1. Clean Coal Combustion: Meeting the Challenge of Environmental and Carbon Constraints
A.R. Ericson

2. Post-combustion capture
Our Vision for New Coal Power
Portfolio of Clean Technologies
Near-zero emissions
Carbon
Free
Power O2
Oxygen Fired CFB
Concentrated
CO2
COMPLETE
COMBUSTION
or PC PC
USC PC
Post-combustion capture
CO22
Air
CFB
USC CFB
Carbonate
looping
CO2 Capture
And Sequestration
COAL
CHEMICAL
LOOPING
CO22
CO22
PARTIAL
COMBUSTION
CO2
Scrubbing
PETROCHEMICAL O2
IGCC H2
H2 GT
water shift
Air
IGCC
Fuel Cell 3
AIR BLOWN IGCC

3. Outlook for New Ultra Clean Coal Capacity
Presentation Roadmap
Outlook for New Ultra Clean Coal Capacity
Market Realities
Environmental Performance – Mission Critical
Advanced Cycle Designs
Coal Generation in a Carbon Constrained World

4. Drivers for New Capacity North America
Our economies continue to drive
electricity demand growth
Source: NERC 2006 Long Term
Reliability Assessment

5. Existing US Coal Fleet Expanding output to meet demand
Equivalent to 45 GW of new coal capacity

6. Drivers for New Coal Build North America
Base Energy needs versus Peaking Capacity
Base load demand expected to increase at roughly GDP
Economics
Fuel Cost
End User price shocks driving demand for low cost energy
Coal availability and prevalence
200+ Years of Reserves in North America
Advent of OTC (over the counter) markets for coal and emissions
Environmental regulations drive new clean plants
Fuel diversity
Source: U.S. EIA

7. New Coal Capacity Faces Challenges
Economics
Utilization of all low cost domestic coals …and opportunity fuels
Competitive costs
Operations
Highest reliability and commercial availability
Operating parameters to meet demands of grid
Environmental
Near zero emissions …
and a carbon strategy

8. Meeting the Goals for Coal Based Power - Emissions

9. Source: Energy Velocity database ( EPA CEMS 2005 data )
Operating Coal Combustion – Best in Class Emissions
2005 Wtg. Avg SO2 Emissions - US Coal Units
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
Lbs/MMBtu
Top 20 - Lowest SOx emitters
PC and CFB
Clean Coal technologies have demonstrated the
lowest emissions :
Exceed Requirements
Cost Effectively
Reliably
2005 Wtd Avg NOx Emissions - US Coal Units
0.00
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
Lbs/MMBtu
Top 20 - Lowest NOx emitters
Proven advanced clean coal combustion utilizing pulverized coal or circulating fluidized bed currently meets all emission requirements at competitive costs. State of the art emissions control systems integrated with PC/CFB can achieve extremely low emissions including NOx, SO2, particulate and mercury. This is an important point and one that is often misstated today.
In fact older operating PC and CFB units, retrofit with emissions controls, are achieving emissions lower than operating IGCC plants.
The first figure on this slide shows the 20 lowest SO2 emissions of older operating coal plants reporting under the EPA Acid rain program, ranging from lb/MMBTU (a PC unit burning sub-bituminous coal). It should be noted that we would have to go to #39 to find one of the two operating IGCC units.
NOx emissions data also demonstrate that older operating PC’s are achieving low rates of emission. It should be noted that the several of these older units achieve these low Nox emissions by advanced burners alone ie., without an SCR. The also represent the retrofit of new firing systems in older furnace designs. The majority of new coal plants would incorporate an SCR for high levels of Nox reductions.
Ultimately, IGCC technology must prove the claims of low emissions levels…. And must compete with lower cost, equally clean , combustion technology. Let the regulators set the emissions targets and let technology suppliers compete for the most reliable and cost effective solutions to meet the limits.
Bit. PC
SubBit. PC
CFB
IGCC (operating)
Source: Energy Velocity database ( EPA CEMS 2005 data )

10. Ultra Clean Coal Combustion Emissions Control Capability
Today’s state-of-the-art
NOx >95% reduction with optimized firing systems and SCR
SO2 >99% capture with Wet FGD and DBA
Particulates 99.99% capture
Hg % capture (coal dependent)
Next steps
Continued improvements
Integrated Multi-pollutant systems to reduce costs
High Hg capture on all coals (without reliance on ACI)
Introduction of CO2 capture

12. Karlshamn Power Plant
Unit 3
Power capacity: 3 x 340 MW
Fuel: Heavy fuel oil (max. 3.5% S)

13. FLOWPAC Karlshamm Performance Levels
Sulfur Content in the Fuel: 2.5%
Inlet Gas Conditions (at ESP outlet)
English
Metric
Flue Gas Flow
~ 870,000 acfm
1,080,000 Nm3/hr
Flue Gas Temp
270°F
130°C
Particulate Matter (PM)
0.025 lb/MMBTU
30 mg/Nm3
Outlet Gas Conditions (at stack)
SO2 (>99% w/ no additives)
< 19 ppmv
< 55 mg/Nm3
SO3 (~70% removal)
< 1 ppmv
< 2 mg/Nm3
PM (>60% removal -oil soot)
< 0.01 lb/MMBTU

14. When Additional Control is Needed - Mercury Capture Technologies
Chemistry:
Hgo: gaseous form as a result of combustion, very difficult to capture
Hg2+: oxidized form, easier to capture
Halogens (Br, Cl) in coal or additive promote oxidation
Adsorption of Hg2+ onto particulate – unburned carbon, carbon additives, flyash, scrubber droplets
Ultimate removal from the system with the flyash and with scrubber byproduct
Mercury Speciation and Impact of Current Controls:
The following major conclusions can be drawn from the ICR database:
• There is a general trend that shows higher mercury levels in lignite followed by
bituminous coal and subbituminous coal. However, the existing air pollution
controls may not show the same trend at the stack outlet.
• Mercury speciation depends on the type of firing, chlorine and sulfur content
of the coal, and probably the ash constituents that may catalyze some of the
reactions during combustion.
• Fabric filters are better in capturing mercury than hot or cold ESPs or than
particulate scrubbers.
• Both dry and wet FGDs are excellent at capturing ionic mercury.
• Both dry and wet FGDs have difficulty in capturing elemental mercury.
• Dry FGDs are somewhat better in capturing elemental mercury than are wet
FGDs (10%–15%).
Additives:
Halogen(s)
Powdered Activated Carbon
Halogenated Powdered Activated
Carbon
= Potential additive injection
points

15. Multi-pollutant APC Systems
Integrated APC systems based around commercially proven and reliable technologies
Use readily available reagents
Produces reusable byproduct(s)
No impact on fly ash
Superior cost/performance ratio:
Extremely compact design
Reduces capital costs for equipment, erection and BOP
Fewer moving parts reduces maintenance costs
Superior environmental performance
Reduced permitting schedule/cost
Avoided cost for SO2 credits
Targeted emissions levels:
SO2: lb/MMBTU (> 99.5%)
Hg: 1.0 lb/TBTU (> 90%)
PM: lb/MMBTU (99.99%)
NOx: 0.05 lb/MMBTU w/SCR
“Polishing” (Level TBD) w/o SCR
Controls SOx, PM10/PM2.5 Mercury & NOx

16. Meeting the Challenge -
Advanced Cycles

17. Increased Value for Efficiency
Annual Fuel Savings, MUSD
500 MW Unit
Efficiency
~$10M/yr 16
42%
40%
38%
36%
~$6.5M/yr 14 12 10 8 6 4 2 20 25 30 35 40 45 50
Coal Price USD/Short Ton
Compared to 34% subcritical efficiency, 11,000 BTU/lb coal, 80% capacity factor

18. Efficiency – Critical to emissions strategy
Source: National Coal Council
From EPRI study
100% Coal
Coal w/ 10% co -
firing
biomass
Commercial
Supercritical
Existing US coal avg 33%
Net Plant Efficiency (HHV), %

19. Clear Trend to Supercritical for Global Steam Power
Worldwide orders for new coal generation

20. 147 GW, 230 Supercritical Coal Fired Boilers Ordered Since 1990
Clear Trend to Advanced Supercritical Cycles
147 GW, 230 Supercritical Coal Fired Boilers Ordered Since 1990 GW
Number of Units
Maximum of SH or RH Temp
Maximum of SH or RH Temp

21. Supercritical Flexible for power grid needs
Operating Performance
Turndown – Supercritical PC/CFB units have
Flexibility to rapidly change load
Turndown to lower minimum loads during off peak
Maintain efficiency when operating at part loads
Excellent startup ramp rates to meet grid demand
Supercritical
Drum
Hot Start Up,
after 2 hr shutdown
Warm Start Up,
after 8 hr shutdown
Cold Start Up,
after 36 hr shutdown

22. Progression of Plant Efficiency via Advanced Steam Conditions and Plant Designs
US-DOE :Ultra-Supercritical Boiler Project
Operating Target: 1400°F/5500 psig
European Thermie Project
Operating Target: 1292°F/ 4500 psig
TARGET %
41%- 43%
38-41%
Up to
5400/1300/1325(psi/°F/°F)
37-38
Advanced USC
35-37%
-Efficiency (net) HHV
Typical Steam Parameters
4000/1110/1150(psi/°F/°F)
3480/1005/1050 (psi/°F/°F)
4000/1075/1110 (psi/°F/°F)
UltraSupercritical
Commercial
State of Art
Supercritical
2400/1005/1005
167/540/540
Sliding
Pressure
Supercritical
Subcritical
Technology
Mature
Supercritical
Ni-based
Materials
Material Development
Advanced
Austenitic
Materials
T91
1960
1980
2000
2010
2020

23. Meeting the Goals for Coal Based Power - Efficiency
Actual efficiency for operating IGCC ~ Operating (old) PC
Efficiency of current proposed IGCC projected to match today’s Supercritical PC
Ultrasupercritical PC and next generation IGCC goals on par
Annual average IGCC efficiency up to 10% lower due to greater inefficiencies at part-load operation

24. Meeting the Challenge
CO2 Reduction

25. Maximize MWs per lb of carbon processed Fuel switch with biomass
CO2 Mitigation Options –
for Coal Based Power
Increase efficiency
Maximize MWs per lb of carbon processed
Fuel switch with biomass
Partial replacement of fossil fuels = proportional reduction in CO2
Then, and only then ….Capture remaining CO2 for EOR/Sequestration
= Logical path to lowest cost of carbon reduction

26. Innovative options continue to emerge and develop
CO2 Capture
Innovative options continue to emerge and develop
Post Combustion Capture
Adsorption
Absorption
Hydrate based
Cryogenics / Refrigeration based
Oxy-fuel Firing
External oxygen supply
integrated membrane-based
Oxygen carriers (chemical looping)
Decarbonization
reforming (fuel decarbonization)
carbonate reactions (combustion decarbonization)

27. Amine-Based Absorption - CO2 Capture
SHADY POINT, OKLAHOMA, USA An AES CFB power plant with MEA CO2 separation
MEA has demonstrated performance on coal based flue gas
Work required to address:
Regeneration power
Compression ratio
Cost of solvent

28. Advancements Absorption Stripping CO2 Capture
Amine scrubbing continues to develop
Ionic Liquids “designer solvents”
“Piperazine” - alternative solvent
Process integration and improvement has driven cost down from 70 to $/ton CO2 --- further progress expected
With industry focus on improvements, advanced amines likely to be competitive solution for post combustion capture

29. CO2 Capture Innovations Chilled Ammonia System
Existing
Stack
Ammonia reacts with CO2 and water and forms ammonia carbonate or bicarbonate
Moderately raising the temperature reverses the above reactions – producing CO2
Regeneration at high pressure
Existing
SO2 Scrubber
Concentrated
CO2 to Sequestration
Flue Gas
Energy
Recovery
Energy
Recovery
Energy
Recovery CO
Energy
Recovery
Energy 2
Recovery
CO2 Absorption Tower
Tower
CO2 Lean
Regeneration
Fluid
Cooling the flue gas to 0-10 oC. Condensing H2O and eliminating residual contamination.Reducing FG volume and increasing CO2 concentration.
Operating the absorber at 0-10 oC for high CO2 capture efficiency with low NH3 emission.
Regeneration at >120 oC and >20 bar to generate high pressure CO2 stream with low moisture and ammonia concentration.
Flue Gas
CO2 Rich
Flue Gas
Cooling
Cooling
System

30. Advantages of Chilled Ammonia
High efficiency capture of CO2
Low heat of reaction
High capacity for CO2 per unit of solution
Easy and low temperature regeneration
Low cost reagent
No degradation during absorption-regeneration
Tolerance to oxygen and contaminations in flue gas

31. We Energies Pleasant Prairie Host Site Location for 5MW Pilot

32. Carbon Free Power Advanced Combustion
Innovative Combustion Options for 2010 and Beyond
Oxygen Firing – Direct concentration of CO2 to >90% for reduced capture costs
Chemical Looping –Leapfrog technology with potential to achieve significantly lower costs than PC/CFB/IGCC

33. Oxygen Firing to produce concentrated CO2 stream
Compressor
Air Separation
Unit (ASU) N 2
Boiler O
, N
Air in-leakage
Fuel
Condenser H CO
Recycle
3 MWt pilot CFB
Oxygen Firing – Direct concentration of CO2 to >90% for reduced capture costs

34. 30 MWth Oxy-fired PC Pilot Plant – Vattenfall
Location of pilot plant in the Industrial Park Schwarze Pumpe
2020
approx. 4 - 5
Commercial
Plant approx.
1000 MWel
2015
Realisation with CO2
sequestration,
1:20
Demo Plant
600 MWth
Vattenfall...,
ALSTOM, others
2008
Test of the oxyfuel
process chain
1:60
Pilot Plant
30 MWth
CEBra, BTU Cottbus,
Vattenfall, ALSTOM
2005
Fundamentals of
oxyfuel combustion
with flue gas
recirculation
1:50
Test Plant
500 kWth
Universities (Stuttgart,
Chalmers, Dresden)
Vattenfall, ALSTOM..
2004
Laboratory
Tests
10 / 55 kWth
Partners
Com
Objective
Scale up
Factor
Development
Steps

35. Future Technologies for CO2 Capture Chemical Looping
Oxidizer
Reducer
CaS
CaSO4
CO2 & H2O
Coal,
Limestone
Air
Depleted Air, Ash,
Chemical Looping
Gasification
Calciner
CO2
CaCO3
Cold Solids
Chemical Looping
Combustion
CaCO3
CaO
Hydrogen
Hot Solids
CaS
Coal is Indirectly Combusted or Gasified by Hot Oxygen Carrying Reactant
The Reactant is not Consumed and is alternately Reduced (oxygen removed) and Oxidized (oxygen replenished) as it Cycles between Reactors
The Reactant also Carries Heat Where Needed
In ALSTOM’s process, Calcium Compounds from Limestone are used as the Reactant
Several Related Processes can be Based on this Concept
Depleted Air, Ash,
CaSO4
Reducer
CaSO4
Air
Oxidizer
Coal,
Steam

36. Technology Choices Reduce Risk and Lower Costs
Multiple Paths to CO2 Reduction Innovations for the Future
‘Hatched’ Range reflects cost variation from fuels and uncertainty
Technology Choices Reduce Risk and Lower Costs
No CO2 Capture
With CO2 Capture
Note: Costs include compression , but do not include sequestration – equal for all technologies

37. Conclusions
New coal fired power plants shall be designed for highest efficiency to minimize CO2 and other emissions
Lower cost, higher performance technologies for post combustion CO2 capture are actively being developed, and more are emerging
There is no single technology answer to suit all fuels and all applications
The industry is best served by a portfolio approach to drive development of competitive coal power with carbon capture technology