Overview of the Kemper County IGCC Project Using Transport Integrated Gasification (TRIGTM)

Coal BarnEmergency Crushed Coal

Coal

Transport Integrated Gasification (TRIGTM)

Flare Derricks

Control/Admin Bldg

Coal Preparation

Gasifiers, Syngas Coolers, PCDsProcess Air

Compressors

StackCoal Loading Hoppers

Combined

Water Treatment Bldg

Sulfuric Acid Production

Cooling Towers

CycleCO2/Sulfur Removal Area

2010 Gasification Technology Conference2010 Gasification Technology ConferenceWashington, D. C. - November 1, 2010

Kemper County IGCC Project Overview2x1 Integrated Gasification Combined Cycle (IGCC)2x1 Integrated Gasification Combined Cycle (IGCC)

– 2 TRansport Integrated Gasifiers (TRIG™)– 2 Siemens SGT6 - 5000F CTs– 1 Toshiba Steam Turbine (Tandem Compound Double Flow)

582 MW k d 524 MW – 582 MW peak and 524 MW on syngas– Heat Rate 11,708 Btu/kWh (29.5% HHV Efficiency w/ CO2

control and 40+% moisture coal)– Selexol for H2S and CO2 removal

65+% CO t ( 800 lb/ Wh i i t )

Plant SitePlant Site

– 65+% CO2 capture (~800 lb/mWh emission rate)– Mine Mouth Lignite

Owner & Operator: Mississippi PowerOver $2 billion capital investmentCommercial Operating Date: May 2014Use treated effluent from Meridian as makeup waterBy-Products (TPY)

~3 000 000 - Carbon dioxide used for EOR– 3,000,000 - Carbon dioxide used for EOR– ~135,000 - Sulfuric acid– ~20,000 - Ammonia

Kemper Lignite CompositionAverage Min Max

Heat Content btu/lb 5,290 4,765 5,870Moisture % 45.5 42 50Ash % 12.0 8.6 17Sulfur % 1.0 0.35 1.7

Kemper County IGCC Project Map Plant Site

Meridian

~ 70 miles transmission

~ 60 miles CO2 pipeline (for EOR)2 p p ( )

~5 miles natural gas pipeline

~31,000 acre mine site

~2,900 acres plant siteNew CO2Pipeline

~ 30 miles treated effluent line

Visual Comparison of Main Gasifier Types(Not to Scale)

GE Conoco TRIGTMShell SiemensSyngas

MHISyngas

CoalCoalCoal

Air

Oxygen

Oxygen-blownThe image cannot be displayed. Your computer may not have enough memory to open the image, or the image may have been corrupted. Restart your computer, and then open the file again. If the red x still appears, you may have to delete the image and then insert it again.

Oxygen-blownThe image cannot be displayed. Your computer may not have enough memory to open the image, or the image may have been corrupted. Restart your computer, and then open the file again. If the red x still appears, you may have to delete the image and then insert it again.

No burner-blown

The image cannot be displayed. Your computer may not have enough memory to open the image, or the image may have been corrupted. Restart your computer, and then open the file again. If the red x still appears, you may have to delete the image and then insert it again.

Air- -blownor O2

Burner- type, slaggingThe image cannot be displayed. Your computer may not have enough memory to open the image, or the image may have been corrupted. Restart your computer, and then open the file again. If the red x still appears, you may have to delete the image and then insert it again.

Burner- type, slagging No-burnerNon-slaggingNo-burner

Non-slagging

Development of the TRIG™ for Power and Chemical ProductionChemical Production

TRIGTM Leverages Long History of KBR Fluid Catalytic Cracking (FCC) Expertise

FirstC i l Late

30's

1942

CommercialFCC Unit

for Exxon

Orthoflow™A Design

1951

Early

Orthoflow™C Design

ResidFCCs Early

1960's

19761980's 1990 1996 1996 China 2011 USA 2014

FCCs

Orthoflow™ F Design

Design Based on FCC Technology

Pilot PlantTech Center

Grand Forks, ND2,600 Hours Test Run

PSDF at Wilsonville, AL. >14,600 hrs in gasification >2,200 hrs on

TRIGTM In Kemper County, MS, USA & Dong Guan, China

Mississippi Lignitethru Dec ‘09

TRIGTM IGCC Attributes / Advantages

Simple, Well Established Design– Based on technology in use for 70 years

Either Air- or Oxygen-Blown

First Separation

Device

Syngas

yg– Air for power– Oxygen for liquid fuels and chemicals

High Reliability Design– Non-slagging design:

RiserSecond

Separation Device

Provides 10-20 year refractory life Eliminates black water systemProvides non-fouling syngas cooler operation

– No burners to fail and be replaced– Dry dust removal eliminates gray water system

Upper Mixing Zone

Seal Lower Fuel Costs

– Coarse, dry coal feed allows:Fewer, lower power pulverizersLess drying than other dry-feed gasifiers

Cost effective using high moisture high ash low

Standpipe

J-Leg

Seal LegCoal

Air

– Cost-effective using high moisture, high-ash, low rank coals (PRB and lignite)

Excellent Environmental Performance– Lower water use compared to pulverized coal (PC)– Excellent emissions performanceLower

Startup Burner

Stp

– Lower cost carbon capture compared to PCLower Mixing Zone

SteamOxygen

Kemper Primary Syngas Cooler(Commercial Design by Borsig)

PDSF cooler Inlet after 1300 hrs operation

Non-slagging design leads to no fouling vs slagging gasifier designsNever fouled with coal ash Temperature reduction ~800 to 1000 0F

Dry Particulate Filtration – Proven OperationPressure Drop – Note Return to Baseline after each Pulse

Beginning of run End of run

Pressure Drop – Note Return to Baseline after each Pulse

Sizing Hot Gas Filters Based on Ash Characteristics

Stable baseline pressure dropExcellent filtration performance >99.9999%Highly reliable failsafe system Typical Run Outlet Particle Loading

2 42.83.2

on, p

pmw

Turbine specification, 2.4 ppmw

Failsafes

R = drag, inwc/(ft/min)/(lb/ft2)

Relat

ive F

ilter S

ize

100150

200

250300

350

400 Subbituminous, 40% CarbonSubbituminous, 25% CarbonLignite, 10% CarbonLignite, 20% Carbon

0.40.81.21.6

22.4

e C

once

ntra

ti

Note Margin

Allowable Pressure Drop, inH2O60 80 100 120 140 160 180 200

R

050 0

0 100 200 300 400 500 600Run HoursPa

rtic

l

Kemper Dry Ash Filter(Commercial Design By Pall)( g y )

Continuous Coarse Ash DepressurizationContinuous Coarse Ash Depressurization(Gasifier Level Control Performance)

240

230

235

Level / SPT

220

225

210

215 • 100% Reliability since 1st Day of Operation • High Capacity• No Moving Parts

N P i i G N d d

CCAD Level Ctrlr CCAD Level Ctrlr 1:00 2:00 3:00 4:00 5:00 6:00 7:00 8:00 9:00 10:00 11:00 12:00 13:00 14:00 15:00 16:00 17:00

205

200

• No Pressurizing Gas Needed• Small & Clean Gas Venting• Transport using inherent gas

Confidential and Proprietary

Typical Coal Feed Particle SizeTransport Gasifier vs Pulverized Coal p

161820

mic

rons

, %

90

100

Sieve Size, Mesh

1420354248606580100

115

150

170

200

250

270

325

400

810121416

grea

ter t

han

1180

m

Moisture Content Must Also Be <25%

% P

assi

ng

50

60

70

80

02468

cent

age

of P

artic

le g

0 0 0 0 0 0 0 0 0 0 0 0 0 00 010

20

30

40

PC Boiler Transport Gasifier

0 5 10 15 20 25 30Percentage of Particle less than 45 microns, %

Perc

PDAC Feeder Operation

Particle Size, μm

40 50 60 70 80 90 200

300

400

500

600

700

800

900

100

1000

Feed

Rat

e, lb

/hr

M d C l F d R t

0 2 4 6 8 10 12 14 16 18 20 22 24Time, hours

Coa

l F Measured Coal Feed Rate

Coal Feed Rate Setpoint

Kemper CO2 Capture SchemeTwo Stages WGSSelexol Physical SolventRefrigerated to 40°F

Carbon Capture: 65+%CO2 Emissions: 800 lb CO2/MWhYield: >3 MM Tons/yr CO2

Kemper County TRIGTM 3-D PerspectiveHRSGs

Gas Turbines Steam Turbine

Air Compressors

HP Coal Feeders

CO2 and H2S RemovalRemoval

Gasifiers (2)

Fluid Bed Dryer System

Sulfuric Acid ProductionProduction

Flare Derricks

Kemper County TRIGTM 3-D Perspective

Sour Water/NH3 Recovery System

H2S Absorbers (2)

Particulate Collection Device (PCD)

Dry Ash Filters (4)

CO2 Compressors

AGR Regenerators

Crushed Coal Silos

Gasifiers (2)

CO2 Absorbers (6)

CO2 Flash Drums (8)

Main Syngas Coolers (4)

HP Coal Feeders (12)

2 ( )

Syngas COS Hydrolysis

NH3 Removal

Mercury Adsorbers

Coal Mills (6)Back-pulse

S D

WGS R t

y gHumidifiers

COS HydrolysisSurge Drums

Admin. Bldg.

Steam Turbine

Process Air Compressors

WGS ReactorsWarehouse

Kemper County TRIGTM(A Sense of Scale)( )

Water Gas Shift (WGS) Reactors

(12)WGS RecuperatorWGS R t

High Temp Syngas Recuperator (2)

Syngas Saturator/Scrubber Recuperator (2)

WGS Recuperator (2)

WGS Reactor Isolation Valves

Recuperator (2)

6’ Person

Kemper Status/Summary ScheduleOn June 3, 2010, the Mississippi Public Service Commission issued a Certificate of Convenience & Necessity for the project authorizing construction. Construction began after PSC certification. DOE has issued a Record of Decision on for the NEPA process related to CCPI funding.MDEQ i d th fi l PSD it M h 9 2010MDEQ issued the final PSD permit on March 9, 2010.2009

1st 2nd 3rd 4th2010 2013 201420122011

1st 2nd 3rd 4th 1st 2nd 3rd 4th 1st 2nd 3rd 4th1st 2nd 3rd 4th1st 2nd 3rd 4th

Detail DesignLong Lead Procurement

Bulk Equip. Procurement Sitework

Piling/CaissonsFoundations

Today

FoundationsGI General Contractor

CC General ContractorStart-up

CODy CO

Kemper CountyConstruction Mid-Oct 2010Initial clearing & grubbing for TRIG™ site complete

Earthwork to begin Week of 10/4g

Foundation work to begin next year.

Majority of construction work slated for 2012.

TRIGTM IGCC Attributes / Advantages

Simple, Well Established Design– Based on technology in use for 70 years

Either Air- or Oxygen-Blown

First Separation

Device

Syngas

yg– Air for power– Oxygen for liquid fuels and chemicals

High Reliability Design– Non-slagging design:

RiserSecond

Separation Device

Provides 10-20 year refractory life Eliminates black water systemProvides non-fouling syngas cooler operation

– No burners to fail and be replaced– Dry dust removal eliminates gray water system

Upper Mixing Zone

Seal Lower Fuel Costs

– Coarse, dry coal feed allows:Fewer, lower power pulverizersLess drying than other dry-feed gasifiers

Cost effective using high moisture high ash low

Standpipe

J-Leg

Seal LegCoal

Air

– Cost-effective using high moisture, high-ash, low rank coals (PRB and lignite)

Excellent Environmental Performance– Lower water use compared to pulverized coal (PC)– Excellent emissions performanceLower

Startup Burner

Stp

– Lower cost carbon capture compared to PCLower Mixing Zone

SteamOxygen