1. Introduction - Firenze University Press

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The discharge pressure of "LASTST" is fixed to be equal to the saturation pressure for an atmospheric temperature which is assumed to be 25 °C. Unlike the topping cycle, implementing design specifications as constraints does not work well for the bottoming cycle. It is found that implementing design specifications and optimization constraints separately for the bottoming cycle makes the optimizer convergence easy. The optimization constraints include vapor quality of the outlet stream from the de-aerator be equal to zero and the inlet pressure of the valve "B27" be greater than its outlet pressure. Table 2. Results of Optimization of Bottoming cycle Variables Units Before Optimization After Optimization Outlet pressure of HPPMP bar 100 104.9 Outlet pressure of IPPMP bar 25 24.5 Outlet pressure of LPPMP bar 5 8.6 Discharge pressure of LPST bar 0.3 0.33 Outlet pressure of CONDPUMP bar 0.2 0.29 Split fraction of B29 (LPFW) 0.1663 0.2025 Split fraction of B29 (LPIPFW) 0.083 0.060 Split fraction of B14 (Stream 30) 0.3 0.2 Split fraction of B25 (Stream 33) 0.95 0.94 Outlet Temperature of air from ECON K 400.4 38<strong>1.</strong>15 Outlet Temperature of HPSTM from HPSP K 460 501 Outlet Temperature of IPSTM from HPSP K 460 485 Efficiency 23.47 % 25.65 % Optimization of the bottoming cycle increases its efficiency (bottoming cycle efficiency is defined as the ratio of power output from the bottoming cycle to the product of fuel flow rate and heating value) from 23.47 % to 25.65 % - an increase of 2.18 percentage points. The total efficiency of the power plant thus increases by 2.92 percentage points. This is a significant improvement in the efficiency, which plays an important role in determining the feasibility of AZEP cycles, see also the discussion in the next section. A summary of results from the optimization of the topping and bottoming cycles is shown in Table 3. Table 3. Summary of Optimization of Top and Bottoming cycle Efficiency Before Optimization After Optimization Increment in Percentage points Top cycle 25.33 % 26.07 % 0.74 Bottoming cycle 23.47 % 25.65 % 2.18 Entire power plant 48.8 % 5<strong>1.</strong>72 % 2.92 165
4. Conclusion Fig. 5. Partial Emission ITM cycle analysis Reference [10] gives a detailed analysis of partial emission cycles along with a new metric (see Fig. 5) which compares plants at the fleet level. Different variations of partial emission ITM cycles have been proposed to increase the efficiency. Improving the efficiency of a partial emission cycle by a small fraction is not very useful if the CO2 emissions simultaneously increase by a large amount. Fig. 5 shows the first law efficiency and specific CO2 emissions for different cycles which have been studied in the literature [6, 12-24]. Theoretically it is possible to get 100% CO2 separation for AZEP 100 cycle with large number of compression and cooling stages in the CO2 compression and purification unit, but this involves unreasonable capital costs. Therefore, practically, CO2 compression and purification units are not 100% efficient as seen in Fig. 5, which shows a small CO2 emission for the AZEP 100 cycle simulation result. A linear combination of the AZEP 100 and a combined cycle is also shown for comparison. In Fig. 5, AZEP 100 cycles from literature assume 100% CO2 separation and hence have zero CO2 emissions .The black dotted line represents the stipulated locus of partial emission cycles from AZEP 100 to AZEP 72 [10]. The green solid line represents the linear combination of a zero emission cycle and a combined cycle with an efficiency of 65 %. The green line shows the efficiency and the specific CO2 emission for different combinations of the AZEP 100 and the best efficiency reported for a combined cycle without carbon capture. For the partial emission cycle to be feasible, it should have better efficiency than the combination of an AZEP 100 and a combined cycle for the same specific CO2 emission [10]. This implies that for the partial emission cycles to be considered feasible, they must lie above the green line, which is not the case for virtually all partial emission cycles proposed. As can be seen from Fig. 5, after optimization the AZEP 100 cycle lies above the green line. This means after optimization the AZEP 100 cycle which nominally has complete capture (zero CO2 emission) is viable even after the imperfections of the CO2-H2O separation is accounted for this cycle, but not for the literature results. Note that fuel-cell based processes can achieve substantially higher performance, but require completely different technology. The improvements obtained for the nominally zero emissions cycle herein, suggest that optimization of partial emission cycles may increase their efficiency to a significant extent and make them viable. 166
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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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Page 143 and 144: Abstract: PROCEEDINGS OF ECOS 2012
Page 145 and 146: moisture - 0,2237 ash - 0,0876 LHV
Page 147 and 148: 2.2 CFB plant For the current momen
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 185 and 186: Abstract: PROCEEDINGS OF ECOS 2012
Page 187 and 188: 3.1. JACOBIAN-ASPEN Interface ASPEN
Page 189 and 190: Fig. 3. Triple Pressure Bottoming S
Page 191: As seen from Table 1, the mass flow
Page 195 and 196: [19] Yantovski E., Shokotov M., Sho
Page 197 and 198: investigation and the developing of
Page 199 and 200: University of L’Aquila and German
Page 201 and 202: hydrogen combustion technology at d
Page 203 and 204: eversibility of a pre-treated synth
Page 205 and 206: Fig. 1. TG curves collected for spe
Page 207 and 208: (see Fig 5). Carbon dioxide uptake
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Page 211 and 212: CO2 capture capacity up to 150 th c
Page 213 and 214: the way for biogas utilisation is t
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Page 217 and 218: 4. Pilot plant tests In order to de
Page 219 and 220: Concerning the absorption reaction,
Page 221 and 222: with Regeneration (AwR), consists i
Page 223 and 224: [25] Aspen Plus 2004.1. Cambridge,
Page 225 and 226: systems for fuel drying waste strea
Page 227 and 228: heated in a heat exchanger placed i
Page 229 and 230: Fig. 2. Lower heating value of fuel
Page 231 and 232: Acknowledgements The results presen
Page 233 and 234: large amount of CO2 [1,5-7]. APCr a
Page 235 and 236: N 1 i ( x x i n 1 m ) 2.3. Carbon
Page 237 and 238: DTA analysis of the untreated APCrs
Page 239 and 240: Table 4. Relative Error (%) of the
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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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