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Carbon Management in Power Generation Process

Carbon Management in Power Generation Process. An Research Overview for Research in Power Generation and Utility Fuels Group. Our Goal is to Prevent This:. Keep fossil fuel-based power g eneration as a viable option. Research Overview (1). Utility Fuels Biomass fast pyrolysis

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Carbon Management in Power Generation Process

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  1. Carbon Management in Power Generation Process An Research Overview for Research in Power Generation and Utility Fuels Group

  2. Our Goal is to Prevent This: Keep fossil fuel-based power generation as a viable option

  3. Research Overview (1) • Utility Fuels • Biomass fast pyrolysis • three-in-one process for bio-oil production • Engineering fuel from coal fine and biomass • Impoundment remediation

  4. The Integration Efforts on Utility Fuels

  5. Test Burn of Coal/Biomass Briquettes at the EKCC Reductions in SO2/NOx emissions relative to coal normally used

  6. Research Overview (II) • Power Generation • New generation technology development • combustion (PCLC) • steam generation • Emission control (SO2/SO3/Hg) • Post-combustion carbon management

  7. Do We Have to Pay for Separation • Targeted Process: • From a dilute state to over 90% purity • dStotal = dSsystem + dSsurrounding ≥ 0 • the entropy of an isolated system which is not in equilibrium will tend to increase over time, approaching a maximum value at equilibrium; • the entropy change dS of a system undergoing any infinitesimal reversible process is given by δq / T, where δq is the heat supplied to the system and T is the absolute temperature of the system.

  8. The Minimum Work for Separation Only • The first law • The Second law from 14% to 90% 175 kJ/kg CO2 (166 Btu/kg CO2) ~4% of coal HHV

  9. CO2 Capture Options in Power Generation

  10. Absorption Processes – Chemical • Two islands system • Absorber • Regenerator • Connected by pumps • Energy Involved • Temperature Swing • Heat removal • Energy input Clean gas (CO2<1%) CO2 Stream (>90%) Lean Sorbent Abs Reg Flue Gas (CO2 ~14%) Heat Rich Sorbent

  11. IGCC PC Flue Gas Post Combustion Scrubbing in Fossil Power Plants • Challenges: • Low CO2 partial pres. (~0.14 atm) • Large volume • ‘Poison’ contamination • Consequences: • Capital Costs $700-1000/kW • Absorbers three or four times • diameter as FGD with packing • Strippers and BOP • 25-35% of plant output reduction

  12. Research Activities at PGUF (1) >80% COE Increased i.e. >60 mills/kWh • >30 mills/kWh • >21.5 mills/kWh 8.5 mills/kWh CCS Direct $1000/kW CCS Indirect 1350 Btu/lb CO2capted. T.S.M. D.F.O. 5.5 mills/kWh 2.5 mills/kWh A 1 14 m/kWh Compression 6 m/kWh - CAPX- 6 m/kWh 7.5 m/kWh - OPEX- 1 m/kWh - OPEX- Absorber 7.5 m/kWh ∆Habs Solvent 1.5 m/kWh - CAPX- RR CL CO2 PP NC BOP Stripper

  13. Solvent Preferred • The magic solvent should have (1) High reaction rate; (2) High cyclic carbon capacity; (3) Less reaction energy; and (4) contamination-tolerated

  14. Scrubber Size for Various Solvent

  15. Technologies/Solvent Underdeveloped • $1000/kW CAPX • - $1M/1MWe • 85% Capacity Factor • 13.8% ROI • 20 yrs • 1350Btu/lb CO2 Cap. • - $4/MMBtu coal • - $35/MWh • - only additional boiler 80% Slower 60% Lesser on Heating, but Chilling 85% Slower 30% Lesser on OPEX 2 Orders Slower 50% Lesser on OPEX Dev/Demo 50% on CAPX, 40% lesser on OPEX 40% Faster. 20% Lesser on OPEX

  16. The Impact of CAER’s Solvent Research 2 Orders Slower 50% Lesser on OPEX $1000/kW CAPX, 85% CF, 13.8 ROI 20 yrs, 1350Btu/lb CO2 Captured Dev/Demo 50% on CAPX Heat Integra. 40% on OPEX 40% Faster. 20% Lesser on OPEX 10% Faster. 30% Lesser on OPEX 50% Faster 40% Lesser on OPEX

  17. Research Activities at PGUF (2) >80% COE Increased i.e. >60 mills/kWh • >30 mills/kWh • >21.5 mills/kWh 8.5 mills/kWh CCS Direct $1000/kW CCS Indirect 1350 Btu/lb CO2capted. T.S.M. D.F.O. 5.5 mills/kWh 2.5 mills/kWh A 1 14 m/kWh Compression 6 m/kWh - CAPX- 6 m/kWh 7.5 m/kWh - OPEX- 1 m/kWh - OPEX- Absorber 7.5 m/kWh ∆Habs Solvent 1.5 m/kWh - CAPX- RR CL CO2 PP NC A 2 BOP Stripper

  18. The Impact of CAER’s Catalytic Research 80% Slower 60% Lesser on Heating, but Chilling 85% Slower 30% Lesser on OPEX 60% Slower 30% Lesser on OPEX $500/kW CAPX, 85% CF, 13.8 ROI 20 yrs, 800Btu/lb CO2 Captured

  19. Research Activities at PGUF (3) >80% COE Increased i.e. >60 mills/kWh • >30 mills/kWh • >21.5 mills/kWh 8.5 mills/kWh CCS Direct $1000/kW CCS Indirect 1350 Btu/lb CO2capted. T.S.M. D.F.O. 5.5 mills/kWh 2.5 mills/kWh A 1 14 m/kWh Compression 6 m/kWh - CAPX- 6 m/kWh 7.5 m/kWh - OPEX- 1 m/kWh - OPEX- Absorber 7.5 m/kWh ∆Habs Solvent 1.5 m/kWh - CAPX- RR CL CO2 PP NC A 2 BOP A 3 Stripper

  20. The Impact of Post-Combustion Dewatering Research 85% Slower to MEA 30% Lesser on OPEX 5% Extra on CAPX 20% Lesser OPEX to Catalytic NH3 60% Slower to MEA 30% Lesser on OPEX

  21. Research Activities at PGUF (4) >80% COE Increased i.e. >60 mills/kWh • >30 mills/kWh • >21.5 mills/kWh 8.5 mills/kWh CCS Direct $1000/kW CCS Indirect 1350 Btu/lb CO2capted. T.S.M. D.F.O. 5.5 mills/kWh 2.5 mills/kWh A 1 14 m/kWh Compression 6 m/kWh - CAPX- 6 m/kWh 7.5 m/kWh - OPEX- 1 m/kWh - OPEX- Absorber 7.5 m/kWh ∆Habs Solvent 1.5 m/kWh - CAPX- RR CL CO2 PP NC A 2 BOP A 3 A 4 Stripper

  22. The Impact of CAER’s Stripping Research 85% Slower to MEA 30% Lesser on OPEX 5% Extra on CAPX 20% Lesser OPEX to Catalytic NH3 60% Slower to MEA 30% Lesser on OPEX Additional 30% Lesser OPEX

  23. Research Activities at PGUF A 5 >80% COE Increased i.e. >60 mills/kWh • >30 mills/kWh • >21.5 mills/kWh 8.5 mills/kWh CCS Direct $1000/kW CCS Indirect 1350 Btu/lb CO2capted. T.S.M. D.F.O. 5.5 mills/kWh 2.5 mills/kWh A 1 14 m/kWh Compression 6 m/kWh - CAPX- 6 m/kWh 7.5 m/kWh - OPEX- 1 m/kWh - OPEX- Absorber 7.5 m/kWh ∆Habs Solvent 1.5 m/kWh - CAPX- RR CL CO2 PP NC A 2 BOP A 3 A 4 Stripper

  24. Solid Impacts on Column?

  25. Corrosion Study Using Electrochemical and Traditional Cells A106 with O2 A106

  26. Activity Integration and Synergy Slipstream Demo Pilot-scale Proof of Concept Brainstorm

  27. CAER Carbon Management Research Completed commissioning using K2CO3 Solvent Only reaches 3%-10% capture 100-hour Preliminary Study using K2CO3/Piperizane (PZ) Could reach 90% capture Precipitation of PZ Two-month MEA with 32 runs using ceramic packing MEA degradation vs. stripping temperature Mass transfer under utility flue gas conditions 1.5-year study using Aqueous Ammonia Ammonia slip vs. rich-solution pH etc Mass transfer/energy vs. packing and operating parameters Troubleshooting and problem solving On-going new solution study Catalyzed solvent Formulated solvent

  28. Energy Consumption vs. CO2 Capture Efficiency

  29. Where We are • Carbon Management Research Group • Formed last year with four utilities (AEP, Duke, East Ky Power, Eon), EPRI and KY DEDI • ICCI and Big Rivers joined this year • A 10-year research program with $24M investment • Currently $2.4/year funding level • Develop more energy and cost effective carbon management technologies • Address specific materials, controls and waste management solutions

  30. Three Research Topics • Short-medium Term Projects • Post-Combustion CO2 Capture • 0.1MWth Pilot-scale study • 0.5~1MWth Slipstream field testing at members’ sites • Technical-Economic Analysis • Long-term Project • Chemical Looping Combustion/ Gasification for Solid Fuels

  31. One more ---Energy Conservation is SUPER Important Pre-Industry Early Industry 20 century Is it maximum soon?

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