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ENERGY PRODUCTION –
CASE STUDIES
Lior Handelsman - VP Product Strategy &
Business Development, Founder
1
2. Part 1: Introduction
1. Introduction
2. Product selection
3. Design considerations
4. Energy loss elimination
2
3. What is the Best Design ?
What module to choose?
What type of inverter to choose?
How to best connect modules to inverters?
What are the best string lengths?
What size wiring to use?
How much wiring?
How to avoid energy losses?
3
4. Part 2: Product selection
1. Introduction
2. Product selection
3. Design considerations
4. Energy loss elimination
4
5. Component Selection – Selecting PV module
Technology
Cost
Power mismatch
Availability
Bankability
Product and Power warranty
Degradation over time
©2010 SolarEdge
5
6. Component Selection – Selecting PV module
Technical Data
Basic parameters (@25deg)
Pmpp: 190 Wdc
Pptc: 168.8 Wdc
Voc: 32.8 Vdc
Vmp: 26.7 Vdc
Isc: 8.05 Vdc
Imp: 7.12 Vdc
Temperature coefficients
Pmp_t: ‐0.49 % / ⁰C
Voc_t: ‐0.34 % / ⁰C
Vmp_t: ‐0.47 % / ⁰C
Isc_t: 0.06 % / ⁰C
Imp_t: 0.02 % / ⁰C
American Technical Publishers, 2007 ©2010 SolarEdge
6
7. Component Selection – Selecting Inverter
Central inverter or String inverter?
Advantages of String Inverters:
Higher yields in fields with high mismatch
Negligible loss during failure in large fields
Simple maintenance and replacement
Outdoor installation - protection class IP65
Advantages of Centralized Inverters:
Higher inverter efficiency
Less wire losses through high voltage DC cabling
Simpler AC cabling
Lower cost per Wp
©2010 SolarEdge
7
8. Case 1: Utility Scale Solar Plant
Waldpolenz, Germany (40MW)
©2010 SolarEdge
8
9. Large Scale Planning - Considerations
String Inverter vs. Centralized Inverter
Tradeoff between space and cost
If space is not a constraint, use lower-cost/ lower capacity
thin-film modules to reduce costs
Cable loss and BoS reduction
For Centralized inverters, use combiner boxes to combine
multiple DC string cables to thicker ones. Combiner boxes
reduce wiring costs and power losses, simplify installation and
contribute to improved safety of the PV array. However –
combiner boxes increase total system cost
©2010 SolarEdge
9
10. Large Scale Planning - Centralized Inverter (1/2)
• 10.87MW field (~145,000 modules)
• Graphical layout represents a 1.9MW section: 26,880 x First Solar 75w modules,
connected to a 1.9 MW inverter
20kV Transformer per
Inverter
Each DC cabinet:
14-16 clusters
Each 1.9MW Inverter: Each cluster:
16 DC cabinets (=224 clusters x 120 modules) 12 strings x 10 modules
©2010 SolarEdge
10
12. Large Scale Planning - String Inverter
Each string
connected to
7.8kW inverter
Each string: 1 Transformer per
104 modules 1MW field
©2010 SolarEdge
12
13. Case 2: Commercial Site with Limited Space
A 100kW roof has been simulated using PVsyst
Panel rows have been placed distanced apart to minimize inter-row shading
The roof space is 2,000 sqm
Kyocera KD210GH-2P modules x 210w x 480 = 100.8 kW
48 modules per row, 10 rows, 9 m between rows
©2010 SolarEdge
13
14. System Design
100kW system
Inverters 1 X 100kW
Modules per string 24
Strings per inverter 20
©2010 SolarEdge
14
16. Case 2: Commercial Site with Limited Space
Alternative Design
On the same roof we reduce the distance between module rows to double the
power capacity, while increasing inter-row shading
PVsyst design and energy calculation
Kyocera KD210GH-2P modules x 210 x 960 = 201kW
48 modules per row, 20 rows, 4.5 m between rows
©2010 SolarEdge
16
17. System Design
100kW system 200kW system
Inverters 1 X 100kW 1 X 200kW
Modules per string 24 20
Strings per inverter 20 48
©2010 SolarEdge
17
18. Site Layout +
injection point
A B
Combiner Boxes: 2
(24 strings per box)
. . . Wiring:
. . . — String-combiner
. . . box, total: 4640m
(DC)
— Combiner boxes-
inverter: 50m (DC)
18
©2010 SolarEdge
20. Comparative Analysis
100kW system 200kW system
Peak power 100.8 kWp 201.6 kWp
Combiner boxes 1 2
Wiring 2,000m (DC) 4,000m (DC)
Shading loss 1.5% 11.4%
Annual AC energy 175 MWh 306 MWh
AC energy / sqm 87.5 kWh/m2 153 kWh/m2
System cost* €300,000 €590,000
IRR 12.4% 10.5%
LCOE (€cent/kWh) 12.62 14.06
* Estimation ©2010 SolarEdge
20
21. Part 3: Design considerations
1. Introduction
2. Product selection
3. Design considerations
4. Energy loss elimination
21
22. How to Best Combine the Modules and Inverter?
Inverter Sizing
Consider module orientation – panels will not always be at peak
Maximize array performance NOT maximize inverter loading
Don’t over power the inverter !
In Israel - rated DC power should be about +3-7% of rated AC power
Going above this you will have:
Frequent inverter power limiting
Reduced energy yields during high irradiance
©2010 SolarEdge
22
23. How to Best Combine the Modules and Inverter?
Inverter Sizing – Cont.
16
14
12
10
8
6
4
2
0
1,000
1,050
1,200
1,250
1,300
1,100
1,150
100
200
250
300
350
400
450
550
600
650
700
750
850
900
950
150
500
800
50
Irradiance (W/m 2 )
Energy (%) Occurrence (%)
©2010 SolarEdge
23
24. How to Best Combine the Modules and Inverter?
String Sizing
What is the coldest ambient Temperature? (-8)
Calculate the maximum voltage from the module (Voc_max)
Voc max = Voc * ( 1+((Tamb_min – Tstc) * Voc_t)
Voc_max=32.8Vdc+(32.8Vdc *(‐8⁰C‐25⁰C)*‐0.34%/⁰C))=36.48 Vdc
- Design the maximum string length to the coldest temperature
Inverter Vmax=550VDC
Maximum string length = 550VDC/36.48VDC=15 modules
©2010 SolarEdge
24
25. How to Best Combine the Modules and Inverter?
String Sizing
What is the hottest ambient Temperature? (45deg)
Cell temperature can be 25-30deg above this!
Calculate the minimum MPP voltage of the module (Vmp_min)
Vmp min = Vmp * ( 1+((p_ p ((Tamb – Tstc +ΔT) * Vmp_t))
Vmp_min=26.7Vdc+(26.7*((32⁰C‐25⁰C+30⁰C)*‐0.47%/⁰C))=22.06
- Design the minimum string length to the hottest temperature
Inverter Vmax=250VDC
Maximum string length = 250VDC/22.06VDC=12 modules
©2010 SolarEdge
25
26. Logical Layout of PV Field
XXX panels
YYY panels in string
ZZZ inverters
Total of RRR kW
AC distribution box
Medium voltage transformer
©2010 SolarEdge
26
27. Wire Dimensioning Recommendations:
Rule of thumb - No more than 2% wire losses
Choose correct wire as a function of current and length
Max. voltage drop DC - cables (STC) : ∆UDC ≤ 1%
Too much DC voltage drop will put inverter out of MPPT in
hot days
Max. voltage drop AC - cables (Pn) : ∆UAC ≤ 1%
Too Much AC voltage drop and the inverter will have frequent
AC overvoltage disconnections
©2010 SolarEdge
27
28. Part 4: Energy loss elimination
1. Introduction
2. Product selection
3. Design considerations
4. Energy loss elimination
28
29. Inherent Problems in Traditional Systems
Energy Loss System Drawbacks
Module mismatch (3-5% loss) No module level monitoring
Partial Shading (2-25% loss) Limited roof utilization
Undervoltage/Overvoltage (0-15%) Safety Hazards
Dynamic MPPT loss (3-10% loss) Theft
SolarEdge solution overcomes all energy losses
providing up to 25% more energy while solving
the other system drawbacks at a comparable
price to traditional inverters
©2010 SolarEdge
29
30. SolarEdge System Overview
Module level optimization Module level monitoring
Fixed voltage - ideal installation Enhanced safety solution
©2010 SolarEdge
30
31. Distributed DC Architecture – Flexible Design
No string sizing
Parallel Strings can be of unequal length
The Result:
Easy to Design
Long strings less home-runs reduced wiring
Installation never passes 550VDC
Not temperature dependent
©2010 SolarEdge
31
32. Distributed DC Architecture – Fixed String Voltage
Fixed inverter input voltage - at optimal inverter input
Strings of different lengths
Modules on multiple roof facets
Modules with different power ratings
Modules of different technologies
The Result:
Maximum roof utilization
Easily scalable
10%-20% savings on wiring and BoS components
15% saving in labor
©2010 SolarEdge
32
33. Back to case 2:
System Design – 200kW field, SolarEdge Layout
100kW system 200kW system 200kW
SolarEdge
Inverters 1 X 100kW 1 X 200kW 17 x SE12k
Modules per string 24 20 56 / 57
Strings per inverter 20 48 1
©2010 SolarEdge
33
34. SolarEdge Site Layout panel board +
injection point
Wiring:
— String-inverter,
total: 485m (DC)
— Inverters-
. . .
. . transformer: 835m
.
. . . (AC)
©2010 SolarEdge
34
36. Comparative Analysis
100kW system 200kW system 200kW SolarEdge
Peak power 100.8 kWp 201.6 kWp 201.6 kWp
Combiner boxes 1 2 0
Wiring 2,000m (DC) 4,000m (DC) 330m(DC)+679m(AC)
Shading loss 1.5% 11.4% 5.2%
Annual AC energy 175 MWh 306 MWh 341 MWh
(+11.4% gain over
200kW traditional system)
AC energy / sqm 87.5 kWh/m2 153 kWh/m2 170.5 kWh/m2
System cost €300,000 €590,000 €615,000
IRR 12.4% 10.5% 12.6%
LCOE (€cent/kWh) 12.62 14.06 11.93
©2010 SolarEdge
36
37. Comparative Analysis – System Cost Breakdown
Cost of 200kW and 200kW SolarEdge system components, relative to 100kW system
components (100%)*
0% 50% 100% 150% 200% 250%
Inverter cost
Electrical BoS cost
Cables, fuses, combiner boxes
100kW system
Monitoring Included 200kW system
12-year warranty 200kW SolarEdge
Included
Other system costs
Modules, racking
Total system cost
* Estimation ©2010 SolarEdge
37
38. Comparative Analysis
100kW system 200kW system 200kW SolarEdge
Peak power 100.8 kWp 201.6 kWp 201.6 kWp
Combiner boxes 1 2 0
Wiring 2,000m (DC) 4,000m (DC) 330m(DC)+679m(AC)
Shading loss 1.5% 11.4% 5.2%
Annual AC energy 175 MWh 306 MWh 341 MWh
(+11.4% gain over
200kW traditional system)
AC energy / sqm 87.5 kWh/m2 153 kWh/m2 170.5 kWh/m2
System cost* €300,000 €590,000 €615,000
IRR 12.4% 10.5% 12.6%
LCOE (€cent/kWh) 12.62 14.06 11.93
* Estimation ©2010 SolarEdge
38
39. Case 3: Distributed DC Architecture – Enabler
Installation on 4 roof facets enables 15kW capacity
Different types of panels connected in a string enable full roof
utilization
Design and
installation by
Solgal Energy
©2010 SolarEdge
39
40. 3 Types of Modules, 3 Long Strings, 4 Orientations
25 Suntech 280W modules
34 Suntech 210W modules
4 Suntech 185W modules
PowerBox per module
3 single phase SE5000 SolarEdge inverters
2 strings of 20 modules and 1 string of 23 modules
©2010 SolarEdge
40
41. Full Roof Utilization Proves to be Cost Efficient
The larger the system, the lower the cost per kWp
Efficiency decreases in non-south-facing facets
South East West North System total System average
KWp 4.3 3.8 2.9 3.9 14.9
KWh/KWp /day KWh/day KWh/KWp/day
January 2.82 2.26 1.50 0.98 28.9 1.9
February 3.38 2.88 2.11 1.54 37.6 2.5
March 4.15 3.76 3.06 2.49 50.7 3.4
April 4.77 4.59 4.07 3.64 64.0 4.3
May 5.33 5.40 5.10 4.79 76.9 5.2
June 5.70 5.92 5.76 5.54 85.3 5.7
July 5.67 5.82 5.58 5.31 83.4 5.6
August 5.63 5.53 5.01 4.55 77.5 5.2
September 5.33 4.90 4.05 3.40 66.5 4.5
October 4.52 3.87 2.89 2.15 50.9 3.4
November 3.53 2.86 1.90 1.24 36.4 2.4
December 2.76 2.17 1.38 0.86 27.5 1.8
Year average 4.47 4.16 3.53 3.04 57.1 3.8
Year total 1630 1520 1290 1110 20853 1400
As % of maximum potential 99% 92% 78% 67% 85%
(1650 KWh/KWp/year)
With total system efficiency of 85% of complete-south system, the ratio
between system cost and system throughput remains attractive
Average production – >5kWh / kWp per day 41
©2010 SolarEdge
42. Module Level Monitoring – Physical System Layout
String 3, panels 1-20:
Facet West West East East
Model 210w 280w 280w 210w
©2010 SolarEdge
42
43. Module Level Monitoring – Power Curves
280w West 280w East
210w West 210w East
280w East
280w West
210w East
210w West
©2010 SolarEdge
43
44. Module Level Monitoring – Accurate Fault Detection
2.1.5
Module 2.1.5 (red
curve) is partially
shaded by the bottom
right corner of the
opposite module, as
shown in the power
curves
©2010 SolarEdge
44
45. Module Level Monitoring – Accurate Fault Detection
* Before module
re-mounting
2.1.5
Underperformance of
module 2.1.5 was
automatically alerted
by the system, and the
module was
remounted to avoid
the shading as shown
in the power curves
©2010 SolarEdge
45
46. Thank you
Websites:
Email: info@solaredge.com www.solaredge.com
Twitter: www.twitter.com/SolarEdgePV www.solaredge.de
Blog: www.solaredge.com/blog www.solaredge.jp
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