NA-FxxxGx series

SYSTEM DESIGN BOOK ~Thin-film PV system~

NA-FxxxGx

Please read this book carefully before installing the thin-film PV system

SED0911001 Ver2.0

NA-FxxxGx series

Revision Record

SIGNATURE No. DATE CHANGE PAGE

Approved by Checked by Prepared by

1 JUN.3.2009 First Issue

2 NOV.4.2009

From chapterⅠ to

chapterⅦ are totally

revised.

Number of series at line

15th is revised.

Change the description

of PV module type in

Appendix.

Chapter

Ⅰ～Ⅶ

21

Appendix

NA-FxxxGx series

Content Ⅰ.BEFORE INSTALLATION·····················································1

Ⅱ.GENERAL WARNING ····························································1

Ⅲ.INSTALLATION CONDITION ·················································2 Ⅲ.1 LOCATION······················································································································· 2 Ⅲ.2 INCLINATION ANGLE AND DIRECTION OF THE PV MODULE·································· 6 Ⅲ.3 NO NEGATIVE VOLTAGE ON SHARP THIN-FILM MODULE······································ 8

Ⅲ.3.1 COUNTERMEASURES ··················································································· 10 Ⅲ.4 INVERTER······················································································································· 11 Ⅲ.5 CONNECTION OF THE MODULE···················································································· 12

Ⅳ. SPECIAL NOTE OF THE THIN FILM PV MODULE SPECIFICATION·······15 Ⅳ.1 INITIAL AGING················································································································ 15 Ⅳ.2 QUANTUM EFFICIENCY VS WAVELENGTH CHARACTERISTICS··························· 15 Ⅳ.3 LONG TERM VARIATION AND SEASONAL VARIATION OF

ELECTRICAL CHARACTERISTICS ······························· 16 Ⅳ.3.1 LONG TERM VARIATION OF ELECTRICAL CHARACTERISTICS.....................16 Ⅳ.3.2 SEASONAL VARIATION OF ELECTRICAL CHARACTERISTICS.......................16

Ⅴ. SPECIFICATION OF BALANCE OF SYSTEM (BOS) ········ 17 Ⅴ.1 INVERTER ······························································································································17

Ⅴ.1.1 MODULE POTENTIAL····························································································17 Ⅴ.1.2 CAPACITY···············································································································17

Ⅴ.2 PROTECTION DEVICES········································································································18 Ⅴ.2.1 DIODE························································································································18 Ⅴ.2.2 FUSE··························································································································18

Ⅴ.3 DC DESIGNING AND SIZING CABLES.................................................................................20 Ⅴ.3.1 MINIMIZING OF THE VOLTAGE LOSSES·····························································20 Ⅴ.3.2 WITHSTAND VOLTAGE··························································································20 Ⅴ.3.3 CURRENT CARRYING CAPACITY········································································20

Ⅵ. SYSTEM DESIGN EXAMPLE ·············································· 21 Ⅵ.1 EXAMPLE OF 1MW PV SYSTEM DESIGN···········································································21

Ⅵ.1.1 SYSTEM CONFIGURATION (10kW) ·····································································21 Ⅵ.1.2 SYSTEM IMAGE (10kW) ························································································22 Ⅵ.1.3 EQUIPMENT LIST (10kW)······················································································22

Ⅵ.2 EQUIPMENT LIST PER CAPACITY OF PV SYSTEM···························································22

Ⅶ. ESTIMATION OF THE GENERATING POWER ················· 23

APPENDIX APPENDIX EFFECTS OF SHADE

1

Ⅰ. BEFORE INSTALLATION a) Before designing a PV system with SHARP PV modules (Type NA-FxxxGx), please read

this document carefully for correct design and installations.

b) This document provides supplementary information as a guideline on the PV system design for system designers, installers, operators, and field engineers in charge of maintenance. We shall not guarantee the contents of this document, and shall not be responsible for any damage caused by the contents and accuracy of this document.

c) Please check the latest electrical and mechanical specifications of the products (PV

module, inverter etc.). d) Before designing PV system and installation please make sure the national and local

rules and regulations, corresponding standards, required licenses etc. In most case, contact with local government, grid- company, or/and related agencies is necessary.

e) Only qualified person such as qualified engineer shall install, operate and maintain PV system.

Ⅱ. GENERAL WARNING Please see all the warnings written on each specification of PV systems and follow

them.

PV system shall be designed under the specification of all products.

Please read the installation manual carefully and follow the instruction of each ground-required product.

Keep non qualified person away from all PV system component.

PICTRIAL INDICATION Various pictorial indications are included in this manual. Such indications and their meanings are as follows.

Must not do.

NNNooo GGGooooooddd Not recommend.

Must do.

GGGooooooddd Recommend

Read the specifications and installation manual, and follow their contents.

2

Ⅲ. INSTALLATION CONDITION Ⅲ.1Location a) Read the specifications and manual carefully before installing the PV system, and carry

out the installation procedures correctly.

b) It is recommended not to shade PV modules by surrounding trees, leaves, chimneys,

buildings and other obstacles. In general, PV system is designed not to shade adjacent PV modules at noon in winter solstice in Europe. In Japan, PV system is generally designed not to shade adjacent PV modules from 9:00 to 15:00 in winter solstice. PV modules in shade make reduction of the output power of PV modules. Dirt build-up on the glass surface and/or shading for many hours may cause PV module decoloration. (See Appendix EFFECTS OF SHADE)

Figure1.1 Effects of shade

Reduction of power generation

Decoloration by dirt and/or

shading for many hours.

NNNooo GGGooooooddd

NNNooo GGGooooooddd

θ

SHADE

At noon in winter solstice in Europe.

From 9:00 to 15:00 in winter solstice in Japan.

GGGooooooddd

3

Snow

Steel Angle PV module

Snow

PV module

c) When installing the PV system in a heavy snow area, it is recommended to fix a steel angle at the bottom head of the mounting structure in order to resist the weight of snow. If not so, the weight of heavy snow may bend down the frame of the PV module.

Figure1.2 Countermeasure in a heavy snow area

GGGooooooddd

Being bent down

NNNooo GGGooooooddd

GGGooooooddd

4

d) When the PV system is installed at the area where thunderbolt may occur, it is recommended to use the Surge Protection Devices (SPD) with PV system.

Figure1.3 Countermeasure at the area where thunderbolt may occur e) Example of the thunder protection system with air-termination rods It is recommended to make sure some points as shown below.

1. The safety distance ‘S’ between an air-termination rod and the PV array complies with IEC61024-1.

2. Air-termination rods do not shade the PV modules.

S

Safety Distance

Rolling Sphere

Air-termination Rod

Shading LinePV array

S

Safety Distance

Rolling Sphere

Air-termination Rod

Shading LinePV array

α

Combiner box Inverter

GGGooooooddd

GGGooooooddd

Figure1.4 Thunder protection system with air-termination rods

5

f) Equipotential bonding It is recommended that the equipotential grid is bonded to incoming electrically conductive system to an electric room including controller, monitoring equipments, inverter etc. All metallic parts and electrical utilities are directly connected to the equipotential grid. Also, power lines are indirectly connected to the equipotential grid through Surge Protection Devices (SPD). In order to protect building from the lightning surge intrusion, it is recommended that bonding is as close as possible to the services entrance.

DC

AC

Electric room

SPD

Equipotential grid

Air-termination rod

PV module

Combiner box

Figure1.5 Equipotential bonding

GGGooooooddd

6

Ⅲ.2 INCLINATION ANGLE AND DIRECTION OF THE PV MODULE a) In order to generate the maximum power throughout the year, it is recommended that

the PV module faces to the south. In general it is said that the best inclination angle of PV module is equal to the latitude of installation site. However if the installation site has low irradiance season such as rainy or snowy season, the inclination angle should be reconsidered to generate the maximum power throughout the year. Please refer to chapter Ⅶ b) for optimum inclination angle in cities in Europe.

Inclination angle θ

Azimuth：south

South 0°

North 0°

East 0°

West 0°

θ

Surface

Figure1.6 Inclination angle and direction

b) If the inclination angle of the PV module is 5 degrees or more, a certain amount of dirt on

the PV module glass surface would be washed off by normal rain. However, dirt may build up on the glass surface according to ambient environmental conditions even if the inclination angle is 5 degrees or more. Dirt build-up on it may cause the decrease of output power. Dirt build-up on the glass surface and/or shading for many hours may cause PV module decoloration. When maintaining the output is required, clean the PV module glass surface only with a soft cloth using water, and keep the glass surface clean.

GGGooooooddd

GGGooooooddd

θ＜5°

NNNooo GGGooooooddd Reduction of power generation

θ≧5°

GGGooooooddd PV module

Figure1.7 Inclination angle

PV module

Decoloration by dirt and/or shading for many hours.

7

c) The PV modules must be installed with the stripe lines in vertical position. The installation with the stripe lines in the horizontal position is prohibited. Because permanent damage could occur to an output characteristic of the PV modules, or corrosion of thin-film layer might appear if the PV modules are installed in the horizontal position and snow, dust and dirt cover some PV cells which are aligned with long side frame.

Prohibited Figure1.8 Installation direction

Cell

Shade or dirt

Shade and dirt

Reduction of all current from cell

Current

Output Power

Reduction of certain current from cell

Cell

8

Ⅲ.3 NO NEGATIVE VOLTAGE ON SHARP THIN-FILM MODULE

The PV module shall be set positive voltage to ground (e.g. Mounting structure, frame). If not so, PV module has the possibility of corrosion and output power is reduced.

Na+

Na+

-

+

+

-

Inverter

０Ｖ

０Ｖ

０Ｖ

Na+

-

+

＋５４０Ｖ

＋４８０Ｖ

＋０Ｖ

＋６００Ｖ

６００Ｖ

０Ｖ

０Ｖ

＋５４０Ｖ

＋６０Ｖ

Na+

Na+

-

+

+

-

Inverter

０Ｖ

０Ｖ

０Ｖ

０Ｖ

０Ｖ

Na+

-

+

-６００Ｖ

-１２０Ｖ

-６０Ｖ

６００Ｖ

０Ｖ

０Ｖ

-５４０Ｖ

-６０Ｖ

Figure1.9 No negative voltage on SHARP thin film module

Vol

tage

to g

roun

d [V

]

0

+

－

Volta

ge to

gro

und

[V]

0 +

－

! +

－

+

－

9

（REASON）

SHARP thin-film module is a superstrate design as shown below. If you do not take proper step as mentioned previously, electric potential of Transparent Conducting Oxide (TCO), which is close to cover glass, would become all negative and it makes potential difference from module frame into TCO. There is the possibility that Na ion in glass moves to the TCO if the module has the big potential difference. In this case, the TCO close to frame has the possibility of corrosion and electrical characteristics change of PV module may occur.

Figure1.10 Module structure (superstrate design)

Na+

Corrosion

0V

TCO : Negative potential

Cover Glass

Conductor

Thin film cell

Module frame

10

Ⅲ.3.1COUNTERMEASURES

There are some solutions to keep PV module positive voltage to ground. a) Use inverter which can set DC electrical potential to positive voltage to ground by the

control system, protection method, the wiring and structure etc. *Please read the details in the documents of Inverter published by manufacturers

Figure1.11 Inverter can set DC electrical potential to positive voltage to ground

b) Set the DC negative pole of the inverter to ground. Contact with the inverter manufacture and confirm the following points. 1. There is nothing wrong with the inverter which set its DC negative pole to ground. 2. This countermeasure mentioned above has no effect on protection functions (e.g. DC

ground fault detection function) of the inverter.

GGGooooooddd

Figure1.12 Inverter sets its DC negative pole to ground

Inverter Na

+

Na+

-

+

+

-

Inverter

０Ｖ

０Ｖ

０Ｖ

Na+

-

+

＋５４０Ｖ

＋４８０Ｖ

＋０Ｖ

＋６００Ｖ

６００Ｖ

０Ｖ

０Ｖ

＋５４０Ｖ

＋６０Ｖ

DC AC Use a suitable inverter to keep positive voltage of the DC side to ground.

Vol

tage

to g

roun

d [V

]0

+

－

+

－

+

－

Inverter Na

+

Na+

-

+

+

-

Inverter

０Ｖ

０Ｖ

０Ｖ

Na+

-

+

＋５４０Ｖ

＋４８０Ｖ

＋０Ｖ

＋６００Ｖ

６００Ｖ

０Ｖ

０Ｖ

＋５４０Ｖ

＋６０Ｖ

Functions

DC AC +

－

11

Ⅲ.4 INVERTER

When grounding DC system, IEC (IEC 62109-2 (CD2) 7.102.3.3) requires two conditions for Inverter.

1. The voltage of the grounded array connection must stay below 1V. 2. The current through the connection may not exceed 1A.

When one of the two conditions is not true, it is necessary to apply the protection device in order to interrupt the grounding current and the inverter has to switch off the grid within 0.3 seconds. Figure1.13 IEC (IEC 62109-2 (CD2) 7.102.3.3) requirement in case of grounded DC system

Inverters for thin-film module which can be grounded by negative pole must have the functions mentioned above. If you use an inverter which does not have the functions, ground-fault current flows in PV arrays. When earth fault or a person touching an unearthed conductor and earth simultaneously, it might cause energy hazard or electric shock.

*Quote from IEC 62109-2（CD2）7.102.3.3

Some alternations are due to make the

figure of negative pole grounding.

Ground-fault current

Figure1.14 Ground-fault current

Na+

Na+

-

+

+

-

Inverter

０Ｖ

０Ｖ

０Ｖ

Na+

-

+

＋５４０Ｖ

＋４８０Ｖ

＋０Ｖ

＋６００Ｖ

６００Ｖ

０Ｖ

０Ｖ

＋５４０Ｖ

＋６０Ｖ

＜1V ≦1A

AC

To grid

Cut the connection

Disconnect within 0.3 seconds

DC+

－

12

Ⅲ.5 CONNECTION OF THE PV MODULE

Be sure to take proper measure (e.g. fuse for protection of PV module and cable from over

current, and/or blocking diode for prevention of unbalanced strings voltage) to block reverse

current flow.

When a part of PV module is in the shade, PV cell works as resistance. Then the reverse

current flows from other strings to the failed strings, the module of which is covered by

shade. PV module could be destroyed by this reverse current which is greater than

maximum series fuse.

Be sure not to flow the reverse current which is greater than maximum series fuse into PV

module. It is recommended that protection device is connected according to the following

procedures.

Figure1.15 Connection of the PV module

Shade

Cell

Protection device

I’

I”

I=I’+I”＞

Maximum series fuse

Current

Connect the protection devices Parallel connection without the protective

measures is prohibited

Shade

I

13

a) IN CASE OF USING DIODE

Using the diodes is recommended: Connect a diode or more in series every string or every

two strings. It is necessary that it or they have enough IFAV* of the current from PV strings

and enough VRRM** of system voltage. Please determine the diode (or diodes) specification

in consideration of weather tight, ambient temperature, life time, failure rate and so on.

Connecting more than two strings with the blocking point is prohibited because the possible

reverse current from other strings may damage the module.

Figure1.16 In case of using diode

GGGooooooddd

I≦5A

OK

1 string 2 strings

Shade

I<5A

I<5A

I’<5A I”<5A

I=I’+I”<10A

+

-

or +

-

+

-

GGGooooooddd GGGooooooddd

I＞5A I＞5A I＞5A

Current

Prohibited

Shade Shade

More than 2 strings

Maximum fuse rate 5A

1 diode or more

Blocking point

14

b) IN CASE OF USING FUSE

Fuses are available: Connect a fuse which has ratings 5 ampere and rated voltage DC

greater than or equal to system voltage every string in accordance with IEC61730 (For

instance, the type Helio Fuse, Ferraz Shawmut products, is available, as of May. 2009).

More than one string with the fuse is prohibited because the possible reverse current from

another array may damage the module.

Figure1.17 In case of using fuse

Prohibited

+

-

+

-

Rated ting 5A

Rated voltage DC≧System voltage

I≦5A

OK

I≦5A I＞5A

Shade

5A I’≦5A

I”<5A

I=I’+I”<10A

Current

1 string More than

1 string

Maximum fuse rate 5A

NA-FxxxGx series

15

Ⅳ. SPECIAL NOTE OF THE THIN FILM PV MODULE SPECIFICATION Following two points are unique thin film specifications which shall be considered for system design. Ⅳ.1 INITIAL AGING Due to initial aging of the thin-film module the maximum power decline 10% or more from an initial value within a few days. It will take several periods for the maximum power to reach the rating value. Please refer to specifications sheet for details. Ⅳ.2 QUANTUM EFFICIENCY VS WAVELENGTH CHARACTERISTICS The tandem structure is shown in Figure4.1. TCO stands for Transparent Conductive Oxide. Top layer cell is of amorphous silicon. Bottom layer cell is of microcrystalline silicon. The typical Quantum Efficiency (QE) characteristics are shown in Figure4.2. Tandem structure has a wide range of wavelengths of light to be converted into electricity. Amorphous silicon generates electricity with shorter wavelengths of light. Microcrystalline silicon generates electricity with long wavelengths of light.

glasisTCO

Top cell

Bottom cellelectrode

Ligth Induce

Figure 4.1 Tandem structure

0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

350 450 550 650 750 850 950 1050 1150

Wavelength [nm]

QE

[ele

ctor

on/p

hton

]

Amorphous silicon cell(Top cell)

Micro crystal silicon cell(Bottom cell)

Figure4.2 Quantum Efficiency versus Wavelength characteristics

Glasses

Microcrystalline silicon

[ele

ctro

n/ph

oton

]

Incident light

Glasses

TCO

Top layer cell

Bottom layer cellElectrode

NA-FxxxGx series

16

Ⅳ.3 LONG TERM VARIATION AND SEASONAL VARIATION OF ELECTRICAL CHARACTERISTICS This guide describes only reference information. These are not items guaranteed. Users shall consider the other information like a tolerance of other system devices. Ⅳ.3.1 LONG TERM VARIATION OF ELECTRICAL CHARACTERISTICS The data was calculated by expedite test. <Scope> All of thin-film PV module made by Sharp Corporation which PV cell has tandem (amorphous silicon / microcrystal silicon, 2-junction) structure (NA-F115G5, NA-F121G5, NA-F128G5) <Description> Thin-film PV modules have differences between initial electrical characteristics and nominal electrical characteristics as shown in the SPECIFICATION’s DATA SHEET. After installing modules outdoor, the electrical characteristics are changed from initial characteristics. An example of a long term variation of Pmax is shown in the DATA SHEET. Please refer to the DATA SHEET for Pmax. A predicted annual average value of each characteristic after 25 years is listed below. Voc: 99 ～ 100% (relative to nominal value)

Vpm: 97 ～ 99% (relative to nominal value)

25 years

Nominal valueVoc

Nominal valueVpm

0

99 - 100%

97 - 99%

Ⅳ.3.2 SEASONAL VARIATION OF ELECTRICAL CHARACTERISTICS The data is based on exposure test in Japan and Germany. <Scope> All of thin-film PV module made by Sharp Corporation which PV cell has tandem (amorphous silicon / microcrystal silicon, 2-junction) structure (NA-F115G5, NA-F121G5, NA-F128G5) <Description> The electrical characteristics of thin-film PV modules have a seasonal effect. An example of a seasonal effect of Pmax is shown in the SPECIFICATION’s DATA SHEET. Please refer to DATA SHEET for Pmax. A predicted value of amplitude of a seasonal effect is listed below. Voc: ±0～2%

Vpm: ±1～3%

Nominal valueVoc

Nominal valueVpm

0

0～+2%

＋1～＋3%

0 ～－2%

－1～－3%

NA-FxxxGx series

17

Ⅴ. SPECIFICATION OF BALANCE OF SYSTEM (BOS) Ⅴ.1 INVERTER

It is recommended to follow the selection procedure as shown below.

Ⅴ.1.1 MODULE POTENTIAL

An inverter shall be used which can set the PV module potential to positive voltage to ground. (e.g. Mounting structure, frame). Read Ⅲ.3 and Ⅲ.4 carefully.

Ⅴ.1.2 CAPACITY

Please read the specification of the inverter carefully and select the inverter in accordance with the recommended maximum PV generator power described in specification of the inverter.

If the recommended maximum PV power is not provided in the specification, the following condition is available. However, the following factor depends on ambient environment of installation site.

Max. input DC power ≦ 1.1～1.2 × PV generator power @STC

ELECTRIC MODE

PROTECTION

COODINATION

START

RATED OUTPUT

VOLTAGE

NUMBER OF SERIES

LOCATION

END

→ Take measures not to cause trouble with the PV system as it is damaged by seawater and heavy snow.

→ Three-phase four-wire, single-phase two-wire, single-phase three-wire etc. Follow the electric mode in the installation site.

CAPACITY

MODULE POTENTIAL → The PV module shall be set positive voltage to ground. An inverter shall be used which can set the PV module potential to positive voltage to ground.

→ Follow the recommended maximum PV generator power described in specification of the inverter.

→ Rated output voltage of the inverter shall be equal to voltage at the point of

common coupling (PCC). If unable to do so, meet the voltage at the PCC

using transformer.

→ Calculate the number of series considering PV output voltage under the temperature in the installation site and input voltage range of inverter.

→ Comply with a local regulation in the installation site.

Figure5.1 Selection procedure of inverter

Ⅲ.3 and Ⅲ.4

NA-FxxxGx series

18

Ⅴ.2 PROTECTION DEVICES

In case of parallel connection, please be sure to take proper measure (e.g. fuse for protection of module and cable from over current, and/or blocking diode for prevention of unbalanced strings voltage) to block the reverse current flow. The current may easily flow in a reverse direction.

Ⅴ.2.1 DIODE

It is recommended to use the diode which has higher repetitive peak reverse voltage (VRRM) than 2400V. Please determine the diode specification considering the following current and ambient environment etc. in the installation site. The current capacity of the diode varies according to the ambient environment. ・ Output current Isc of PV module. ・ Ambient temperature where the diode installed (e.g. combiner box, collection box). ・ Life time. ・ failure rate etc.

If this is contravened, over current can easily break the diode. Ⅴ.2.2 FUSE

(ABOUT FUSE) Fuse has rated current and melting current. Rated current is a maximum current that the fuse can continuously conduct without interrupting the circuit. If melting current flows, the metal wire within fuse rises to a higher temperature and either directly melts, or else melts a soldered joint within the fuse, opening the circuit. Therefore,

Melting current ＞ Rated current

*Please contact the fuse manufacturer about fuse used.

電流　 I / I@定格

溶断

時間

[sec]

1 10 1510-3

10-2

10-1

100

104

101

102

103

GGGooooooddd

Rated current Melting current

Mel

ting

time

[sec

]

Example

Current [I / Rated I]

Figure5.2 Time-current characteristics of fuse

NA-FxxxGx series

19

Fuse must comply with following 3 conditions. 1 Rated voltage is higher than system voltage (600V or 1,000V). 2 Rated current is higher than or equal to 1.25 times initial Isc at STC based on IEC.

Rated current ≧ 1.25 times initial Isc at STC

3 Select melting current which does not allow current higher than Maximum series fuse to flow in

a reverse direction.

Figure5.3 conditions for using fuse

2 1.25×initial Isc＠STC

OOOKKK！！！ 1 Rated voltage is higher than system voltage.

I＞5A I≦5A 3

NA-FxxxGx series

20

Ⅴ.3 DC DESIGNING AND SIZING CABLES

It is recommended to follow three essential criteria: the minimizing of the voltage losses, the withstand voltage, the current carrying capacity of the cable. Ⅴ.3.1 MINIMIZING OF THE VOLTAGE LOSSES

Sizing of the cable cross-sections takes into consideration economic potential (cable power loss vs cable cost etc.) and the need for as little voltage loss (also power loss) as possible. Ⅴ.3.2 WITHSTAND VOLTAGE

The withstand voltage of the cable is higher than or equal to the system voltage (600V or 1,000V). Ⅴ.3.3 CURRENT CARRYING CAPACITY

Current carrying capacity is higher than or equal to 1.25 times initial Isc at STC. 1.25 times initial Isc at STC ≦ Current carrying capacity

Figure5.4 DC designing and sizing cables

Please read the specification of the cable carefully and confirm the current carrying capacity. Current capacity of cable varies according to the ambient environment.

Combiner box

+

－

Fuse

1 Takes into consideration voltage loss (also power loss). 2 Withstand voltage ≧ system voltage 3 1.25 times initial Isc at STC ≦ Current carrying capacity

DC cable

GGGooooooddd

NA-FxxxGx series

21

Ⅵ. SYSTEM DESIGN EXAMPLE Please follow the procedure below in designing the system. [ CONDITIONS of SYSTEM DESIGN EXAMPLE ] Grid-connected system (not stand alone system) Ⅵ.1 EXAMPLE OF 10kW PV SYSTEM DESIGN Ⅵ.1.1 SYSTEM CONFIGURATION (10kW) System capacity : 10kW PV module : NA-F121G5 (Thin-film PV module Pm=121W, Vpm=45.0V, Ipm=2.69A) Inverter : 10kW inverter with the grounding kit.

(Rated output power 10kW) Inclination angle : 35° Azimuth : South Installation method : ・The modules are installed in vertical position, 2-column, ground-based. ・Connect PV modules with 8-series per string. ・10kW system is in a configuration of 8-series×11-string. Table 6.1 10kW system configuration

Item Specification Series×strings Quantity Total Capacity 10.65kW PV module NA-F121G5

/121W 8×11 88pcs (121W × 88pcs)

Inverter 10kW inverter

with the grounding kit.

- 1unit -

NA-FxxxGx series

22

Ⅵ.1.2 SYSTEM IMAGE (10kW)

Figure6.1 System image

Ⅵ.1.3 EQUIPMENT LIST (10kW) Table6.2 Equipment list (10kW) SSppeecciiffiiccaattiioonn QQuuaannttiittyy UUnniitt

PV module Thin-film 121W 88 Pieces

Inverter 10kW 1 Unit DC combiner box 11 strings 1 Unit Mounting structure 1 Unit

Ⅵ.2 EQUIPMENT LIST PER CAPACITY OF PV SYSTEM Table6.3 Equipment list per capacity of PV system

Capacity of PV system SSppeecciiffiiccaattiioonn Unit

10kW 20kW 30kW 40kW 50kW 100kW88 176 264 352 440 880 PV module NA-F121G5

/121W

(8×11) (8×22) (8×33) (8×44) (8×55) (8×110)Inverter 10kW Unit 1 2 3 4 5 10 DC combiner box 11 strings Unit 1 2 3 4 5 10

Mounting structure Unit 1 * The number in parentheses is the number of series × strings.

DC Combiner box

10kW inverter

PV Array

Grounding kit

+

－

8-series

11 strings

Fuse

NA-FxxxGx series

23

Ⅶ. ESTIMATION OF THE GENERATING POWER a) Calculation of the annual power generation (100kW system) This is calculation of the annual power generation for 28 cities.

The numbers in the map represent the cities of the table in the next page.

*Estimated by SHARP. *The simulation data is not guarantee of the power generation.

The above estimated generating power is calculated based on the following condition. 1. Direction ：South 2. Inclination ：Optimum angle for each city 3. System capacity is 100kW 4. It is assumed that the temperature of the thin-film PV module is the average temperature of

each city as shown by the table below plus 40℃. The temperature coefficient is calculated as -0.24%/℃.

5. Transformer efficiency is 100%. 6.The calculation formula for monthly power generation is as follows and the annual power

generation is the sum of the monthly power generation.

1

2

3

4

5

6

7

89

10

11

1213

14

15

16

17

1819

20

21

22

2324

（25：Guyana South America）

26

27

28

U　・　PPo

Epd　＝ 　・　K'　・　Kpt　・　K''Epd : Power generation(kwh/day)

U : Irradiation of global radiation(kWh/m2・day)

P : System output power(kW)

Po : Correction irradiation(=kkW/m2)

K' : Correction coefficient

Kpt : Temperature coefficient

K" : Other losses

P=100, Po=1000, K’=0.84 Kpt=1-0.24*(T+18.4-25)/100, K”=1

NA-FxxxGx series

24

b) Data of monthly average temperature and daily average irradiation

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec17.4 ℃ 11 11.6 13.5 15.2 18.4 21.5 24.4 24.9 22.7 18.8 14.5 11.81.98 MWh/m2 3.71 4.25 5.29 5.80 6.23 6.50 6.68 6.42 5.67 4.77 3.67 3.36155 MWh/year

17.9 ℃ 11.6 12.4 13.7 15.7 18.6 22.1 25.1 25.5 23.3 19.2 14.9 12.12.04 MWh/m2 4.45 5.07 5.97 6.10 6.32 6.47 6.81 6.45 6.07 5.23 4.00 4.03166 MWh/year

16.3 ℃ 9 10.3 11.8 14.0 17.5 21.6 24.9 24.9 21.9 17.7 12.6 9.42.02 MWh/m2 4.39 5.04 5.94 5.97 6.32 6.40 6.77 6.42 6.00 5.23 3.87 4.00166 MWh/year

18.5 ℃ 12.5 13.0 14.6 16.1 18.8 22.3 25.4 26 24.1 19.9 16.2 13.32 MWh/m2 3.27 3.78 4.99 5.30 5.69 6.07 6.26 6.02 5.47 4.45 3.33 3.06

163 MWh/year18.2 ℃ 10.7 11.9 14.0 16.0 19.6 23.4 26.8 26.9 24.4 19.5 14.3 11.12.03 MWh/m2 4.16 4.64 5.90 5.73 6.42 6.60 7.13 6.74 6.40 5.23 3.83 3.74165 MWh/year

13.9 ℃ 5.5 7.0 9.3 11.6 15.5 20.4 24.3 23.8 20.3 14.5 8.9 5.91.93 MWh/m2 3.74 3.96 5.90 5.50 6.48 6.93 7.13 6.87 6.06 4.74 3.37 2.58159 MWh/year

17.5 ℃ 9.5 10.9 13.1 15.2 19.3 23.2 26.9 26.8 23.8 18.5 12.9 9.72.04 MWh/m2 4.32 4.82 5.94 5.73 6.36 6.53 7.10 6.71 6.40 5.29 3.90 3.84166 MWh/year

16.3 ℃ 9.7 10.4 12.1 14 17.3 21 24.1 23.7 21.5 17.7 13.3 10.61.68 MWh/m2 3.00 3.61 4.77 5.10 5.23 5.77 6.19 5.90 5.30 4.26 3.10 2.77137 MWh/year

16.8 ℃ 11.4 12.3 13.7 15.1 17.4 20.2 22.4 22.8 21.7 18.5 14.5 11.81.94 MWh/m2 3.42 3.89 5.90 5.73 6.32 6.73 6.94 6.97 6.17 5.00 3.33 3.13158 MWh/year

17.2 ℃ 11.9 12.6 13.7 15.1 17.5 20.6 23.3 23.4 21.8 18.7 15.1 12.72.22 MWh/m2 4.61 4.89 6.61 6.27 7.00 7.23 7.52 7.39 7.03 6.07 4.07 3.97182 MWh/year

14.5 ℃ 9.3 10.1 11.5 12.9 15.1 18.1 19.9 19.8 19 16.2 12.3 9.91.82 MWh/m2 3.39 3.79 5.26 5.50 6.10 6.47 6.36 6.48 5.90 4.71 3.23 2.67150 MWh/year9.7 ℃ 3.6 3.5 5.1 7.6 11.7 14.5 16.4 16.7 14.7 11.4 6.9 4.6

1.15 MWh/m2 1.03 2.35 2.74 4.27 4.87 4.57 4.84 4.55 3.47 2.48 1.60 1.0396 MWh/year

8.8 ℃ 1.1 1.1 4.4 7.2 12.2 15 17.2 17.2 13.9 9.4 5 2.21.13 MWh/m2 1.07 1.82 2.74 4.13 4.90 5.07 4.74 4.55 3.57 2.23 1.30 0.84

94 MWh/year7.8 ℃ -2.2 -0.4 3.4 7.6 12.2 15.4 17.3 16.6 13.4 8.2 2.8 -0.9

1.37 MWh/m2 2.03 2.93 3.87 4.57 5.07 5.13 5.36 5.07 4.43 3.13 1.90 1.45114 MWh/year

18.7 ℃ 12.8 13 13.8 15.7 18.8 22.7 25.5 26.2 24 20.7 16.5 14.11.9 MWh/m2 3.10 4.11 5.29 6.03 6.42 6.83 6.77 6.45 5.90 4.87 3.60 3.07155 MWh/year9.7 ℃ 2.5 3.4 5.8 8.7 12.6 15.4 17 16.8 14.4 10.5 6.2 3.51.1 MWh/m2 1.16 2.00 2.84 3.80 4.61 4.67 4.65 4.36 3.43 2.36 1.40 0.8491 MWh/year

8.3 ℃ 0 1.1 4 7.5 11.8 14.9 16.9 16.4 13.4 9.1 3.8 11.19 MWh/m2 1.07 2.32 3.03 4.20 4.84 4.97 5.23 4.71 3.80 2.55 1.43 1.00

99 MWh/year10.7 ℃ 4.9 5.1 6.8 9 12.2 15.3 17.4 17.1 14.8 11.8 7.8 5.71.32 MWh/m2 1.68 2.68 3.36 4.90 5.16 5.13 5.16 4.94 4.07 2.84 2.03 1.29109 MWh/year9.7 ℃ 4 3.9 5.9 7.9 11.1 14.3 16.6 16.5 14 10.4 6.5 4.7

1.11 MWh/m2 1.16 1.89 2.81 4.20 4.55 4.63 4.71 4.39 3.40 2.26 1.57 0.8792 MWh/year9 ℃ 3.1 3.1 5.2 7.6 10.6 14 15.8 15.4 13.2 10 6 4.2

1.05 MWh/m2 1.07 1.75 2.52 3.97 4.39 4.40 4.39 4.29 3.30 2.13 1.47 0.8487 MWh/year

9.7 ℃ 4.1 4.2 5.9 8.0 11.4 14.5 16.4 16.1 13.9 10.7 6.6 4.81.08 MWh/m2 1.10 1.61 2.77 3.60 4.65 4.80 4.74 4.07 3.40 2.19 1.53 1.03

90 MWh/year8.5 ℃ 3.2 3.3 5.1 7.1 9.9 13 14.5 14.3 12.3 9.5 5.4 3.9

1.08 MWh/m2 1.10 1.96 2.74 3.97 4.74 4.70 4.68 4.07 3.30 2.07 1.30 0.8190 MWh/year

14.9 ℃ 7 8.1 10.3 13.1 16.9 20.7 23.7 23.1 20.4 16.2 11 8.11.84 MWh/m2 3.32 3.71 5.13 5.70 6.13 6.60 6.90 6.55 5.73 4.36 3.30 2.84151 MWh/year

13.8 ℃ 5 6.5 10.0 13.1 16.5 20.4 22.8 22.2 19 14.4 9.7 5.91.71 MWh/m2 3.16 3.57 4.77 5.20 5.77 6.17 6.55 6.19 5.33 3.84 2.90 2.68141 MWh/year

26.5 ℃ 26.1 26.1 26.1 26.7 26.7 26.1 26.1 26.7 27.2 27.2 26.7 26.11.79 MWh/m2 3.94 4.21 4.45 4.50 4.26 4.47 5.13 5.65 6.20 6.10 5.43 4.32143 MWh/year

15.2 ℃ 8.1 9.1 10.7 13.3 16.7 20.7 23.6 23.1 20.4 16.4 11.6 8.81.71 MWh/m2 3.07 3.71 4.90 5.17 5.26 5.83 6.23 6.00 5.47 4.26 3.40 3.00141 MWh/year

12.9 ℃ 5.4 6.9 8.7 11.3 14.8 18.4 21.3 20.8 18.5 14.3 8.9 5.91.57 MWh/m2 2.32 3.18 4.39 4.90 5.23 5.67 6.00 5.65 5.27 3.90 2.70 2.19129 MWh/year

10.6 ℃ 1.8 3.7 6.2 9.6 13.4 16.7 19.7 18.9 16.2 11.8 6.1 2.71.39 MWh/m2 1.74 2.43 3.68 4.60 4.94 5.57 6.10 5.48 4.70 2.97 1.93 1.42115 MWh/year

No.CountryAverage temperature [℃]

Annual irradiation [MWh/m2]Annual generated power [MWh/year]

25

26

27

28

21

22

23

24

17

18

19

20

13

14

15

16

9

10

11

12

5

6

7

8

1

2

3

4

France

Italy

Belgium

Luxemburg

UK

Spain

Portugal

Holland

Germany

Average irradiation [kWh/m2・day]

Average temperature [℃]Month

28.Lyon(34°)

1.Valencia(35°)

2.Alicante(35°)

3.Murcia(35°)

4.Almeria(34°)

5.Sevila(32°)

6.Madrid(34°)

7.Cordoba(35°)

8.Barcerlona(36°)

9.Lisboa(32°)

10.Faro(near by Albuferia)

(33°)11.Porto

(34°)

12.Utreccht(36°)

18.Southampton(40°)

19.Oxford(35°)

20.Birmingham(36°)

13.Hamburg(37°)

14.Munchen(39°)

15.Palermo(32°)

16.Brussels(34°)

City(Optimum angle)

25.Cayenne(Guyana South

America)

(5°)

26.Perpignuan(35°)

27.Toulouse(35°)

21.Leeds(38°)

22.Edinburgh(39°)

23.Marseille(35°)

24.Montpellier(35°)

17.LuxemburgCity(33°)

*This data refers to the data of METEONORM.

NA-FxxxGx series

APPENDIX

NA-FxxxGx series

ⅰ

Appendix EFFECTS OF SHADE 1. Distance between arrays

If solar arrays are shaded by mountains, buildings, electric poles, trees and so on, the power

output might decrease. Therefore you will need to install the modules so as not to be shaded

basically. Also, you will need to arrange them such as not to allow any array to be shaded by the

array in front of it. It is recommended to have inclination angle of 5 degree or more, to avoid the

possible decrease in power output due to dust and dirt getting deposited on the surface of the

module.

Refer to the following table about distance between arrays in each area and inclination.

* [Conditions for calculation of distance between arrays]

• PV modules: NA-FxxxGx

• The modules are installed in vertical orientation, 2-column, ground-based.

• Distance between modules is 40mm long, 40mm wide.

• The solar arrays are not covered with shade at the noon time of December 21st.

TableA.1 Distance between arrays

Latitude

Longitude

10°

15°

20°

25°

30°

35°40°

45°

10°15°20°25°30°35°40°

45°

10°15°20°25°30°35°40°45°

2,099

3,069

3,945E12.3

N48.08

E11.35

2,935

3,627

4,291

Ｎ41.53

Ｎ40.25

Ｗ3.43

1,490

Area InclinationDistance between arrays

1,500

2,449

4,340

4,098

3,324

1,006

1,982

2,898

3,725

Spein（Madrid）

Italy（Roma）

Germany(Munich)

1,0661,588

2,594

3,520

6,068

ｍｍ

2,221

4,9225,516

Spain

Dimension between arrays

Inclination

Distance between arraysFigureA.1 Distance between arrays

* Reference value