5 Deemed 18

Solar thermal Up to 20kW 18.0 Deemed 20

Medium installationsSolid biomass 45 - 500kW 6.5 Deemed 15

Biogas on - site combustion 45 - 200kW 5.5 Deemed 10

Ground source heat pumps 45 - 350kW 5.5 Deemed 20

Air source heat pumps 45 - 350 2.0 Deemed 20

Solar thermal 20 - 100 17.0 Deemed 20

Large installations

Solid biomass 500 Plus 1.6 - 2.5 metered 15

Ground source heat pumps 350 plus 1.5 metered 20

9.3.2 Deeming

Deeming is the process whereby a building will be assessed on how much heat it actuallyneeds to heat it to a certain temperature. Thus, the payment from the RHI will be based uponthe amount of heat required to heat a property, rather than the actual amount of heat used bythat property over a certain period.

The Domestic Hot Water and Space Heating requirements for any building will be estimatedusing the BREDEM (the Building Research Establishment Domestic Energy Model). This is astandardised model for estimating the amount of energy required by a property for spaceheating and Domestic Hot Water (DHW). It is a simple, long established, method ofestimating energy use. It considers both the physical aspects of a property and the lifestyle of

the occupants.

Unfortunately it does not take into account how the occupier actually uses the heatingsystem, but takes a standard level of heating requirement (21 degrees for a living room, and18 degrees for other areas, with 2 hours of heating used in the mornings and 7 hours at nightfor weekdays, with 13 hours a day at weekends). This way, it produces a very standardisedenergy rating for a property, disregarding the individual occupiers preferences for howhot/cool they actually use the property, thus allowing homes to be compared on a like for likebasis. For Hot Water requirements it ignores the actual number of people that actually live ina building, but focuses on the actually floor area of a building, assuming that a larger floorarea will have more people living there. In essence, it will provide an energy rating that isindependent of the size of the home, providing an energy rating per square meter. The modelgives accurate results, often within a +/- 10% reading of actual data readings.


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10. Appendix D Solar Thermal Collectors

Solar thermal systems use energy from the sun to heat water. This replaces other energysources such as natural gas and electricity as a means of providing hot water to buildings forHWS or heating services.

The most important part of a solar thermal system is the collector. The collectors role is toabsorb the suns energy and efficiently convert it to heat for transfer to the hot water system.The collector is normally mounted on the roof of a building. There are a number of differenttypes of solar thermal system; a typical system is shown below.

Hot water is supplied to the building by transferringthe heat (energy) absorbed by the collector andpumping it down to the cylinder tank.

Here the hot water heats the cooler feed water viaa heat exchanger coil. The fluid within the collectorcircuit usually contains an antifreeze ton preventfreezing during cold weather. The cylinder usedhas a second heat exchanger circuit at the top ofthe cylinder designed to heat the tempered water

to required full operating temperature.

During sunny summer weather the thermal heat from the collector may be of sufficienttemperature to heat the water to full operating temperature without additional top up heatingfrom the boiler.

This application may be suitable for applications where there is a known hot water demandfor which the system can be calculated. IN the instance for space heating, there becomes theissue that the system provides hot water when it is likely not to be required i.e. during warmerweather. Therefore purpose design and installation of solar heating systems are not normally

provided solely around space heating only.

Flat Plate CollectorThe construction of a solar panel follows that of aradiator, where the working fluid is channelledacross a heat absorbing material (usually metal dueto its inherent high thermal conduction properties)where it then able to absorb the heat into theworking fluid to be passed by means of a pump tothe point of application. The absorbent material isusually matt black to minimise re-reflection of theinsolation and a glazed envelope is placed acrossthe collector to prevent wind cooling and minimiseconduction losses.


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Evacuated Tube Collector

Evacuated tube collectors are also used wherehigher water temperatures are required. Heatpipes with one end enclosed in a clear evacuatedtube transfer the heat energy across viaconduction into heater pipe where liquid ispumped through collecting the thermal energy.This system although more expensive reduceslosses to the surrounding and the likelihood offreezing of the working fluid in winter and provides

higher water temperatures. Due to the mechanicsof the heat pipe, the collector is often required tobe mounted at a particular angle to ensureoperation.


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11. Appendix E Solar Panel Data

Product

Manufactu

rer

Width

(mm)

Height

(mm)

Area(Metre

Squared)

Watts permetre

squared

Efficiency

% Technology

PeakOutput

(Watts)

Peak

Voltage

Peak

Current

MaximumSystem

VoltageNE-80EJEA Sharp 1200 537 0.64 124.15 12.41 Polycrystalline 80 21.60 4.63 600

NE-165UC1 Sharp 1575 826 1.30 126.83 12.68 Polycrystalline 165 34.60 4.77 600

NE-170UC1 Sharp 1575 826 1.30 130.67 13.07 Polycrystalline 170 34.80 4.90 600

ND-123UJF Sharp 1499 662 0.99 123.95 12.39 Polycrystalline 123 17.20 7.15 600

ND-130UJF Sharp 1499 662 0.99 131.00 13.10 Polycrystalline 130 17.40 7.50 600

ND-176UC1 Sharp 1328 994 1.32 133.33 13.33 Polycrystalline 176 23.42 7.52 600



NU-U230F3 Sharp 1640 994 1.63 141.09 14.11 Monocrystalline 230 30.00 7.67 600

NU-U235F1 Sharp 1640 994 1.63 144.16 14.42 Monocrystalline 235 30.00 8.40 600

NA-V115H5 Sharp 1409 1009 1.42 80.89 8.09 Thin Film 115 174.00 0.66 1000





KD210GH-2PU Kyocera 1500 990 1.49 141.41 14.14 Polycrystalline 210 26.60 7.90 1000KD185GH-2PU Kyocera 1338 990 1.32 139.66 13.97 Polycrystalline 185 23.60 7.84 1000

KD135GH-2PU Kyocera 1500 668 1.00 134.73 13.47 Polycrystalline 135 17.70 7.63 1000

KD135SX-1PU Kyocera 1500 668 1.00 134.73 13.47 Polycrystalline 135 17.70 7.63 750

KD95SX-1P Kyocera 1043 660 0.69 138.01 13.80 Polycrystalline 95 17.90 5.31 750

KD70SX-1P Kyocera 778 660 0.51 136.32 13.63 Polycrystalline 70 17.90 3.92 750

KD50SE-1P Kyocera 706 744 0.53 95.19 9.52 Polycrystalline 50 17.90 2.80 750

KC16T Kyocera 517 280 0.14 110.53 11.05 Polycrystalline 16 17.40 0.93 50



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ProductManufactu

rerWidth(mm)

Height(mm)

Area(Metre

Squared)

Watts permetre

squaredEfficiency

% Technology

PeakOutput(Watts)

PeakVoltage

PeakCurrent

MaximumSystemVoltage


BP350J BP Solar 839 537 0.45 110.98 11.10 Polycrystalline 50 17.50 2.90 600

BP380J BP Solar 1209 537 0.65 123.22 12.32 Polycrystalline 80 17.60 4.60 600

BP3160N BP Solar 1593 790 1.26 127.14 12.71 Polycrystalline 160 35.10 4.55 1000



BP4175T BP Solar 1587 790 1.25 139.58 13.96 Polycrystalline 175 35.40 4.90 1000

SX-305M BP Solar 269 251 0.07 74.05 7.41 Polycrystalline 5 16.50 0.27 50

SX-310J BP Solar 425 273 0.12 86.19 8.62 Polycrystalline 10 16.80 0.59 50

SX-320U BP Solar 502 425 0.21 93.74 9.37 Polycrystalline 20 16.80 1.19 50

SX-330U BP Solar 595 502 0.30 100.44 10.04 Polycrystalline 30 16.80 1.78 50

PowerGlaz RG-SMT5(36)M Romag 1197 530 0.63 130.83 13.08 Monocrystalline 83 18.10 4.60 1000

PowerGlaz RG-SMT6(48)P 648185 Romag 1318 994 1.31 141.21 14.12 Polycrystalline 185 24.50 7.70 1000






PowerGlaz RG-SMT6(54)P 654210 Romag 1482 994 1.47 142.56 14.26 Polycrystalline 210 27.54 7.60 1000PowerGlaz RG-SMT6(54)P 654200 Romag 1482 994 1.47 135.77 13.58 Polycrystalline 200 26.91 7.50 1000










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ProductManufactu

rerWidth(mm)

Height(mm)

Area(Metre

Squared)

Watts permetre

squaredEfficiency

% Technology

PeakOutput(Watts)

PeakVoltage

PeakCurrent


HIT-240HDE4 Sanyo 1610 861 1.39 173.13 17.31 HIT 240 35.50 6.77 1000

HIT-235HDE4 Sanyo 1610 861 1.39 169.53 16.95 HIT 235 35.10 6.70 1000

HIT-205DNKHE1 Sanyo 1630 862 1.41 145.90 14.59 HIT 205 41.30 4.97 1000

HIT-200DNKHE1 Sanyo 1630 862 1.41 142.34 14.23 HIT 200 40.70 4.92 1000

HIT-N220E01 Sanyo 1580 798 1.26 174.49 17.45 HIT 220 41.60 5.31 1000

HIT-N215E01 Sanyo 1580 798 1.26 170.52 17.05 HIT 215 40.90 5.27 1000

Imerys Roof Tile Imerys 1377 475 0.65 84.09 8.41 Polycrystalline 55 0.00 0.00 0

SCHOTT POLY 225 Schott 1685 993 1.67 134.47 13.45 Polycrystalline 225 29.80 7.55 600




PV-TD175MF5 Mitsubishi 1658 834 1.38 126.56 12.66 Polycrystalline 175 23.90 7.32 1000




PV-TE130MF5N Mitsubishi 1495 674 1.01 129.02 12.90 Polycrystalline 130 17.40 7.47 1000



PV-TE115MF5N Mitsubishi 1495 674 1.01 114.13 11.41 Polycrystalline 115 17.10 6.75 1000PV-MF185TD4 Mitsubishi 1658 834 1.38 133.79 13.38 Polycrystalline 185 24.40 7.58 780

PV-MF180TD4 Mitsubishi 1658 834 1.38 130.17 13.02 Polycrystalline 180 24.20 7.45 780



PV-MF130TE4N Mitsubishi 1495 674 1.01 129.02 12.90 Polycrystalline 130 17.40 7.47 780




PV-AD190MF5 Mitsubishi 1658 834 1.38 137.41 13.74 Polycrystalline 190 24.70 7.71 1000


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ProductManufactu

rerWidth(mm)

Height(mm)

Area(Metre

Squared)

Watts permetre

squaredEfficiency

% Technology

PeakOutput(Watts)

PeakVoltage

PeakCurrent





PV-AE130MF5N Mitsubishi 1495 674 1.01 129.02 12.90 Polycrystalline 130 17.40 8.05 1000




PV-MF170EB4 Mitsubishi 1580 800 1.26 134.49 13.45 Polycrystalline 170 24.60 6.93 780


PV-MF125EA4 Mitsubishi 1248 803 1.00 124.73 12.47 Polycrystalline 125 18.80 6.63 600

PV-MF120EC4 Mitsubishi 1425 646 0.92 130.36 13.04 Polycrystalline 120 17.60 6.84 780

PV-MF110EC4 Mitsubishi 1425 646 0.92 119.49 11.95 Polycrystalline 110 17.10 6.43 780


PV-MF130EA4 Mitsubishi 1248 803 1.00 129.72 12.97 Polycrystalline 130 19.20 6.79 600

YL 165 P-23b Yingli 1310 990 1.30 127.23 12.72 Polycrystalline 165 23.00 7.17 1000





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