1. CO2 CAPTURE TECHNOLOGIES
GUIDO MAGNESCHI, GLOBAL CCS INSTITUTE
WORKSHOP FOR CIVIL, CHEMICAL, ELECTRICAL, ENVIRONMENTAL AND MECHANICAL
ENGINEERS: INTRODUCTION TO CAPTURE, USE AND GEOLOGICAL STORAGE OF CO2
October 13-14, 2014
DF CFE Technology Museum
SUPPORTED BY:

2. OUTLINE
1. Overview of CO2 capture systems
2. Post-Combustion capture systems
3. Pre-Combustion capture systems
4. Oxy-Combustion capture systems
5. Industrial CCS (oil&gas, iron&steel, cement)
SUPPORTED BY:

3. DEFINITION OF CO2 CAPTURE
Separation of the CO2 from a gas stream produced in a
power station or an industrial process to obtain pure CO2 for
geological sequestration or further use
SUPPORTED BY:
Source: CO2CRC

4. OVERVIEW OF CCS SYSTEMS
SUPPORTED BY:
Source: CO2CRC

5. OVERVIEW OF CO2 CAPTURE SYSTEMS
Classified by application
SUPPORTED BY:
Capture routes
for power
generation

6. OVERVIEW OF CO2 CAPTURE SYSTEMS
SUPPORTED BY:
Source: DOE/NETL
Classified by capture technique

7. POST-COMBUSTION SYSTEMS
 Systems for the separation of CO2 from flue gases produced
by a combustion
 State of art: chemical absorption with amine-based
solvents
 Standard solvent is a solution of Mono Ethanol Amine (MEA)
30-40%-wt in water
 Several companies have produced
proprietary amine based solvent
with improved performance and
resistance but also alternative
solvents (e.g. amino-acid salts) for
CO2 capture purposes
SUPPORTED BY:

8. CHEMICAL ABSORPTION WITH AMINE-BASED
SOLVENTS
Electric Power
SUPPORTED BY:
Flue Gas
LP Steam
Cooling Water
CO2
Condensate
N2/O2
Source: Sintef
~130 °C
saturated
>95 % pure
90% captured
~40 °C
PC 12-14% CO2
NGCC 3-5% CO2

9. CHEMICAL ABSORPTION WITH AMINE-BASED
SOLVENTS
 Solvent regeneration energy: 2.5-3.5 GJth/t CO2 (depends on
solvent, process configurations and flue gas source)
 Overall efficiency penalty* (in power plants):
 PC plants 9-11%-points (20-25% less power output)
 NGCC plants 8-10 %-points (15-20% less power output)
 Utilities: Cooling Water / Electricity / Demi-water / LP Steam
 Solvent requires periodic regeneration and make-up because it
degrades during use (high temp., O2, NOx, SOx)
 Waste disposal and HSE aspect to consider
*including CO2 compression to 110 bar
SUPPORTED BY:

10. CHEMICAL ABSORPTION WITH AMINE-BASED
SOLVENTS
3D rendering ROAD project (Netherlands)
SUPPORTED BY:
Source: ROAD/EOn
1000 MWe coal fired
250 MWe

11. LARGE POST-COMBUSTION SYSTEMS: MAIN
DEVELOPERS
amine based:
 Shell (Cansolv)
 Mitsubishi Heavy Industries (KM CDR)
 Aker Solutions
 Fluor (Econamine FG+)
 Alstom/DOW
 Doosan/HTC
 Linde/BASF
non-amine based:
 Alstom (Chilled Ammonia Process)
 Siemens (PostCAP)
SUPPORTED BY:

12. POST-COMBUSTION: INNOVATIVE TECHNOLOGIES
Technology Readiness Level (TRL):
1-2 = concept; 2-5 = lab/bench scale; 5-7 = pilot; 7-9 = demonstrations
Technology Test Stage TRL
POST-COMBUSTION
Amine-based solvents Demo 7-9
Advanced amine-based solvents Pilot 5-7
Amino-Acid salt solvent Pilot 5-7
Aqueous Ammonia solvent Demo 7-9
Precipitating solvents Lab/Bench 2-5
Two-phase liquid solvents Lab/Bench 2-5
Catalysed enhanced absorption Lab/Bench 2-5
Ionic liquids Lab/Bench 2-5
Temperature or Pressure Swing Adsorption with solid sorbents
(TSA/PSA)
SUPPORTED BY:
Pilot 5-7
Calcium Looping (CaL) Pilot 5-7
Membranes Pilot 5-7
Cryogenic CO2 separation Lab/Bench 2-5
Source: Global CCS Institute – Status Report 2014 (Nov 2014)

13. PRE-COMBUSTION SYSTEMS
 Systems for the separation of CO2 from H2 (before combustion)
 Applicable to Integrated Gasifier Combined Cycle (IGCC) plants (15-60
%vol CO2)
 State of art: chemical absorption with physical and chemical
solvents (commercially available processes)
 chemical solvents: e.g. Methyl Diethanolamine (MDEA)
 physical solvent: Rectisol and Selexol
 mixtures of chemical and physical solvents are also possible
 Overall efficiency penalty* in IGCC plants is 9-11 %-points (20-25%
less power output)
* Including CO2 compression to 110 bar
SUPPORTED BY:

14. CO2 ABSORPTION BY PHYSICAL SOLVENTS
Example of application in IGCC
SUPPORTED BY:
40 °C
48 bar 21 °C
1.7 bar

15. CO2 ABSORPTION BY PHYSICAL SOLVENTS
SELEXOL is the most suitable for IGCC applications
Shifted
Syngas
SUPPORTED BY:
LP Steam
Cooling Water
Electric Power
CO2
Condensate
~40 °C
~35 bar

16. PRE-COMBUSTION AT IGCC PLANT
3D rendering IGCC 2 x 290 MWe (Kemper County, US)
SUPPORTED BY:
Source: Southern
Company

17. PRE-COMBUSTION: INNOVATIVE TECHNOLOGIES
Technology Readiness Level (TRL):
1-2 = concept; 2-5 = lab/bench scale; 5-7 = pilot; 7-9 = demonstrations
Technology Test Stage TRL
PRE-COMBUSTION
Physical and chemical solvents Demo* 7-9
Ionic liquids Lab/bench 2-5
Pressure Swing Absorption Based (PSAB) Lab/bench 2-5
Ammonium Carbonate-Ammonium Bicarbonate process (AC-ABC) Pilot 5-7
Temperature or Pressure Swing Adsorption with solid sorbents
(TSA/PSA)
SUPPORTED BY:
Lab/bench 2-5
Sorption Enhanced Water Gas Shift (SEWGS) Lab/bench 2-5
Sorption Enhanced Steam-Methane reforming (SESMR) Pilot 5-7
WGSRs membranes Lab/bench 2-5
Membranes Pilot 5-7
Cryogenic CO2 separation Concept 1-2
Source: Global CCS Institute – Status Report 2014 (Nov 2014)
* The technology is commercial but its use for CO2 capture in IGCC is under demonstration

18. OXY-COMBUSTION SYSTEMS
 Systems for the combustion of fuels in oxygen in order to produce a
near pure stream of CO2 ready for compression and transport
 Applicable to any combustion processes but,
1. The boiler must be air leakages free,
2. Flue gas recirculation is required (to avoid high combustion T)
SUPPORTED BY:
N2
Oxygen
Fuel
CO2 (+ H2O)
OXY
COMBUSTION
Air
Air
Separation
Unit (ASU)

19. OXY-COMBUSTION SYSTEMS
NEW
SUPPORTED BY:
NEW
NEW
EXISTING

20. OXY-COMBUSTION SYSTEMS
 Require only additional electric power (ASU), no heat (steam)
 Do not use chemical solvents
 Overall efficiency penalty* in coal fired power plants:
PC plants 7-10%-points (20-25% less power output)
NGCC plants 11-13 %-points (25-30% less power output)
Main Developers:
 Air Liquide, Air Products, Praxair, Linde, Babcock&Wilcox,
Doosan, Foster-Wheeler, Alstom
*including CO2 compression to 110 bar
SUPPORTED BY:

21. AIR SEPARATION UNIT (ASU)
 State of the art ASU is cryogenic separation: ~180 kWhe/tO2
 Commercial ASU producers: Air Liquide, Air Products,
Praxair, Linde
 Alternatives: Ion and Oxygen Transport Membranes
(ITM/OTM) but not yet mature for commercial applications
SUPPORTED BY:
ITM module
Source: Air Liquide Source: Air Products

22. OXY-COMBUSTION: INNOVATIONS
Technology Readiness Level (TRL):
1-2 = concept; 2-5 = lab/bench scale; 5-7 = pilot; 7-9 = demonstrations
Technology Test Stage TRL
OXY-COMBUSTION
Atmospheric oxy-combustion Demo 7-9
Ion Transport Membranes (ITM) Pilot 5-7
Oxygen Transport Membranes (OTM) Lab/Bench 2-5
Pressurized oxy-combustion Pilot 5-7
Chemical Looping Combustion (CLC) Pilot 5-7
SUPPORTED BY:
Source: Global CCS Institute – Status Report 2014 (Nov 2014)
Chemical
Looping
Combustion

23. CO2 CAPTURE IN INDUSTRIAL PROCESSES
SUPPORTED BY:
Industrial
Sector
Process
(CO2 sources)
Estimated year of
maturity
Oil refining Fluid Catalytic Cracker (FCC)
Residues gasification
Hydrogen from Synthetic Gas Reforming (SGR) *
2020-30
2015-20
Currently mature
Hydrogen from fossil
fuels/biomass
Coal/Biomass Gasification
Steam Methane Reforming
Currently mature
Currently mature
Natural gas processing Gas sweetening * Currently mature
Liquid fuel Synthesis Fisher-Tropsch process * Currently mature
Bio-fuels synthesis Ethanol *
Bio-synthetic gas (digestion) *
Currently mature
Currently mature
Chemicals Ammonia * Currently mature
Iron & Steel Blast furnace
Direct Iron Reduction (DRI) *
2020-30
Currently mature
Cement Calcinator 2020-30
* Near pure CO2 streams are produced as part of the existing process

24. OIL REFINING: FLUID CATALYTIC CRACKER
FCC is one of the biggest CO2
emission source in a refinery
Amine based post combustion capture
is tested at Technology Centre
Mongstad (TCM).
Flue gas may need additional cooling
and sulphur removal compared to post-combustion
in power plant
Oxyfuel application tested in Brazil in
2012 by the CO2 Capture Project
(CPP)
SUPPORTED BY:
Source: CO2 Capture Project

25. HYDROGEN PRODUCTION
Two main routes:
• Coal/Biomass gasification
• Steam Methane Reforming (SMR) of natural gas
Existing commercial processes for the separation of CO2/H2
Also called Acid Gas Removal (AGR)
SUPPORTED BY:

26. NATURAL GAS PROCESSING
Natural gas with high CO2 content have to be processes to meet
commercial specification. (Acid Gas Removal or Gas Sweetening)
Existing commercial processes for the separation of CO2 but also
experience with CO2 capture
In Norway, the Sleipner and Snohvit projects remove CO2 from flue
gases and re-inject it in depleted reservoir
In north and south America CO2 is removed and used in EOR application
(e.g. Lost Cabin and Petrobas Lula)
SUPPORTED BY:

27. ACID GAS REMOVAL
List of available processes for various type of CO2 separation applications
(IGCC pre combustion, hydrogen production, NG processing,…)
SUPPORTED BY:
Source: DOE/NETL

28. CEMENT PRODUCTION
1st option: Post-combustion
2nd option: Oxy-combustion
 Post-combustion technologies (amine, solid sorbents, membranes and
calcium looping) tested at Brevik cement factory in Norway
 Oxy-fired calcinator + calcium looping tested at cement factory in Taiwan
SUPPORTED BY:

29. IRON & STEEL
Capturing CO2 from the
flue gas of a blast
furnace
But not many
developments in recent
years
In the newer Direct
Reduction Iron process
(DRI) the CO2 is a by
product (see the ESI
project)
SUPPORTED BY:

30. THANK YOU!
GUIDO.MAGNESCHI@GLOBALCCSINSTITUTE.COM
WORKSHOP FOR CIVIL, CHEMICAL, ELECTRICAL, ENVIRONMENTAL AND MECHANICAL ENGINEERS:
INTRODUCTION TO CAPTURE, USE AND GEOLOGICAL STORAGE OF CO2
October 13-14, 2014
DF CFE Technology Museum
SUPPORTED BY: