oxyoxy--combustion for coal fired power plant combustion ... ieaghg (sicily presentatio… ·...

OxyOxy--Combustion for Coal Fired Power Plant Combustion for Coal Fired Power Plant with COwith CO22 CaptureCapturewith COwith CO22 CaptureCapture

Review of the Past 20 Years of R&D ActivitiesReview of the Past 20 Years of R&D ActivitiesWhat are the Different Technical Issues and Challenges to Its DevelopmentWhat are the Different Technical Issues and Challenges to Its Development

By

Stanley SantosIEA G h G R&D PIEA Greenhouse Gas R&D Programme

Cheltenham, UK

http://www.ieagreen.org.uk*Corresponding Author’s Email: [email protected]

Presentation OutlinePresentation OutlineIEA G h G R&D P• IEA Greenhouse Gas R&D Programme○ Introduction to IEAGHG and its activities.

• Introduction to Oxy-Coal Combustion with CO2 Capture inIntroduction to Oxy Coal Combustion with CO2 Capture in Power Generation○ General overview of the Oxy-Combustion○ Historical perspective in development of oxy-coal combustion with

CCS for application in power generation○ Technical considerations and issues in the development of oxy-coal p y

combustion with CCS in the perspective of power generation (retrofit or new built power plants)

• Concluding Remarks

http://www.ieagreen.org.uk 2

Concluding Remarks

I t d ti tI t d ti tIntroduction to Introduction to IEA Greenhouse Gas R&D ProgrammeIEA Greenhouse Gas R&D Programme

(IEAGHG)(IEAGHG)(IEAGHG)(IEAGHG)

http://www.ieagreen.org.uk

Introduction to IEAGHGIntroduction to IEAGHG• The IEA (Legal) Framework:• The IEA (Legal) Framework:

○ Common rules for participation in IEA Implementing Agreements (IA);○ Some 40 of these IA are listed at http://www.iea.org○ Participants can be:

Contracting Parties (intergovernmental organisations, countries or designated representatives)g p )Sponsors (private sector enterprises not designated by a government)

○ IEA GHG is an IA in which the Participants contributing to a common fund to finance the activities.fund to finance the activities.

Funding is approximately 2 million US$/year.


Current MembershipCurrent Membership


The Programme is supported by 17 governments, EC and 17 sponsors

Introduction to IEAGHGIntroduction to IEAGHG• A collaborative research programme which started

in 1991It i l i t l t t h l i th t• Its main role is to evaluate technologies that can reduce greenhouse gas emissions.

• The Programme’s Objective:To provide members with definitive informationTo provide members with definitive information on the role that technology can play in reducing

greenhouse gas emissions


g g

Activities of IEAGHGActivities of IEAGHGWhat does the Programme do now?What does the Programme do now?

• New 5-year phase started in 2005:○ 3 Main activities:

Generate technology and market informationConfidence buildingInformation disseminationInformation dissemination

○ Aimed at answering:How do mitigation options compare?g p pCan the option be done safely and legally?What needs to be done to introduce the mitigation option and be confident it will be successful?


option and be confident it will be successful?

IEAGHG ActivitiesIEAGHG Activities

• This IA has been operating for 15 years. • IEAGHG has:

○ Accumulated >100 studies covering carbon capture and storage (CCS), other mitigation technologies,and storage (CCS), other mitigation technologies, and alternative energy carriers.

○ Succeeded in establishing CCS as a mitigationSucceeded in establishing CCS as a mitigation option capable of major reductions in the emission of CO2 to atmosphere.


p

IEAGHG IEAGHG -- Completed StudiesCompleted Studies• In the previous year some of the member’s studies completedIn the previous year, some of the member s studies completed,

include:○ Comparison of power plants with CO2 capture technologies○ CO2 capture at low rank coal power plants○ CO2 capture at low rank coal power plants○ Near-zero emission power plants○ Environmental assessment for CO2 capture and storage○ Permitting issues for CO2 capture and storage○ Permitting issues for CO2 capture and storage○ Cost and capacity for CO2 storage in Europe and N America○ Monitoring requirements for CCS○ Safe storage of CO2 – analogies with the natural gas industrySafe storage of CO2 analogies with the natural gas industry○ Use of CDM for CCS○ More than 100 studies completed . . .


IEAGHG Studies (cont’d)IEAGHG Studies (cont’d)• For 2007 IEAGHG will be releasing the following member’sFor 2007, IEAGHG will be releasing the following member s

studies:○ Report on Capture Ready Plant

Work done in cooperation with IEA under task required by theWork done in cooperation with IEA under task required by the Gleneagles G8 meeting

○ Techno-economic evaluation of co-production of hydrogen and electricity with carbon capture

○ CO2 capture in the cement industry○ Many others…

• Full Listing of our studies – please contact us atg [email protected]


IEAGHG Research NetworkIEAGHG Research Network• Objectives• Objectives

○ To provide an avenue for discussion on specific issues toward development of CCS and support any confidence building activities

○ http://www.co2captureandstorage.info/networks/networks.htmp p g

• IEAGHG manages 6 Research Networks○ International CO2 Capture Networkp○ International Oxy-Combustion Network○ Biofixation Network○ Monitoring Network○ Risk Assessment Network○ Well Bore Integrity Network


Participants from 2nd Oxy-Combustion Workshop (CT, USA – Jan. 2007)

GHGT Conference SeriesGHGT Conference Series• IEA GHG is the guardian of the• IEA GHG is the guardian of the

GHGT conference series• Latest GHGT-8 held in Trondheim,

Nor a attracted more than 950Norway attracted more than 950 delegates

• Premier international conference on h t l t h lgreenhouse gas control technology

• Next conference (GHGT-9) will be held at Washington D.C. USA -November 2008○ http://mit.edu/ghgt9/


Communication & Information DisseminationCommunication & Information Dissemination

Quarterly newsletter

Topical ReportsTopical Reports


OxyOxy--Combustion Application in the IndustryCombustion Application in the Industry(General Overview)(General Overview)


Development of OxyDevelopment of Oxy--Fuel Combustion Application in IndustryFuel Combustion Application in Industry


Adapted from slide of Sho Kobayashi, Praxair

Pictures from IFRF, Air Liqiude, Asahi Glass, Linde Gas

OxyOxy--Combustion with COCombustion with CO22 Capture for Capture for Coal Fired Power StationCoal Fired Power Station


Historical Perspective (1980 Historical Perspective (1980 –– 2000)2000)• 1982: Initial suggestion by Abraham et. al. (1982) of using Oxy-Coal Combustion to

produce CO2 for EOR○ 1st public document looking at capturing CO2 from flue gas using oxy-combustion.

• As early as 1978 – economic feasibility of oxy-coal combustion was investigated for EOR li ti (H F B b k & Wil / A W l k ANL)EOR application (H. Farzan, Babcock & Wilcox / A. Wolsky, ANL)

• 5 major pilot scale studies between 1980 - 2000○ ANL Research Programme

B tt ll (115 kW)Battelle (115 kW)EERC (3 MW)

○ EU – IFRF IFRF (2.5 MW)MBEL – Air Products – Naples & Ulster University (150 kW)International Combustion – Imperial College – EDP – IST (150kW & 35MW)

○ NEDO – IHI (1.2 MW)CANMET (300 kW)


○ CANMET (300 kW)○ US DOE – B&W / Air Liquide (1.2 MW)

17

ANL ANL -- EERC StudyEERC StudyWorld’s 1st OxyWorld’s 1st Oxy--Coal Industrial Pilot Scale StudyCoal Industrial Pilot Scale Study

( )( )Tower Furnace (~ 3MWth)Tower Furnace (~ 3MWth)


OxyOxy--Coal / Fuel Oil Combustion Boiler ProjectsCoal / Fuel Oil Combustion Boiler Projects(1 (1 MWeMWe = 3 = 3 MWtMWt = 10 = 10 MMBtuMMBtu/hr)/hr)

1000 01000 0300.0

100 0

1000.0SASK Power

UtilityB il

300.0

100 0

1000.0SASK Power

UtilityB il

11.7

20.010.0

10.0

25.030.0

10.0

100.0

MW

e International CombustionVattenfall

CS Energy

TOTAL

DOOSAN-BabcockJupiter

J it

Boilers

11.7

20.010.0

10.0

25.030.0

10.0

100.0

MW


CS Energy

TOTAL


J it

Boilers

1.0

0 5

1.0

4.05.0

1.0

1.7

1.0

M

ANL/EERC

JSIM/NEDO

IFRF

B&W/AL

Jupiter

CIEMAT

ENEL

IndustrialFurnaces

1.0

0 5

1.0

4.05.0

1.0

1.7

1.0

M

ANL/EERC

JSIM/NEDO

IFRF

B&W/AL

Jupiter

CIEMAT

ENEL

IndustrialFurnaces

0.2

0.50.4 0.3

0.20.1 0.2

0.11980 1990 2000 2010 2020

ANL/BHP

IHI B&W/AL

CANMET

PowerGen

IVD-StuttgartRWE-NPOWERTest

Furnaces0.2

0.50.4 0.3

0.20.1 0.2

0.11980 1990 2000 2010 2020

ANL/BHP

IHI B&W/AL

CANMET

PowerGen


Furnaces


1980 1990 2000 2010 2020

Year

1980 1990 2000 2010 2020

Year

OxyOxy--Coal Combustion TechnologyCoal Combustion Technology• “Oxy-Combustion” – is the use of oxygen instead of air for

burning of fuel.○ this technology is the least mature among the 3 mostly considered○ this technology is the least mature among the 3 mostly considered

capture technology options for the power generation.○ For boiler application, part of the flue gas is recycled to reduce flame

temperaturetemperature.

• 3 main development issues○ Boiler and burner development (“design issues”)p ( g )○ Air Separation Unit – “Cost and capacity of oxygen production”○ CO2 processing – “Removal of impurities”


OxyOxy--Coal Combustion TechnologyCoal Combustion Technology

Air separation

Air

Oxygen VentRecycled flue gas

Fuel Boiler Purification/ compression

Cooling (+FGD)

CO2

PowerSteam

Steam


Powerturbine

COAL

HP ADVANCED

HP HEATER

MILL STACK (START

UP)

ADVANCED SUPERCRITICAL BOILER

ID FAN

DEAERATOR

IP

HP PUMP

ESPLP

CONDENSOR

FGD

LP HEATERCOLD FD FAN

LP PUMP

AIR IN


Convective Section of the boilerh t t f fil B d i i

MILL STACK (START

COAL

HP ADVANCED

SUPERCRITICAL BOILER

• heat transfer profile• ash deposition and fouling issue

Burner design issue• Ignition• flame stability• devolatilisation & char burnout

HP HEATER

(START UP)

IP

ID FAN

DEAERATORRadiant Section of the Boiler• heat transfer profile

l i i

HP PUMP

ESPLP

FGD• slagging issue• fireside corrosion issue

Prior to any retrofit of carbon captureLP HEATER

CONDENSOR

COLD FD FAN

LP PUMP

Prior to any retrofit of carbon capture technology, it is essential to repower

the plant in order to achieve the highest possible efficiency

23

PUMP

AIR IN

COALHP

HP HEATER

MILL

3

STACK (START

UP)

NITROGEN

AIR

ASU

ADVANCED SUPERCRITICAL BOILER

HP

4

ID FAN

DEAERATOR

IP

OXYGEN

2

HP PUMP

4

ESP

FD / RECYCLE

FAN

GAS

LP

SECONDARY RECYCLE

PRIMARY RECYCLE

Gas / Gas

Heater

LP HEATER GAS DRIER

AIRINTAKE

START UP

/

GASCONDENSOR

COLD PA FAN

LP

1 - IP STEAM BLEED 2 - HEAT FROM ASU ADIABATIC MAC 3 - CO2 COMPRESSOR STAGE HEAT 4 – FLUE GAS FEEDWATER HEATING

PUMP

GAS COOLER & WATER REMOVAL

CO2 PRODUCT FOR COMPRESSION

1 2 3 4

34

CO2 PURIFICATION

INERTS3

24

REMOVALINERTS 3

BFWBFWSystem Steam turbines

Balance fed direct to burner

Boiler270º CMaximum23% Oxygen!! 340º C

Boiler ESP105º C

HexASUSecondary CO2 Recycle

CoalMill 330º C

Primary CO2 Recycle

y y

Cool & dry

CO d t

250º C

25

CO2 product

OxyOxy Coal CombustionCoal CombustionOxyOxy--Coal CombustionCoal CombustionTechnology DevelopmentTechnology Development

(Burner and Boiler)(Burner and Boiler)(Burner and Boiler)(Burner and Boiler)


Composition of the Comburent Through the Burner Throat (Secondary Air)Composition of the Comburent Through the Burner Throat (Secondary Air)(Babcock and Wilcox)(Babcock and Wilcox)


Composition of Flue GasComposition of Flue Gas(Babcock and Wilcox)(Babcock and Wilcox)( )( )


Gas compositions (omitting nonGas compositions (omitting non--condensables)condensables)and volumes for bituminous coal fired with air and oxygenand volumes for bituminous coal fired with air and oxygen

(Courtesy of Prof. Adel Sarofim (Courtesy of Prof. Adel Sarofim –– University of Utah)University of Utah)

Air Firing Oxy-Firingg y g

CO2 17 % by volume 64%

H2O 8.9% 34%

NO 2770xCR* ppm 10 700xCR* ppmNOx 2770xCR ppm 10,700xCR ppm

SOx 2470 ppm 9400 ppm

Moles 1 0.26

CR* = fractional conversion of coal nitrogen to NOx+ Bituminous Coal Empirical Formula (CH1.1O0.2N0.017S0.015)

Recyled Flue Gas RatioRecyled Flue Gas RatioRecyled Flue Gas RatioRecyled Flue Gas RatioImpact to the Flame PropertiesImpact to the Flame Properties

RFG

mmmR+

=RFGPFG mm +


Adiabatic Flame Temperature and Flue Gas Volume as Adiabatic Flame Temperature and Flue Gas Volume as Compared to Recycle RatioCompared to Recycle Ratio


Optimum Recycle RatioOptimum Recycle Ratio

Critical factors that may affect on these values:○ Amount water in the recycle flue gas○ Amount of air in leakage (Air Ingress)


○ Amount of air in-leakage (Air Ingress)

Flame Description Flame Description –– Impact of Recycle RatioImpact of Recycle Ratio(Courtesy of IFRF)(Courtesy of IFRF)

Figure 3(a): normal air-fired operation Figure 3(b): O2-RFG flame with recycle ratio = 0.58

Figure 3(c): O2-RFG flame with recycle ratio = 0.76 Figure 3(d): O2-RFG flame with recycle ratio = 0.52

Coal Flame Photos:Coal Flame Photos:Coal Flame Photos:Coal Flame Photos:Air Fired vs OxyAir Fired vs Oxy--FiredFired

(Courtesy of IHI)(Courtesy of IHI)

Air mode（O2：21%）


Oxy mode（O2：21%） Oxy mode（O2：30%）

Coal Flame Photos:Coal Flame Photos:Impact of Recycled Flue GasImpact of Recycled Flue GasImpact of Recycled Flue GasImpact of Recycled Flue Gas

(Courtesy of IFRF)(Courtesy of IFRF)

Recycle Ratio = 0.76Recycle Ratio = 0.58(~ 0.61 include the CO2 to transport coal)


( 0.61 include the CO2 to transport coal)

Ratio of Convective Heat Transfer CoefRatio of Convective Heat Transfer Coefficientficient(Courtesy of IFRF)(Courtesy of IFRF)

⎟⎞

⎜⎛

⎟⎞

⎜⎛

⎟⎞

⎜⎛ 3

1PrRe kh

n

⎟⎟⎠

⎞⎜⎜⎝

⎛⎟⎟⎠

⎞⎜⎜⎝

⎛⎟⎟⎠

⎞⎜⎜⎝

⎛=

0

1

0

1

0

1

0

1

PrPr

ReRe

kk

hh

http://www.ieagreen.org.uk 36Effect of Recycle Ratio on Convective heat transfer coefficient [IFRF APG1 Trials]

RadiativeRadiative Heat Flux Heat Flux MeasurementsMeasurements

(Courtesy of IFRF)(Courtesy of IFRF)( y )( y )Ellipsoidal Radiometer Results were also obtained by:

• ANL-EERC

• CANMET

Data from Narrow Angle Radiometer is necessary for radiation modelling development

Radiative Flux Using Ellipsoidal Radiometer in Air (Baseline) and O /RFG (Flames B with recycle ratio = 0 73

p

Knowledge gap is in the radiation factor contribution of solid


(Baseline) and O2/RFG (Flames B with recycle ratio = 0.73 and Flame C with recycle ratio = 0.58) – IFRF APG2 Trials

contribution of solid particles in the furnace

Issue of Air Ingress (Air InIssue of Air Ingress (Air In--leakage)leakage)

11stst Large Scale Demonstration of OxyLarge Scale Demonstration of Oxy--Coal Combustion (35MWth) Coal Combustion (35MWth) –– What Are the Lesson Learned...What Are the Lesson Learned...


Problem with Air IngressProblem with Air Ingress11stst Large Scale OxyLarge Scale Oxy--Coal CombustionCoal Combustion11 Large Scale OxyLarge Scale Oxy Coal Combustion Coal Combustion

Burner Test Experience Burner Test Experience -- International Combustion Ltd.International Combustion Ltd.

30 MWth Low NOx burner

Because of Air Ingress the desired CO2composition (only ~ 28% dry basis).

1% of air ingress ~ 4% decrease in CO2composition.

the combustion trial gained significant

39

experience in burner start up

OxyOxy--Combustion: KEY ISSUESCombustion: KEY ISSUESSO issue is a big• SO3 issue is a big missing link!

• ANL study (1985) haveANL study (1985) have indicated that SO3formation is 3 to 4 times

t d tgreater as compared to conventional air – firing mode

• We need to know more about this potential

From Chemical Engineering Progress (Vol. 70)


operational issue.g g g ( )

Key Challenges Ahead…Key Challenges Ahead…• Boiler and burner issuesBoiler and burner issues

○ coal properties devolatilisation and ignition propertieschar burnout (reactivity)slagging, fouling and ash depositionpollutant emissionpollutant emission

○ how to deal with air In-leakage○ boiler materials in relation to corrosion.boiler materials in relation to corrosion.○ safety issue particularly in handling oxygen

• Large scale demonstration of oxy-coal combustion


a ge sca e de o st at o o o y coa co bust oprocess

41


(ASU / Oxygen Production)(ASU / Oxygen Production)(ASU / Oxygen Production)(ASU / Oxygen Production)


Air Separation UnitAir Separation UnitFor 500 MWe (Net Output) – You will require ~10,500 t/d of oxygen!

NO

Cold liquid air

N2O2

Air HP MP LP

reflux by reboilCold gaseous airreflux

5 barg

reflux by reboil

reboil3.5 barg

Process Description: Oxygen supplyProcess Description: Oxygen supply• Two levels of air compression (saves power)• Oxygen production in HP/MP/LP 3 column system

○ power reduced to 201kwh/ton

• Optimum oxygen purity suggested:○ 95%○ higher purity not worthwhile due to:

Excess O2 requirement (19%)Boiler air in leakage (1%)ESP air in leakage (2%)


ESP air in leakage (2%)

44

Issues involving ASUIssues involving ASU• World’s Largest ASU

○ South Africa (operated by Air Liquide) ~ 5000 TPD○ Mexico (operated by BOC/Linde – N2 production) ~3 -

4000 TPD

O i i f i d t i l d ith d t• Opinion of industrial gas producers with regard to development of very large scale ASU vs. development of novel oxygen productiondevelopment of novel oxygen production.

• Debate with regard to multiple ASU trains vs single large scale ASU train operation flexibility issue!


large scale ASU train – operation flexibility issue!

45


(CO2 Purification and Compression)(CO2 Purification and Compression)(CO2 Purification and Compression)(CO2 Purification and Compression)


Purification of Purification of OxyfuelOxyfuel--Derived CO2 for Derived CO2 for Sequestration or EORSequestration or EOR

• CO2 produced from oxyfuel requires purification○ Cooling to remove water○ Inerts removal○ Compression

• Current design has limitations○ SOx/NOx removal○ Oxygen removal○ Recovery limited by phase separation


• Necessary to define CO2 quality requirement!!!

CO2 Compression and Purification System –Inerts removal and compression to 110 bar

Flue Gas Expander

Aluminium plate/fin exchangerFlue GasHeater

Flue Gas Vent 1.1 bar20°C20°C25% CO275% inerts

-55°C

Driers

inerts

CO2 product110 bar110 bar 96% CO24% Inerts-60°C dp

48

30 bar Raw CO2Saturated 30°C76% CO2 24% Inerts

p

CO2 Purity and Recovery

-55°C is as cold as we can make the phase separationCO2 purity depends on pressure

– At 30 bar and -55°C, CO2 purity is 95%– Higher pressure gives lower purity CO2Higher pressure gives lower purity CO2

CO2 recovery depends on pressure– Lower pressure gives lower CO2 recovery

At 15 b d 55°C CO i 75%– At 15 bar and -55°C, CO2 recovery is 75%– At 30 bar and -55°C, CO2 recovery is 90%

CO2 recovery depends on feed compositionCO2 recovery depends on feed composition– Increases from zero at 25mol% to 90% at 75mol%– Reducing air ingress increases CO2 capture rate

49

CO2 Purity IssuesBasic Design

CaseEOR Case

H2O < 500 ppm

CO2 > 90% mol

< 50 ppm

> 90% mol

SO2 From H&MB

NO From H&MB

O < 4% mol

< 50 ppm

From H&MB

100 ppm O2 < 4% mol

Ar + N2 + O2 < 4% mol

R l ti di h d ff h di l

100 ppm

< 4% mol

Regulations regarding onshore and off-shore disposal are being drafted world-wideCo-disposal of other wastes (NOx, SOx, Hg) is a sensitive issue

50

issueImportant that the CO2 can be purified for disposal or EOR

NOx SO2 Reactions in the CO2Compression SystemCompression System

We realised that SO2, NOx and Hg can be removed in the CO2compression process, in the presence of water and oxygen.compression process, in the presence of water and oxygen. SO2 is converted to Sulphuric Acid, NO2 converted to Nitric Acid:

– NO + ½ O2 = NO2 (1) Slow– 2 NO2 = N2O4 (2) Fast– 2 NO2 + H2O = HNO2 + HNO3 (3) Slow– 3 HNO2 = HNO3 + 2 NO + H2O (4) Fast

NO + SO = NO + SO (5) Fast– NO2 + SO2 = NO + SO3 (5) Fast– SO3 + H2O = H2SO4 (6) Fast

Rate increases with Pressure to the 3rd poweronly feasible at elevated pressure– only feasible at elevated pressure

No Nitric Acid is formed until all the SO2 is convertedPressure, reactor design and residence times, are important.

51

CO2 Compression and Purification System –Removal of SO NOx and HgRemoval of SO2, NOx and Hg

1.02 bar 30 bar to DriersSO2 removal: 100% NOx removal: 90-99%

30°C67% CO28% H2O25%

Saturated 30°C76% CO224% InertsWater

InertsSOx NOx BFW

15 bar30 barcwCondensate

cw

cwcw

Dilute H SO

cw

Dilute HNO3

52

Dilute H2SO4 HNO3

Hg

SOx/NOx Removal – Key FeaturesFeatures

Adiabatic compression to 15 bar:– No interstage water removal– All Water and SOx removed at one place

NO acts as a catalyst– NO is oxidised to NO2 and then NO2

oxidises SO2 to SO3: The Lead Chamberoxidises SO2 to SO3: The Lead Chamber Process

Hg will also be removed, reacting with the nitric acid that is formed (To What Extent???)

53

CO2 Purity - CompositionRaw Flue Gas

@ 35°C, 1 02 b

CO2 Product Vent

@ 35°C, 110 b

@ 11°C, 1 1 b1.02 bara

mol%

CO2 71 5

110 bar 1.1 barmol% mol%

Corrected Corrected

96 3 24 6CO2 71.5

N2 14.3

O2 5.9

96.3 24.6

2.0 48.7

1.1 19.42Ar 2.3

SO2 0.4

NO 400 ppm

0.6 7.1

0 0

< 10 ppm < 100 ppmNO 400 ppm

NO2 10 ppm

H2O 5.6

< 10 ppm < 100 ppm

< 10 ppm 0

0 0

54

Oxygen removal – Option 2

Driers

Feed to distillationdistillation column

55

30 bar Raw CO2Saturated 30°C76% CO2 24% Inerts

Oxygen removal – Option 2

Recycle to Feed

Impure CO 30 barCO2 30 bar

column

Pure CO2Pump to pipeline

Reboiler heated with feed

56

pressure or flash to tanker pressure

stream

Purity, Recovery and PowerPurity, Recovery and Power

Power includes ASU and CO system powerPower includes ASU and CO2 system power

Description CO2 PressureCO2

Recovery

Relative Specific Oxygen ContentCO2 Purity Pressure Recovery Power

Standard Cycle 95.90 mol% 0.91 mol% 110 bar 89.0% 1.00

Content

High Purity Option 2 99 98 mol% 100 00 ppm 110 bar 87 7% 0 99High Purity Option 2 99.98 mol% 100.00 ppm 110 bar 87.7% 0.99

30 bar liquid CO2 99.98 mol% 100.00 ppm 30 bar 87.7% 0.98

7 bar liquid CO2 100 00 mol% 5 01 ppm 7 bar 87 7% 1 027 bar liquid CO2 100.00 mol% 5.01 ppm 7 bar 87.7% 1.02

57

Issues involving CO2 purification processIssues involving CO2 purification process• We need to establish what is appropriate and acceptable• We need to establish what is appropriate and acceptable

level of impurities in our CO2 based on aspects of:○ Health, Safety and Environment considerations

What are the regulations to be established without disadvantaging any capture technology (What is acceptable!!!)

○ Quality specifications defined by transportation/delivery of CO2 to the storage sites

Also to consider the changes to the CO2 properties by the impurities and its possible reactions

Q lit ifi ti d fi d b th t CO2 f diff t○ Quality specifications defined by the storage CO2 for different storage options

• The quality of CO2 (specific level of impurities)


q y ( p p )should be openly discussed!

58

Large Scale OxyLarge Scale Oxy--Coal Combustion Coal Combustion Projects that will provide a big step Projects that will provide a big step forward for Oxyforward for Oxy--Coal Combustion…Coal Combustion…


SchwarzeSchwarze PumpePumpe OxyOxy--Combustion Pilot PlantCombustion Pilot PlantTime Table for Implementation of Oxy-Fuel Project

2009 2010 20112005 2006 2007 2008

Pre- and Order planning

Permission planning

Execution planning

Commissioning

Erection

Operation

Courtesy of Vattenfall



Artist’s View of Artist’s View of Vattenfall’sVattenfall’s Pilot PlantPilot Plant



SchwarzeSchwarze PumpePumpe OxyOxy--Combustion Pilot PlantCombustion Pilot Plant


Courtesy of Vattenfall AB

DoosanDoosan Babcock Burner Test (2008/09)Babcock Burner Test (2008/09)

40 MWth


Callide A Project: JapaneseCallide A Project: Japanese--Australian CollaborationAustralian Collaboration

Nth Denison Trough

Callide-A Power Station Capacity: 4 x 30 MWe Commissioned: 1965 – 1969 Refurbished: 1997/98Refurbished: 1997/98 Steam Parameters: 4.1 MPa, 460oC Steam Flowrate: 123 t/h steam

Figure 2: Location of Callide-A Project A Planned retrofit to a coal fired power plant with an oxy-combustion boiler


Figure 2: Location of Callide A Project. A Planned retrofit to a coal fired power plant with an oxy combustion boiler

64

Japanese and Australian CoJapanese and Australian Co--operationoperation• Callide A Oxy Combustion Retrofit Project• Callide-A Oxy-Combustion Retrofit Project• IHI (Japan) and CS Energy (Australia)

• Project is also supported by the Australia Coal A i i JC l JP (EPDC)Association, JCoal, JPower (EPDC)

• FEED study is expected to be completed by end of this year


• Construction is expected to start by next year...65

Concluding RemarksConcluding RemarksF d t l d t di f th i i l f O C l• Fundamental understanding of the principles of Oxy-Coal Combustion with Flue Gas Recycle have been well establish during the past 20 years of R&D activitiesg p y○ There are still some gaps in knowledge – but we are already ready

for large scale demonstration of the technology. - We need to identify other potential show stoppersidentify other potential show stoppers…

• What is needed right now is to achieve the LARGE SCALE DEMONSTRATION OF OXY-COMBUSTION○ Oxy-combustion will be a competing option vs. post-combustion for

coal fired power plant retrofit○ Oxy-combustion will be a competing option vs. IGCC for new built


Oxy combustion will be a competing option vs. IGCC for new built coal fired power plant.

66

OxyOxy--Coal / Fuel Oil Combustion Boiler ProjectsCoal / Fuel Oil Combustion Boiler Projects(1 (1 MWeMWe = 3 = 3 MWtMWt = 10 = 10 MMBtuMMBtu/hr)/hr)

1000 01000 0300.0

100 0

1000.0SASK Power

UtilityB il

300.0

100 0

1000.0SASK Power

UtilityB il

11.7

20.010.0

10.0

25.030.0

10.0

100.0

MW


CS Energy

TOTAL


J it

Boilers

11.7

20.010.0

10.0

25.030.0

10.0

100.0

MW


CS Energy

TOTAL


J it

Boilers

1.0

0 5

1.0

4.05.0

1.0

1.7

1.0

M

ANL/EERC

JSIM/NEDO

IFRF

B&W/AL

Jupiter

CIEMAT

ENEL

IndustrialFurnaces

1.0

0 5

1.0

4.05.0

1.0

1.7

1.0

M

ANL/EERC

JSIM/NEDO

IFRF

B&W/AL

Jupiter

CIEMAT

ENEL

IndustrialFurnaces

0.2

0.50.4 0.3

0.20.1 0.2

0.11980 1990 2000 2010 2020

ANL/BHP

IHI B&W/AL

CANMET

PowerGen


Furnaces0.2

0.50.4 0.3

0.20.1 0.2

0.11980 1990 2000 2010 2020

ANL/BHP

IHI B&W/AL

CANMET

PowerGen


Furnaces


1980 1990 2000 2010 2020

Year

1980 1990 2000 2010 2020

Year

oxyoxy--combustion for coal fired power plant combustion ... ieaghg (sicily presentatio… ·...

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