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CO 2 removal from an IGCC power plant

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CO 2 removal from an IGCC power plant. Comparison of the CO 2 capture options. Content. Scope of the study The existing separation processes Choice of separation process(es) Integration in the IGCC Conclusion. Scope of the study The existing separation processes

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slide1

CO2 removal from an IGCC power plant

Comparison of the CO2capture options

content
Content
  • Scope of the study
  • The existing separation processes
  • Choice of separation process(es)
  • Integration in the IGCC
  • Conclusion
slide3
Scope of the study
  • The existing separation processes
  • Choice of separation process(es)
  • Integration in the IGCC
  • Conclusion
igcc and co 2 abatement options
IGCC and CO2 abatement options
  • Pre combustion capture
  • Post combustion capture in an end of pipe process
  • Post combustion with CO2 working fluid and pure O2 combustion
slide5

Heat

Recovery

Dust

Filter

Desulfuration

Coal

Preparation

Gasification

O2

ASU

From Tac

compressor

Electricity

N2

TAV

Saturation

Heat

Recovery

Steam

Generator

Cycle

Steam

Air

TAC

Stack

TAC : Combustion turbine

TAV : Steam turbine

ASU : Air separation unit

slide6
Scope of the study
  • The existing separation processes
  • Choice of separation process(es)
  • Integration in the IGCC
  • Conclusion
co 2 capture options
CO2 capture options
  • Chemical absorption
  • Physical absorption
  • Adsorption
  • Membrane
chemical absorption
Chemical Absorption
  • Primary and secondary amines and Tertiary Amines :
  • Sterically hindered amines :

AMP, 2-Amino-2-Methyl-1-Propanol

  • Mixed amines
physical solvents
Physical solvents
  • Selexol Dimethylether of

Polyethylene Glycol

  • Purisol N Methyl Pyrrolidone
  • Rectisol Methanol
slide10
Scope of the study
  • The existing separation processes
  • Choice of separation process(es)
  • Integration in the IGCC
  • Conclusion
choice of solvents
Choice of solvents
  • Chemical solvent AMP 30% wt
  • Hot potassium K2CO3

Carbonate*

  • Mixed amines MDEA 25% MEA 5% wt
  • Physical solvents METHANOL

SELEXOL*

NMP

*with courtesy of UOP

synthesis gas composition
Synthesis gas composition

Synthesis gas pressure 24 bars abs.

Flow rate 50 kg/s

mains results
Mains results
  • Solvents losses
  • Electrical consumptions
  • Steam consumptions
further work
Further work
  • The calculation of the CO2 separation integration will be performed with an international quality coal with :
      • Methanol
      • Selexol
  • The optimal CO conversion and CO2 removal will be studied
  • The overall electrical efficiency will be calculated
slide20
Scopeof the study
  • The existing separation processes
  • Choice of separation process(es)
  • Integration in the IGCC
  • Conclusion
slide21

Heat

Recovery

Dust

Filter

Desulfuration

Coal

Preparation

Gasification

O2

ASU

From Tac

compressor

Electricity

N2

TAV

Saturation

Heat

Recovery

Steam

Generator

Cycle

Steam

Air

TAC

Stack

slide22

Heat

Recovery

Dust

Filter

Desulfuration

Coal

Preparation

Gasification

Electricity

TAV

Heat

Recovery

Cycle

Steam

Steam

Generator

O2

ASU

From Tac

compressor

steam

N2

Shift

Conversion

CO2

Separation

Saturation

steam

Air

TAC

Stack

igcc efficiency and co 2 removal
IGCC efficiency and CO2 removal

Physical absorption, methanol

Based case net efficiency : 43.34 %

conclusion
Conclusion
  • Pre-combustion separation
  • Physical solvents are less demanding in electrical and steam, even with higher frigory needs
  • The overall net efficiency decreases of 8 points for 81 mole percent CO2 separation
  • Further work : Selexol integration Sensibility analysis for reduced separation rate
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