Upload
marcell-tirta
View
233
Download
2
Embed Size (px)
Citation preview
7/21/2019 PV Power Systems
1/72
Photovoltaic Power Systems -2
Grid connected PV
Professor Chem Nayar
Curtin University of Technology
Perth , Western Australia
7/21/2019 PV Power Systems
2/72
Grid Connect PV Systems
Simplest of systems
No storage
Maximise PV to Grid
7/21/2019 PV Power Systems
3/72
Grid Connect PV Systems
Net Metering single meter runs in both directions
Can also be with two meters : one to measure energy sold
and the other energy bought
7/21/2019 PV Power Systems
4/72
Components of a Grid Connected System
7/21/2019 PV Power Systems
5/72
SPECIFICATION (NOMINAL VALUE)
MODEL : PV-MF130EA2
MAXIMUM SYSTEM VOLTAGE 600 V
MAXIMUM POWER (Pmax) 130 W
OPEN CIRCUIT VOLTAGE (Voc) 24.2 V
SHORT CIRCUIT CURRENT (Isc) 7.39 A
MAXIMUM POWER VOLTAGE (Vmp) 19.2 VMAXIMUM POWER CURRENT (Imp) 6.79 A
PV PANELS
7/21/2019 PV Power Systems
6/72
Sine wave output Low harmonic distortion (lessthan 4%)
Input voltage range 160 350 VDC
Output voltage range 187 253 VAC
Single phase, can operate in
frequency range 50 Hz +/- 6% Power factor > 0.98
High efficiency (more than 90%)
Maximum power point tracking
Mains and solar generator are galvanically
isolated
Disconnect from grid line within 1 cycle in
case of abnormal condition
Computer interface for local and remote
monitoring and data retrieval
7/21/2019 PV Power Systems
7/72
Connecting Solar Panels
Series connection to increase voltageParallel connection for increasing current
Terminology Module
String
Sub array
Array
7/21/2019 PV Power Systems
8/72
PV Array Diagram
7/21/2019 PV Power Systems
9/72
Array of sub arrays
7/21/2019 PV Power Systems
10/72
7/21/2019 PV Power Systems
11/72
Blocking Diodes to prevent reverse
current flow
PCU
7/21/2019 PV Power Systems
12/72
Cable Sizing
Size for volt drop Maximum of 5% recommended
Size for current rating
Note that energy can typically feed from boththe array and the power conditioner
Current rating of the cable is the rating of the
protective device, not the PV output Consider cable exposed temperature when
sizing for current rating
7/21/2019 PV Power Systems
13/72
Protection Requirements
Module protection Bypass diodesString protection
Blocking diodes
Fuses
Array protection
Overcurrent protection disconnection
7/21/2019 PV Power Systems
14/72
Australian Requirement
Breaker trip current to be between 1.25 x Isc
2 x Isc
Isc is for the section feeding through thetrip device
Cable is then sized to the breaker
Note some PV manufacturers recommendmaximum fuse ratings for the modules
7/21/2019 PV Power Systems
15/72
Components
Over current protection Must be DC voltage rated
DC arcs are hard to extinguish
Disconnection Distinguish between isolators for breaking
down the array and load break isolators for
disconnection under load Plugs and sockets cant be separated under
load
7/21/2019 PV Power Systems
16/72
Components cont.
Blocking diodes Are not considered a fuse
Cannot be relied upon to block reverse current
Make sure they meet the voltage rating requirementsof the system
They can get hot, keep them cool
Australian requirements include breaker the arrayinto Extra Low Voltage (ELV) sections and being
able to isolate the inverter for removal
7/21/2019 PV Power Systems
17/72
Australian considerations
Australian requirements include breaking the array into ELV sections for safe
install and maintenance
being able to isolate the inverter for saferemoval
7/21/2019 PV Power Systems
18/72
GRID CONNECTED INVERTER SYSTEM
Converts DC current from solar panels to AC current and feed to the
grid . The system uses 50 Hz voltage waveform from grid line as a
reference signal and feed current to the grid line. Before connecting,the inverter will check property of grid line according to followingconditions :-
Voltage level
Frequency range
Phase of signal
If all conditions are within specified range and synchronized withinternal generating frequency, the inverter will be connected to thegrid
In case there is some abnormal condition with the grid, invertershould disconnect itself for both safety to human life and safety to
the system.
7/21/2019 PV Power Systems
19/72
PV/Grid Energy System Inverter
Configurations
Large Single Inverter Type (Central
Inverter)
Multiple Small Inverter Type (StringInverter)
DC Bus (Multi-string Inverter)
AC Module
7/21/2019 PV Power Systems
20/72
PV/Grid Energy System
Inverter Configurations
7/21/2019 PV Power Systems
21/72
Central Inverter Type
Series and Parallelconnection on DC side
All PV panels
connected to single DC
bus
Single Central Inverter
Affected by partial
shading of panels
Only one protection
system required
7/21/2019 PV Power Systems
22/72
Kalbarri PV System
in Western Australia (1995)
10kW 10kW
35kVA
(75kVA)
250Vdc
6.6kV
100kVA
415Vac
10kW10kW 10kW10kW
35kVA
(75kVA)
250Vdc35kVA
(75kVA)
250Vdc
6.6kV
100kVA
415Vac
6.6kV
100kVA
415Vac
6.6kV
100kVA
415Vac
7/21/2019 PV Power Systems
23/72
String Inverter TypeOne inverter per
string
Panels grouped
into smaller
inverter ratedpower of Inverter (
0.7-5kW)
Not so badlyaffected by shading
Not badly affected
by inverter failure
7/21/2019 PV Power Systems
24/72
@ 3.3kW
Grid-Connected PV Inverter (String Type)
7/21/2019 PV Power Systems
25/72
String Inverter Battery Backup
Controller Back up Line
AC Grid Line
DC 48 V
AC Line
DC from PV
160 to 240 V
AC Line
DC 48 V
7/21/2019 PV Power Systems
26/72
Grid-Connected PV System
with Back up Inverter
Kang Som-Mao, Ratchaburi
PV
CONTROLLER -
BATTERY batteries for S-218C
INVERTER APOLLO G304 And S-218C
75 Wp x 42 modules
7/21/2019 PV Power Systems
27/72
DC Linked or Multistring type
Each panel orgroup have a DC-DC step up
converterHigh voltage DC
link feeds
transformer-lessconverter
7/21/2019 PV Power Systems
28/72
DC Linked
#1String HFTboostL
PVC
1S
3S
4S
2S
1D
3D
2D
4D
DCC
HFTboostL
PVC
1
S3
S
4S
2S
1D
3D
2D
4D
DCC
HFTboostL
PVC
1S
3S
4S
2S
1D
3D
2D
4D
DCC
gridi
gridLGridGround
3S
4S
1S
2S
#2String
#3String
7/21/2019 PV Power Systems
29/72
AC Modules
One Inverter perpanel
High volume/ lowcost
Plug-and-play
7/21/2019 PV Power Systems
30/72
Inverter characteristics
Efficiency
Response times
Harmonic output
Fault current contribution
Synchronisation
Frequency control
Power factor
DC injection
Requirement Standard Details
7/21/2019 PV Power Systems
31/72
General AS/NZS 3100 Electrical Safety Requirement
Compatibility with AS 60038 A.C. Voltage and frequency ratings
electrical installation
Power flow direction N/A Power flow between energy source and grid may
be in either direction
Power factor AS 4777.2 Range between 0.8 leading to 0.95 lagging
between all outputs from 20% to 100%
of rated volt-amperes
Harmonic Currents AS 4777.2
Harmonic current shall not exceed the limits in
Table 1.
EMC
Radio
Communications
Act
Voltage fluctuation
AS/NZS
61000.3.3 Rated less that or equal to 16A per a phase
and flicker
AS/NZS
61000.3.5 Rated more than 16A per a phase
Impulse protection IEC 60255-5 Withstand a standard lightning impulse of 0.5J, 5kV
with 1.2/50 waveform
Transient voltage AS 4777.2 Voltage-duration curve derived from
limits measurements taken at a.c. terminal shall
Not exceed the limits listed in Table 2.
Direct current N/A Single-phase inverter: the dc output current of the
injection inverter at the a.c. terminals shall not
exceed 0.5% of its rated output or 5mAwhich ever is greater
Three-phase inverter: the dc output current of the
inverter at the a.c. terminals measured between
any two phases or between any phase and neutral
shall not exceed 0.5% of its rated output or 5m
which ever is greater
Data logging and AS/NZS 60950 Any electronic data logging or communications
communication equipment incorporated in the inverter requires to
devices comply with the appropriated requirements
7/21/2019 PV Power Systems
32/72
DC-AC ELECTRICAL CONVERSION
EFFICIENCY
Efficiency is the most important parameter for grid-connected PV
generation Depends on whether galvanic insulation transformer is used
between the AC on the grid side and the DC generated on the PVside or not.
Transformer can be either 50 Hz LF transformers, or HF
transformers. The presence or absence of LF or HF transformers in the inverters
influences not only the size, weight, ease of installation and materialcosts, but also the earthing and safety measures to be adopted in thePV system, and the control of DC injection feed into the grid.
Inverters with an LF transformer can achieve DC-AC efficiency of92%,while those with an HF transformer typically achieve amaximum efficiency of 94%.
7/21/2019 PV Power Systems
33/72
European EfficiencyNormalized efficiency, E, and is
valid for irradiance levels in centralEurope. It is defined as a function of
the efficiency at defined percentage
values for nominal AC power. This is
shown in the following equation:
E = 0.035% + 0.0610% +0.1320% + 0.130% + 0.4850% +
0.2100%
7/21/2019 PV Power Systems
34/72
94.292.690.892.3E
94.292.890.093.3100
95.093.490.993.850
94.693.192.593.130
94.292.392.091.020
91.588.990.485.810
86.785.184.877.55
Transformerless
LF (new
technology)
LF (old
technology)HF
Efficiency by inverter type (%)
AC power
(% of nominal)
Experimental inverter efficiencies for different string inverters; values used are
representative of state-of-the-art technology
Experimental inverter efficiencies
7/21/2019 PV Power Systems
35/72
MAXIMUM POWER POINT TRACKING EFFICIENCY
The DC power input to an inverter depends on which
point in the current-voltage (I-V) curve of the PV arrayit is working at. Ideally, the inverter should operate atthe maximum power point (MPP) of the PV array. TheMPP is variable throughout the day, mainly as a
function of environmental conditions such asirradiance and temperature, but inverters directlyconnected to PV arrays have an MPP trackingalgorithm to maximize energy transfer. The MPP
tracking efficiency, MPPT, can be defined as the ratioof the energy obtained by the inverter from a PVarray, to the energy obtained with ideal MPP trackingover a defined period of time.
MAXIMUM POWER POINT
7/21/2019 PV Power Systems
36/72
where PDC isthe DC input
power to the
inverter and PMis the power at
MPP
MAXIMUM POWER POINT
TRACKING EFFICIENCY
7/21/2019 PV Power Systems
37/72
Inverters for grid-connected PV
systems must generate energy at adefined quality
The standards (example:
international Standard IEC 61000-
3-2 ) above require a THD of
5% for the harmonic spectra of the
current waveform. nominal.
2
1 1
1
2
1
2
1
100
100
100%
=
=
=
h s
sh
s
ss
s
dis
I
Ix
I
IIx
I
IxTHD
Total Harmonic Distortion
Table 1 - Harmonic current limits [2]
Harmonic order number Limit for each individual harmonic
based on percentage of fundamental
2-9 4%
10-15 2%
16-21 1.50%
22-33 0.60%
Even harmonics 25% of equivalent odd harmonics
Total harmonic distortion (to the 50th harmonic) 5%
AS 4777
7/21/2019 PV Power Systems
38/72
Power Factor
Traditionally poor due to displacement power factor
harmonics
Present technology is very good
Maintain close to unity without great difficulty
Can regulate power factor or reactive powerfor voltage control or power factor correction
applications
7/21/2019 PV Power Systems
39/72
Example :Current THD and power
factor vs AC power
7/21/2019 PV Power Systems
40/72
DC Injection
Is possible if an output transformer is notpresent
Control systems can be added to preventexcessive injection
Is regulated by standards
Limits of 5 mA (0.025% of the rms outputcurrent for a 5 kW system, based on the IEC61000-3-2) or 0.5% (UL1741) are beingadopted in the UK and US respectively
7/21/2019 PV Power Systems
41/72
Synchronisation
Performed automatically
Typically uses zero crossing detection on
the voltage waveform
Can be instantaneous on the next zero
crossing
If phase locked loops are used it could takea up to few seconds
7/21/2019 PV Power Systems
42/72
Frequency Control
Locked to the grid
May have a bias to drift in the event of grid
failure
Lock range may be limited
Germany 49.8Hz - 50.2Hz
Australia 48Hz - 52Hz India 47Hz - 53Hz
7/21/2019 PV Power Systems
43/72
Prevention of Islanding
An island occurs when the invertercontinues to supply power to a portion of
the grid that has become isolated from the
rest of the systemThe power may be unstable during the
island period
7/21/2019 PV Power Systems
44/72
Anti islanding methods
Inverters are required to have measures toprotect against this occurring
Passive methods
Under/Over voltage Under/Over Frequency
Active Methods
Frequency drift
Impedance measurement
Power Shifting
7/21/2019 PV Power Systems
45/72
Earth Leakage Current
In the US, the National Electrical Code, NEC,
requires all PV installations with system
voltages above 50 V DC to be earthed.
Ground fault protection ('GFP') devices areused to measure the earth leakage current, in
order to disconnect from the ground (that is,
unearth the installation), in the case of fault.
Stray leakage currents may be an issue in the
sensitivity of this protection.
7/21/2019 PV Power Systems
46/72
Fault currents
Battery-less systems can only deliverwhat the energy source can deliver
for PV this can be very little to a maximum
of 1.2 times rated current wind is extremely variable
If a battery is present the fault current
contribution is limited by the inverter.
Typically in the range of 100% to 200%
7/21/2019 PV Power Systems
47/72
AC Power Output
The losses in a PV system are due to: Inverter losses
Dust/dirt in the modules
Mismatch in modules
Differences in ambient conditions from
Standard Test Conditions (STC) 1000w/m2,AM 1.5 and 250C.
Pac =Pdc,STCx efficiency
7/21/2019 PV Power Systems
48/72
Mismatch in Arrays
7/21/2019 PV Power Systems
49/72
Mismatch in Arrays
7/21/2019 PV Power Systems
50/72
Mismatch in Arrays
7/21/2019 PV Power Systems
51/72
1. Select the size of the system to be installed2. Select main equipment to be installed, calculate
for matching of spec. of
2.1 PV panel2.2 Grid connected inverter3. Examine location for PV mounting. There should
be no obstruction of sunlight for whole day or at
least 9.00 a.m. to 4.00 p.m.4. Consider for tilt angle of panels according to
latitude of that location5. Select PV mounting structures.
System design
7/21/2019 PV Power Systems
52/72
6. Check ampere capacity of each string of inverter, select sizeof blocking diode to be 30 % larger than string short circuitcurrent with diode max voltage more than 2 times of maxsystem voltage.
8. Select proper wire size so voltage drop for DC side is lessthan 3%8.1 Select wire size between each string to the combiner box
to enable less than 1% voltage drop8.2 Select wire size between the combiner box to control
box / inverter to enable less than 2% voltage drop9. Select proper wire size so voltage drop for AC side is less
than 3%10. Select size of disconnect switch both DC and AC side to
proper rating
System design
Case Study : A PV grid connected system in
7/21/2019 PV Power Systems
53/72
1. Select size of system to be around 3 kWp2. Select main equipments as
2.1 PV panel - Mitsubishi model PV-MF130EA2- 130 Wp / panel- 2 strings with 12 panels in each string- Isc / string = 7.39 amp.- Total PV power = 130 x 24 = 3,120 Wp
- V max = Voc = 24.2 x 12 = 290.4 Vdc- Oper. volt. at max. power = 19.2 x 12 = 230.4 Vdc- Max DC current = Isc x 2 = 7.39 A x 2 = 14.78 Amp
2.2 Grid connected inverter - Leonics G-303M- 2.7 kW output- Max DC voltage = 350 Vdc- Nominal Operating PV voltage = 230 Vdc
3. Location for PV mounting is on the roof deck with no obstruction ofsunlight for whole day
4. Select hot dip galvanized steel for PV mounting with stainless steelnuts & bolts
5. Tilt angle of panels is set to 14 deg. facing south as Bangkok locates atlatitude 13.73 deg. North
Case Study : A PV grid connected system in
Bangkok
7/21/2019 PV Power Systems
54/72
6. Plan to install control box and inverter in training room , 3 rd floor.
7. Selection of blocking diode7.1 Min. device rating (I) = Isc x 1.3
= 7.39 x 1.3 = 9.61 A
7.2 Min. device rating (V) = Voc x 2
= 290.4 x 2 = 580.8 V
Then select blocking diode to be 10 ampere 600 V. for each string.
8. Measure cable length of the system
8.1 Cable length between each string to the combiner box
= 10 meters
Select wire for each string to be 4 sq.mm. to get voltage drop < 1%
Voltage drop in each string = 11,650 x 10 x 7.39 = 0.86 V
Percentage of volt. Drop = 0.86 / 205 = 0.42 %
Case Study : A PV grid connected system in Bangkok
Case Study : A PV grid connected system in Bangkok
7/21/2019 PV Power Systems
55/72
8.2 Cable length between combiner box to control box / inverter is 35 m.Select wire size to be 10 sq.mm. to get voltage drop < 2%
Voltage drop = 3,903 x 35 x 7.39 x 2 = 2.02 V
Percentage of volt. Drop = 2.02 / 205 = 0.99 %
9. Cable length between Control Box / Inverter to load panel is 12 meters
Select wire size to be 2.5 sq.mm. to get voltage drop < 3%
Voltage drop = 15,695 x 12 x (2,700/238)
= 2.14 V
Percentage of volt. Drop = 2.14 / 238 = 0.90 %
10. Max DC current = 7.39 x 2 = 14.78 A
Max AC current = 2,700 / 232 = 11.64 A
Select both DC and AC breaker to be 20 A
7/21/2019 PV Power Systems
56/72
7/21/2019 PV Power Systems
57/72
Calculate annual energy output
Use data source and get annual daily average energy
available Adjust down for losses
Inverter 7%
Temperature 15%
Cable 3% Dirt 2%
Orientation 1%
Total about 25%-30%
Multiply by the size of the array to get the electrical kWhroutput OR
Use a modelling package
7/21/2019 PV Power Systems
58/72
Verify
Does it fit in the areaDoes it meet budget
Does it produce required kWhr
Is the CO2 offset met
Check it works
Re-size if necessary
7/21/2019 PV Power Systems
59/72
System Acceptance Test1. Sum total module ratings at STC (Standard Test Condition) : Watts STC
2. Estimate inverter AC output to be 70% of Watts STC : Watts AC-estimated
3. Measure real AC output and irradiation, then define
Watts AC-corrected = Real AC output / irradiation x 1000
4. Compare that Watts AC-corrected is more than Watts AC-estimated
Result from the installation
Generating power and irradiation is measured on Mar 26, 2004 at 11.25 p.m.
Watts STC = 130 x 24 = 3,120 Wp
Watts AC-estimated = 3,120 x 0.7 = 2,184 Watts
Watts AC-corrected = 2,010 / 870 x 1000 = 2,310 Watts
4. Watts AC-corrected (2,310) > Watts AC-estimated (2,184)
*** PASS SYSTEM ACCEPTANCE TEST ***
7/21/2019 PV Power Systems
60/72
Generating Power VS Time for 3.12 kWp
Grid Connected inverter at Leo Electronics Co., Ltd. (Apr 1, 2004)
0
500
1000
1500
2000
2500
7 8 9 10 11 12 13 14 15 16 17 18
Time
Generating
Power
7/21/2019 PV Power Systems
61/72
Date Gen. Power Date Gen. Power Date Gen. Power
1/4/2004 14.30 24/3/2004 13.73 16/3/2004 12.85
31/3/2004 12.79 23/3/2004 12.12 15/3/2004 10.88
30/3/2004 12.13 22/3/2004 10.94 14/3/2004 12.53
29/3/2004 12.33 21/3/2004 8.02 13/3/2004 12.02
28/3/2004 13.49 20/3/2004 7.22 12/3/2004 11.67
27/3/2004 13.51 19/3/2004 8.57 11/3/2004 13.21
26/3/2004 13.14 18/3/2004 11.87 10/3/2004 11.34
25/3/2004 13.01 17/3/2004 14.68 9/3/2004 10.15
Max. Generating Power/day 14.68
kWh/day
Min. Generating Power/day 7.22 kWh/day
Average Generating Power/day 11.94 kWh/day
Power generating from Grid Connected System
7/21/2019 PV Power Systems
62/72
Orientation terminology
7/21/2019 PV Power Systems
63/72
Tracking Array
The PV array may either be fixed, sun-tracking
with one axis of rotation, or sun-tracking withtwo axes of rotation.
Generally fixed arrays are used thoughsignificant increase in energy yield is possiblewith single axis tracking with an additional smallgain using duel axis tracking
Trackers
add cost but offset by PV savings require some maintenance
Very good for water pumping applications
Tracking Relative Energy
7/21/2019 PV Power Systems
64/72
g gy
Production
0%
20%
40%
60%
80%
100%
120%
140%
160%
Albany Geraldton Halls Creek
Fixed north facing
at latitude angle
N-S Axis tracker -horizontal
N-S Axis tracker -
Fixed at latitude
angleDual Axis
34o57" 28o48" 18o14"
7/21/2019 PV Power Systems
65/72
Energy from Power of the Sun
0
200
400
600
800
1000
1200
0:00
2:00
4:00
6:00
8:00
10:00
12:00
14:00
16:00
18:00
20:00
22:00
Time
Powe
rEnergy =Power x Time
Area = 7500W.hr
= Area under curve
7/21/2019 PV Power Systems
66/72
Peak Sun Hours
0
200
400
600
800
1000
1200
0:00
2:00
4:00
6:00
8:00
10:00
12:00
14:00
16:00
18:00
20:00
22:00
Equivalent Time at 1 peak sun (1000W/m2)
7.5 hours
Area = 7500W.hr1000W/m2
Solar Irradiance
7/21/2019 PV Power Systems
67/72
0
250
500
750
1000
0:00 6:00 12:00 18:00 0:00
Time
IrradianceS(W/sqm)
18/05/98
A typical sunny day in Perth
0
250
500
750
1000
0:00 6:00 12:00 18:00 0:00
Time
IrradianceS(W
/sqm)
15/05/98
A Typical cloudy day in Perth
Solar Irradiance
Average Daily Solar Radiation Perth
7/21/2019 PV Power Systems
68/72
Average Daily Solar Radiation, Perth
Calculate annual energy output
7/21/2019 PV Power Systems
69/72
Calculate annual energy output
Use data source and get annual daily average energy
available Adjust down for losses
Inverter 7%
Temperature 15%
Cable 3% Dirt 2%
Orientation 1%
Total about 25%-30%
Multiply by the size of the array to get the electrical kWhroutput OR
Use a modelling package
Verify
7/21/2019 PV Power Systems
70/72
Verify
Does it fit in the area
Does it meet budget
Does it produce required kWhr
Is the CO2 offset met
Check it works
Re-size if necessary
Suboptimal orientation the
7/21/2019 PV Power Systems
71/72
impact
Common in building integrated
applications
Roof may be wrong orientation
Facade may be vertical
Tilt angle may be dictated by aesthetics
7/21/2019 PV Power Systems
72/72