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Frontiers in Energy

ISSN 2095-1701

ISSN 2095-1698(Online)

CN 11-6017/TK

邮发代号 80-972

2019 Impact Factor: 2.657

Frontiers in Energy  2020, Vol. 14 Issue (3): 590-606   https://doi.org/10.1007/s11708-020-0809-6
  研究论文 本期目录
煤与生物质间接耦合发电系统的热力学性能与经济性分析
叶步青, 张睿(), 曹晋, 史兵权, 周勋, 刘冬()
南京理工大学能源与动力工程学院电子设备热控制工信部重点实验室;南京理工大学能源与动力工程学院先进燃烧实验室
Thermodynamic and economic analyses of a coal and biomass indirect coupling power generation system
Buqing YE, Rui ZHANG(), Jin CAO, Bingquan SHI, Xun ZHOU, Dong LIU()
MIIT Key Laboratory of Thermal Control of Electronic Equipment, and Advanced Combustion Laboratory, School of Energy and Power Engineering, Nanjing University of Science and Technology, Nanjing 210094, China
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摘要:

煤与生物质耦合发电技术被认为是一种很有前景的节能减排技术。基于生物质气化技术、煤与气化气共燃技术,本文提出了一种新型的煤与生物质间接耦合燃烧系统。为便于比较,还建立了一种传统的煤与生物质直接耦合燃烧系统。本文对直接耦合燃烧系统和间接耦合燃烧系统进行了流程模拟,并分析了两种系统的热力学性能和经济性。分析结果表明,间接耦合燃烧系统的热力学性能稍差,但经济性优于直接耦合燃烧系统。当生物质混合比例为20%时,间接耦合燃烧系统的热效率和㶲效率分别为42.70%和41.14%,系统的内部收益率(IRR)和动态投资回报期(DPP)分别为25.68%和8.56年。燃料和产品的价格波动对间接耦合燃烧系统的经济性有很大的影响。环境影响分析表明,间接耦合系统可以减少NOx的生成,降低环境成本。

Abstract

The coal and biomass coupling power generation technology is considered as a promising technology for energy conservation and emission reduction. In this paper, a novel coal and biomass indirect coupling system is proposed based on the technology of biomass gasification and co-combustion of coal and gasification gas. For the sake of comparison, a coal and biomass direct coupling system is also introduced based on the technology of co-combustion of coal and biomass. The process of the direct and the indirect coupling system is simulated. The thermodynamic and economic performances of two systems are analyzed and compared. The simulation indicates that the thermodynamic performance of the indirect coupling system is slightly worse, but the economic performance is better than that of the direct coupling system. When the blending ratio of biomass is 20%, the energy and exergy efficiencies of the indirect coupling system are 42.70% and 41.14%, the internal rate of return (IRR) and discounted payback period (DPP) of the system are 25.68% and 8.56 years. The price fluctuation of fuels and products has a great influence on the economic performance of the indirect coupling system. The environmental impact analysis indicates that the indirect coupling system can inhibit the propagation of NOx and reduce the environmental cost.

Key wordsbiomass    indirect coupling system    process simulation    thermodynamic analysis    economic analysis
收稿日期: 2019-08-02      出版日期: 2020-09-14
通讯作者: 张睿,刘冬     E-mail: zhangrui@njust.edu.cn (Rui ZHANG);dongliu@njust.edu.cn (Dong LIU)
Corresponding Author(s): Rui ZHANG,Dong LIU   
 引用本文:   
叶步青, 张睿, 曹晋, 史兵权, 周勋, 刘冬. 煤与生物质间接耦合发电系统的热力学性能与经济性分析[J]. Frontiers in Energy, 2020, 14(3): 590-606.
Buqing YE, Rui ZHANG, Jin CAO, Bingquan SHI, Xun ZHOU, Dong LIU. Thermodynamic and economic analyses of a coal and biomass indirect coupling power generation system. Front. Energy, 2020, 14(3): 590-606.
 链接本文:  
https://academic.hep.com.cn/fie/CN/10.1007/s11708-020-0809-6
https://academic.hep.com.cn/fie/CN/Y2020/V14/I3/590
Fig.1  
Fig.2  
Items Yulin bituminous coal Dangtu rice straw
Ultimate analysis
Car/% 67.77 44.43
Har/% 4.15 5.54
Nar/% 1.01 0.80
Sar/% 1.73 0.18
Oar/% 8.09 49.05
Proximate analysis
Mar/% 7.99 9.68
Aar/% 9.26 12.34
Var/% 32.68 62.22
FCar/% 50.07 15.76
Qnet,ar/(MJ·kg−1) 26.43 13.56
Tab.1  
Fig.3  
Fig.4  
Fig.5  
Fig.6  
Fig.7  
Fig.8  
Facilities Sr Scale unit Ir /($106) IF b Year
Coal preparation [42] 273 t/h 61.774 1.67 0.65 2008
Biomass preparation [42] 65 t/h 15.067 1.52 0.77 2008
Boiler [43] 600 MW 89.940 1.00 0.70 2011
CFB gasifier [44] 68.8 dry, t/h 42.848 1.69 0.70 2002
Steam turbines and condenser [45] 275 MW 66.700 1.16 0.67 2007
SCR [46] 2234 NO, kg/h 31.810 1.00 0.65 2015
FGD [47] 5731.69 SO2, kg/h 15.948 1.00 0.65 2004
Tab.2  
Impact category Pollutant PWR/($?t1)
Global warming CO2 12.70
NOx 4063.49
Acidification SO2 952.38
NOx 566.67
Photochemical ozone formation NOx 603.17
Solid waste Slag 19.05
Tab.3  
Items Unit Blending ratio of biomass
5% 10% 15% 20%
Input
Coal input t/h 190.00 180.00 170.00 160.00
Coal energy input MW 1394.92 1321.50 1248.08 1174.67
Biomass input t/h 19.49 38.98 58.47 77.96
Biomass energy input MW 73.42 146.83 220.25 293.67
Output
Steam turbines MW 652.70 649.84 647.46 645.56
Crushers MW - 4.07 - 4.07 - 4.08 - 4.08
Primary air fan MW - 1.26 - 1.21 - 1.16 - 1.12
Secondary air fan MW - 1.70 - 1.64 - 1.57 - 1.51
Induced draft fan MW - 1.21 - 1.17 - 1.12 - 1.08
Pumps MW - 10.80 - 10.75 - 10.71 - 10.68
ESP MW - 0.20 - 0.18 - 0.16 - 0.14
FGD MW - 0.05 - 0.05 - 0.05 - 0.04
Summary
Net power production MW 633.41 630.77 628.61 626.91
Energy efficiency % 43.14 42.96 42.81 42.70
Tab.4  
Items Unit Blending ratio of biomass
5% 10% 15% 20%
Input
Coal input t/h 190.00 180.00 170.00 160.00
Coal energy input MW 1394.92 1321.50 1248.08 1174.67
Biomass input t/h 19.49 38.98 58.47 77.96
Biomass energy input MW 73.42 146.83 220.25 293.67
Output
Steam turbines MW 665.57 663.18 661.28 659.85
Crushers MW -4.07 -4.07 -4.08 -4.08
Primary air fan MW -1.31 -1.32 -1.32 -1.33
Secondary air fan MW -1.77 -1.78 -1.79 -1.79
Induced draft fan MW -1.26 -1.27 -1.27 -1.28
Pumps MW -11.01 -10.97 -10.94 -10.92
ESP MW -0.22 -0.26 -0.27 -0.28
FGD MW -0.05 -0.05 -0.05 -0.04
Summary
Net power production MW 645.87 643.47 641.56 640.13
Energy efficiency % 43.99 43.82 43.69 43.60
Tab.5  
Fig.9  
Items Unit Blending ratio of biomass
5% 10% 15% 20%
Input
Coal input t/h 190.00 180.00 170.00 160.00
Coal exergy input MW 1427.86 1352.71 1277.56 1202.41
Biomass input t/h 19.49 38.98 58.47 77.96
Biomass exergy input MW 80.31 160.63 240.94 321.26
Exergy loss
CFB gasifier and boiler MW 430.24 435.56 445.97 451.75
Steam turbines MW 391.30 389.59 388.16 387.02
Flue gas treatment unit MW 53.22 57.41 55.76 57.98
Summary
Net power exergy MW 633.41 630.77 628.61 626.91
Exergy efficiency % 42.00 41.68 41.40 41.14
Tab.6  
Items Unit Blending ratio of biomass
5% 10% 15% 20%
Input
Coal input t/h 190.00 180.00 170.00 160.00
Coal exergy input MW 1427.86 1352.71 1277.56 1202.41
Biomass input t/h 19.49 38.98 58.47 77.96
Biomass exergy input MW 80.31 160.63 240.94 321.26
Exergy loss
Boiler MW 374.16 377.13 380.90 384.21
Steam turbines MW 399.02 397.59 396.45 395.59
Flue gas treatment unit MW 89.12 95.15 99.59 103.74
Summary
Net power exergy MW 645.87 643.47 641.56 640.13
Exergy efficiency % 42.82 42.52 42.25 42.01
Tab.7  
Fig.10  
Items Value
Prices
Yulin bituminous coal $77.414/t
Dangtu rice straw $36.912/t
Water $0.310/t
Limestone $25.377/t
Liquid ammonia $461.400/t
Electricity $0.056/kWh
Gypsum $9.228/t
Subsidy of the renewable energy power generation $0.035/kWh
Parameters
Plant lifetime [39] 30 a
Facility available days per year 300
O&M [39] 4%
Discount rate [39] 8%
Overall interest rate during construction [51] 9.8%
Construction period 3 a
Tab.8  
Items Unit Blending ratio of biomass
5% 10% 15% 20%
Fuel and material costs
Coal $106/a 125.90 120.33 114.75 109.18
Biomass $106/a 5.18 10.36 15.54 20.72
Water $106/a 3.06 3.04 3.03 3.02
Limestone $106/a 1.19 1.11 1.06 1.00
Liquid ammonia $106/a 6.21 5.42 4.57 3.56
Product sales
Electricity $106/a 255.39 254.33 253.45 252.77
Subsidy $106/a 7.98 15.90 23.76 31.60
Gypsum $106/a 0.74 0.70 0.66 0.63
Capital investment
Coal preparation $106 51.41 49.63 47.82 45.97
Biomass preparation $106 5.71 9.74 13.31 16.61
Boiler $106 92.42 92.38 92.34 92.31
CFB gasifier $106 26.68 43.34 57.57 70.41
Steam turbines $106 95.36 95.08 94.85 94.66
SCR $106 41.18 37.71 33.73 28.89
FGD $106 21.86 21.23 20.59 19.94
FCI $106 334.62 349.12 360.22 368.80
Interest during installation $106 32.79 34.21 35.30 36.14
EPC $106 26.77 27.93 28.82 29.50
Project contingency $106 54.21 56.56 58.36 59.75
TPC $106 415.60 433.61 447.39 458.05
Summary
Fuel and material cost $106/a 144.98 143.69 142.36 140.86
Annual output value $106/a 263.37 270.22 277.22 284.37
Annual profit $106/a 101.77 109.19 116.96 125.19
IRR % 21.10 22.26 23.81 25.68
DPP a 9.34 9.16 8.87 8.56
Tab.9  
Items Unit Blending ratio of biomass
5% 10% 15% 20%
Fuel and material costs
Coal $106/a 125.90 120.33 114.75 109.18
Biomass $106/a 5.18 10.36 15.54 20.72
Water $106/a 3.12 3.11 3.10 3.09
Limestone $106/a 1.19 1.11 1.06 1.00
Liquid ammonia $106/a 7.17 7.40 7.57 7.79
Product sales
Electricity $106/a 260.41 259.45 258.68 258.10
Gypsum $106/a 0.74 0.70 0.66 0.63
Capital investment
Coal preparation $106 51.41 49.63 47.82 45.97
Biomass preparation $106 5.71 9.74 13.31 16.61
Boiler $106 92.47 92.44 92.41 92.38
Steam turbines $106 96.62 96.39 96.20 96.06
SCR $106 45.23 46.11 46.97 47.81
FGD $106 21.86 21.23 20.59 19.94
FCI $106 313.30 315.55 317.31 318.78
Interest during installation $106 30.70 30.92 31.10 31.24
EPC $106 25.06 25.24 25.39 25.50
Project contingency $106 50.75 51.12 51.40 51.64
TPC $106 389.12 391.91 394.10 395.92
Summary
Fuel and material cost $106/a 146.22 146.15 146.05 146.01
Annual output value $106/a 260.41 259.45 258.68 258.10
Annual profit $106/a 98.63 97.62 96.87 96.26
IRR % 22.53 21.80 21.26 20.81
DPP a 9.11 9.25 9.31 9.41
Tab.10  
Fig.11  
Fig.12  
Impact category Pollutant Unit Blending ratio of biomass
5% 10% 15% 20%
Global warming CO2 $/h 5953.60 5607.22 5277.32 4947.42
NOx $/h 19.33 15.27 11.24 7.24
Acidification SO2 $/h 49.58 52.36 51.01 49.59
NOx $/h 2.70 2.13 1.57 1.01
Photochemical ozone formation NOx $/h 2.87 2.27 1.67 1.07
Solid waste Slag $/h 103.90 102.01 100.10 98.19
Environmental cost $/h 6131.98 5781.25 5442.91 5104.52
Tab.11  
Impact category Pollutant Unit Blending ratio of biomass
5% 10% 15% 20%
Global warming CO2 $/h 5953.62 5607.80 5277.85 4948.04
NOx $/h 24.78 26.14 27.49 28.83
Acidification SO2 $/h 49.54 50.21 50.91 58.74
NOx $/h 3.46 3.64 3.83 4.02
Photochemical ozone formation NOx $/h 3.68 3.88 4.08 4.28
Solid waste Slag $/h 111.65 117.21 122.91 128.56
Environmental cost $/h 6146.73 5808.87 5487.07 5172.47
Tab.12  
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