98 sudipta

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98 sudipta

  1. 1. Biomass Based Net CO2-negative Cogeneration – Performance Study Using ASPEN Plus® Kuntal Jana and Sudipta De* Department of Mechanical Engineering Jadavpur University Kolkata- 700032 India
  2. 2. Some future options with fossil fuels……… • IGCC with carbon capture (pre-combustion or post-combustion) Oxy-fuel combustion and CO2 capture and storage Membranes specific for certain gases – O2, CO2, H2 etc. and integration with existing technology
  3. 3. Global Primary Bioenergy Supply Global Bioenergy Electricity Generation 2000-10
  4. 4. Possible options ………..….. • Biomass based power (CO2 – neutral). • Improving energy efficiency and environment performance (Cogeneration, Gasification) • Reducing CO2 emission even more (net CO2 – negative) • Combining all these – possible future sustainable options with efficient and net CO2- negative power generation units. • Challenges – technology maturity, scaling up….
  5. 5. Objective of the Present Work Objective • Model development of biomass integrated gasification combined cogeneration (BIGCC) with CO2 capture • Simulation of the model by using ASPEN Plus® • Defining a non-dimensional thermodynamic performance parameter- capture performance • Finding the optimum degree of CO2 capture, based on thermodynamic performance, i.e., capture performance
  6. 6. Schematic of biomass integrated gasification combined cogeneration with post-combustion CO2 capture GT-Cycle Gasification Water HEATER SYNGAS COMPRESSOR SYNGAS CLEANER GASIFIER DRIER Biomass CO2 CAPTURE Syngas Air ECONOMIZEREVAPORATOR GAS COOLER Ash CO2 SUPERHEATERREHEATER GAS TURBINE COMBUSTOR STEAM TURBINE PUMP Air AIR COMPRESSOR CONDENSER ST-Cycle Steam Vent gas
  7. 7. Schematic of amine based CO2 capture process Make-up amine AMINE TREATMENT PLANT Vent-gas CO2 CO Product2 Product o Amine (40 C) ABSORBER RICH-LEAN AMINE HEAT EXCHANGER o Flue gas (40 C) CONDENSER PUMP Rich-amine solution FLUE GAS COOLER STRIPPER SOX REMOVAL UNIT Lean-amine solution Flue gas Reboiler
  8. 8. B20 FLU-EXHS TO-ATMP FLU-EXIT ECO-EVA GAS-SEP AMONI A WATER H2S DRI ER GT-SYN W RYI ELD HP-WRK SYN-COMW HOT-BI O HP-ST SYN-COMP RSTOIC GAS-TURB COMB-GAS WET-BIO DRY-BI O BIOMASS ECO-IN W GT-WORK GIBS-OUT COMP-SYN DRY-FLSH SPH-OUT RH-IN SPH-IN Q PUMP FLUE-OUT GT-AIR Q-DECOMP COMP-WRK SEPARATE HOT-FLUE PUMP-W RK GT-COMB DECOMP SPRH SYN-GAS Q-COND FEED-WTR SOLI D RGIBBS COMP-AI R SYN-OUT GASI -AIR B18 LP-ST COND RH-OUT LP-WRK W S3 C-SEP PR-WTRI N S5 LP-OUT AIR-COMP C-ASH COLD-SYN PRO-HT PRW TROUT S48 ASPEN Plus® model of BIGCC CO2OUT STRIPIN STRIP PUMP TREATGAS AB COL-MEA LEANMEA POUT Q Q-MEA RICHMEA COL-FLU HX HOUT HEATER COOLER Q-REB FLUEGAS MEAOUT H2O-IN H2O-OUT Q ASPEN Plus® model of Post-combustion CO2 capture
  9. 9. Model development & Simulation • Simulation Software – ASPEN Plus ® (Developed by MIT, DOE – USA) • Biomass feed rate – 1000 kg/hr of sugarcane bagasse • Property methods: 1. Gasification and GT-power generation - Peng-Robinson equation of state with Boston Mathias alpha function (PRBM) 2. Carbon capture process - Electrolyte Non Random Two Liquid (ELECNRTL) 3. Steam turbine power generation and process-steam generation - Steam table (STEAM TA)
  10. 10. Operating Parameters Configurations Reaction in gasification Air compression, Syngas compression Combustion air Parameters Pressure Equivalence ratio Pressure ratio Isentropic efficiency Mass flow rate Value 1atm 25% of stoichiometric air 14 0.9 25% excess of stoichiometric air Gas cleaning Separation efficiency of solids particles 85% Gas turbine combustor Pressure Heat duty Discharge pressure Isentropic efficiency HP stage temperature HP stage pressure LP stage temperature LP stage pressure Temperature Pressure Isentropic efficiency LP-ST discharge pressure Temperature Pressure Amine concentration CO2/amine (mole basis) 14atm 0 1atm 0.9 5380C 12.4MPa 5000C 3.2MPa 250C 1atm 0.92 0.07MPa 400C 1.7 bar 30% by mass 32% Calculation type No. of stages Condenser type Condenser pressure Reboiler type Distillate rate Reflux ratio Equilibrium 20 Partial vapor 10 psia Kettle 1000 Kg/hr 0.10 Gas turbine Superheater-Reheater Feed water for ST cycle HP and LP Steam turbine Lean amine solution Lean loading Stripper column
  11. 11. Results 2.5 2 1.5 1 0.5 0 NET GT-POWER (MW) LPST-POWER (MW) HPST-POWER (MW) TOTAL POWER (MW) Power output of BIGCC with postcombustion CO2 capture Variation of net-reboiler heat duty with carbon capture efficiency 0.4 0.2 0 -0.2 -0.4 -0.6 -0.8 REBOILER HEAT DUTY (MW) UTILITY HEAT (MW) NET REBOILER HEAT DUTY (MW) Heat consumption, Utility heat and net reboiler heat of BIGCC with postcombustion CO2 capture
  12. 12. Variation of capture performance with carbon capture efficiency
  13. 13. Conclusions • Reboiler heat duty increases sharply beyond 50% of CO2 capture • For plants with CO2 capture, utility heat may be utilized for CO2 capture process • For net CO2 negative plant, operational condition may be thermodynamically optimized with selection of suitable carbon capture efficiency (say, for this study 0-0.5).

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