Presentation at the Korean Power Industry Conference on EPRI\'s low CO2 emission coal power technology R&D efforts.

1. EPRI’s Low CO2 Emission
Coal Power Research,
Development and
Demonstration Programs
November 2009
Jeffrey N. Phillips
Sr. Program Manager
Advanced Generation Options
© 2009 Electric Power Research Institute, Inc. All rights reserved. 1

2. Introduction
• EPRI’s efforts are focused on:
– Reducing CO2 emissions on kg/MWhr basis by
increasing thermal efficiency of coal power plants
– Improving the economics of pre-combustion, post-
combustion, and oxy-combustion CO2 capture
technologies
• EPRI’s efforts range from lab tests to large
demonstrations
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3. Decreasing CO2 Emissions with More Efficient
Designs
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4. Increased Efficiency = Reduced Fuel & Emissions
Advanced steam
conditions can reduce
CO2 emissions by 30-33%
compared to average U.S.
coal power plant
Adapted by I.Wright, ORNL from B. Vitalis, Babcock Power
© 2009 Electric Power Research Institute, Inc. All rights reserved. 4

5. Advanced-Ultrasupercritical Steam Boiler
Consortium Phase I & II
1: Conceptual
Design
2: Material Properties
3: Steamside
Oxidation
4: Fireside Corrosion 8: Design Data & Rules
(including Code
5: Welding interface)
6:
Fabricability
7:
Coatings
Develop the materials technology to fabricate
and operate a A-USC Steam Boiler with
Steam Parameter up to 760°C
5
© 2009 Electric Power Research Institute, Inc. All rights reserved.

6. Advanced-Ultrasupercritical Steam Turbine
Consortium Phase II
• Steam Conditions from boiler and phase I turbine studies
– 730°C, 39MPa Main Steam
– 760°C, Re-heat
– Size to 1000MW
• Tasks
– Rotor/Disc Testing (near full-size forgings)
– Blade/Airfoil Alloy Testing
– Valve Internals Alloy Testing
– Rotor Alloy Welding and Characterization
– Cast Casing Alloy Testing
– Casing Welding and Repair
© 2009 Electric Power Research Institute, Inc. All rights reserved. 6

7. Economic Analysis Shows Advanced USC
Provides Cost-Effective CO2 Reductions
582ºC 680ºC
SCPC A-USC
Thermal Efficiency, %HHV 38.5 42.7
Levelized Cost of Electricity $/ 53.3 55.3
MWh
CO2 emissions, kg/MWh 853 765
Avoided CO2 emissions cost, N/A 22.5
$/metric ton vs. 582ºC SCPC
Reference: EPRI Technical Report 1015699, September 2008
© 2009 Electric Power Research Institute, Inc. All rights reserved. 7

8. CoalFleet IGCC User Design Basis
Specification (see EPRI Report 1017501, Nov. 2009)
• Defines power company technical requirements for a site-
specific IGCC plant; supplier alliances to propose plants
that meet the UDBS EPR I
• UDBS represents major collaborative effort
TION
CIFICA
IS SPE
– All sectors of industry engaged US E R
DESIG
N BAS
101750
1
Report
– 30+ people developed UDBS Ver. 9
– Approved by all CoalFleet members
• Robust, 1600-page industry-developed
and tested guideline, primer, and
lessons-learned compendium
• Flexible, yet promoting of standardized, optimized designs
• Already in use by numerous CoalFleet participants
© 2009 Electric Power Research Institute, Inc. All rights reserved. 8

9. IGCC Case Studies
Performance Summary (see EPRI Report 1019368, October 2009)
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10. IGCC Engineering and Economic Evaluations
2009–10 Study Content
• 50 Hz F-Frame Gas Turbine Cases
– Northeast Netherlands site
• Coal Type
– Eastern Australian export coal
• Gasification Technologies
– General Electric, Siemens, Shell,
Prenflo PDQ, Mitsubishi Heavy Industries, ConocoPhillips
• Greenfield Carbon Capture and Storage
• Sensitivity Analyses
– G-Frame GT, Cost Estimates for CO2 Liquefaction and HP
Gasification cases
• 2008–09 Capital Costs Revisited
© 2009 Electric Power Research Institute, Inc. All rights reserved. 10

11. ITM for Low Cost Oxygen Production
Overview
• A ceramic membrane to separate oxygen from air
• Intermediate-sized 150 tons O2/day test unit integrated with 5-15 MWe
turbomachinery system
– Utilizes commercial-scale ceramic membrane modules for
oxygen separation
– Representative of arrangement for full-scale
IGCC plant with CCS
0.5 tons O2/day ITM
• Three-year program to design,
build, and test system Modules
– Team: Air Products (with Ceramatec and
Siemens), DOE, and EPRI
• EPRI has launched the collaborative
– Builds on major investments by Air Products and DOE
– Will incorporate real-world utility plant design and
integration considerations
– Forms a bridge to commercial IGCC application Images courtesy Air Products.
– May enhance oxy-combustion applications © Air Products. All rights reserved.
• Additional organizations are welcome to join the collaborative
© 2009 Electric Power Research Institute, Inc. All rights reserved. 11

12. ITM for Low Cost Oxygen Production
Potential Benefits
• Reduces barriers to IGCC technology
deployment
– Decreases capital cost by ~7%
– Decreases auxiliary power consumption by ~6%
– Improves plant efficiency by ~1 percentage point
– Reduces oxygen plant footprint by 50%
– Reduces cooling water requirement by 60%
• Large forecast growth in oxygen plant market should drive
learning-by-doing cost reduction after commercialization
• Potential use with oxy-combustion boilers
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13. Improving the Economics of CO2 Capture &
Storage
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14. Challenges for Post-Combustion CO2 Capture
• What to do with CO2?
– SO2: ~ 1,400 ppmv in flue gas Can’t use consumable sorbents for CO2
capture (like those used for SO2 Capture).
– CO2: ~140,000 ppmv in flue gas
• Concentrating flue gas CO2
– Best option at present: scrub the gas with highly alkaline solutions which can then be
stripped of the CO2
• Putting the CO2 in the ground (required pressures: 100 – 175 bar)
• The overall capacity/efficiency penalty with current technology:
– 750 MW plant will net 492 MW with CO2 Capture (258 MW loss)
© 2009 Electric Power Research Institute, Inc. All rights reserved. 14

15. Capture Technologies Reviewed
(see EPRI Report 1016995)
Absorption, Liquid Absorption, Liquid, cont. Membrane, Active
• MHI, KS-1 •InnoSepra • MTR
• Chilled Ammonia (CAP) •CarbonTrap • RITE, Cardo polyimide
• CANSOLV •TNO CASTOR2 • Tetramer Technologies
• "7/2" MEA & PZ •JustCatch • Poly(Ionic Liquid) Membrane
• CASTOR Solvent •CO2 Solution • NanoGloWa
• IFP, Dual Phase •Three H Technologies, Inc. Membrane, Support
• Econamine FG+ •Catalyte • Carbozyme
• PowerSpan ECO2 Absorption, Solid • Coral
• Ionic Liquids, Notre Dame •RTI • Kvaerner Membrane Contactor
• Sargas •Hyperbranched Polyamine • PureStream
• Skyonic Skymine •Polyethyleneimine (PEI) Cryogenic
• AWL •Amine on inert support • CO2 Frosting
• WowClean •CO2 Wheel, Toshiba • Enecogen
• Ionic Liquids, U. S. Carolina
Adsorption Biological Fixation
• MEA:MDEA •Metal Organic Frameworks (MOFs) •
• COCS Solvent, RITE UNLV PRB
•Advanced Mesoporous Materials •
• GRT Independence BioProducts
•Heavy Reflux PSA •
• Immobilized Activator Carbon Capture Corp.
•CO2CRC Adsorbent •
• Enzyme Catalysis GreenFuel
•U. Akron •
• AEEA GSCleanTech
•U. Wyoming carbonaceous sorbent •
• D3 Conc. Solar Photoreactor
•ADA-ES •
• HTC Purenergy Many new Algae Systems
•VMI
• RCO2
© 2009 Electric Power Research Institute, Inc. All rights reserved. Mineralization 15

16. Assessing Technical Readiness Level (TRL)
TRL-9 Full-Scale Commercial • Most candidate CO2 removal
Deployment technologies assessed are
still a “twinkle in the eye”
TRL-8 Sub-Scale Commercial
Demonstration Plant • Significant development time
required to bring even the
TRL-7 Pilot Plant, 5 to 25% of full-scale
most ready technology to
TRL-6 Process Development Unit <5% TRL-9
TRL-5 Component Test in Relevant
# Technologies at indicated TRL
Environment
TRL-4 Laboratory Component Testing
TRL-3 Analytical, “Proof of Concept”
TRL-2 Application Formulated
TRL-1 Basic Principles Observed
© 2009 Electric Power Research Institute, Inc. All rights reserved. 16

17. AEP-Alstom Chilled Ammonia Post-Combustion
CO2 Capture Scale-Up – Overview
• ~20 MWe demonstration facility
at AEP’s Mountaineer plant
• ~90,000 tonnes-CO2/yr
– Next development step after 1.7 MWe
R&D pilot at We Energies’ Pleasant
Prairie Power Plant
– Injection into two on-site wells
PVF 2-23-09, Photo courtesy of AEP/Alstom. All rights reserved.
– 1–5 year injection program plus
post-injection monitoring
– Started capturing CO2 on September 1 and injecting on October 1
• Alstom designed and built the facility, and will serve as lead operator for
the first year. AEP may operate the facility for an additional 1-4 years.
• EPRI will measure and report unit performance, operability, and reliability
over project duration; EPRI will also monitor CO2 storage performance
© 2009 Electric Power Research Institute, Inc. All rights reserved. 17

18. Southern Co.-MHI KM-CDR Advanced Amine
Post-Combustion CO2 Capture – Overview
• ~25 MWe demonstration facility at Alabama Power’s Plant Barry
(~ 140,000 tonnes-CO2/year)
– Potentially lower regeneration energy than other amines; less corrosive;
low O2 degradation
– Injection program under U.S. DOE’s Southeast Regional Carbon
Sequestration Partnership (SECARB) Project—ongoing
– 4 years of CO2 injection plus 4 years of post-injection monitoring
– Startup scheduled for 4th Quarter 2010
• Southern Co. is leading the project and will install and operate the
plant; MHI is designing the CO2 capture facility
• EPRI will measure and report CO2 capture performance, operability,
and reliability
• EPRI is managing CO2 injection and monitoring operations under U.S.
DOE research partnership
© 2009 Electric Power Research Institute, Inc. All rights reserved. 18

19. Questions?
Together…Shaping the Future of Electricity
Jeffrey Phillips
jphillip@epri.com
Jong Kim
jkim@epri.com
© 2009 Electric Power Research Institute, Inc. All rights reserved. 19