Apec workshop 2 presentation 5 e apec workshop mexico capture technologies - g magneschi
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CO 2 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:
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Transcript of Apec workshop 2 presentation 5 e apec workshop mexico capture technologies - g magneschi
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:
OUTLINE
SUPPORTED BY:
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)
DEFINITION OF CO2 CAPTURE
SUPPORTED BY:
Source: CO2CRC
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
OVERVIEW OF CCS SYSTEMS
SUPPORTED BY:
Source: CO2CRC
OVERVIEW OF CO2 CAPTURE SYSTEMS
SUPPORTED BY:
Capture routes for power generation
Classified by application
OVERVIEW OF CO2 CAPTURE SYSTEMS
SUPPORTED BY:
Source: DOE/NETL
Classified by capture technique
POST-COMBUSTION SYSTEMS
SUPPORTED BY:
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
CHEMICAL ABSORPTION WITH AMINE-BASED SOLVENTS
SUPPORTED BY:
Flue GasLP Steam
Cooling Water
Electric Power
CO2
Condensate
N2/O
2
Source: Sintef
~130 °Csaturated
>95 % pure90% captured
~40 °C
PC 12-14% CO2
NGCC 3-5% CO2
CHEMICAL ABSORPTION WITH AMINE-BASED SOLVENTS
SUPPORTED BY:
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
CHEMICAL ABSORPTION WITH AMINE-BASED SOLVENTS
SUPPORTED BY:
Source: ROAD/EOn
1000 MWe coal fired
250 MWe
3D rendering ROAD project (Netherlands)
LARGE POST-COMBUSTION SYSTEMS: MAIN DEVELOPERS
SUPPORTED BY:
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)
POST-COMBUSTION: INNOVATIVE TECHNOLOGIES
SUPPORTED BY:
Technology Test Stage TRLPOST-COMBUSTION Amine-based solvents Demo 7-9Advanced amine-based solvents Pilot 5-7Amino-Acid salt solvent Pilot 5-7Aqueous Ammonia solvent Demo 7-9Precipitating solvents Lab/Bench 2-5Two-phase liquid solvents Lab/Bench 2-5Catalysed enhanced absorption Lab/Bench 2-5Ionic liquids Lab/Bench 2-5Temperature or Pressure Swing Adsorption with solid sorbents (TSA/PSA)
Pilot 5-7
Calcium Looping (CaL) Pilot 5-7Membranes Pilot 5-7Cryogenic CO2 separation Lab/Bench 2-5
Technology Readiness Level (TRL): 1-2 = concept; 2-5 = lab/bench scale; 5-7 = pilot; 7-9 = demonstrations
Source: Global CCS Institute – Status Report 2014 (Nov 2014)
PRE-COMBUSTION SYSTEMS
SUPPORTED BY:
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
CO2 ABSORPTION BY PHYSICAL SOLVENTS
SUPPORTED BY:
Example of application in IGCC
40 °C 48 bar 21 °C
1.7 bar
CO2 ABSORPTION BY PHYSICAL SOLVENTS
SUPPORTED BY:
Sh
ifte
d
Syn
ga
s
LP Steam
Cooling Water
Electric Power
CO2
Condensate
~40 °C~35 bar
SELEXOL is the most suitable for IGCC applications
PRE-COMBUSTION AT IGCC PLANT
SUPPORTED BY:
3D rendering IGCC 2 x 290 MWe (Kemper County, US)
Source: Southern Company
PRE-COMBUSTION: INNOVATIVE TECHNOLOGIES
SUPPORTED BY:
Technology Test Stage TRLPRE-COMBUSTION Physical and chemical solvents Demo* 7-9Ionic liquids Lab/bench 2-5Pressure Swing Absorption Based (PSAB) Lab/bench 2-5Ammonium Carbonate-Ammonium Bicarbonate process (AC-ABC) Pilot 5-7Temperature or Pressure Swing Adsorption with solid sorbents (TSA/PSA)
Lab/bench 2-5
Sorption Enhanced Water Gas Shift (SEWGS) Lab/bench 2-5Sorption Enhanced Steam-Methane reforming (SESMR) Pilot 5-7WGSRs membranes Lab/bench 2-5Membranes Pilot 5-7Cryogenic CO2 separation Concept 1-2
Technology Readiness Level (TRL): 1-2 = concept; 2-5 = lab/bench scale; 5-7 = pilot; 7-9 = demonstrations
Source: Global CCS Institute – Status Report 2014 (Nov 2014)
* The technology is commercial but its use for CO2 capture in IGCC is under demonstration
OXY-COMBUSTION SYSTEMS
SUPPORTED BY:
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)N
2
Oxygen
Fuel
CO2 (+ H2O)OXY
COMBUSTION
AirAir
SeparationUnit (ASU)
OXY-COMBUSTION SYSTEMS
SUPPORTED BY:
NEW
NEW NEWEXISTING
OXY-COMBUSTION SYSTEMS
SUPPORTED BY:
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
AIR SEPARATION UNIT (ASU)
SUPPORTED BY:
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
ITM module
Source: Air ProductsSource: Air Liquide
OXY-COMBUSTION: INNOVATIONS
SUPPORTED BY:
Technology Test Stage TRLOXY-COMBUSTION Atmospheric oxy-combustion Demo 7-9Ion Transport Membranes (ITM) Pilot 5-7Oxygen Transport Membranes (OTM) Lab/Bench 2-5Pressurized oxy-combustion Pilot 5-7Chemical Looping Combustion (CLC) Pilot 5-7
Technology Readiness Level (TRL): 1-2 = concept; 2-5 = lab/bench scale; 5-7 = pilot; 7-9 = demonstrations
Source: Global CCS Institute – Status Report 2014 (Nov 2014)
Chemical Looping Combustion
CO2 CAPTURE IN INDUSTRIAL PROCESSES
SUPPORTED BY:
Industrial Sector
Process (CO2 sources)
Estimated year of maturity
Oil refining Fluid Catalytic Cracker (FCC)Residues gasificationHydrogen from Synthetic Gas Reforming (SGR) *
2020-302015-20
Currently mature
Hydrogen from fossil fuels/biomass
Coal/Biomass GasificationSteam Methane Reforming
Currently matureCurrently 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 matureCurrently mature
Chemicals Ammonia * Currently mature
Iron & Steel Blast furnaceDirect Iron Reduction (DRI) *
2020-30Currently mature
Cement Calcinator 2020-30
* Near pure CO2 streams are produced as part of the existing process
OIL REFINING: FLUID CATALYTIC CRACKER
SUPPORTED BY:
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)
Source: CO2 Capture Project
HYDROGEN PRODUCTION
SUPPORTED BY:
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)
NATURAL GAS PROCESSING
SUPPORTED BY:
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)
ACID GAS REMOVAL
SUPPORTED BY:
List of available processes for various type of CO2 separation applications (IGCC pre combustion, hydrogen production, NG processing,…)
Source: DOE/NETL
SUPPORTED BY:
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
CEMENT PRODUCTION
IRON & STEEL
SUPPORTED BY:
Capturing CO2 from the flue gas of a blast furnaceBut not many developments in recent years
In the newer Direct Reduction Iron process (DRI) the CO2 is a by product (see the ESI project)
THANK [email protected]
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:
