Alstom Boilers

Alternative FuelsPresentationCHOA

May 2006May 2006

ALSTOM Today

EnergyEnergyEnergyEnergy

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2

The new ALSTOMThe new ALSTOMThe new ALSTOMThe new ALSTOM

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Power Power

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N°1 to N°3

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A global leader in infrastructure A global leader in infrastructure A global leader in infrastructure A global leader in infrastructure for Power Generation and Rail Transportfor Power Generation and Rail Transportfor Power Generation and Rail Transportfor Power Generation and Rail Transport

PowerPower

EnvironmentEnvironment

N°1

� Boilers (Utility, Industrial and HRSGs)

� Environmental (Air Pollution Control)

� Large Steam Turbines

� Large Gas Turbines

� Turbo-generators

� Heat Exchange Systems

� Hydro Power Plants

� BOP, Electrical & Control Systems

� Power Plant construction and maintenance services

� Turnkey power plants

Alstom Technologies / Capabilities

Flue Gas

Desulfurization– Wet FGD

– Dry FGD

– FDA

Particulate

Control– Fabric Filter

– Electrostatic

Precipitator

Ash

Handling

Pulverizer

Boiler

Steam Turbine

and Generator

-SCR Systems

-SCONOx

Construction

Substation

Systems

Air Preheater

NOx Control

Fossil Fuel Power PlantFossil Fuel Power PlantFossil Fuel Power PlantFossil Fuel Power Plant

Alternative Fuels

May 2006May 2006

Alberta Natural Gas Price

$0

$2

$4

$6

$8

$10

$12Nov-99

Jul-00

Mar-01

Nov-01

Jul-02

Mar-03

Nov-03

Jul-04

Mar-05

Nov-05

NGX/AECO

$/GJ

Boiler Fuels

CoalCoalCoalCoal

PetcokePetcokePetcokePetcoke

Coal

Biomass

Waste Coals...

Oil Refining WastesSludge

and other Industrial Wastes

Gas &

Oil

FUEL OPTIONS

Coal $0.50 to $2.00 / GJ

Petcoke

Asphaltene $-0.50 to $0.50 / GJ

Residual

Natural Gas $5.50 to $15.50 / GJ

Bitumen $6.00 to $14.50 / GJ

BOILER & EMISSION CONTROL TECHNOLOGY

May 2006May 2006

Industrial Suspension Fired Boiler

Pulverized Coal Boiler (PC)

Circulating Fluidized Bed Boiler (CFB)

Modular CFB Boilers

POLLUTANTS CONTROLLED

Sulfur Oxides

Nitrogen Oxides

Particulate Matter

Halides

Heavy Metals

Organic Matter

Mercury

AIR POLLUTION CONTROL

Air Pollution Control Development

1950s 1960s 1970s

1980s

1990-2000 End Product Recovery

and Utilization

DESOXDENOX

“Tall Stack

Concept”

DESOX

Emission Control Technologies

Particulate Control:Particulate Control:Particulate Control:Particulate Control:

• Dry Electrostatic Precipitators (ESP)

• Wet Electrostatic Precipitators ( WESP)

• Pulse Jet Fabric Filters (HRFF)

• Reverse Air Fabric Filters (LRFF)

• Venturi Scrubbers (VS)

• Condensing Scrubbers (MoDo)

Emission Control Technologies

Flue Gas Flue Gas Flue Gas Flue Gas DesulfurizationDesulfurizationDesulfurizationDesulfurization & Acid Gases:& Acid Gases:& Acid Gases:& Acid Gases:

� Wet Lime/Limestone Flue Gas Desulfurization (WFGD)

� Wet Sodium FGD and Acid Gases Absorption (WSFGD)

� Seawater FGD (SWFGD)

� Dry Lime Flue Gas Desulfurization (DFGD)

� Flash Dryer Absorber (FDA)

� Selective Catalytic Reduction (SCR)

DFGD Process FlowDry Recycle

Spray Dryer

Fabric Filter I.D. Fan

Slaker

FeedTank

StorageTank

B

B

Lime

Water

RecycleSiloWater

Disposal

Flue Gas

Disposal

MAKE-UP WATER TANK

TO WWTS

HYDROCLONE

BELT FILTER

SPRAY TOWER ABSORBER

ELECTROSTATIC PRECIPITATOR

STACK

WATER

AIR

LIMESTONE

BALL MILL

TO BALL MILL

FROM MW TANK

GYPSUM

WFGD Process Diagram

Limestone/Forced Oxidation

SO2(Sulphur dioxide)

H2O(Water)

CaCO3(Calcium carbonate,

limestone)

O2(Oxygen)

CaSO4•2H2O(Calcium sulphate,

gypsum)

CO2(Carbon dioxide)

SO2 + CaCO3 + ½O2 + H2O →→→→ CaSO4•2H2O + CO2

Limestone/Forced Oxidation

Boiler / Environmental Equipment Boiler / Environmental Equipment Boiler / Environmental Equipment Boiler / Environmental Equipment ArrangementsArrangementsArrangementsArrangements

Boil SCR AH FF/ESP ID FAN WFGD WESP STACK 1

Boil SCR AH FF/ESP ID FAN WFGD STACK 2

Boil SCR AH SDA-DFGD FF/ESP ID FAN STACK 3

Boil SCR AH FDA-DFGD FF/ESP ID FAN STACK 3

CFB AH FDA-DFGD FF/ESP ID FAN STACK 1

CFB AH FF/ESP ID FAN STACK 3

Typical ~NOx Typical ~SO2 Typical Typical ~SO2 ~H2SO4 TypicalBoiler Cooling PM10 Gas Flow ~ PM 2.5 Discharge

1. Max Multi-Control (NOx + SOx + H2SO4 burning high sulfur fuel)2. NOx + SOx Control burning mid-level sulfur fuel (~2%)3. NOx + SOx + H2SO4 burning low/mid sulfur fuel (<2%)

SNCR

CFB BOILER PRESENTATION

May 2006May 2006

Copyright 2005 ALSTOM

ALSTOM CFB Timeline

1X300 MW (RH)2X300 MW (RH)2X300 MW (RH)

1986 1987 1989 1990 1993 1996 2000 2004

Baima,Kaiyuan,

Qinhuangdao

Baima,Kaiyuan,

Qinhuangdao

Scott Paper

Scott Scott PaperPaper

1x 65 MW

CFB

IONE Westwood NEPCO Ultra-Systems

IONE IONE Westwood Westwood NEPCO NEPCO UltraUltra--SystemsSystems

7 Units15-43 MW

CFBThames Shady Point

Thames Shady Point

5X75 MW (RH)

CFB Texas-New Mexico

Texas-New Mexico

2X155 MW (RH)

CFB WarriorRun

WarriorWarrior

RunRun

1X210 MW (RH)

CFBProvence,KEPCO

Provence,KEPCO

1X250 MW (RH)1X220 MW (RH)

CFB

CFB

Guayama,Red Hills,Seward.

E. KentuckySulcis

Guayama,Red Hills,Seward.

E. KentuckySulcis

2X250 MW (RH)2X250 MW (RH)2X290 MW (RH)1X260 MW (RH)1X340 MW (RH)

CFB

0000

100100100100

200200200200

300300300300

400400400400

500500500500

600600600600

700700700700

800800800800

19

76

19

76

19

76

19

76

19

79

19

79

19

79

19

79

19

82

19

82

19

82

19

82

19

85

19

85

19

85

19

85

19

88

19

88

19

88

19

88

19

91

19

91

19

91

19

91

19

94

19

94

19

94

19

94

19

97

19

97

19

97

19

97

20

00

20

00

20

00

20

00

20

03

20

03

20

03

20

03

CFBs - Proven Technology

Year of OrderYear of OrderYear of OrderYear of Order Year of OrderYear of OrderYear of OrderYear of Order

MWeMWeMWeMWe NumberNumberNumberNumber

Cumulative Capacity (Cumulative Capacity (Cumulative Capacity (Cumulative Capacity (MWeMWeMWeMWe) Cumulative Number of UnitsCumulative Number of UnitsCumulative Number of UnitsCumulative Number of Units

0000

10000100001000010000

20000200002000020000

30000300003000030000

40000400004000040000

50000500005000050000

19

76

19

76

19

76

19

76

19

79

19

79

19

79

19

79

19

82

19

82

19

82

19

82

19

85

19

85

19

85

19

85

19

88

19

88

19

88

19

88

19

91

19

91

19

91

19

91

19

94

19

94

19

94

19

94

19

97

19

97

19

97

19

97

20

00

20

00

20

00

20

00

20

03

20

03

20

03

20

03

OverOver 46,000 46,000 MWeMWe, , overover 700 700 unitsunits

CFB Process SchematicFuel + Limestone + Air = Clean Power

Superheat and/or Reheat

Economizer

Air Out

Air

Heater

Air

InFabric Filter

or

Electrostatic

PrecipitatorI.D.

Fan

Stack

To

Ash Silo

Sec.

Air

Fan

Prim.

Air

Fan

Superheat/

Reheat and/or

Evaporative

Surfaces

Fluid

Bed Heat

Exchanger

Scal Pot

Cyclone

Furnace

Cooling Water

Ash Cooler

Secondary Air

Fuel Storage

Crusher

Limestone StorageDrum

Ash

Refractory Surface

Superheat or Reheat Surface

Evaporative Surface

Superheat and/or

Evaporative

Surfaces

Limestone

CrusherLimestone

Day Bin

Fuel

Day

Storage

Gravimetric

Feeder

Blower

Primary

Air

Gravimetric

Feeder

Reheat as an option

External FBHE as option

ALSTOM Power ALSTOM Power ALSTOM Power ALSTOM Power ---- Leadership in CFB TechnologyLeadership in CFB TechnologyLeadership in CFB TechnologyLeadership in CFB Technology

CFB DriversCFB DriversCFB DriversCFB Drivers

Clean Power

� Environmentally AcceptableEnvironmentally AcceptableEnvironmentally AcceptableEnvironmentally Acceptable

– SO2 removal without FGD

• Removals as high as 98.5% with FDA

– Inherent low NOx

• low combustion temperatures and staged combustion

� Fuel FlexibilityFuel FlexibilityFuel FlexibilityFuel Flexibility

– Multiple and low grade fuels

� Dry Ash disposal/ Reuse byDry Ash disposal/ Reuse byDry Ash disposal/ Reuse byDry Ash disposal/ Reuse by----productproductproductproduct

� High ReliabilityHigh ReliabilityHigh ReliabilityHigh Reliability


Experience With a Wide Range of Fuels

ALSTOM Power CFB experience includes:

� Anthracite

� Bituminous coal

� Subbituminous coal

� Lignite

� Brown Coal

HHV Btu/lb 14000 1050

HHV MJ/kg 33 2.4

Moisture 62% 3%

Ash 76% 4%

Carbon 71% 19%

Sulfur (maf) 13% 0.3%

Constituent LowHigh

A wide range of constituents


• Petroleum coke

- delayed and fluid

• Biomass

- ranging from wood chips to olive pits to paper mill sludge

• Coal wastes

- anthracite culm, anthracite silt, bituminous gob, washery wastes

• Oil shale (test unit)

• Sewage sludge

High Volatile Fuel

Low Volatile Fuel

CFB’sCFB’s w/SNCR

CFB Emissions TrendsNOx Emissions - BACT Region 5

0

0.05

0.1

0.15

0.2

0.25

0.3

0.35

1985 1995 2005

NOx Emissions (lb/MMBTU)

Emission Trends

86

88

90

92

94

96

98

100

1985 1995 2005

SO2 Removal (%)

CFB Emissions Trends SO2 Removal -BACT Region 5

CFB w/ FDA

FDA DFGD ProcessFDA DFGD ProcessFDA DFGD ProcessFDA DFGD Process

TC Fabric Filter

Recirculation

Humidifier

Water

Reagent End Product

• High recirculation

• No slurry handling

• “Dry” product ~5% water

• High utilization of reagent

• Fresh Lime for PC Boiler

• No Fresh Lime for CFB

CFBs - High Availability

High availabilities with both wasteHigh availabilities with both waste fuels fuels and coaland coal

%

Percent of Time Boiler Available in 2004

Source: CIBO forUS CFBsNote: Culm and gob are wastes associated with the mining or processing of anthracite and bituminous coal respectively

0000

10101010

20202020

30303030

40404040

50505050

60606060

70707070

80808080

90909090

100100100100

Plant size & fuel typePlant size & fuel typePlant size & fuel typePlant size & fuel type

1-39 MW coal1-39 MW coal1-39 MW coal1-39 MW coal

40-99 MW coal40-99 MW coal40-99 MW coal40-99 MW coal

40-99 MW40-99 MW40-99 MW40-99 MWculmculmculmculm

40-99 MW gob40-99 MW gob40-99 MW gob40-99 MW gob

>=100 MW>=100 MW>=100 MW>=100 MWcoalcoalcoalcoal

CFB boiler Benefits

� Multiple Waste Fuel capabilities– Co-Firing with waste wood (CO2 emissions Credit)

� Low emissions (NOx, SOx )

� High boiler efficiencies – (90 % Petcoke)– Less Fuel burnt (Lower CO2 emissions)

� Superheated steam– Capital efficiency (higher heat output/capital)

– Plant efficiency (Lower CO2 emissions)

� Customized steam conditions and electrical production– BP steam turbine with process extraction

� Low boiler blowdown ~ 1%– Less recycle, power consumed (Lower CO2 emissions)

� Dry SO2 / SO3 capture process (No water consumption)

� Dry bottom/fly ash (construction applications)

� CO2 capture ready

34

Boiler Water Limits

Maximum Boiler Water Concentrations

DrumPressure

psig.

Boiler WaterRange of Totaldissolved Solids

ppm Max.

Boiler WaterRange of TotalAlkalinity

ppm

Boiler WaterSuspendedSolids

ppm Max

Steam Range of TotalDissolved Solids(exclusive of Silica)

ppm Max

0 - 300 700-3500 140-700 15 0.2 – 1.0

301 - 450 600 – 3000 120 – 600 10 0.2 – 1.0

451 – 600 500 – 2500 100 – 500 8 0.2 – 1.0

601 – 750 200 – 1000 40 – 200 3 0.1 – 0.5

751 – 900 150 – 750 30 – 150 2 0.1 – 0.5

901 – 1000 125 – 625 25 – 125 1 0.1 – 0.5

1001 - 1800 100 TBD 1 0.1

CO2 Capture

May 2006May 2006

CO2 Reduction/Capture

1. Efficiencies– Boiler (combustion air, fuel, moisture, flue gas temp)

– Plant (electrical, superheat)

2. Waste Wood Co-Firing

3. Oxygen-Fired CFB (combustion)

4. CO2 Frosting (back-end)

5. Advanced Chemical Looping

CONDNESATE

GASRECIRCULATION

FAN

FLUIDIZING

GASBLOWER

COMBUSTOR

Cyclone

BACKPASSHEAT

EXCHANGERS

CFB Steam Generator Unit

ASH

COOLER

ExternalHeat

Exchanger

NITROGENAIR

INDUCED DRAFTFAN

AIRSEAPARATION

UNIT

GasCooler

PARTICULATEREMOVALSYSTEMOXYGEN

HEATER

PFWH

LIMESTONE

COAL

OXYGEN

AIRINFILTRATION

Compressor

Air SeparationUnit (ASU)

N2

BoilerO2

O2, N2

Air in-leakage

Fuel

Condenser

H2O

CO2 Recycle

Front-End

Tail-End

Integrated

Oxygen Firing to produce concentrated CO2 stream

The “Oxy-fuel” concept

CO2-Rich Productto Gas Processing

System

ExisitingFGD

ExistingStack

2 stageCooling

Chiller

CO2Absorber

Regenerator

HX

CO2

HPPump

Wash

Wash

Reboiler

Schematic of commercial Ammonia-based CO2 capturesystem retrofited downstream of the FGD

Flue Gas

Water

Rich Slurry

Lean Slurry

CO2

Flue Gas

Purge

Lean AC

Rich ABC

120F

35F

Cooling & Cleaning of FG CO2 Absorption CO2 Regeneration

The system is expected to achieve 90% removal of CO2 and high removal of residualSO2, HCl, HF, SO3, PM2.5.The CO2 capture system has the following main subsystems:1. Flue Gas Cooling.2. CO2 absorption.3. Pressure regeneration.

CO2 Frosting

Advanced Chemical Looping

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Alstom Boilers