1. Introduction - Firenze University Press

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Summary In this paper the air separation unit integrated with the oxy type pulverized boiler was analyzed. The oxy type boiler supplies the live steam and the reheated stem to the steam cycle. The gross power of the steam turbine generator of the steam cycle is equal to 460 MW. For the analysis the characteristics of the boiler thermal efficiency, auxiliary power rate of the steam cycle, carbon dioxide capture unit and air separation unit as a function of oxygen recovery rate in the "four-end" type separation membrane were determined. It should be noticed that the value of the boiler thermal efficiency shown in Figure 4 is increasing from about 55% (for 40% of the oxygen recovery rate) to about 83% (for 100% of the oxygen recovery rate). This characteristic is nonlinear and the acceleration of growth of the boiler thermal efficiency decreases with increasing oxygen recovery rate. The auxiliary power rate of the carbon dioxide capture unit and the auxiliary power rate of the oxytype pulverized boiler shown in Figure 5 decreases with increasing the oxygen recovery rate. This characteristics are nonlinear. The auxiliary power rate of steam cycle is the same for all oxygen recovery rates, because the power of steam turbine is held at a constant level. The auxiliary power rate of the air separation unit shown in Figure 6 unlike the other auxiliary power rates has a negative value in the studied range of oxygen recovery rate. This means that the expander generates more power than the power needed to drive the compressor. The auxiliary power rate of the air separation unit increases with the increase of the oxygen recovery rate. It should be noticed that the value of the net efficiency of electricity generation shown in Figure 7 is increasing from about 35% (for 40% of the oxygen recovery rate) to about 38% (for 100% of the oxygen recovery rate). This characteristic is nonlinear and the acceleration of growth of net efficiency of electricity generation decreases with increasing the oxygen recovery rate. This graph indicates that the studied integrated models have the highest net overall efficiency for the oxygen recovery value equal to 100%. Acknowledgements The results presented in this paper were obtained from research work co-financed by the National Centre for Research and Development within a framework of Contract SP/E/2/66420/10 – Strategic Research Programme – Advanced Technologies for Energy Generation: Development of a technology for oxy-combustion pulverized-fuel and fluid boilers integrated with CO2 capture. LITERATURE [1] Chmielniak T., The role of various technologies in achieving emissions objectives in the perspective of the years up to 2050. Rynek Energii, 2011;92:3-9 [2] Chmielniak T., ukowicz H., Kochaniewicz A., Trends of modern power units efficiency growth. Rynek Energii, Nr 6(79), 2008, 14-20. [3] Badyda K., Kupecki J., Milewski J., Modelling of integrated gasification hybrid power systems. Rynek Energii, 2010;88:74-79. [4] Kotowicz J., Janusz-Szymaska K., Influence of CO2 separation on the efficiency of the supercritical coal fired power plant. Rynek Energii, 2011, 2 (93), 8-12. [5] Liszka M., Zibik A.: Coal – fired oxy – fuel power unit – Process and system analysis. Energy, 35 (2010), 943 – 95<strong>1.</strong> [6] Toftegaard M.B., Brix J., Jensen P.A., Glarborg P., Jensen A.D., Oxy-fuel combustion of solid fuels. Progress in Energy and Combustion Science, 2010;36:581-625 [7] Dillon D.J., White.V., Allam R.J., Wall R.A., Gibbins J., Oxy-combustion Process for CO2 Capture from Power Plant. Mitsui Babcock Energy Limited,2005 259
[8] Buhre B.J.P., Elliott L.K., Sheng C.D., Gupta R.P. and Wall T.F., Oxy-fuel combustion technology for coal-fired power generation. Progress in Energy and Combustion Science, 2005;31:283-307 [9] Pfaff I., Kather A., Comparative thermodynamic analysis and integration issues of CCS steam power plants based on oxy-combustion with cryogenic or membrane based air separation. Energy Procedia 1 (2009) 495-502. [10] Stadler H. et al.: Oxyfuel coal combustion by efficient integration of oxygen transport membranes. International Journal of Greenhouse Gas Control 5 (2011) 7-15. 260
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Proceedings e report 90
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ECOS 2012 : the 25 th International
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Advisory Committee (Track Organizer
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The 25 th ECOS Conference 1987-2012
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VOLUME VI CONTENT VI. 1 CARBON CAPT
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-----------------------------------
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» Personal transportation energy c
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» Excess enthalpies of second gene
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VOLUME IV IV . 1 - FLUID DYNAMICS A
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» Exergy analysis and genetic algo
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» Optimal lighting control strateg
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» Stability and limit cycles in an
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PROCEEDINGS OF ECOS 2012 - THE 25 T
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Fig. 2. The exergy destruction of M
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ineffectiveness of the catalyst, in
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[ P EXmth EX SNG] ESR F where EXm
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Fuel inputkW 728221 203771 237719 3
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Not only at desined Rc (the ratio o
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4. DISCUSSION The graphic exergy an
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Figure 9(a) illustrates the energy
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Engineering Technical Conferences &
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generally there are four kinds of m
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However, even under the off-design
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Fig. 3. 600MW supercritical coal-fi
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CO2 rich loading(molCO2/molMEA) 0.4
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Net efficiency (%) 40.28 30.29 26.4
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Fig. 11. Schematic diagram of heat
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28.67%. In addition, through heat i
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Applied Thermal Engineering 2010;30
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Abstract: PROCEEDINGS OF ECOS 2012
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Fig. 1. Solution diagram of „four
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K ~ K 1 eK 1a p K 1a iK mK
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Oxygen recovery rate, % 105 95 85 7
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Calculated optimal compressor press
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The net amount of the flue gas leav
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Figure 3. Idea for lignite drying b
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Energy efficiency, % 34,00 33,00 32
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points efficiency increase related
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Figure A1b. Thermoflex flow sheet o
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Figure A3a. Thermoflex flow sheet o
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Figure A4. Thermoflex flow sheet of
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2.1. Life Cycle Assessment 2.1.1. G
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these factors. A sensitivity analys
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methane slip contributes to 13% of
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As can be seen in Fig. 5 the impact
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References [1] Eurobserv’er, The
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in which CO2 is separated from H2,
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dimensions of water droplets and wa
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Temperature (°C) 8 7 6 5 4 3 2 1 0
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4. Conclusions In the present paper
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penalty, but without separate captu
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0.5 - 0.7 kg/kg, resulting typicall
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3.3 - Utilising waste heat All exis
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4.5 - Suomusjärvi olivine deposits
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material will change from a few % t
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Fig. 5 Schematic diagram of the PFB
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8. Combined SO2 capture and CO2 min
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Fig. 10 Carbonate- (left) and sulph
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[13] Ekdahl, E., Idman, H. Statemen
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HEAT Fig. 1. Scheme and main reacti
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(raw) materials pre-heating and AS
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Fig 3- Aspen Plus® model 110
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Table 4. Elemental and XRD analysis
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the ÅA CSM route. The content of M
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moisture - 0,2237 ash - 0,0876 LHV
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2.2 CFB plant For the current momen
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The CO2 emission factor which indic
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The CO2 emission factor calculated
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Appendix A Fig A.1. Simulation mode
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(b) Fig. A.2. Simulation model of C
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Table A.1. Calculated parameters at
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References [1] Pfaff I., Oexmann J.
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with a CC installation could be avo
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2.3. Basic CHP plant indices. The b
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3. Off-design calculations The main
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Fig. 6. CHP plant efficiency Fig. 7
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amount of steam delivered to the he
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[5] Lukowicz H., Mroncz M.: Analysi
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water removal is feasible by coolin
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Figure 2. Sketch of the suggested P
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a b Figure 5. a) Exergy balance of
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The basis of comparison of each met
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Figure 7a. Impact of S/CATR on PCU
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However, more energy duty is requir
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3.1. JACOBIAN-ASPEN Interface ASPEN
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Fig. 3. Triple Pressure Bottoming S
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As seen from Table 1, the mass flow
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4. Conclusion Fig. 5. Partial Emiss
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[19] Yantovski E., Shokotov M., Sho
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investigation and the developing of
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University of L’Aquila and German
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hydrogen combustion technology at d
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eversibility of a pre-treated synth
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Fig. 1. TG curves collected for spe
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(see Fig 5). Carbon dioxide uptake
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period is reduced to the first 15 c
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CO2 capture capacity up to 150 th c
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the way for biogas utilisation is t
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projectand is described in the foll
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4. Pilot plant tests In order to de
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Concerning the absorption reaction,
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with Regeneration (AwR), consists i
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[25] Aspen Plus 2004.1. Cambridge,
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systems for fuel drying waste strea
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heated in a heat exchanger placed i
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Fig. 2. Lower heating value of fuel
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Acknowledgements The results presen
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large amount of CO2 [1,5-7]. APCr a
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Page 239 and 240: Table 4. Relative Error (%) of the
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Page 243 and 244: [1] M. Fernández Bertos, S.J.R. Si
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Page 251 and 252: The remaining 25% (5 ml/min) of the
Page 253 and 254: Table 6. Experimental conversions o
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Page 269 and 270: Figure 5. Process flow diagram of M
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Page 275 and 276: Table A2. Extraction equations and
Page 277 and 278: [13] Teir S, Kuusik R, Fogelholm CJ
Page 279 and 280: In the area of coal technologies al
Page 281 and 282: Tabel 1. Characteristics quantities
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Page 291 and 292: 2. Numerical model The purpose of t
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Page 295 and 296: Table 4 - Results of the optimizati
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Page 305 and 306: Table 5. Key data for the four ener
Page 307 and 308: Global CO 2 emissions [ktonnes/yr]
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Page 317 and 318: 2.2.2. Pinch analysis Pinch analysi
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In the presented paper a framework
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[5] Erdil E, Ilkan M, Egelioglu F.
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district energy network simulation
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were decreased by 10°C.All scenari
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Site 3 Heat sources Heat load Site
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3.2.2. Input data and assumptions A
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Fig.7 shows the operation forecast
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[13] TERMIS Operation User Guide, 7
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Polygeneration is a term used to de
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The increase in energy utilization
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are available for an entire year, 8
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6. Extensions to core methodology 6
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thermal storage and possible suppor
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laterites. Ore Geology Reviews, v.
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gasification [15], hybrid biomass g
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the second reactor. In this unit, s
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The variables effect was evaluated
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atio, as well as the shift-syngas f
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Fig. 4. Effect of operating tempera
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SDG has slight effect on the syngas
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[26.] Castle WF. Air separation and
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1. Introduction - Firenze University Press

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