The U.S. Department of Energy’s Post- combustion Carbon ... - NETL - Jared Ciferno... · The U.S....

The U.S. Department of Energy’s Post-combustion Carbon Dioxide Capture R&D Program — Technology Update

Jared Ciferno, Technology ManagerExisting Plants Program

2

Presentation Outline

• DOE/NETL CO2 Capture R&D Program

• PC Post-combustion CO2 Capture– Solvents, Sorbents, Membranes

• PC Oxycombustion CO2 Capture– Pulverized Coal– Chemical Looping

• Advanced CO2 Compression

• DOE National Carbon Capture Center

3

DOE/NETL CO2 Capture R&D

Existing PlantsPost-Combustion CO2

PC Oxycombustion

SequestrationPre-Combustion CO2

Gasification

Advanced Research

Office of Research& Development

Office of Systems, Analyses and Planning

Fuels

Demonstration Programs

FutureGen

Clean Coal PowerInitiative

NETL’s Carbon Capture

R&D

R&D Programs

Demonstration Programs

4

IEP Program Budget

Water 7%

Mercury 3%

Sorbents12%

Solvents 33%

Membranes12%

Oxycombustion23%

Program10%

FY10 Budget Allocation

45 Total ProjectsOrganizations• Industry 17• University 8• National Laboratories 4• Non-Profit 6Total 35

Annual Budget

$Mill

ions

Additional collaboration with DOE ARPA-E and Office of Science (Energy Frontiers Research Institute)

5

1. Scale-up• Current PC capture ~200 tons/day

• 550 MWe plant produces 13,000 tons/day

2. Energy Demand• 20% to 30% in power output

3. Current Cost (for a 550 Mwe plant)• Adds $1500 - $2000/kW capital

• Increase Cost of Electricity (COE) by 80%

4. Regulatory framework• Transport — pipeline network

• Storage

Deployment Barriers for CO2 Capture on New and Existing Coal Plants Today

6

Fossil Energy CO2 Capture Options

Source: Cost and Performance Baseline for Fossil Energy Power Plants study, Volume 1: Bituminous Coal and Natural Gas to Electricity; NETL, May 2007.

Pulverized Coal (PC)Post-combustion

PC Oxy-combustion

Gasification (IGCC)Pre-combustion

7

Fossil Energy CO2 Capture Solutions

Ready for Demonstration

1st Generation physical solvents (CCPI)1st Generation chemical solvents (CCPI)Adv. CO2compression(Ramgen)

Amine solventsPhysical solventsCryogenic oxygen

Chemical looping2nd Gen. OxyboilerBiological processesSolid Sorbents

Cos

t Red

uctio

n B

enef

it 2nd Gen. SolventsH2 and CO2MembranesOxygen Membranes

Post-combustion (existing, new PC)

Pre-combustion (IGCC)

Oxycombustion (new PC)

CO2 compression (all)

202020152010

OTM – O2 Transport Membrane (PC)

8

R&D Timeline to Commercial Demonstration

20102008 20162012 2020 2024

Pilot-Scale Field Testing0.5 — 5 MWe

Large-Scale Field Testing5 — 25 MWe

CommercialDemonstration

Laboratory-Bench Scale R&D

- DOE National CarbonCapture Center

- Utility sites

Core R&D Program Projects 2010 Funding Opportunity Announcement

9







Post-combustion

10

PC Boiler(With SCR)

Sulfur Removal

ParticulateRemoval

Ash

Coal

STEAMCYCLE

CO2 CaptureProcess*

ID Fan

Air

Power

CO2Comp.

Flue Gas

CO2 To Storage2,215 psia

Low Pressure Steam

Optional Bypass(<90% Capture)

Post-combustion CO2 CaptureAmine-based scrubbing

Reference: Pulverized Coal Oxycombustion Power Plants—Volume 1 Bituminous Coal to Electricity, U.S. Department of Energy/National Energy Technology Laboratory, Revision 2 Final Report, August 2008

Two-step separation process requiring 5 energy inputs:

Energy = Q (sensible) + Q (reaction) + Q (stripping) + W (Process) + W (Compression)

ALL must be reduced in order to significantly reduce Capture COE impact!

0

10

20

30

40

50

60

70

80

90

Perc

ent I

ncre

ase

in C

OE

Trans., Stor., & Monit.Compression CapitalCapture CapitalCapture OperatingCapture SteamCapture Aux. PowerCompression power

13%

11%

28%

7%

20%

5%2%

Parasitic PowerCOE by 52%

Operating CostCOE by 7%

Capital CostCOE by 27%

11

Advanced CO2 Solvents

Solvent Technologies• Ionic liquids• Potassium carbonate/enzymes• Phase change solvents• Novel high capacity oligomers• Bicarbonates/additives• Molecular simulations• Enzymes

Today: Laboratory-scale2011: 1 MWe Pilot Scale2015: 5 – 25 MWe Pilot Scale2018: Demonstration Scale

Partners: 1. University of Notre Dame2. Georgia Tech.3. Illinois St. Geological Survey 4. 3H 5. GE Research Corporation6. Lawrence Berkeley Nat. Lab. 7. Siemens Energy8. URS Corporation9. Akermin10. Ion Engineering

Solvent R&D Focus• High CO2 working capacity

( Qsensible, Wprocess)• Low regeneration energy

( Qsensible, Qreaction , Qstripping )• Fast kinetics ( Equipment Size)• Thermally and chemically stable• Non-corrosive, environmentally safe

Development Timeline

12

Solvents: Ionic Liquids University of Notre Dame

Maturity: Laboratory Scale• On 4th year of R&D with Univ. of Notre Dame

– 19x increase in CO2 solubility for physical Ils, 40x increase in CO2 solubility for “functionalized” (amine groups) Ils.

Organic salts with a melting point below 100oC. Choice of anion and cation components determines the physiochemical properties

Advantages:• Interaction mechanisms: physical, electrostatic, charge-transfer, chemical ( Qreaction)• Huge diversity of chemical compounds 105 ( All Energy Inputs)• Computational methods to ‘tune’ molecules for flue gas or syngas applications• Integrate molecular design with process design ( All Energy Inputs)• Low vapor pressure, thermally stable >200oC ( Qstripping, Wcompression)• “Functionalized” chemistry to CO2 capacity and selectivity ( Qsensible, Wprocess)• Supported (membrane) and non-supported process options Challenges:• Current molecules showing low CO2 working capacity• High viscosity (100 to 1,110 centipoise)• Water absorption (flue gas is saturated), sulfur absorption• High chemical cost, unique chemistry — chemical syntheses• 105 varieties — computational modeling to design and down-select

1-n-hexyl-3,5-dimethylpyridinum

bis(trifluoromethane-sulfonyl)amide

13

Solvents: Potassium Carbonate Illinois State Geological Survey

Primary/secondary amine MEA: 1,900 kJ/kg

Tertiary amine MDEA: 1,200 kJ/kg

Carbonate K2CO3: 600 kJ/kgCO2 absorption: CO2 + H2O + K2CO3 = 2KHCO3

Solvent regeneration: 2KHCO3 = K2CO3 + H2O + CO2

Primary/secondary amine MEA: 1,900 kJ/kg

Tertiary amine MDEA: 1,200 kJ/kg

Carbonate K2CO3: 600 kJ/kgCO2 absorption: CO2 + H2O + K2CO3 = 2KHCO3

Solvent regeneration: 2KHCO3 = K2CO3 + H2O + CO2

Advantages:• Low heat of absorption ( Qreaction)

• Low quality stripping steam required (40 – 50 oC) ( Qstripping)• Increased CO2 working capacity, increased kinetics ( Qstripping, Qsensible, Wprocess)• SO2 tolerant (negligible solvent make-up)Challenges:• Enzyme durability, cost, process design• Vacuum stripping

Maturity: Laboratory Scale• Supported enzyme (ceramic, carbon, polymer)

carbonic anhydrase (CA)• Exp. results show reaction rate = MEA

Approach: Carbonic anhydrase enzymes used to accelerate K2CO3 reaction rate

Supported CA

enzyme

14

CO2 Capture by Self-Concentrating Amine Absorbent

3H Company, Inc.Approach:• Develop solvent/absorbent mixtures that can separate into two

phases upon CO2 absorption• Only regenerate the CO2 rich phase• Reduced solvent recirculation• High solvent capacity• Lower overall regeneration energy• Lower auxiliary power • Reduced corrosion• Reduced equipment size• Demonstrated mixtures include

non-aqueous solventmixed with conventionalamines as absorbents

Flue Gas

Purified Flue GasCO2

Absorber Regenerator

Settler

CO2‐lean Phase

CO2‐rich Phase

Maturity: Laboratory Scale

15

Approach:Test an amine-ionic liquid (IL) based solvent scrubbing system to verifya ~60% reduction in energy penalty compared to conventional processes• Water is replaced with IL

• Compared to MEA – ~60% energy reduction – No stripping steam required– Higher loading capacities– Less corrosion– Smaller equipment

• Program includes integrated lab testing, simulation modeling, followed by a~25 kWe bench-scale test at a Xcel Energycoal-fired power plant in Colorado

• Duration – 17 months• Team

Ionic Liquid/Chemical Solvent ION Engineering

Final Phase: Operate bench-scale system with actual flue gas at a coal fired plant

Probable Location of Bench Scale Process at Valmont Xcel Coal-Fired station

16

Siemens POSTCAP Amino AcidCO2 Capture Technology

Siemens Energy, Inc.Approach: • 2.5 MWe Amino Acid Solvent slipstream at TECO’s Big Bend

Station – Amino acid salt (AAS) designed to operate in a conventional

absorption/scrubbing system, however lab test showed:• Less corrosion than MEA• Lower volatility than MEA• Lower regeneration than MEA (2.64 GJ/tonne CO2 vs 4.25)• Capacity similar to hindered amine• Moderately better than MHI’s hindered amine

– Systems analysis shows 44% increase in COE– 5000 hours of bench-scale operation

Maturity: 2.5 Mwe Slip-stream

17

Advanced CO2 Sorbents

Partners: 1. UOP (metal organic frameworks)2. University of Akron (amine

functionalized metal zeolites) 3. ADA-ES (amine, zeolites,

process design) 4. SRI International (Carbon-based)5. TDA (Alumina)6. NETL ORD (Supported amines,

process design)

Project Types• Metal organic frameworks• Supported amines (silica, clay)• Metal zeolites• Carbon-based• Alumina• Sorbent systems development

Sorbent R&D Focus • High CO2 working capacity + Low Cp

( Qsensible, Wprocess)• “Ideal” ΔHrxn ( Qreaction)• Dry scrubbing ( Qsensible, Qstripping = 0)• Fast reaction kinetics ( Equipment Size)• Durability: Thermal, chemical, mechanical• Gas/solid systems ( Wprocess)

- Low pressure drop, heat management

Today: 1 kW pilot scale (ADA-ES)2011: 1 MWe Pilot Scale2016: 5 – 25 MWe Pilot Scale2020: Demonstration Scale


18

Solid Sorbents: Metal Organic FrameworkUOP

Challenges:• Flue gas contaminants (SOx, NOx)• Moisture • System design (pressure drop, large vacuum pumps at 0.01 – 0.05 atm.)• Material and production cost

MOF: Metal “hubs” attached by organic linkers designed to create high surface area, crystalline, microporous and thermally-stable materials.

=

=

Advantages:• High CO2 working capacity (10 - 20%)• Thermally stable to 250 - 400oC• Hydrothermal stability 100 - 200oC

19

Solid Sorbents: Metal Organic FrameworkUOP

Current State: 4 years at laboratory scale• 50+ MOFs for CO2 adsorption prepared down selected to 10 best• Surface area 500 – 2000 m2/g• Independent systems analysis (PSA design) showed COE penalty

decrease from 85% to 55%a

0

0.05

0.1

0.15

0.2

0.25

0.3

0.35

0 0.1 0.2 0.3 0.4 0.5pressure, atm

g C

O2/

g a

dsor

bent

Mg/DOBDC

Ni/DOBDC

MIL-101

ZIF-100

ZIF-100 data from Wang, et al, Nature 2008, 453, 207

= DOBDC linker

OHO

HO O

OH

HO

M/DOBDC MOF

0

0.05

0.1

0.15

0.2

0.25

0.3

0.35

0 0.1 0.2 0.3 0.4 0.5pressure, atm

g C

O2/

g a

dsor

bent

Mg/DOBDC

Ni/DOBDC

MIL-101

ZIF-100

ZIF-100 data from Wang, et al, Nature 2008, 453, 207

= DOBDC linker

OHO

HO O

OH

HO

OHO

HO O

OH

HO

OHO

HO O

OH

HO

M/DOBDC MOF

“Top Ten” MOFs(January 2010)

aCurrent & Future Pulverized Coal Power Generation Technologies: A Pathway Study Focused on Post-combustion Carbon Capture, Noblis for DOE/NETL, May 6, 2010.

20

Reactors for CO2 Dry SorbentsNETL Office of Research and Development

Analysis of five reactor systems to use sorbents:– Structured Bed Concept

• Fixed bed sorber, with internal heat removal• Internal heating of same bed for regeneration

– Moving Bed Concept• Moving bed sorber, with internal heat removal• Moving bed regenerator, with internal heating

– Fluidized Bed Concept • Fluid bed sorber, with internal heat removal• Moving bed regenerator, with internal heating

– Fixed Bed Adsorber Concept• Fixed bed sorber, adiabatic, multi-stage with

interstage heat removal• Heating of same bed for regeneration with hot fluid

stream– Transport Reactor

• Circulating fluid bed sorber• Circulating fluid or moving bed regenerator

FUNCTIONS AND FLOWS OF INFORMATION AND MATERIALS

Process engineering,

design, economics

R&D lab-scale unit design &

construct

Lab-scale operation

Sorbent synthesis

Isotherm development

High-surface area formation

Other physical properties

9

10

11

12

1

2

3 5

4

6 7

8

Needed

ORD workOn reactors

21

Solid Sorbents: Pilot-scale development ADA-ES, Inc.Approach:

• Evaluate performance of 100+ CO2 capture sorbents at bench-scle using simulated flue gas

Success Criteria:• Working capacity, Reaction Energy,Theoretical Regeneration Energy, Consistent

performance, Reaction Kinetics, Durability, Cost

• 1 kW pilot-scale slip-stream tests beginning Jan 2010at 3 field-sites:

Luminant Martin Lake: Lignite (Completed)Xcel Energy Sherco: PRBNCCC Alabama Power Gaston: Bituminous

60 ft

22

Advanced Flue Gas CO2 Membranes

Today: 1 Ton/day slipstream (MTR)2011: 1 MWe Pilot Scale2015: 5 – 25 MWe Pilot Scale2018: Demonstration Scale


Membrane Advantages• Simple operation; no chemical

reactions, no moving parts• Tolerance to acid gases & O2

• Compact, modular small footprint• Builds on existing technology at

similar scale (NG purification)

Membrane Technology Research, Research Triangle Institute, Air Liquide, Gas Technology Institute

Membrane Approaches• Mixed matrix/ionic liquid• Spiral wound• Hollow fiber• Membrane/solvent hybrid• Cryogenic separation

Energy = Q (sensible) + Q (reaction) + Q (stripping) + W (Process) + W (Compression)

0 0 0

Challenges• Cost reduction and scale-up• PM contamination• Power plant integration (recycle)• PCO2 driving force Increased

power consumption

23

CO2 Capture by Sub-Ambient Membrane Operation

American Air LiquideApproach:• CO2 separation using a hollow fiber membrane at cryogenic

conditions-- No external refrigeration

--cooling via valve expansion

-- Commercial AL polyimide fiber

• Duration – 24 months• Team – Air Liquide Delaware Research and Technology Center, MEDAL (Air

Liquide's Membrane Business Entity), Air Liquide Process and Construction, Babcock & Wilcox

Sensitive Unclassified Information (SUI) - Procurement Sensitive

24

Hybrid Membrane/Absorption Process (Membrane Contactor)

Gas Technology Institute

Approach:• Hybrid membrane/solvent absorption process.

– PEEK hollow fiber membrane

– Increases interfacial gas/liquid contact area 10x over conventional packed or tray columns — increases mass transfer

– Selectivity controlled by solvent chemical affinity– Low steam regeneration energy– CO2 generated at pressure– Planned slipstream test at

Midwest Generation’s Joliet PowerStation (Size: 25 kWe)

• Duration – 36 months• Team – PoroGen Corp., Aker Process Systems, Midwest Generation

PEEK—Polymer ether ether ketone

25

Skid footprint is 24’ x 7’250,000 scfd flue gas slipstream

Post-Combustion CO2 Membrane Progress

10

20

30

40

50

60

100 1,000 10,000

CO2/N2selectivity

CO2 permeance (gpu)

PolarisTM

Target area identified from

design calculations

Commercial CA membranes

2008

Laboratory Results

2009

Process Design

10

15

20

25

30

35

40

0 20 40 60 80 100 120

Cost of capture

($/ton CO2)

Membrane CO2/N2 selectivity

1,000 gpu

1,500 gpu

3,000 gpu

90% CO2 recovery

PolarisTM 1

PolarisTM 3

CO2Permeance

Is it competitive?

aCurrent & Future Pulverized Coal Power Generation Technologies: A Pathway Study Focused on Post-combustion Carbon Capture, Noblis for DOE/NETL, May 6, 2010.

2010

Design and Scale-up

26

Membrane CO2 Capture Slipstream Membrane Technology and Research, Inc.

Approach: • 1 MW membrane pilot-scale at APS’ Cholla Power Plant

– PolarisTM polymer-based membrane designed for flue gas applications, developed with DOE/NETL support, have met membrane performance targets

– Currently carrying out a 0.05 Mwe (1 TPD) slip-stream plant at Cholla (XXX inch diameter modules)– The 1 Mwe (20 ton/day) test will be 12 inches in diameter

• Project Duration – 36 months• Team – Arizona Public Services, B&W,

Southern Company/NCCC, EPRI

10

20

30

40

50

60

100 1,000 10,000

CO2/N2selectivity

CO2 permeance (gpu)

PolarisTM

Target area identified from

design calculations

Commercial CA membranes

27

Post-combustion CO2 Capture Progress

Levelized Cost of Electricity, $/MWh

BaselineMEA Capture

Metal OrganicFramework

GE AdvancedSolvents

Phase ChangeSolvents

+80%+50% +47%

+37%

Key Assumptions:-Thirty-year, current dollar levelized COE-June 2007 dollars (equivalent to Feb 2009)-Capital cost component includes owner’s costs-$1.64 coal price

Membrane

+50%

28







29

Pulverized Coal Oxy-combustion

Coal + O2 CO2 + H2OCoal + O2 CO2 + H2O

Reference: Pulverized Coal Oxycombustion Power Plants—Volume 1 Bituminous Coal to Electricity, U.S. Department of Energy/National Energy Technology Laboratory, Revision 2 Final Report, August 2008

PC Oxy-combustion Advantages:• Plant vs. unit operation—multiple cost reduction

opportunities• Applicable to new and existing PC power plants• Current designs lower cost than amine wet scrubbing • Co-sequestration options

30

Pulverized Coal Oxy-combustionPartners: 1. Praxair (O2 Membrane, CO2

Purification)2. Air Products (CO2 Purification)3. Jupiter Oxygen (Burners) 4. Alstom (Pilot plant)5. B&W (Cyclone pilot test)6. Foster Wheeler (Corrosion)7. Reaction Engineering Int. (Retrofit)8. Southern Research Institute (Retrofit)9. NETL ORD (Modeling, CO2

Purification)

Challenges• Cryogenic ASUs are capital and

energy intensive• Existing boiler air infiltration• Corrosion and process control• Excess O2 and inerts (N2, Ar) CO2

purification cost

Today: 10 MWe wall-fired test (B&W)5 MWe T-fired pilot (Alstom)5 MWe burner pilot (Jupiter)

by 2015: 1st Gen (Cryogenic) demo. 2020: 2nd Gen demonstration*


Oxycombustion R&D Focus •New oxyfuel boilers

- Advanced materials and burners- Corrosion

• Retrofit existing air boilers- Air leakage, heat transfer, corrosion - Process control

• Low-cost oxygen • CO2 purification • Co-capture (CO2 + SOx, NOx, O2)

*O2 Membrane + USC materials + Adv. Purification + Adv. Compression

31

Air Dry Wet

Gas Absorption Coefficient

0.07 Max 0.06 Max 0.20 Max

120 MWth Furnace

10.0 Max 20.0 Max 10.0 Max

Gas/Solid Absorption Coefficient

Oxycombustion: Adv. BoilersNETL ORD

Research• Develop models for combustion,

radiation, heat transfer• Investigate methods to integrate CO2

purification with thermal cycle• Evaluate material performance in

existing (600 °C)/advanced (760 °C) steam cycles

Status• Grey-gas radiation model and particle

model under development• Fireside corrosion test: exposure tests

with ash and flue gas; oxide fluxing behavior in ash and flue gas

• Integrated Pollutant Removal (IPR) licensed

• Flame emissions and heat transfer measurements in boilers

Fireside

Wall side

Water-wall tube heat transfer

32

PC Oxycombustion Progress

Alstom Power

Flue GasAir Products

CO2 Purification Slip-Stream Test:• 2-stage compression/purification • Removes SOx, NOx, O2, & Inerts

33

Oxycombustion: Chemical Looping

Key Challenges• Solids transport• Heat Integration

Key Partners (2 projects): Alstom Power (Limestone Based), Ohio State (Metal Oxide)

Status2010 Alstom Pilot test (1 MWe)

1000 lb/hr coal flow1st Integrated operation1st Autothermal Operation

Red1700F

Ox2000F

CaS

Air

Fuel CO2 + H2O

CaSO4

MBHX N2 + O2

Steam

Fuel Reactor (Reducer)CaSO4 + 2C + Heat 2CO2 + CaSCaSO4 + 4H2 + Heat 4H2O + CaS

Air Reactor (Oxidizer)CaS + 2O2 CaSO4 + Heat

Oxy-Firing without Oxygen Plant

Solid Oxygen Carrier circulates between Oxidizer and Reducer

Oxygen Carrier: Carries Oxygen, Heat and Fuel Energy

Carrier picks up O2 in the Oxidizer, leaves N2 behind

Carrier Burns the Fuel in the Reducer

Heat produces Steam for Power

34

76

60

47 3025

0102030405060708090

A B C D E

`

Perc

ent I

ncre

ase

in C

OE

ADVANCEDO2 MembraneSupercritical ADVANCED

Adv. BoilerUltra-SupercriticalCo-Sequestration

O2 Membrane

ADVANCEDChemical LoopingUltra-Supercritical

Adv. BoilerCo-Sequestration

CURRENT STATESupercritical

Cryogenic ASU

Basis: 550 MW Net Output≥90 % CO2 Capture

CURRENT STATEAmine Scrubbing

Reference: Advancing Oxycombustion Technology for Bituminous Coal Power Plants: An R&D Guide, NETL 2010

?

Time to Commercialization

Pathway to Meeting NETL Goals

35







36

Advanced CO2 Compression

R&D FocusReduce capital costsIncrease efficiencyIntegration with CO2 capture processModelingHeat recoveryReduced footprint

Projects:• Ramgen & Dresser Rand Shockwave Compression

• $20 MM DOE funded via ARRA (stimulus)• 13,000 hp demonstration test in 2011 – 2013

• Novel CO2 compression processes — Southwest Research Institute

37

Ramgen CO2 Compression

38

Ramgen CO2 Compression

Courtesy: Ramgen

39







40

National Carbon Capture Center (NCCC) at Power Systems Development Facility (PSDF)

Wilsonville, AL

NCCC Mission: Develop technologies that will lead to the commercialization of cost-effective, advanced coal fueled power plants with CO2 capture• 6 Mwe Transport Gasifier• 3 Mwe Post-Combustion Slipstream• Southern Company

– Peabody Energy– American Electric Power– Luminant– Arch Coal– RioTinto– Electric Power Research Institute

41

FGD

Stack

ID Fan

Plant Gaston

880 MWe12,000 tpd CO2

880 MWe12,000 tpd CO2

Pilot Solvent Test Unit #1

Pilot Test Unit #2

Pilot Test Unit #3

Bench Scale Test Units

Post-Combustion Capture Slip-StreamsAvailable for Technology Developers

3 MWe60 tpd CO2

3 MWe60 tpd CO2

0.5 MWe10 tpd CO2

0.5 MWe10 tpd CO2

1 MWe20 tpd CO2

1 MWe20 tpd CO2

< 0.1 MWe< 1 tpd CO2

< 0.1 MWe< 1 tpd CO2

42

http://www.netl.doe.gov/publications/index.html

Annual NETL CO2 Capture Technology R&D Meeting

Pre-, Post-, Oxycombustion CO2 Capture Technologies

Meeting will include ARPA-E CO2 Projects

Sheraton Station Square HotelPittsburgh, PA

September 13-17, 2010

43

•NETL website:−www.netl.doe.gov

• Annual CO2 Capture Meeting

Jared P. CifernoTechnology Manager, Innovation for Existing PlantsNational Energy Technology LaboratoryU. S. Department of Energy(Tel) 412 [email protected]

•Office of Fossil Energy website:−ww.fe.doe.gov

For More Information About the NETL Existing Plants Program

Reference Shelf

The U.S. Department of Energy’s Post- combustion Carbon ... - NETL - Jared Ciferno... · The U.S....

Documents

Transcript of The U.S. Department of Energy’s Post- combustion Carbon ... - NETL - Jared Ciferno... · The U.S....