1. Introduction - Firenze University Press

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The calculated parameters in characteristic points of the analyzed systems are presented in Tables A.1, A.2, A.3 in appendix A. 5. Results The crucial calculated parameters at system boundaries of each analysed CHP unit have been presented in Table 3. For the same district heat production, obtained net and gross electricity production is the highest for IGCC unit. The CO2 emission for both plants equipped with CO2 capture is relatively low. Lack of energy consumption for the CO2 capture installation in case of reference CFB plant results in the highest value of energy utilization factor achieved. EUF indicator for the IGCC CHP plant is lower than for other systems as it does not take into account different quality of products. When comparing exergy efficiency, the highest value is achieved for the reference CFB plant (without CO2 capture). The decrease of exergy efficiency caused by CO2 capture and compression is ca. 8 percentage points, but in case of IGCC CHP plant the exergy efficiency plant is only 3 points lower than for the reference system. Table 3. Results of simulation analysis Parameter Unit CFB CHP plant without CO2 capture (reference) 123 CFB CHP plant with CO2 capture IGCC CHP plant with CO2 capture Total district heat production MWth 110,22 110,26 110,14 including: - waste heat MWth 0 53,24 29,22 - steam-fed heat exchangers MWth 110,22 57,02 80,92 Fuel flow rate kg/s 9,34 10,40 13,02 Fuel chemical energy (LHV-based) MW 188,29 209,66 262,48 Gross electricity production MWe 64,70 64,10 113,30 Net electricity production MWe 60,10 50,80 78,40 Electric power consumption for CO2 compressors MW - 6,10 7,00 CO2 emission from CHP plant (total) kg/s 18,46 2,06 2,52 CO2 mass flow rate for transportation (captured) kg/s - 18,49 22,20 EUF (Eq. 1) % 0,90 0,77 0,72 Fuel exergy input MW 205,24 228,53 286,11 District water exergy increase (Eq. 3) MW 10,36 10,36 10,36 Exergy efficiency (Eq. 2) - 0,35 0,27 0,32 CO2 emission factor per GJ of produced district heat (Eq. 4) kgCO2/GJt 48,86 -81,59 -131,95
The CO2 emission factor calculated in accordance with (4) is below zero for both cases with CO2 capture due to effect of coupling CO2 capture and cogeneration effectiveness. Better values has been obtained for IGCC CHP plant. Values of emission factor have been achieved for assumed net electric efficiency of equivalent power station equal to 44%. For better recognition of the impact of equivalent plant efficiency on CO2 emission, sensitivity analysis has been prepared as presented in Fig. 4. Emission factor (kgCO2/GJ) 100,0 50,0 0,0 -50,0 -100,0 -150,0 -200,0 0,34 0,35 0,36 0,37 0,38 0,39 0,40 0,41 0,42 0,43 0,44 0,45 0,46 el_equiv IGCC CHP CHP with CO2 capture CHP without CO2 capture Fig. 4. Sensitivity analysis of equivalent power station efficiency on CHP emission factor. 6. Concluding remarks Two configurations of coal-fed CHP plants with massive CO2 removal and waste heat recovery systems have been proposed and analysed assuming constant district heat demand. Obtained results of exergy analysis indicate, that the drop of efficiency due to CO2 removal and compression (ca. 8 % points for CFB CHP) is lower than for large-scale coal-fired power units (ca. 10-12 % points for similar CCS heat demand as reported in [10,11]), as the waste heat recovery lets for partial cancellation of negative impact of CCS on overall plant efficiency. An IGCC CHP unit with CO2 capture has significantly better emission factors and thermodynamic excellence when comparing to CHP plant with CFB boiler and post-combustion CO2 capture process. Advantages of IGCC CHP unit are mainly due to commonly known effect of Brayton and Rankine cycles integration, as well as, due to advantage of pre-combustion CO2 removal over postcombustion system (referring to assumed in this paper energy demands for both installations). Negative value of CO2 emission factor which arises from applied CO2 removal processes and substituting of electricity produced in other power stations (system advantage of cogeneration), enables potentially for substituting emission from power facilities, where decreasing emission is economically ineffective or impossible (e.g. peak-load boilers). Future work should be focused on off-design analysis of both proposed CHP systems to evaluate change of supply of waste heat as function of variable ambient temperature and district heat demand. The comparative economic analysis reflecting the costs of district heat production, as well as, costs of avoiding the CO2 emission should also be done. 124
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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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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
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Page 147 and 148: 2.2 CFB plant For the current momen
Page 149: The CO2 emission factor which indic
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
Page 197 and 198: investigation and the developing of
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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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