1. Introduction - Firenze University Press

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CO2 rich loading(molCO2/molMEA) 0.45 Energy consumption of reboiler (MJ/t CO2) 3404 Energy consumption of condenser (MJ/t CO2) -684 Mass purity of CO2 (%) 99.8 Mole purity of CO2 (%) 99.6 3.3. Capture Case 1: CO2 capture case without considering the constraint of existing power plant Case 1 is a typical 600MW coal-fired power generation unit combined with CO2 capture system. A simplified process flow diagram of Case1 is shown in Fig. 6. As it can be seen from this figure, flue gas of the generation unit directly enters the absorber of the capture process, and the thermal energy consumed by stripper reboiler is supplied by the steam extracted from the steam turbine subsystem. Fig. 6 illustrates the extraction scheme of the water/steam system. Thus, steam with pressure of 2.1 bar is directly extracted from the IP cylinder of the turbine, supplying thermal energy with temperature of 115oC for stripper reboiler. The pressure selected can ensure a reasonable temperature differential in the reboiler. However, this scheme neglects the constraint of existing power plant. Fig. 6. 600MW supercritical coal-fired power plant with CO2 capture The power generation in Case 1 is the same as that of base case. Besides, its input fuel, boiler capacity, main steam and reheated steam flow rate also equal to that of base case. Neglecting the constraint of existing power plant, large amounts of 2.1 bar steam is directly extracted from the turbine system to provide heat and energy for MEA regeneration in the stripper without consideration of the pressure change in the IP cylinder after the large-scale extraction. 25
Fig. 7. Steam extraction scheme of Case 1 Fig. 8. Steam extraction scheme of Case 2 3.4. Capture Case 2: CO2 capture case with consideration of the constraint of existing power plant Case 2 is generally similar to Case 1 in the process flow. (see Fig. 6 for details). However, Case 2 makes adequate consideration of the constraint of existing power plant. For example, as shown in Fig. 8, the steam extraction point of Case 2 is located at the crossover pipe between the intermediate pressure (IP) and low pressure (LP) cylinders of the steam turbine, which may be the only feasible point to achieve large amount steam extraction in an existing power plant. Here, the steam pressure of the crossover pipe between the IP and LP cylinders can reach 9.32bar, much higher than the required steam pressure for absorbent regeneration (about 2.1bar), which will bring extra power loss due to steam extraction. Furthermore, the extra pressure loss due to the large amount steam extraction and the additional power loss resulted from the extraction are also be well considered in Case 2. Besides, the steam extraction for amine absorption process can account for approximately 50% of the total steam flow exhausted from HP turbine cylinder. It may lead to unstable operation conditions and bring about some safety problems. For example, the pressure at the exhaust of the existing IP turbine would be dropped to a low level, which results in increased mechanical loading of the IP blades, especially the last stages of IP cylinder. Besides, because the flow area of the LP turbine cylinder is not variable, such a large decrease in the steam flow may lead to an unstable operation condition in the LP turbine. 3.5. Performance analysis The performance analysis of three cases is listed in Table 3, the three cases include: Base Case: A typical 600MW supercritical power generation unit, as discussed in Section 3.1; Case 1: CO2 capture case without considering the constraint of existing power plant, as discussed in Section 3.3; Case 2: CO2 capture case with consideration of the constraint of existing power plant, as discussed in Section 3.4; Table 3. Performance analysis of Base Case and Case 1-2 26 Base Case Case1 Case2 Coal input rate (kg/s) 46.66 46.66 46.66 CO2 capture amount (kg/hr) - 447423 447423 CO2 capture rate (%) - 90 90 Reboiler heat duty (MW) - 420.83 420.83 Extracted steam flow (kg steam/kg CO2) - 1.489 1.439 CO2 compression work (kWhe/tonne CO2) - 39.91 39.91 Power output of steam turbine (MW) 604 517.09 461.57 Auxiliary work (MW) 30.22 85.66 85.44 Net power output 573.8 431.43 376.13
Page 1: Proceedings e report 90
Page 4 and 5: ECOS 2012 : the 25 th International
Page 7 and 8: Advisory Committee (Track Organizer
Page 10 and 11: The 25 th ECOS Conference 1987-2012
Page 12 and 13: VOLUME VI CONTENT VI. 1 CARBON CAPT
Page 14 and 15: -----------------------------------
Page 16 and 17: » Personal transportation energy c
Page 18 and 19: » Excess enthalpies of second gene
Page 20 and 21: VOLUME IV IV . 1 - FLUID DYNAMICS A
Page 22 and 23: » Exergy analysis and genetic algo
Page 24 and 25: » Optimal lighting control strateg
Page 26 and 27: » Stability and limit cycles in an
Page 28 and 29: PROCEEDINGS OF ECOS 2012 - THE 25 T
Page 30 and 31: Fig. 2. The exergy destruction of M
Page 32 and 33: ineffectiveness of the catalyst, in
Page 34 and 35: [ P EXmth EX SNG] ESR F where EXm
Page 36 and 37: Fuel inputkW 728221 203771 237719 3
Page 38 and 39: Not only at desined Rc (the ratio o
Page 40 and 41: 4. DISCUSSION The graphic exergy an
Page 42 and 43: Figure 9(a) illustrates the energy
Page 44 and 45: Engineering Technical Conferences &
Page 46 and 47: generally there are four kinds of m
Page 48 and 49: However, even under the off-design
Page 50 and 51: Fig. 3. 600MW supercritical coal-fi
Page 54 and 55: Net efficiency (%) 40.28 30.29 26.4
Page 56 and 57: Fig. 11. Schematic diagram of heat
Page 58 and 59: 28.67%. In addition, through heat i
Page 60 and 61: Applied Thermal Engineering 2010;30
Page 62 and 63: Abstract: PROCEEDINGS OF ECOS 2012
Page 64 and 65: Fig. 1. Solution diagram of „four
Page 66 and 67: K ~ K 1 eK 1a p K 1a iK mK
Page 68 and 69: Oxygen recovery rate, % 105 95 85 7
Page 70 and 71: Calculated optimal compressor press
Page 74 and 75: The net amount of the flue gas leav
Page 76 and 77: Figure 3. Idea for lignite drying b
Page 78 and 79: Energy efficiency, % 34,00 33,00 32
Page 80 and 81: points efficiency increase related
Page 82 and 83: Figure A1b. Thermoflex flow sheet o
Page 84 and 85: Figure A3a. Thermoflex flow sheet o
Page 86 and 87: Figure A4. Thermoflex flow sheet of
Page 88 and 89: Abstract: PROCEEDINGS OF ECOS 2012
Page 90 and 91: 2.1. Life Cycle Assessment 2.1.1. G
Page 92 and 93: these factors. A sensitivity analys
Page 94 and 95: 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
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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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Abstract: PROCEEDINGS OF ECOS 2012
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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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PROCEEDINGS OF ECOS 2012 - THE 25 T
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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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PROCEEDINGS OF ECOS 2012 - THE 25 T
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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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