fundamental study for the power tower's high concentrated
TRANSCRIPT
1 Current affiliation: DEC Dynamic Engineering Consultants
P.O.Box 79593, Dubai, United Arab Emirates
FUNDAMENTAL STUDY FOR THE POWER TOWER’S HIGH CONCENTRATED PHOTOVOLTAIC/THERMAL-COMBINED THERMAL RECEIVER
Ayman Hagfarah1 School of Engineering and Physical Sciences
Heriot-Watt University Dubai, United Arab of Emirates
Mehdi Nazarinia School of Engineering and Physical Sciences
Heriot-Watt University Dubai, United Arab of Emirates
ABSTRACT The present study introduces fundamental aspects of a
novel concentrated photovoltaics (CPV) technology. The
technology is based on combining CPV/T receiver along with a
solar thermal receiver. The combination is referred to as a
High Concentrated Photovoltaic/Thermal – Combined receiver
or HCPV/T-CT. The receiver is allocated in lieu of the
conventional solar thermal receivers in the solar tower power
plant schemes. The plant is designed to generate electricity and
thermal energy simultaneously prior to integration with the
conventional water desalination plant. The centralized
generation in the CPV/T- CT receiver will remarkably simplify
the complexity of the conventional solar power plants, and
eliminate the piping networks’ energy losses in the CPV/T
Dish tracking plants. The viability of the HCPV/T-CT power
tower plant has also been investigated by; firstly, designing and
simulating the plant performance using the System advisor
model (SAM) software, and secondly, designing a prototype
receiver and then deriving a mathematical model. The
Levelised Cost Of Electricity/Energy (LCOE) was found to be
0.119 $/kWhe and 0.021 $/kWhe for electricity and energy
generation, respectively, while the photovoltaic cells
temperature maintained below the 90 °C.
INTRODUCTION
The importance of the clean energy was emphasized
recently by the issues related to the fossil fuel impact on the
environment, energy security, the growth of the population and
the economic development. These factors brought the attention
to the solar energy as an alternative energy resource. The main
challenge for solar energy technologies is the capability to
provide a competitive low Levelised Cost Of Electricity
(LCOE) [1]. On the utility power generation scale the
conventional Concentrated Solar Power (CSP) technologies,
such as Thermal power tower solar plants and the Parabolic
Trough power plant, are comprised of many complex parts
(e.g. Steam turbines, generators, working fluid transportation
system, etc. …) and of these parts incur reduction in the
plant’s efficiency, another example of conventional
Concentrated Solar Power (CSP) technologies is the CPV/T
tracking based system plants where the efficiency is reduced
further due to the pumping and heat losses in the coolant’s
piping network [2]. Another factor that decreases the
concentrated photo-voltaic performance is the hot spot
formation which caused by the inhomogeneity of the
illumination on the cells’ surface and/or by the ineffective
cooling system [3]. The present study focuses on coupling two
of the emerging solar energy technologies; the concentrated
photovoltaic and the Solar power tower. The purpose of the
study is to investigate the viability of a novel type of the CSP
plant technology based on combining of the CPV/T receiver
along with the solar thermal receiver. This combination will be
referred to as a High Concentrated Photovoltaic/Thermal –
Combined Thermal receiver (HCPV/T-CT). The HCPV/T-CT
receiver is allocated in lieu of the conventional solar thermal
receiver in the solar tower power plant scheme. The
centralized concept of the CPV/T- CT plant is developed to
replace the complexity of the conventional CSP plants, and to
reduce the operation cost of the CPV/T Dish tracking and the
parabolic trough plants as it will eliminate the pumping and
the heat losses in the piping network. Moreover the central
fixed receiver is expected to significantly reduce the power
required to track the sun, as in the HCPV/T-CT technology the
sun is tracked only by the heliostats (mirrors) while in the
conventional photovoltaic (CPV/T) or the Stirling system it
required to move the whole system to track the sun [2].
Proceedings of the ASME 2016 10th International Conference on Energy Sustainability ES2016
June 26-30, 2016, Charlotte, North Carolina
ES2016-59051
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II. PREVIOUS STUDIES: The high Concentrating Photovoltaic Power Towers
technology was disclosed by Frohberger [4], Dirk et al in 2010
when they conducted a feasibility study to evaluate the future
potential of the CPV Power Towers in Seville, Spain. In order
to calculate the reflected solar radiation on the receiver, they
used a tray tracing software called OPTIMTSA .The receiver
was a photovoltaic cells allocated on the tower in the lieu of
the conventional solar thermal receiver. They assumed that the
operating temperature of the PV cells was maintained at 25 °C
in their 1 MW prototype plant by means of a water cooling
system in an attempt to obtain a low value of the Levelised
Cost Of Electricity generation (LCOE), the study showed an
overall efficiency of 18.7% for the plant, and a LCOE of 0.29
$/kWh.
III. HCPV/T COMBINED THERMAL RECEIVER
The proposed receiver in this study is a combination of the
solar thermal receiver and a photovoltaic thermal receiver
CPV/T. The two receivers are mechanically coupled to each
other to form a one surface which its axis is parallel to the
tower axis. Each receiver comprises of a surface facing
outward from the power tower to continually receive the
reflected solar irradiance. The resulted apparatus is referred to
as Concentrated Photovoltaic Thermal Combined receiver. A
heat transfer fluid, water, will be pumped to be fluidly coupled
with inward surface of the photovoltaic’s substrate absorbing
the generated heat and controlling the PV cells temperature,
the coolant will flow through small designed passages to insure
a maximum heat transfer rate with minimum pumping losses.
To increase the exergy of the heat transfer fluid while
maintaining the operating temperature of the PV cells below
90 °C, as shown in Fig. (1).
Figure 1. Schematic drawing of the CPV/T- CT receiver, the
drawing shows the front view (aperture surface) of the receiver.
The coolant fluid will continue flowing upward
transferring the absorbed heat from the PV panels’ portion to
enter the solar thermal receiver portion where it will be heated
up to the desired temperature.
The combined solar thermal receiver comprises of
plurality of pipes coated with black paint and directly exposed
to the solar irradiation, a thick layer of insulation material will
be utilized to cover the backward surface of the whole receiver
in order to minimize the convection heat losses. The receiver
will be designed in a way to raise the water temperature up to
90 °C. The harvested thermal energy can be transferred by
means of heat exchanger to the conventional desalination plant
such as conventional Multi-Stage Flash or Multi-Effect
Distillation process [5].
A. Materials selection and evaluation The proposed cells for the receiver are triple junction
InGaP/InGaAs/Ge manufactured and provided by CESI in
Italy. The efficiency of the Cell was confirmed and tested in the
laboratory to be 39% tested at 512 Sun, 25 °C and 1.5 AM.
The Triple Junction PV cells were designed to be fixed on a
Direct Bonded Copper Ceramic Substrate, DBCu Nitride
(AIN), as shown in the Fig. (2).The substrate copper layer was
coated by Cu 70 ± 20 um, Ni 100-300uʺ and Au 20 ±5uʺ. The
gold wire bonding process was used to interconnect the
negative poles of the PV cells with the positive copper layer of
the DBC substrate, Direct Bonded Copper Ceramic Substrate,
DBCu Nitride (AIN), as shown in the Fig. (2).The substrate
copper layer was coated by Cu 70 ± 20 um, Ni 100-300uʺ and
Au 20 ±5uʺ. The gold wire bonding process was used to
interconnect the negative poles of the PV cells with the
positive copper layer of the DBC substrate.
In order to protect the cells without compromising the
quality of the solar irradiation a Low iron clear float glass with
anti-reflective coating is selected to cover the CPV assembly.
The selected glass for the receiver was manufactured by
Pilkington plc, the glass has a transmittance value of 93.9%
for the direct solar light for a 3 mm glass thickness as shown
on the fig (3). A secondary concentrator is used to reduce the
required number of the cells (cells raw material) and to
improve the solar illumination on the Cells surface by
redistributing the solar irradiance on the PV cells surface. Fig.
(2) shows the bypass diodes that were connected in parallel
with the module so to protect the cell from the hot spot
destructive effects in case of the mismatch current. In this
design the solder paste is used to attach the PV cells on the
DBC substrate. The paste contains 62% tin, and its thermal
conductivity is 50 W/K m. The thickness of the solder paste is
0.1 mm.
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Figure 2. Front view of the HCPV receiver module aperture surface shows the 16 Triple junction cells and the bypass diodes soldered to the AIN substrate.
Figure 3. Cross section of the CPV/T receiver module shows the assembly of the secondary concentrator, cover glass, heat
exchanger, CPV cells and the Substrate.
B. The Heat Exchanger The design of the heat exchanger must assure the
capability to dissipate the generated heat (100 W/cm2) in order
to maintain the cell operating temperature below 90 °C. Micro
passages with 500 µm width confined by longitudinal extruded
fins with 500 µm width were designed to increase the heat
transfer rate. The fins are extruded from the heat exchanger’s
base plate as shown in the fig. (3), the base plate material must
have a high thermal conductivity and low cost as well. Since
the usage of the dissimilar metals causes the galvanic
corrosion, the heat exchanger base plate was made of copper to
match with the substrate copper bottom layer. The thickness of
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the base plate was sized 3mm to assure proper diffusion for the
heat flux from the solar cells up to the coolant streams by
means of attempting to reduce the impact of the temperature
gradient of the coolant’s flow stream on the uniformity of PV
cells surface’s temperature. This factor was carefully
considered in this study not only for the mentioned reason but
also to avoid the possibility of the PV cells to work above the
90 °C as a result of the high thermal resistance caused by the
plate thickness. Performing the hot curing process on the
solder paste the 16 triple junction solar cells and the 6 Amp
Schottky diodes were fixed on the substrate to form the HCPV
receiver as shown in the Fig (4).
Figure 4 The assembled parts of the HCPV Receiver prototype.
IV. THE METHODOLOGY
A. System Advisor Model In order to investigate the plant potential and
reliability, as discussed System Advisor Model (SAM, version
2014.1.14) [6] software is used to design, optimize and
simulate the heliostats field and the performance of the
receiver along the day hours and for the whole year
considering Abu Dhabi city weather data. SAM considers the
heliostat’s cosine losses, blocking and shading, when
calculates the direct incident energy on the receiver aperture
area. The pumping requirements, convective and radiative
energy losses were also considered. SAM and the other solar
energy software do not exactly support the CPV/T receivers in
the power tower plant, thus at first the design of the Molten-
salt power tower is considered in lieu of the CPV/T receiver in
the simulation process, also the programme conducts the
financial analysis for the plant and generates the required
number of the heliostats. Then the hourly incident energy,
convective heat loss and the radiation losses of the simulated
conventional Molten-salt receiver for the 8760 hours of the
year is extracted and coupled with CPV/T receiver derived
formula in an excel sheet to find the exact electrical and
thermal energy annual yields.
A comparative study was conduct between the
CPV/T-CT power tower plant and the conventional solar
thermal power tower plant, the purpose of the study is to
illustrate the power output of each plant for the same aperture
area (incident solar energy) the receiver’s aperture area was
fixed at 578 m2 for the both plants. The first plant is the
conventional solar thermal power tower plant simulated
directly by SAM, the second one is the CPV/T-CT power tower
plant semi-simulated by SAM, the incident solar energy were
completely identical set at 500 Suns for both of the simulated
plants. The plants showed capacity of 72 MWe and 60 MWe,
respectively.
B. The Mathematical Model The mathematical model thoroughly analyzed the
heat and mass transfer in the assembly prior to design the
receiver and optimize its performance, the analysis included
the following process; firstly the fluid flow and the forced
convection heat transfer in the heat exchanger, Secondly the
conduction heat transfer through the CPV assembly, Thirdly
the free convection heat and the mass transfer in the secondary
concentrator void generated by the temperature difference,
finally the natural convection heat transfer and radiation heat
transfer between the CPV assembly and the surrounding
environment.
The amount of the generated thermal energy in the
solar cell is function in the cell efficiency and the efficiency in
turn depends on the cell’s temperature. So in order to calculate
the PV operating temperature, it is required first to know the
generated thermal energy on the cell, the complexity of the
analysis stemmed from the linkage of the all values with each
other. A logarithm was developed prior to generate the
mathematical model. The logarithm presume the cell operating
temperature ( initial value) and accordingly find the other
performance characteristics, the resulted values is set again as
initial values for the model, and consequently a series of
iterations processes were conducted to find the correct
operating values. The iteration process numbers were governed
be obtaining the desired residual error value.
V. THE RESULTS AND DISCUSSION
A. The Mathematical Model The solar concentration values (Cr) are plotted with
respect to the other cell’s performance parameters (Cells
operating temperature, Reynolds number, Combined Thermal
Receiver’s efficiency, PV cell’s efficiency and the coefficient of
performance) which based on the mathematical model results.
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The selection of the curves were focused on the non-
dimensional parameters were they can be projected on the
actual receiver size.
The variation of Reynolds number is shown on Fig. 5, it
can be noticed that Reynolds number in the CPV/T receiver
portion was increased in a linear trend with respect to the solar
concentration, this attribute to the increase in the demand for
the water flow rate to carry the generated thermal energy on
the cells as a result of the increase in solar concentration.
Figure 5. Performance curve shows the Reynolds Number for the CPV/T prototype receiver vs. the solar
concentration.
The efficiency of the cells was simulated for each of the
corresponding PV operating temperature; each solar
concentration value requires to adjust the coolant flow rate at
certain value prior to maintain the cooling water-outlet form
the CPV/T portion at 60 °C, although the operating
temperature for the PV cells should be constant since the mass
flow rate keep increasing along with the solar concentration to
overcome the generated heat, instead as shown in the Fig. (6)
it is noticed that the temperature slightly increased along with
the solar concentration, the explanation is accounted for the
CPV assembly materials properties. The minimum allowable
thickness for these materials and its thermal conductivity form
a thermal resistance, the resistance of the CPV structure in
turn creates temperature gradients between the cooling water
and the cells surface.
The second portion of the CPV/T CT receiver is the solar
thermal receiver, it important to consider its performance
characteristic in the study, the efficiency of the receiver was
simulated by SAM programme for the 8761 hours per year
considering Abu Dhabi city weather data. The performed
efficiency calculation was based on the radiation and
convection losses which were simulated by SAM.
Figure 6. Performance curve shows the PV cell surface’s
operating temperature for the CPV/T prototype receiver vs. the solar concentration.
As shown on the Fig. (7) the best operating
conditions for the thermal receiver is found at the higher solar
concentrations, it obvious that the increase in the rate of the
absorbed heat gain is higher than the increase of the radiation
and convection heat losses rate from the aperture surface.
Figure 7. Performance curve shows the thermal efficiency
of the solar thermal receiver portion vs. the solar concentration, the receiver design for maximum
concentration of 1000 sun.
Also the Coefficient Of the Performance (COP) of the
CPV/T receiver where calculated for the solar concentration
range from 300 to 1000 Suns considering the generated
electricity power against the pumping losses in the heat
exchanger , the results showed a slight decrease in the C.O.P
along with the increase of the sun concentration. The value of
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the C.O.P. can be approximated to 99.99% throughout the sun
concentration rang (300 – 1000 sun), the pumping losses in
the heat exchanger is almost negligible compared the
generated power, the low pumping losses is accounted to the
low Reynolds number as shown on the fig. (5).
B. System Advisor Model Using the System Advisor Model (SAM) to design and
simulate the heliostats and the receiver size, it was found that
the tower will require 3767 heliostats to generate 500 Suns on
the receiver aperture area. It also noticed that the CPV/T-CT
plant produce thermal energy 545 GWh/year equivalents to
almost times as much as its electrical power production 95
GWh/year. The Packing factor of the PV cells converts as
much as 27 % of the incident solar irradiance directly to
thermal energy; although this energy will be exploited in the
desalination process downstream, yet it incurred a heat
exchanger design with higher heat transfer coefficient and
higher coolant flow rate as well. This result emphasize the
importance of the packing factor and the necessity of
researches for technologies that can increase the packing factor
by develop a wire bonding technique require less gap area
between the cells.
Table (1) below shows the calculated break down cost for
the CPV/T-CT plant, the break down showed that the
heliostats cost 94$ Million which dominates the plant cost by
almost 50 %, While the CPV cells contribute by only 5%, this
figures outlined the importance of researches which focus on
the heliostats cost reduction rather than the Multijunction
cells. The main result of the feasibility study is LCOE and as
shown in the Table (1) the LCOE for the CPV/T-CT Power
Tower Plant was found to be 0.1186 $USD/kWh, this value is
considered low and competitive compared to the present LOCE
values in the PV-utility scale market, the minimum LOCE
(Electricity) value was 0.119 $USD/kWh in 2013 [1]. .
Table 1. The installation and Operation costs of the CPV/T-CT Power Tower Plant. Description Value Units
Payback period 8.7 Year
Net Present value 25,427,852 $USD
Installation Cost Rate 3,212 $USD/kWh
LCOE (Electricity) 0.11862 $USD/kWh
LCOE (Energy) 0.02074 $USD/kWh
VI. CONCLUSION The study showed that the utilization of CPV/T Combined
Thermal receiver technology in lieu of the conventional solar
thermal receiver is reliable and economically viable. the
simulation results showed that the CPV/T CT power plant has
a Levelised Cost of electricity generation equal to 0.119
$/KWhe, while the equivalent conventional power tower plant
with the thermal receiver has a LCOE 0.165 $/KWhe. Since
the CPV/T CT plant produce thermal energy and electricity
simultaneously, the Levelised Cost of energy generation is so
significant for the evaluation of the plant performance, the
calculation and simulation results showed 0.021 $/KWh of
Levelised Cost of energy generation. The generated
mathematical model proved the ability of the CPV/T receiver
to raise the water temperature up to 65 C ° while maintaining
the PV cells temperature below the 90 C° when the inlet water
temperature is 25 C°. In the CPV/T CT receiver, the
percentage of aperture area of the thermal receiver to the
CPV/T portion was 43.3 %, this ratio of the surface area
APV/Asolar can be projected to any size of the CPV/T CT
power tower plant along with the associated operating
conditions. The design of the HEX showed that it requires a
laminar water flow pattern through the fins’ passages with
maximum 81.16 Reynolds number to maintain the PV cell
temperature below 90 C° under 1000 sun concentration. The
remarkably low Reynolds number for the cooling water flow
reduced the pumping power losses and increased the
Coefficient of performance for the CPV/T receiver to 99.99%.
ACKNOWLEDGMENTS The authors wish to thank CESI S.p.A., Milan, Italy for
their collaboration by manufacturing and providing the Triple
junction solar cells.
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