1. Introduction - Firenze University Press

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[5.] Giunta P, Amadeo N, Laborde M. Simulation of a low temperature water gas shift reactor using the heterogeneous model/application to a pem fuel cell. Journal of power sources. 2006;156(2):489-96. [6.] Dincer I. Green methods for hydrogen production. International Journal of Hydrogen Energy. 2012;37(2):1954-71. [7.] BP. BP Statistical Review of World Energy June 2011. 2011 Available at: http://www.bp.com/statisticalreview. [accessed 10.02.2012]. [8.] Staczyk K, Kapusta K, Wiatowski M, widrowski J, Smoliski A, Rogut J, et al. Experimental simulation of hard coal underground gasification for hydrogen production. Fuel. 2012;91(1):40-50. [9.] Jones RH, Thomas GJ. Materials for the Hydrogen Economy: CRC; 2007. [10.] Energy USDo. Pioneering Gasification Plants. 2011 Available at: http://www.fossil.energy.gov/programs/powersystems/gasification/gasificationpioneer.html. [accessed 10.02.2012]. [11.] Colombia MdMyEad. El carbón Colombiano; Recursos, Reservas y Calidad 2004. [12.] Kopyscinski J, Schildhauer TJ, Biollaz SMA. Methanation in a fluidized bed reactor with high initial CO partial pressure: Part II— Modeling and sensitivity study. Chemical Engineering Science. 2011;66(8):1612-21. [13.] Minchener AJ. Coal gasification for advanced power generation. Fuel. 2005;84(17):2222-35. [14.] Emun F, Gadalla M, Majozi T, Boer D. Integrated gasification combined cycle (IGCC) process simulation and optimization. Computers & Chemical Engineering. 2010;34(3):331-8. [15.] Nikoo MB, Mahinpey N. Simulation of biomass gasification in fluidized bed reactor using ASPEN PLUS. Biomass and Bioenergy. 2008;32(12):1245-54. [16.] Ramzan N, Ashraf A, Naveed S, Malik A. Simulation of hybrid biomass gasification using Aspen plus: A comparative performance analysis for food, municipal solid and poultry waste. Biomass and Bioenergy. 2011;35(9):3962-9. [17.] Shen L, Gao Y, Xiao J. Simulation of hydrogen production from biomass gasification in interconnected fluidized beds. Biomass and Bioenergy. 2008;32(2):120-7. [18.] Liu B, Yang X, Song W, Lin W. Process Simulation Development of Coal Combustion in a Circulating Fluidized Bed Combustor Based on Aspen Plus. Energy & Fuels. 2011;25(4):1721- 30. [19.] Robinson PJ, Luyben WL. Simple Dynamic Gasifier Model That Runs in Aspen Dynamics. Industrial & Engineering Chemistry Research. 2008;47(20):7784-92. [20.] Chiesa P, Consonni S, Kreutz T, Robert W. Co-production of hydrogen, electricity and CO2 from coal with commercially ready technology. Part A: Performance and emissions. International Journal of Hydrogen Energy. 2005;30(7):747-67. [21.] Davison TY. GE Gasification Project Update. Gasification 11 Conference: GE Energy; 2012. [22.] Smith AR, Klosek J. A review of air separation technologies and their integration with energy conversion processes. Fuel Processing Technology. 2001;70(2):115-34. [23.] Vinson DR. Air separation control technology. Computers & Chemical Engineering. 2006;30(10–12):1436-46. [24.] AG L. Cryogenic Air Separation, History and Technological progress. Pullach: 2009 Available at: http://www.lindele.de/process_plants/air_separation_plants/documents/L_2_1_e_09_150dpi.pdf. [accessed 10.02.2012]. [25.] Chen P-C, Chiu H-M, Chyou Y-P, Yu C-S. Processes Simulation Study of Coal to Methanol Based on Gasification Technology. Engineering and Technology. 2010;65:988-96. 353
[26.] Castle WF. Air separation and liquefaction: recent developments and prospects for the beginning of the new millennium. International Journal of Refrigeration. 2002;25(1):158-72. [27.] Damartzis T, Zabaniotou A. Thermochemical conversion of biomass to second generation biofuels through integrated process design—A review. Renewable and Sustainable Energy Reviews. 2011;15(1):366-78. [28.] Topsøe H. Sulphur resistant/sour water-gas shift catalyst. Lyngby 2009. [29.] Bell D, Towler B. Coal Gasification and Its Applications: ELSEVIER; 2010. [30.] Korens N, Simbeck D, Wilhelm D. Process screening analysis of alternative gas treating and sulfur removal for gasification. Prepared for DOE/NETL. 2002. [31.] Heil S, Brunhuber C, Link K, Kittel J, Meyer B. Dynamic Modelling of CO2-removal units for an IGCC power plant. Proceedings 7th Modelica Conference; Sep. 20-22; Como, Italy: The Modelica Association; 2009. p. 77-85. [32.] Larson ED, Consonni S, Katofsky RE, Consulting N, Burlington I, Iisa K, et al. A Cost- Benefit Assessment of Gasification-Based Biorefining in the Kraft Pulp and Paper Industry Volume 1 Main Report. Princeton University, Princeton, NJ. 2006. [33.] Yuehong Z, Hao W, Zhihong X. Conceptual design and simulation study of a co-gasification technology. Energy Conversion and Management. 2006;47(11–12):1416-28. [34.] Chen C, Jin Y-Q, Yan J-H, Chi Y. Simulation of municipal solid waste gasification in two different types of fixed bed reactors. Fuel. [Available online 24 August 2011]. 2011. [35.] Wang Y, Dong W, Dong L, Yue J, Gao S, Suda T, et al. Production of Middle Caloric Fuel Gas from Coal by Dual-Bed Gasification Technology. Energy & Fuels. 2010 2010/05/20;24(5):2985-90. [36.] Walton SM, He X, Zigler BT, Wooldridge MS. An experimental investigation of the ignition properties of hydrogen and carbon monoxide mixtures for syngas turbine applications. Proceedings of the Combustion Institute. 2007;31:3147-54. [37.] Davison J, Bressan L, Domenichini R. CO2 capture in coal-based IGCC power plants. 7th International Conference in Greenhouse Gas Control Technologies; Vancouver2004. 354
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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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N 1 i ( x x i n 1 m ) 2.3. Carbon
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DTA analysis of the untreated APCrs
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Table 4. Relative Error (%) of the
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CaO HCl CaCl H O 193kJ / mol (
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[1] M. Fernández Bertos, S.J.R. Si
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2. Process development 2.1. Backgro
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to dissolve the chloride salts prec
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The remaining 25% (5 ml/min) of the
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Table 6. Experimental conversions o
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p p 1 1. 5 p H 1 1. 5 2O p mi
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Calculating from the Aspen Plus mod
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[11] Mattila, H.-P., Experimental s
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Mg2SiO4(s) + 2CO2(g) →2MgCO3(s) +
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(Mg/Fe) of the mineral rock, Mg-sil
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Figure 2. Effect of Mg/Fe ratio of
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Figure 4 shows that an increase in
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Figure 5. Process flow diagram of M
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2. Only cold utility is needed belo
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extraction process at 400 °C (~ 62
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Table A2. Extraction equations and
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[13] Teir S, Kuusik R, Fogelholm CJ
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In the area of coal technologies al
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Tabel 1. Characteristics quantities
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N m eT 4a ~ T cp T4a 1 ( K
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Auxiliary power rate of ASU, % 40 4
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[8] Buhre B.J.P., Elliott L.K., She
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1.1 - Cement Manufacturing The ceme
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2. Numerical model The purpose of t
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-0.309x15.77x2 2.085x3 240x4 12.53x
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Table 4 - Results of the optimizati
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1. Define the studied system (in th
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cycle) or a lignin extraction plant
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limiting factor for the maximum siz
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Table 5. Key data for the four ener
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Global CO 2 emissions [ktonnes/yr]
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for biofuels and the investment cos
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The possibility to capture CO2 from
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[17] Berglin N, Andersson L. Proces
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Therefore NL Agency (an agency of t
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2.2.2. Pinch analysis Pinch analysi
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3. Case study 3.1. Plant and proces
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Te 1000 mp era 900 tur 800 e [°C 7
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Application of the approach led to
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The advantage of dynamic models is
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e equal at both time intervals and
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Page 337 and 338: In the presented paper a framework
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Page 349 and 350: 3.2.2. Input data and assumptions A
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Page 353 and 354: [13] TERMIS Operation User Guide, 7
Page 355 and 356: Polygeneration is a term used to de
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Page 361 and 362: 6. Extensions to core methodology 6
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Page 367 and 368: Abstract: PROCEEDINGS OF ECOS 2012
Page 369 and 370: gasification [15], hybrid biomass g
Page 371 and 372: the second reactor. In this unit, s
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Page 377 and 378: Fig. 4. Effect of operating tempera
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1. Introduction - Firenze University Press

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