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Comparative Performance of Grid Integrated SolarPhotovoltaic Systems Under the Tropical
Environment
Hamidah Ismail∗, Sathyajith Mathew∗, Aloka S†, Balakrishnan Narayanaswamy†, Lim Chee Ming∗,Saiful Azmi Hussain∗
∗ Universiti Brunei Darussalam, UBD|IBM Centre,
Jalan Tungku Link, Gadong BE 1410, Brunei Darussalam
[email protected], {sathyajith.mathew, cheeming.lim, saiful.husain}@ubd.edu.bn†IBM Research Bangalore, KA, India
{alokas1, murali.balakrishnan}@in.ibm.com
Abstract—As the output from the solar PV systems variessignificantly with technologies, designs and prevailing weatherparameters, their evaluation under actual field conditions isimportant in identifying their real performance characteristics. Inthis paper, comparative performances of six different PV systemsconnected to a 1.2 MWp grid integrated solar farm are presented.The solar technologies considered are the single crystalline(sc-Si), poly crystalline (mc-Si), micro crystalline (nc-Si/a-Si),amorphous silicon (a-Si), Copper Indium Selenium (CIS) andHeterojunction with Intrinsic Thin Layer (HIT). Following theIEA guidelines, the array yield, capture losses, array efficiencyratio, and performance ratio were taken as the criteria for theperformance comparison. Among the six different module types,the systems based on amorphous silicon and HIT offer the bestperformance under the tropical environment considered.
Index Terms—renewable energy, solar insolation, photovoltaicsystem, tropical climate, reference yield, array yield, capture loss,performance ratio, efficiency ratio, poly crystalline silicon, singlecrystalline silicon, micro crystalline silicon, amorphous silicon,CIS, HIT
I. INTRODUCTION
With the rapid reduction in the system costs and promotional
policies for clean energy technologies, the solar photovoltaic
(PV) sector is growing at a fast rate. For example, with
the added capacity of 31.3 GW during the year, the global
cumulative installation of solar PV systems have reached
above 101 GW by the end of 2012 [1, 2]. Future projections
also show a steady growth in the global PV market and the
installed capacity may reach between 208 GW and 343 GW
by 2016, depending upon the support scenarios. Majority of
these installations are grid connected. Hence, the contribution
of solar PV generated electricity in the power sector is going
to be significant.
An estimate on the expected output from an existing solar
PV system is essential for its efficient grid integration and
smart power management. Such information is also vital in
the design of new PV power plants. Photovoltaic modules are
tested for their performances by the manufacturer/certifying
agencies. However, these tests are conducted at standard con-
ditions (STC) and under controlled environments. Apart from
the available solar insolation, performance of a PV system
is sensitive to various weather parameters such temperature,
humidity, wind speed and cloud cover. Hence, to understand
the real performance of a PV system at a given location and
environment, it has to be evaluated under the actual field
conditions.
Such field assessments are essential for the industry, as
the information generated can be used for bench marking the
quality of the products. Researchers and developers can use
the results in identifying the key areas to be focused for future
development. System integrators can use this information for
PV performance modeling which can further be extended
to solar power forecasts and dispatch decisions. For policy
makers, it gives the basic information for formulating the clean
energy policy frameworks - for example fixing the feed in tariff
and other production incentives.
The importance of field evaluation of PV systems has
been well identified by the industry, R&D institutions and
development agencies. For example, the International En-
ergy Agency (IEA), through its Photovoltaic Power Systems
(PVPS) project, has established standard monitoring tech-
niques and performance analysis methods for quantifying the
performance of PV systems under different weather conditions
[3]. Several studies were conducted on the performance of PV
systems at different locations and environmental conditions
[4-9]. These studies are based on small sized systems with
capacity less than 5 kWp. In [10-16], performances of larger
grid integrated systems, ranging from 36 kWp to 960 kWp
in size, have been reported. Useful information on solar
PV performance, under the respective regional conditions,
could be brought out through these initiatives. However,
only one type of solar cell has been evaluated under these
investigations and hence a comparison on different solar
technologies under the same environment is not available.
[18] tested three modules, namely the mc-Si, sc-Si and a-Si
under a similar tropical environment. Their findings indicate
that the crystalline silicon (c-Si) modules outperform the a-Si
modules, however, their performance decreased significantly
during cloudy days whereas the performance of a-Si modules
shows a slight increase. Though our study is also done under a
IEEE ISGT Asia 2013 1569815041
1
Fig. 1. General layout of the 1.2 MWp grid-connected PV system.
tropical environment, local weather conditions also affect the
performance of PV modules, hence, our findings are not the
same.
In this paper, the comparative field performance of six
different types of solar PV systems - consisting of both the
first and second generation solar cells is reported. This study
also serve to create a better understanding of the behaviour of
solar PV systems under a tropical environment. These systems
are installed at a 1.2 MWp grid connected experimental solar
farm in Brunei Darussalam.
II. THE EXPERIMENTAL SYSTEM
The experimental site is located in Seria, Belait District,
Brunei Darussalam. The farm consists of six different types
of solar cells. They are (1) Single crystalline (sc-Si), (2)
Poly crystalline (mc-Si), (3) Micro crystalline (nc-Si/a-Si), (4)
Amorphous silicon (a-Si), (5) Copper Indium Selenium (CIS)
and (6) Heterojunction with Intrinsic Thin Layer (HIT). The
specifications for these systems are given in Table 1. As we
can see, these modules have different conversion efficiencies
and hence, the number of modules and the panel area for 200
kWp rated capacity are different.
The layout of the solar farm and the data acquisition system
are shown in Fig. 1. Every two types of the solar module are
grouped together and connected to a converter and every two
converters are connected to an inverter. The data monitoring at
the solar farm consists of sensors and data loggers to measure
the weather parameters such as horizontal and inclined solar
insolation, wind speed at the panel height, ambient temper-
ature, relative humidity and precipitation. Outputs from the
panels, both DC and AC, are sensed at one second interval,
which are then averaged into hourly values for this study.
Performance data from the solar farm during 2012 was used
for the study.
A. First generation PV modules
The mono crystalline or single crystalline silicon (sc-Si)
and polycrystalline or multi crystalline silicon (mc-Si) solar
modules are known as the first generation PV modules as
they are the more mature technology and more dominant. Due
to extensive research and development over the years, these
generation of modules are now able to achieve very high effi-
ciency; typically in the range of 13% to 19%. As pure silicon
is needed, thus requiring energy intensive processes, overall
production cost are relatively higher than other technologies
[19].
1) Single crystalline silicon PV modules: Single crystalline
silicon cells are made from single large silicon crystals.
Compared to other PV cells, they exhibit higher efficiency but
tend to lose efficiency at high temperatures. The production
costs are highest, since it involves a complex, energy intensive
process. They have high longevity and durability.
2) Poly crystalline silicon PV modules: Poly crystalline sil-
icon cells are composed of multiple silicon crystals. Since the
TABLE ISPECIFICATION OF THE SOLAR MODULES
PV module type Po (W) ηSTC No. of Area(%) modules (m2)
Single crystalline 180 14.1 1,116 1,462Polycrystalline 185 13.4 1,098 1,518Microcrystalline 130 8.2 1,540 2,426Amorphous Silicon 100 6.3 2,000 3,150CIS 80 8.9 2,500 1,979HIT 205 16 980 1,257
2
Fig. 2. Monthly averaged daily array yields.
production process is relatively simpler than single crystalline
silicon cells, the costs are comparatively lower. The poly
crystalline silicon modules are slightly less efficient than the
single crystalline. The durability and longevity are comparable
to single crystalline PV modules. As they come at a lower
price and a comparable performance, poly crystalline silicon
PV modules are the more popular choice in the market.
B. Second generation PV modules
This generation of PV modules refer to the emerging thin
film technologies such as the amorphous (a-Si), CIS, the
hybrid micro crystalline (nc-Si/a-Si) and HIT solar modules.
Amorphous silicon (a-Si) is a non-crystalline form of silicon.
The panels are formed by depositing a thin layer of silicon on a
substrate material. The micro crystalline module here refers to
a hybrid technology combining the micro crystalline cells (nc-
Si) with an a-Si cell. HIT consist of a thin sc-Si surrounded
by ultra-thin a-Si while CIS is a solid state semi conductor
copper indium selenide (CuInSe2).
Although material and production costs are lower than the
former generation as they require less or no silicon, their lower
efficiencies create a setback resulting in lower demand and
modest productions, hence retails prices are more expensive.
Their degradation characteristics are also less understood.
Among its advantages are its flexibility and light-weight;
suitable for residential or building integration (i.e., BIPV).
Thin film technologies are also less affected by shading as
different materials with different absorption properties are
layered atop one another to enable absorption of multiple light
spectrums (both long and short wavelengths) [19].
III. PERFORMANCE CRITERIA
Nomenclature
• P0 - Peak capacity (Wp)
• EDC - DC energy output (kWh/m2)
• G - Reference radiation taken as 1 kW/m2
• Hd - Daily in-plane radiation on the panel (kWh/m2)
• YA - Array yield (hours/day)
• YR - Reference yield (hours/day)
• LC - Capture loss (hours/day)
• PR - Performance ratio
• ηR - Efficiency ratio
The performance parameters and procedures, suggested by
the IEA under the PVPS project (IEA PVPS Task 2 [3,17]) has
been adopted for the analysis. Based on this, the array yield,
capture losses, array efficiency ratio, and performance ratio
were calculated for the six different types of solar modules.
These parameters are defined in brief in the following sections.
A. Array Yield
Array yield YA (h/day) is the array DC energy output
(kWh/m2) per installed capacity per unit area of the PV array
(kWp/m2) which is given by
YA =EDC
P0(1)
B. Reference Yield
Reference yield, represented by YR (h/day) is the ratio of
total daily in plane radiation Hd (kWh/m2) on the panels to
the reference in plane radiation G (1 kW/m2). Hence,
YR =Hd
G(2)
C. Capture Loss
Array capture loss LC is the difference between the refer-
ence yield and the array yield. Thus,
LC = YR − YA (3)
D. Performance Ratio
Performance ratio, PR is the ratio of array yield and
reference yield.
PR =YA
YR(4)
Fig. 3. Annual averaged daily array yield and capture losses.
3
E. Efficiency Ratio
Array efficiency ratio, ηR which reflects the systems field
efficiency, is the ratio between the energy output (DC) per
in-plane irradiation on the array and the arrays efficiency at
standard test conditions.
ηR =EDC
H
ηSTC(5)
IV. RESULTS AND DISCUSSION
Variations in monthly averaged daily array yield and capture
loses are shown in Figs. 2 and 3 respectively. The array
yield normalizes individual module size and efficiency, and
represents the number of hours the module would have to
operate at its rated capacity to yield the same energy that it
has produced in a day. It can be noted that the array yield
varies accordingly with the variation of local solar radiation
in Fig. 7.
Comparing the different types of PV systems, the a-Si
modules showed the highest average array yield in most of
the months. The annual averaged daily array yield for a-Si
modules was 4.45 h/day, which was followed by HIT modules
(4.38 h/day). The lowest annual averaged daily array yield of
3.99 h/day was observed in case of sc-Si PV system (Fig. 3).
The capture losses in different PV modules are displayed
in Fig. 3. The major factors contributing to the capture
losses are thermal capture losses and miscellaneous capture
losses. Thermal capture losses reflect the reduction in cell
efficiency with the rise in cell temperature (higher than 25◦C).
Miscellaneous capture losses can be caused by low irradiance,
shadowing effect, spectral reflectivity, and dirt accumulation.
Following the same trend as in array yield, capture losses
were minimum in case of a-Si modules (18.2 %), followed
by HIT (19.5 %). The highest losses, at a level of 26.7 %,
were observed in case of sc-Si modules.
The monthly averaged daily performance ratios for the mod-
ules are shown in Fig. 4. The performance ratio compares the
actual performance of the module with the theoretical lossless
ideal condition while eliminating the effect of the variation
of in-plane solar radiation. It quantifies how effectively a
particular technology could interact with the solar resource
available at a given location, which may be affected by the
reflectivity of the modules’ surface and reduced efficiency due
to increase in ambient temperature. The amorphous silicon
and HIT modules showed the highest performance ratios
throughout the year. As expected, the performance ratios were
highest in months when the ambient temperature (and there
by cell temperature) is relatively lower.
The monthly averaged daily efficiency ratios of different
modules are compared in Fig. 5. This indicates how well the
PV modules could perform in real environment in comparison
to its laboratory performance under ideal conditions. From
the figure, it can be seen that field performance of the CIS
modules was close enough to its rated performance throughout
the year. The annual average efficiency ratio for these modules
Fig. 4. Monthly averaged daily performance ratios.
was 0.88, followed by a-Si (0.82) and HIT (0.8) modules. The
lowest performance ratio (0.71) was shown by sc-Si cells.
Fig. 6 shows the hourly variations of solar insolation levels
and the efficiency ratio of the cells averaged over the one
year period. It can be seen that the second generation modules
such as the Micro crystalline and amorphous silicon modules
reach their highest efficiency ratios at an earlier time, hence
at lower insolation levels. The Amorphous silicon and HIT
modules consistently maintained higher efficiency ratios even
at lower insolation levels, followed by the CIS modules.
Although the maximum efficiency ratio of micro crystalline
(nc-Si/a-Si) at high insolation levels are lower compared to
the other second generation PV technologies, it has the second
highest efficiency ratio, just below the amorphous modules
during hours when insolation levels are lower. Thus, second
generation thin film technologies could operate at higher
levels for a wider range of solar spectra. This is a desirable
characteristic, especially while operating at locations like in
Brunei Darussalam, where it is cloudy and the solar insolation
levels fluctuate significantly [17].
Fig. 5. Variation in monthly averaged daily efficiency.
4
Fig. 6. Hourly variation of Solar Irradiance and Efficiency Ratio.
Fig. 7. Monthly variation of solar radiation.
Fig. 8. Frequency of Solar Radiation in Brunei.
V. CONCLUSIONS
Field performances of six different solar PV systems, with
a nominal power rating of 200 kWp each, were analyzed
and compared under this study. Following the IEA guidelines,
array yield, capture losses, efficiency ratio and performance
ratio are considered as the yardsticks for the performance
assessment. PV systems based on a-Si showed the highest
array yield and performance ratio under the study. Capture
losses were also the lowest for this type of modules. Perfor-
mance of HIT modules was also impressive under the given
conditions. However, the efficiency ratio was found to be the
highest for the CIS modules followed by the a-Si and HIT
systems. Based on these performance parameters, PV systems
with a-Si modules are found to be best suited for the tropical
environment of Brunei Darussalam. Sc-Si modules showed the
poorest field performance with regard to all the considered
measures. It should be noted that the assessment was purely
based on the technical performance while economic aspects
also play a major role in the final selection of the PV system
for a given location.
A study carried out under a similar climate in Malaysia
evaluated three types of PV modules such as a-Si, sc-Si and
mc-Si modules over a four day period covering two sunny days
and two cloudy days. Solar radiation of 369 and 402.24 W/m2
were considered for cloudy days, and 796.16 and 807.49
W/m2 for sunny days, both for a duration of 6 sunshine hours
[18]. The result shows a considerably lower PR (below 60%)
and ηR (below 45%) compared to that under Brunei condition.
Their comparison results are contrary to this paper where the
PR and ηR are highest for mc-Si modules, followed by sc-Si
and a-Si modules whereas under the Brunei condition, a-Si
modules gives the highest PR and ηR followed by mc-Si and
sc-Si.
Fig. 8 is the frequency of Brunei solar radiation where it
is divided into three categories based on its intensity such
as low, medium and high corresponding to the colours red,
blue and green. It can be seen that the solar radiation of
Brunei predominantly occurs in the medium region while
the study done in Malaysia has only considered radiation
values corresponding to the low and high intensity regions.
It that study, the sc-Si and mc-Si modules show very high
performances compared to a-Si under high solar radiation
while the a-Si performs almost on par with the sc-Si and mc-Si
modules during low solar radiation.
Based on these two studies, it may be concluded that a-Si
modules will perform worse than c-Si modules at high solar
radiation, on par with c-Si modules at low solar radiation
and better than c-Si modules at mid-range solar radiation.
Despite a-Si having the lowest efficiency under the study in
Malaysia, the efficiency was almost consistent for both sunny
and cloudy days whereas mc-Si and sc-Si modules suffer
from considerable drop in efficiency under cloudy condition.
This is consistent with the advantage associated with thin film
technologies.
Though this analysis is based on the field performance
5
of the PV systems at a specific site, the results can give
useful implications on the expected performances of such
systems under similar climatic conditions. Further, the field
performances can be correlated with various environmental
parameters to develop PV performance models, which can
be used in conjunction with Numerical Whether Prediction
(NWP) models to come up with a power forecasting system
for the given solar farm.
ACKNOWLEDGMENT
The support extended by the Energy Department, the Prime
Ministers Office (EDPMO), Brunei Darussalam, during the
course of this study, is thank fully acknowledged.
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