ECCRIA 10 - Coal Research Forum

10th European Conference on Coal Research and its Application
(ECCRIA 10)
STEADY STATE SIMULATION AND EXERGY ANALYSIS
OF SUPERCRITICAL COAL-FIRED POWER PLANT
(SCPP) WITH CO2 CAPTURE
Akeem K Olaleye
Supervisors:
Process and Energy Systems Engineering Group
Department of Chemical Engineering
School of Engineering
University of Hull
Dr. Meihong Wang
Gregg Kelsall (BF2RA, UK)
CONTENT
1
Background and Motivation
SCPP with CO2 Capture
Process Simulation and Integration
Exergy Analysis
Results and Discussion
Conclusions
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Background and Motivation
2
 Coal-fired power plants play a vital role in meeting energy demands
 Coal-fired power plants are the single largest sources of CO2 emissions
UK Electricity generation by source
Global CO2 Emission
Other
2.5%
Renewables
11.3%
Gas
28.0%
Nuclear
19.0%
Coal
39.0%
(Data Source: DECC,2012)
(Data Source: ‘Sustainable aviation CO2 Roadmap’)
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Background and Motivation
3
Power Generation with CO2 Capture
Post Combustion Technology
Air
Combustion
Power
& Heat
Flue gas
~14% CO2
CO2
Capture
CO2
Pre Combustion Technology
Fossil
Fuel
CO2
Capture
Gasification
H2
Combustion
Syngas
20-40% CO2
CO2
Compression &
Transport for
Storage
Power
& Heat
CO2
O2/steam
Oxy-Combustion Technology
OxyCombustion
Power
& Heat
Flue gas
>80% CO2
CO2
Capture
CO2
Fossil Fuel-fired Power Generation with CCS
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SCPP with CO2 Capture
4
Supercritical?
Subcritical Coal-fired power plant:
•
•
•
Typical coal-fired (subcritical) power plant is based on
the rankine cycle.
economizer
Boiler
Subcritical plant efficiencies : 30-38%
Operating pressure: <22.1MPa
Supercritical Coal-fired power plant :
•
super heater
HP, LP
Turbines
pump
Supercritical is based on an increase in the main steam
parameters (T& P), giving rise to a ‘supercritical rankine
cycle’
•
Operating pressure: >22.1MPa
•
There is no generation of steam bubbles within the
water, because the pressure is above the "critical
pressure" at which steam bubbles can form.
•
Supercritical technology can lead to an increase in
efficiency (about 42%)
condenser
Basic (subcritical) rankine cycles
supercritical rankine cycles
ECCRIA 10
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SCPP with CO2 Capture
5
Integration of Increase efficiency with emission reduction
ECCRIA 10
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SCPP with CO2 Capture
6
•
Exergy Analysis is useful for system
optimization:
 Location of Exergy Destruction
 Prioritise system/ components for
efficiency improvement
Exergy Analysis?
•
Need for power plant emission reduction
•
Need for improvement in efficiency
•
Improvement in components design
 Compare components or Systems to
make Design decisions
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Process Simulation & Integration
7
SCOPE

Model of a reference SCPP

Integration of the SCPP model with CO2 Capture model

Estimate Exergy of Individual streams in Aspen Plus®
(EXERGYML, EXERGYMS and EXERGYFL)

Conventional Exergy Analysis to estimate the quantity and
location of exergy destruction and losses

Advanced Exergy Analysis to Identify optimum option for system
Integration

Case studies on Exergy Destruction in SCPP with CO2 Capture
REFERENCE SCPP
•
Greenfield coal-fired supercritical steam plant
•
The steam turbine conditions correspond to 24.1MPa/593°C
•
Net plant power, after consideration of the auxiliary power load,
is 550 MWe.
•
The plant operates with an estimated HHV efficiency of 39.1 %
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Process Simulation & Integration
8
FGD & CO2 Capture
Condensate/Feedwater
Heating
Coal mill & Boiler
Turbine & Steam
Extraction
Hierarchical Model Development in Aspen Plus®
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Process Simulation and Integration
9
Boiler Parameters (NETL, 2007)
Description
BOILER Hierarchy
Value
Steam cycle (MPa/oC/oC)
24.1/593/593
As received coal (kg/s)
51.82
Coal Heating value, HHV (MJ/kg)
27.113
Condenser Pressure (mmHg)
50.8
Boiler Efficiency (%)
89.0
Cooling water to Condenser (oC)
16.0
Cooling water to Condenser (oC)
27.0
Ash Distribution, Fly/Bottom ash (%)
98.4
Excess air (%)
20.0
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Process Simulation & Integration
10
Turbine Parameters (NETL, 2007)
Parameters
TURBINE & Steam Extraction Hierarchy
Value
HP Turbine efficiency (%)
90.0
IP Turbine efficiency (%)
92.0
LP Turbine efficiency (%)
94.0
Generator efficiency (%)
98.4
Feedwater Heating Train
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Process Simulation & Integration
CO2 Capture Hierarchy
11
Design Parameters for the scale-up of the PCC model
Description
Value
Flue gas mass flow rate (kg/s)
603.4
Flue gas composition (CO2)
0.2135
Flue gas composition (N2)
0.7352
Flue gas composition (H2O)
0.0513
CO2 Capture level (%)
90.0
Estimated flowrate of CO2 Capture (kg/s)
128.83
Required MEA flowrate (kg/s)
828.193
Estimated Lean solvent flow rate (kg/s)
2967.9
Estimated Rich solvent flow rate (kg/s)
3040.2
Lean MEA mass fraction (wt. %)
30.48
Lean MEA CO2 loading (mol CO2/mol MEA)
0.29
Key Process Parameters of the PCC model
Parameter
Absorber
Desorber
Calculation type
Rate-based
Rate-based
Type of packing
Sulzer BX 500
Sulzer BX 500
Total Height of Packing (m)
30.0
30.0
Diameter of column (m)
7.6
9.4
3
1
Column Number
No. of Equilibrium stages
20
20
Operating Pressure (bar)
1.013
1.62
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Exergy Analysis
12
Conventional Exergy Analysis
Main Parameter for Exergy Calculation
Conventional exergy analysis identifies:
 The location
 The Magnitude, and
 The sources of thermodynamic inefficiencies
in a thermal system.
The exergy for the overall SCPP system can be written as
𝛦𝐹,𝑡𝑜𝑡𝑎𝑙 = 𝛦𝑃,𝑡𝑜𝑡𝑎𝑙 + 𝛦𝐷,𝑡𝑜𝑡𝑎𝑙 + 𝛦𝐿,𝑡𝑜𝑡𝑎𝑙
(1)
Parameters
Value
Environment Temperature (K)
298.15
Environment Pressure (bar)
1.013
Fuel Input Exergy factor
1.02
Parameter for Estimating Chemical Exergy of MEA Species
Parameters (DGAQFM)
Value
MEA
whereas for the nth component,
𝛦𝐹,𝑛 = 𝛦𝑃,𝑛 + 𝛦𝐷,𝑛
(2)
The exergy efficiency of the nth component
ε𝑛 = 𝛦𝑃,𝑛 𝛦𝐹,𝑛 = 1 − 𝛦𝐷,𝑛 𝛦𝐹,𝑛
(3)
1536.0
MEAH+ (KJ/mol)
-500.504
MEACOO- (KJ/mol)
-196.52
(DGAQFM = Gibbs free energy of formation)
The exergy destruction ratio of the nth component
𝑦𝐷,𝑛 = Ε𝐷,𝑛 Ε𝐹,𝑡𝑜𝑡𝑎𝑙
(4)
The exergy loss ratio is,
𝑦𝐿 = Ε𝐿,𝑡𝑜𝑡𝑎𝑙 Ε𝐹,𝑡𝑜𝑡𝑎𝑙
(5)
Key
𝛦𝐹 = Exergy of fuel
𝛦𝑃 = Exergy of product
𝛦𝐷 = Exergy destroyed
𝛦𝐿 = Exergy loss
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Exergy Analysis
13
Advanced Exergy Analysis
Evaluates:
The interaction among components of the
overall system, and
the real potential for improving a system
component and the overall system
Splitting the exergy destruction into un/av en/ex Parts
un = Unavoidable
av = Avoidable
ex = Exogenous
en = Endogenous
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Exergy Analysis
Advanced Exergy Analysis
Conditions for splitting the Exergy Destruction
 Real (R)
 Theoretical (T)
 Unavoidable (U)
The splitting combinations can be estimated thus:
𝑢𝑛,
𝛦𝐷,𝑛
= 𝛦𝑃,𝑛 (𝛦𝐷,𝑛 /𝛦𝑃,𝑛 )𝑢𝑛
(6)
𝑢𝑛,𝑒𝑥
𝑢𝑛,𝑒𝑛
𝑢𝑛
𝛦𝐷,𝑛 = 𝛦𝐷,𝑛 − 𝛦𝐷,𝑛
(7)
𝑎𝑣,𝑒𝑥
𝑢𝑛,𝑒𝑛
𝑒𝑛
𝛦𝐷,𝑛 = 𝛦𝐷,𝑛 − 𝛦𝐷,𝑛
(8)
𝑎𝑣,𝑒𝑥
𝑢𝑛,𝑒𝑥
𝑒𝑥
𝛦𝐷,𝑛 = 𝛦𝐷,𝑛 − 𝛦𝐷,𝑛
(9)
𝑒𝑛
𝑒𝑛
(𝛦𝐷,𝑛 /𝛦𝑃,𝑛 )𝑢𝑛 ,𝛦𝑃,𝑛
, and 𝛦𝑃,𝑛
are first determined from the unavoidable and SCPPhybrid
Once-through boiler subsystem for Advanced Exergy Analysis
Fuel Saving Potential
𝑻,𝒏
𝑹
∆𝑬∗,𝒏
𝑭,𝒕𝒐𝒕𝒂𝒍 = 𝑬𝑭,𝒕𝒐𝒕𝒂𝒍 − 𝑬𝑭,𝒕𝒐𝒕𝒂𝒍
𝑅
where 𝐸𝐹,𝑡𝑜𝑡𝑎𝑙
= fuel exergy consumption of the SCPP under “Real” condition
𝑇,𝑛
𝐸𝐹,𝑡𝑜𝑡𝑎𝑙 = SCPP-Hybrid only the component of interest operates “Theoretically”
14
Assumptions/Conditions for splitting the Exergy Destruction
Components
Boiler Subsystem
Real (R)
FURN
AIR-PRT
Theoretical (TH)
Unavoidable (UN)
αairfuel = 1.02
αairfuel = 1.02
αairfuel = 1.02
ηboiler = 0.89
ηboiler = 1.0
ηboiler = 1.0
ΔTmin = 0.0
ΔTmin = 65.0
ΔTmin = 100.0
SSH
ΔTmin = 521.0
ΔTmin = 0.0
ΔTmin = 100.0
PSH
ΔTmin = 228.0
ΔTmin = 0.0
ΔTmin = 100.0
RHT
ΔTmin = 362.0
ΔTmin = 0.0
ΔTmin = 100.0
ECON
Turbine Subsystem
ΔTmin = 100.0
ΔTmin = 0.0
ΔTmin = 50.0
VHP-TURB
ηisent = 0.90
ηisent = 1.0
ηisent = 0.92
VHP-TRB2
ηisent = 0.89
ηisent = 1.0
ηisent = 0.96
HP-TURB
ηisent = 0.87
ηisent = 1.0
ηisent = 0.98
IP-TURB
ηisent = 0.92
ηisent = 1.0
ηisent = 0.96
LP1-TURB
ηisent = 0.90
ηisent = 1.0
ηisent = 0.98
LP-TURB2
ηisent = 0.94
ηisent = 1.0
ηisent = 0.96
LP-TURB3
ηisent = 0.97
ηisent = 1.0
ηisent = 0.94
LP-TURB4
ηisent = 0.81
ηisent = 1.0
ηisent = 0.91
BFP-TRB
ηisent = 0.83
ηisent = 1.0
ηisent = 0.86
COND
ΔTmin = 10.0
ΔTmin = 0.0
ΔTmin = 6.0
BF-PUMP
ηisent = 0.88
Feedwater Heating Subsystem
ηisent = 1.0
ηisent = 0.93
FWH-1
ΔTmin = 2.8
ΔTmin = 0.0
ΔTmin = 1.5
FWH-2
ΔTmin = 2.8
ΔTmin = 0.0
ΔTmin =1.5
FWH-3
ΔTmin = 3.1
ΔTmin = 0.0
ΔTmin =1.7
FWH-4
ΔTmin = 6.3
ΔTmin = 0.0
ΔTmin = 4.2
DEAERATOR
ΔTmin = 1.0
ΔTmin = 0.0
ΔTmin = 0.3
BS-PUMP
ηisent = 0.87
ηisent = 1.0
ηisent = 0.91
FWH-5
ΔTmin = 5.3
ΔTmin = 0.0
ΔTmin = 4.3
FWH-6
ΔTmin = 100.0
ΔTmin = 0.0
ΔTmin = 65.0
FWH-7
ΔTmin = 3.0
ΔTmin = 0.0
ΔTmin = 65.0
FWH-8
ΔTmin = 2.8
ΔTmin = 0.0
ΔTmin = 1.8
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Results and Discussion
15
Results – Conventional Exergy Analysis
Components
EF,n(MW) EP,n(MW) ED,n(MW) yD,n(%)
Ɛn(%)
Boiler Subsystem
COALMILL
1430.61
AIR-PRHT
81.11
DECOMP
1427.01
BURN
1487.97
SSH-1
109.51
RHT
41.60
SSH2
93.70
PSH1
54.37
PSH2
64.99
ECON
46.58
1425.00
61.67
1426.85
1005.98
83.26
30.10
72.38
45.67
52.93
33.90
5.61
19.44
0.16
481.99
26.25
11.50
21.32
8.70
12.06
12.68
0.39
1.36
0.01
33.69
1.83
0.80
1.49
0.60
0.85
0.89
99.61
76.03
99.99
67.61
76.03
72.36
77.25
84.00
81.44
72.78
Turbine Subsystem
VHP-TURB
171.57
VHP-TRB2
40.30
HP-TURB
29.91
IP-TURB
76.97
LP1-TURB
82.34
LP-TURB2
56.66
LP-TURB3
35.63
LP-TURB4
23.77
BFP-TRB
20.03
COND
26.99
164.66
38.09
28.53
72.11
81.30
55.95
35.22
20.74
15.76
0.35
6.91
2.21
1.38
4.86
1.04
0.71
0.41
3.03
4.27
26.64
0.48
0.15
0.10
0.34
0.07
0.05
0.03
0.21
0.30
1.86
95.97
94.52
95.39
93.69
98.74
98.75
98.85
87.25
78.68
1.30
Components
EF,n(MW)
EP,n (MW)
Feedwater Heating Subsystem
FWH-1
9.96
8.04
FWH-2
9.92
6.57
FWH-3
4.36
3.47
FWH-4
16.87
12.85
DEAERATOR
22.76
19.31
BS-PUMP
3.50
3.12
FWH-5
23.18
19.83
FWH-6
41.69
38.27
FWH-7
28.79
27.08
FWH-8
20.73
16.81
BFP
17.84
15.79
FGD Subsystem
BGS Filter
41.39
40.83
ID-FAN
37.91
34.43
Desulphurizer
42.62
36.95
MEA-Based CO2 Capture Subsystem
FG-Cooler
70.19
36.82
BLOWER
50.08
20.06
ABSRBR
96.2
41.52
DESRBR
235.64
153.57
PUMP
11.89
11.63
T-COOLER
36.82
30.89
MHEX
48.81
36.83
Loss (MEA)
ED,n (MW)
yD,n(%)
Ɛn(%)
1.92
3.35
0.89
4.02
3.45
0.38
3.35
3.42
1.71
3.92
2.05
0.13
0.23
0.06
0.28
0.24
0.03
0.23
0.24
0.12
0.27
0.14
80.72
66.23
79.59
76.17
84.84
89.14
85.55
91.80
94.06
81.09
88.51
0.56
3.48
5.67
0.04
0.24
0.40
98.65
90.82
86.70
33.37
30.02
54.68
82.07
0.26
5.93
11.98
5.15
2.33
2.10
3.82
5.74
0.02
0.41
0.84
0.36
52.46
40.06
44.55
65.17
97.81
83.89
75.46
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Results and Discussion
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Results – Conventional Exergy Analysis
SCPP Exergy Destruction and Losses (No CO2 capture)
1.34% 8.58%
Boiler Subsytem
3.93%
Turbine Subsystem
Feedwater Heating
Subsystem
FGD Subsystem
7.11%
Exergy Destruction in once-through boiler subsystem
4.06%
2.00%
0.88%
3.06%
4.69%
3.36%
1.81%
COALMILL
0.03%
AIR-PRHT
4.14%
DECOMP
BURN
SSH-1
RHT
Losses
SSH2
79.04%
PSH1
PSH2
75.97%
Exergy Destruction in Turbine subsystem
ECON
Feedwater Heating subsystem
FWH-1
13.43%
4.29%
VHP-TURB
VHP-TRB2
2.68%
13.80%
11.79%
IP-TURB
2.02%
LP1-TURB
FWH-2
FWH-3
HP-TURB
9.44%
1.38%
7.05% 6.76%
3.13%
6.02%
14.15%
12.04%
FWH-4
DEAERATOR
BS-PUMP
LP-TURB2
FWH-5
LP-TURB3
0.80%
51.77%
8.30%
5.89%
FWH-6
LP-TURB4
11.79%
12.14%
BFP-TRB
COND
1.34%
FWH-7
FWH-8
BF-PUMP
Distribution of Exergy losses and Destruction in the SCPP Subsystems
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Results and Discussion
17
Results – Conventional Exergy Analysis
Exergy Destruction in MEA-Based CO2 Capture
0.11% 2.59%
5.24%
2.25%
14.60%
13.13%
Exergy Destruction in SCPP with Base Case CO2 Capture
FG-Cooler
Boiler Subsytem
23.59%
BLOWER
1.02%
Turbine Subsystem
ABSRBR
Feedwater Heating Subsystem
DESRBR
3.00%
PUMP
FGD Subsystem
T-COOLER
MEA-Based CO2 Capture Subsystem
26.17%
66.95%
MHEX
35.90%
Loss
5.43%
Distribution of Exergy Destruction in (a) CO2 Capture subsystems and (b) SCPP with CO2 Capture
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Results and Discussion
18
Case Study: CO2 Capture
Absorber Intercooling Configuration (AIC)
Split-flow Configuration (SF)
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Results and Discussion
19
Case Study: CO2 Capture
Performance Indicator of the SCPP and the CO2 Capture Cases
Description
Reference
SCPP
Performance Summary
SCPP- Base Case
CO2 Capture
SCPP-AIC
SCPP-SF
SCPP –
(AIC+SF)
Total (steam turbine) power (MW)
580.26
482.28
484.52
486.42
488.58
Auxiliary load (MW)
28.28
52.04
51.95
48.45
42.8
Gross plant power (MW)
551.98
430.24
432.57
437.97
445.78
Generator loss (MW)
1.83
1.83
1.83
1.83
1.83
Net power output (Mwe)
550.15
428.41
430.74
436.14
443.95
Unit efficiency, HHV (%)
39.10
30.45
30.61
31.00
31.55
CO2 Capture Performance Summary
Reboiler Duty (MW)
-
528.78
511.81
492.02
466.57
Energy penalty (%)
-
22.13
21.70
20.72
19.30
Efficiency penalty (%)
-
8.65
8.49
8.10
7.55
Exergy Destruction, yD (%)
52.61
46.27
46.15
45.81
43.19
Exergy Losses, EL (%)
8.34
5.03
4.62
4.37
3.58
Exergetic efficiency, Ɛ (%)
39.05
48.7
49.23
49.82
53.23
Exergetic Performance
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Results and Discussion
20
Case Study: CO2 Capture
Case 1: Exergy Destruction in SCPP with Absorber
Intercooling
21.40%
1.05%
3.09%
5.59%
68.87%
Case 2: Exergy Destruction in SCPP with Splitflow
Case 3: Exergy Destruction in SCPP with Absorber
Intercooling and Split-flow
19.36%
21.06%
1.08%
3.17%
1.06%
3.10%
5.61%
5.73%
69.17%
Exergy Destruction in SCPP with three cases of MEA-Based CO2 Capture
70.66%
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Results and Discussion
21
Results – Advanced Exergy Analysis
Fuel Saving potential & Advanced Exergy Destruction of the SCPP
Components
ET,nF,tot
Boiler subsytem
FURN
1390.37
AIR-PRT
1371.03
SSH
1404.17
PSH
1407.10
RHT
1404.91
ECON
1407.50
Turbine subsystem
VHP-TURB
1386.47
VHP-TRB2
1400.94
HP-TURB
1401.10
IP-TURB
1399.30
LP1-TURB
1401.19
LP-TURB2
1402.74
LP-TURB3
1402.25
LP-TURB4
1382.22
BFP-TRB
1389.80
COND
1407.72
Feedwater heating subsystem
FWH-1
1407.11
FWH-2
1407.13
FWH-3
1406.73
FWH-4
1405.92
DEAERATOR
1406.98
BS-PUMP
1407.42
FWH-5
1406.14
FWH-6
1406.65
BF-PUMP
1402.38
FWH-7
1405.92
FWH-8
1405.07
FGD Subsystem
BGS Filter
1407.25
ID-FAN
1405.90
Desulphurizer
1403.98
ΔE*,nF,tot
ETD,n
ERD,n
EunD,n
EavD,n
EenD,n
EexD,n
EenD,n
Endo/Exo-genous Exergy destruction
EexD,n
Subsystems
Eun,enD,n
Eav,enD,n
Eav,exD,n
Eun,exD,n
17.35
36.68
3.55
0.62
2.81
0.22
361.50
6.81
149.67
2.89
4.28
6.20
361.50
18.00
203.17
13.80
24.25
13.42
330.95
9.24
169.59
7.59
14.28
10.74
30.55
8.76
33.58
6.21
9.97
2.68
304.45
16.15
181.59
12.24
21.58
11.64
57.05
1.85
21.58
1.56
2.67
1.78
291.66
8.25
150.54
6.79
12.58
9.30
12.79
7.90
31.05
5.45
9.00
2.34
17.76
0.86
2.53
0.76
0.97
0.34
39.29
0.99
19.05
0.80
1.70
1.44
21.25
6.78
6.62
8.42
6.53
4.98
5.47
25.50
17.92
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
31.68
7.11
2.27
1.42
4.81
1.01
0.68
0.53
3.64
2.10
31.68
6.18
1.58
0.79
3.24
0.65
0.39
0.37
1.82
1.38
0.00
0.93
0.69
0.63
1.57
0.36
0.29
0.16
1.82
0.72
31.68
6.46
1.59
1.16
3.18
0.92
0.61
0.48
3.32
1.18
25.54
0.65
0.68
0.26
1.63
0.09
0.07
0.05
0.32
0.92
6.14
5.61
0.99
0.54
1.73
0.57
0.33
0.36
1.65
0.61
-
0.85
0.60
0.62
1.45
0.35
0.28
0.12
1.67
0.57
-
0.08
0.09
0.01
0.12
0.01
0.01
0.04
0.15
0.15
-
0.57
0.59
0.29
1.51
0.08
0.06
0.01
0.17
0.77
-
0.61
0.59
0.99
1.80
0.74
0.30
1.58
1.07
5.34
1.80
2.65
1.94
3.26
0.86
4.00
3.12
0.00
2.86
2.18
0.00
1.64
4.03
2.03
3.41
0.93
4.03
2.98
2.31
2.90
2.45
2.17
2.19
4.65
1.74
2.93
0.76
3.58
2.64
1.39
2.58
2.14
1.16
1.89
3.28
0.29
0.48
0.17
0.45
0.34
0.92
0.32
0.31
1.01
0.30
1.37
1.79
2.48
0.64
2.94
1.86
1.40
2.26
1.62
1.58
1.66
2.85
0.24
0.93
0.29
1.09
1.12
0.91
0.64
0.83
0.59
0.53
1.80
1.55
2.40
0.60
2.93
1.80
0.93
2.14
1.59
0.85
1.59
1.87
0.24
0.08
0.04
0.01
0.06
0.47
0.12
0.03
0.73
0.07
0.98
0.05
0.40
0.13
0.44
0.28
0.45
0.20
0.28
0.28
0.23
0.39
0.19
0.53
0.16
0.65
0.84
0.46
0.44
0.55
0.31
0.30
1.41
0.47
1.82
3.74
0.38
0.00
2.86
0.62
4.21
5.81
0.41
2.86
4.63
0.21
1.35
1.18
0.56
3.67
4.43
0.06
0.54
1.38
0.48
2.87
2.96
0.08
0.80
1.47
0.13
0.55
-0.29
-0.07
-0.01
1.67
Exo(%)
Endo(%)
Boiler
20.0
80.0
Turbine
14.0
86.0
Feedwater
heaters
30.0
70.0
Avoidable/Unavoidable Exergy destruction
Subsystems
av (%)
un (%)
Boiler
15.0
85.0
Turbine
70.0
30.0
Feedwater heaters
20.0
80.0
Fuel Saving potential
Subsystems
Value (MW)
Boiler
61.23
Turbine
103.47
Feedwater heaters
17.47
FGD
6.03
ECCRIA 10
R-D-CSPP-PSE PIRSES-GA-2013-612230
Results and Discussion
22
Results – Advanced Exergy Analysis
(c)
(b)
(a)
Splitting the Exergy destruction of Boiler Subsystem into (a) AV/UN (b) EN and EX (c) AV,EN and UN,EN
(a)
(c)
(b)
Splitting the Exergy destruction of Turbine Subsystem into (a) AV/UN (b) EN and EX (c) AV,EN and UN,EN
ECCRIA 10
R-D-CSPP-PSE PIRSES-GA-2013-612230
Results and Discussion
23
Results – Advanced Exergy Analysis
(a)
(b)
(c)
Splitting the exergy destruction of Feedwater Subsystem into (a) AV/UN (b) EN and EX (c) AV,EN and UN,EN
ECCRIA 10
R-D-CSPP-PSE PIRSES-GA-2013-612230
Conclusions
24
Conventional Exergy Analysis
 Boiler Subsystem: The most exergy destruction occurs in the furnace combustion chamber (76%).
 Turbine Subsystem: The maximum exergy destruction occurs in the steam condenser (52%).
 Feedwater Heating: The HP feedwater heaters accounts for most of the exergy destruction (43.65%).
 CO2 Capture: The absorber (26%) and the desorber (36%) are the main sources of exergy destruction.
Advanced Exergy Analysis
 Fuel saving potential: The turbine subsystem are almost double that of the boiler subsystem. The feedwater heater
almost has no influence on fuel consumption
 Exo/Endo/-genous exergy destruction: Most exergy destruction of SCPP components is endogenous (over 70%).
 Un/Avoidable exergy destruction: 30–50% of exergy destruction in the turbine subsystem is generally avoidable.
ECCRIA 10
R-D-CSPP-PSE PIRSES-GA-2013-612230
Thanks
25
ECCRIA 10
R-D-CSPP-PSE PIRSES-GA-2013-612230
Acknowledgement
26
Biomass and Fossil Fuel Research Alliance (BF2RA)
EU FP7 Marie Curie
Multiphase Flow Measurement Research Group,
South East University, Nanjing, China
ECCRIA 10
R-D-CSPP-PSE PIRSES-GA-2013-612230
Questions
27
ECCRIA 10
R-D-CSPP-PSE PIRSES-GA-2013-612230