Potential of performance improvement of concentrated solar power plants by optimizing the parabolic trough receiver
Honglun YANG1, Qiliang WANG1, Jingyu CAO1, Gang PEI1(), Jing LI2()
1. Department of Thermal Science and Energy Engineering, University of Science and Technology of China, Hefei 230026, China 2. School of Engineering and Computer Science, University of Hull, Hull, HU6 7RX, UK
This paper proposes a comprehensive thermodynamic and economic model to predict and compare the performance of concentrated solar power plants with traditional and novel receivers with different configurations involving operating temperatures and locations. The simulation results reveal that power plants with novel receivers exhibit a superior thermodynamic and economic performance compared with traditional receivers. The annual electricity productions of power plants with novel receivers in Phoenix, Sevilla, and Tuotuohe are 8.5%, 10.5%, and 14.4% higher than those with traditional receivers at the outlet temperature of 550°C. The levelized cost of electricity of power plants with double-selective-coated receivers can be decreased by 6.9%, 8.5%, and 11.6%. In Phoenix, the optimal operating temperature of the power plants is improved from 500°C to 560°C by employing a novel receiver. Furthermore, the sensitivity analysis of the receiver heat loss, solar absorption, and freeze protection temperature is also conducted to analyze the general rule of influence of the receiver performance on power plants performance. Solar absorption has a positive contribution to annual electricity productions, whereas heat loss and freeze protection temperature have a negative effect on electricity outputs. The results indicate that the novel receiver coupled with low melting temperature molten salt is the best configuration for improving the overall performance of the power plants.
Specific solar field cost (traditional/novel receiver)/($·m−2)
150/154.5
Specific HTF systems/($·m−2)
70
Specific power block cost/($·kW−1)
1150
Balance of plant/($·kW−1)
120
Specific land cost/($·Acre−1)
10000
Contingency/%
7
O&M cost
Fixed cost by capacity/($·kW−1·year−1)
66
Variable cost by generation/($·MWh−1)
4
Financial parameters/%
1
Annual insurance cost
CRF/%
9.88
Lifespan of the system/year
30
Bank rate/%
8
Tab.4
Location
Operating temperature/°C
LCOE with novel receiver/(cent·kWh−1)
LCOE with traditional receiver/(cent·kWh−1)
LCOE reduction
Phoenix
290–390
12.4
12.6
1.1%
290–550
12.1
13.0
6.9%
Sevilla
290–390
15.8
16.0
1.4%
290–550
15.8
17.3
8.5%
Tuotuohe
290–390
24.0
24.4
1.7%
290–550
25.0
28.2
11.6%
Tab.5
Fig.12
Fig.13
Fig.14
Fig.15
A
Area/m2
C
Cost
D
Diameter/m
e
Enthalpy/(J·kg−1)
fabs
Friction factor
h
Heat transfer coefficient/(W·m−2·K−1)
k
Conduction coefficient/(W·m−1·K−1)
L
Length/m
m
Mass flow rate/(kg·s−1)
Nu
Nusselt number
P
Perimeter/m
Pr
Prandtl number
Thermal loss/(W·m−2)
Heat transfer rate/(W·m−1)
Re
Reynolds number
T
Temperature/°C or K
v
Velocity/(m·s−1)
Efficiency
Incident angle/(°)
Discrete unit length/m
Incident angle modifier
Thermal conductivity/(W·m−1·K)
AEP
Annual electricity production
CRF
Capital recovery factor
CSP
Concentrated solar power
DNI
Direct normal irradiation
HTF
Heat transfer fluid
LCOE
Levelized cost of electricity
MS
Molten salt
SAM
Solar advisor model
SM
Solar multiple
Subscripts
a
Ambient
abs
Absorber
b
Frame
cond
Conduction heat transfer
conv
Convection heat transfer
cs
Cross section
eff
Effective
f
Heat transfer fluid
i
Inner
invest
Investment
o
Outer
OM
Operation and maintenance
SCA
Solar collector assembly
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