1. Introduction - Firenze University Press

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conversion to elemental sulphur. The H2S-free gas is supplied to the second stage of AGR where it is brought in contact with a low-temperature lean Selexol solvent for CO2 absorption. The reverse CO2 desorption process occurs in flash drums operating on 3 different pressure steps. Desorbed CO2 is compressed and pumped into the transportation pipeline. The hydrogen-rich (ca 90%) syngas leaving the AGR is diluted by ASU nitrogen and used as a gas turbine (GT) fuel. An F-class GT has been selected. As already mentioned, the steam turbine receives steam from both the HRSG and syngas cooling equipment. All compressors within the ASU and AGR islands have been assumed as electric motor – driven machines. Table 2 summarizes the assumptions/specifications concerning the input/output for the system. Waste heat recovery concept involves final flue gas cooler located in the HRSG, syngas cooler in syngas treating and conditioning line prior to AGR unit, as well as, intercoolers in compression trains of ASU air, nitrogen and CO2 product. All waste heat recovery exchangers are marked in red boxes in Fig.<strong>1.</strong> For further transportation, the CO2 stream is compressed to 13 MPa. Table 2. Assumed parameters for IGCC CHP Plant Parameter IGCC CHP plant <strong>Press</strong>ure in the reactor MPa 4,238 Temperature of syngas at scrubber outlet 119 O C 180 Nitrogen to fuel ratio (for fuel transportation), mass basis - 0,175 Steam to fuel ratio, mass basis - 0,005 Oxygen to fuel ratio, mass basis - 0,66 Specific electricity consumption kWh/Mgfuel 67 Syngas treating and conditioning line CO conversion ratio at 1 st WGSR % 63,6 CO conversion ratio at 2 nd WGSR % 86,2 H2O to CO ratio at 1 st WGSR - 2,34 H2O to CO ratio at 2 nd WGSR - 4 Syngas temperature prior to AGR Acid gas removal and CO2 compression O C 35 Effectiveness of H2S removal % 99 Effectiveness of CO2 removal % 90 Process steam consumption kg/s 1,81 CO2 capture miscellaneous auxiliary load kWh/MgCO2 60 Gas turbine Combustor exit temperature O C 1300 Compressor pressure ratio - 15,5 Steam cycle Live (HP) steam temperature O C 565 Live (HP) steam pressure MPa 12,8 MP steam pressure MPa 3,95
2.2 CFB plant For the current moment, one of the closest to commercial application method for CO2 capture in classic coal-fed CHP units is post-combustion absorption using MEA or similar solvent. The main energy requirement for this type of process is heat demand for desorption of CO2 from the amine solution. Proposed CHP plant with CO2 capture is equipped with CFB boiler, tap-backpressure steam turbine and CO2 capture unit – Fig. 2. CFB boiler produces live steam which has typical parameters for modern CFB boilers installed recently in Poland (560C, 16,1MPa). Boiler is equipped with economizer, convective and radiant superheater. Steam expands in tap-backpressure steam turbine. Steam cycle is equipped with four heat recovery exchangers The heat necessary for the CO2 removal unit is taken from the steam turbine exhaust as a back-pressure steam. The rest of steam flow available at the turbine outlet is supplied to the district water heater which operates in parallel with other heaters utilizing waste heat from the CO2 absorption and compression units - district water is preheated basically in CO2 dehumidifier and CO2 compression train (inter-coolers). Fig. 2. Concept of CFB CHP plant Hot flue gas leaving the economiser is primarily cooled down in rotating heat exchanger, where combustion air is preheated. Then in electrostatic precipitator fly ash is removed and finally prior to CO2 absorption process, flue gas is cooled down to 40C and desulphurized for final required SO2 concentration (10 ppmv). Absorption unit is composed of absorber and stripper columns. In absorber column flue gases are brought in contact with MEA solvent, rich solvent is then injected into a stripper column where occurs its regeneration and CO2 is separated. For further transportation, the CO2 stream is compressed to 13 MPa. For comparison purposes, the typical CFB-based CHP plant without CCS has also been studied. The district heat production within the non-CCS CFB CHP plant takes place in two heat exchangers connected to steam turbine outlet (base load) and extraction (peak-load). The structure and thermal 120
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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
Page 96 and 97: As can be seen in Fig. 5 the impact
Page 98 and 99: References [1] Eurobserv’er, The
Page 100 and 101: PROCEEDINGS OF ECOS 2012 - THE 25 T
Page 102 and 103: in which CO2 is separated from H2,
Page 104 and 105: dimensions of water droplets and wa
Page 106 and 107: Temperature (°C) 8 7 6 5 4 3 2 1 0
Page 108 and 109: 4. Conclusions In the present paper
Page 110 and 111: Abstract: PROCEEDINGS OF ECOS 2012
Page 112 and 113: penalty, but without separate captu
Page 114 and 115: 0.5 - 0.7 kg/kg, resulting typicall
Page 116 and 117: 3.3 - Utilising waste heat All exis
Page 118 and 119: 4.5 - Suomusjärvi olivine deposits
Page 120 and 121: material will change from a few % t
Page 122 and 123: Fig. 5 Schematic diagram of the PFB
Page 124 and 125: 8. Combined SO2 capture and CO2 min
Page 126 and 127: Fig. 10 Carbonate- (left) and sulph
Page 128 and 129: [13] Ekdahl, E., Idman, H. Statemen
Page 132 and 133: HEAT Fig. 1. Scheme and main reacti
Page 134: (raw) materials pre-heating and AS
Page 137 and 138: Fig 3- Aspen Plus® model 110
Page 139 and 140: Table 4. Elemental and XRD analysis
Page 141 and 142: the ÅA CSM route. The content of M
Page 145: moisture - 0,2237 ash - 0,0876 LHV
Page 149 and 150: The CO2 emission factor which indic
Page 151 and 152: The CO2 emission factor calculated
Page 153 and 154: Appendix A Fig A.1. Simulation mode
Page 155 and 156: (b) Fig. A.2. Simulation model of C
Page 157 and 158: Table A.1. Calculated parameters at
Page 159 and 160: References [1] Pfaff I., Oexmann J.
Page 161 and 162: with a CC installation could be avo
Page 163 and 164: 2.3. Basic CHP plant indices. The b
Page 165 and 166: 3. Off-design calculations The main
Page 167 and 168: Fig. 6. CHP plant efficiency Fig. 7
Page 169 and 170: amount of steam delivered to the he
Page 171 and 172: [5] Lukowicz H., Mroncz M.: Analysi
Page 173 and 174: water removal is feasible by coolin
Page 175 and 176: Figure 2. Sketch of the suggested P
Page 177 and 178: a b Figure 5. a) Exergy balance of
Page 179 and 180: The basis of comparison of each met
Page 181 and 182: Figure 7a. Impact of S/CATR on PCU
Page 183 and 184: However, more energy duty is requir
Page 187 and 188: 3.1. JACOBIAN-ASPEN Interface ASPEN
Page 189 and 190: Fig. 3. Triple Pressure Bottoming S
Page 191 and 192: As seen from Table 1, the mass flow
Page 193 and 194: 4. Conclusion Fig. 5. Partial Emiss
Page 195 and 196: [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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2.5. Selecting the number of TSs Se
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A) Time Slices for solar thermal en
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The first step of procedure is to p
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cTSs demand TS solar TSs 0 2 4 6 8
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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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