Mark A' Gray

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CO2 Reduction Overview
AEPs Perspective on Reducing Carbon Dioxide
Emissions

• Mark A. Gray
• Vice President - Engineering Services
• American Electric Power

June 14-18, 2008 ? The Skirvin Hotel ?
Oklahoma City, OK
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Coal will continue to be the major source of
electricity generation in the U.S.
2005
3826 TWh
EIA Annual Energy Early Release 2008
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CCS is projected to a be an important source of
CO2 reduction
Achieving all targets is very aggressive, but
potentially feasible
EIA Base Case 2007
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Pulverized Coal plants generate twice as much CO2
Than Natural Gas combined cycle plants
CO2 Reduction Necessary to Achieve NGCC Emission
Levels

• NGSC 36
• US Coal Fleet 62
• USC/IGCC
• (subbitum) 57
• IGCC/USC
• (bituminous) 54

Note H.R. Heat Rate (efficiency). Values
represent typical heat rates, used here for
illustrative purposes only.
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Efficiency Is Foundation ofEmissions Reduction
Strategy

• The easiest ton of CO2 to control is the ton not
  emitted
• Higher efficiency lower overall emissions, not
  just CO2
• SO2, NOx, Particulates, and Mercury reduced at
  the /MWhr basis
• Capital Cost for UltraSuperCritical is 3 higher,
  but..
• Steam and Gas Flows are reduced for USC
• Steam Generator is Smaller
• Higher Pressure Less Steam Volume (Smaller HP
  Turbine and Steam Lines)
• Structural Steel is Reduced for USC
• Less coal burned, less lime (DFGDS) used, less
  flyash produced
• Based on 600 MW Unit

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Ultra Supercritical (USC) vs. Subcritical

• USC Unit consumes 180,000 tons Less Coal per Year
  
• 1500 Fewer Coal Train Cars per year
• 12 Fewer Coal Trains per Year or 480 Trains over
  the Life of Plant
• Fuel Savings is 6 Million per Year (at 2/MMBtu)
• 20,000,000 tons less CO2 over 50 year life
  1,000,000,000 less CO2 CCS cost!!
• USC Unit Consumes 1,600 Tons Less Lime per Year
• 16 Fewer Lime Train Cars per Year
• Lime Savings is 120,000 per Year (at 75 per
  Ton)
• FGD Waste is Reduced by 3,600 Tons per Year
• Total Ash FGD Waste is Reduced by 14,000 Tons
  per Year
• 540,000 Tons Reduction over the Life of Plant
• Reduction in Landfill Size by 5-10 Acres
• Emissions Allocations are Reduced
• SO2 Credit Savings is 120,000 per Year (at 800
  per Ton)
• NOx Credit Savings is 235,000 per Year (at 2300
  per Ton)

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Integrated Gasification Combined Cycle (IGCC)

• Excellent choice when considering future CO2
  capture requirements
• CO2 separation from pre-combustion syngas much
  more efficient than from post-combustion flue gas
• Emissions and efficiency are similar to USC coal
  plant with state-of-the-art controls
• Provides fuel flexibility and by-product
  flexibility
• Marketable byproducts
• Reduced landfill requirements
• Polygeneration potential coproduction of power
  and chemicals
• Syngas contains H2, CO, CO2, which are important
  building blocks in chemical manufacturing

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AEP is Investigating the Feasibility of Various
CO2 Capture Technologies

• Pre-combustion capture (IGCC)
• Tail gas/Acid gas capture
• Water-gas shift
• Post-Combustion Capture Existing units
  possibly on new units
• Conventional or advanced amines
• Chilled ammonia
• Modified-combustion capture on PC plants
• Oxy-coal combustion on new generation with
  advanced oxygen separation plant may prove cost
  effective.

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Pre-Combustion (IGCC)Carbon Dioxide Capture from
Syngas

• No pre-investment for carbon capture
• Space in plot plan to be left for retrofit
  systems
• Clean shift will result in greater impact to
  steam cycle

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Post-CombustionCO2 Capture Technology Evaluation

• Evaluated available CO2 capture options,
  considering both commercial and emerging
  technologies
• Commercially available amine based technologies
• Currently installed on much smaller scale than PC
  plant and other industrial applications
• High parasitic demand reduced unit output
• Conventional amine 30-35
• High steam consumption for regenerating solvent
  (60 of parasitic load)
• Requires very clean flue gas (less than 2-3 ppm
  SO2 NOx)
• Alstoms Chilled Ammonia Process (CAP)
• Commissioning pilot facility at WE Energies
  Pleasant Prairie Plant
• Potential for lower parasitic demand
• Power and steam parasitic load target 18-20
• Lower steam consumption
• Requires clean flue gas but less sensitive to
  contaminants
• Significant fresh water production from chilled
  flue gas

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Alstoms Chilled Ammonia ProcessPost-combustion
capture
Flue Gas Low CO2, Very Low SO2,PM,Hg
Flue Gas High CO2, Low Sulfur
Concentrated CO2
Stack
CO2 to Compression with Energy Recovery
Final Wash
Final Wash
SO2 Removal FGD
CO2 Geologic Storage or EOR 1500 2500 psi
Booster Compressor
CO2 Absorber
Flue Gas
Regenerator
Flue Gas Chiller 40-45F
Lean (CO2) Reagent
Rich (CO2) Reagent
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AEP Chilled Ammonia Development Path

• 20 MW (electric) equivalent slip stream.
• 100,000 to 165,000 metric tons of CO2 per year
• In operation mid 2009
• AEPs estimated cost 70MM
• Key objectives are to evaluate Alstoms chilled
  ammonia process and the effectiveness of using
  geological reservoirs for permanent CO2 storage
• 3-5 years of operation

• 300 MW (electric) scale
• 1.5 million metric tons of CO2 per year
• In operation 2012
• Target of 15 to 20 parasitic load (excluding
  compression)
• Require NOx controls and FGD
• CO2 to be used for Enhanced Oil Recovery (EOR) or
  storage depending on selected location

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CO2 Injectivity in the Mountaineer AreaBased on
Battelle/DOE study from 2002-2007
CO2 injection should also be possible in
shallower sandstone and carbonate layers in the
region
Rose Run Sandstone (7800 feet) is a regional
candidate zone in Appalachian Basin
A high permeability zone called the B zone
within Copper Ridge Dolomite has been identified
as a new injection zone in the region
Mount Simon Sandstone/Basal Sand - the most
prominent reservoir in most of the Midwest but
not desirable beneath Mountaineer site
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Mountaineer Storageand Monitoring System Design
Injection Wells
Passive Seismic/Tiltmeters
Surface CO2 HS Gas Meters
Groundwater/Soil Gas
Periodic Brine Sampling
System CO2 PVT Monitoring
Deep Monitoring Wells
Periodic Wireline Logging
Pressure Gauges
Crosswell Seismic
Rose Run
Copper Ridge
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CO2 Storage Key Discussion Points

• Basic storage requirements
• Depth gt 3,000 feet with porous permeable
  formations
• Thick impermeable caprock for containment
• CO2 not a revenue-producing commodity in the long
  term
• Geology dependent
• May require large number of wells and many square
  miles of well fields
• Sources may be far from storage capacity
  Pipelines likely
• Deep saline vs. EOR
• EOR is niche market open mostly to early adopters
• Deep Saline Permanent storage
• EOR CO2 recycle and store
• Unclear on how much permanently stored
• EOR displaces fluid CO2 for Oil, saline storage
  adds fluid to reservoir
• Other challenges with storage
• Not proven yet in production applications
• Capacity and injection rates very site-specific
• Impacts of trace components in product CO2
• Water, oxygen, ammonia, sulfur, etc
• Co-mingling of multiple compositions from
  multiple sources

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Questions ?