Development in Oxyfuel Combustion Technologies forOxyfuel Combustion Technologies for
Coal Fired Power Plants with CCS(Part 1: Boiler and Burner Development)(Part 1: Boiler and Burner Development)
Stanley SantosStanley SantosIEA Greenhouse Gas R&D Programme
Cheltenham, UK
Instituto de Inginieria UNAM28th March 20128 a c 0
CO2 Capture OptionsCO2 Capture Options
EPRI 2007
2
EPRI 2007
Oxy-Coal Combustion Power Planty
Air separation
Air
Oxygen VentRecycled flue gas
Fuel Boiler Purification/ compression
Cooling (+FGD)
CO2
Steam
PowerSteam turbine
33
Oxy-Combustion TechnologyOxy Combustion Technology• Use of oxygen instead of air in a boiler – “Oxy-
C b i ” i f ibl i f lCombustion” is a feasible option for power plant with CO2 capture. • With significant R&D investment in the past decade, this
technology has achieve a maturity similar to the other leading options for power generation with CCSleading options for power generation with CCS
• Outline for Presentation• Boiler and Burner Development• Air Separation Unit• Flue Gas Processing Unit• CO2 Processing Unit
44
Oxyfuel CombustionO ll S h ti DiOverall Schematic Diagram
5
Where Can You Extract the Recycled Flue Gas (RFG)(For Practical application using low S coal)( pp g )
66
Oxyfuel Combustion Technology
BOILER AND BURNER Oxyfuel Combustion Technology
DEVELOPMENT
7
Development of Oxy-Fuel Combustion Application in Industry
88
Adapted from slide of Sho Kobayashi, Praxair
Pictures from IFRF, Air Liqiude, Asahi Glass, Linde Gas
Historical Perspective – The Early Daysp y y
• 1982: Initial suggestion by Abraham et. al. (OGJ) of using Oxy-Coal Combustion to produce CO2 for EORp• 1st public document looking at capturing CO2 from
flue gas using oxy-combustionflue gas using oxy-combustion.• However ... as early as 1970’s work has
d i h d l f lstarted in the development of oxy-coal combustion with recycled flue gasy g• 1974: Japan initial conception of using oxy-coal combustion for power
generation. (To reduce pollution?)• 1978: Economic feasibility of oxy coal combustion was investigated for
9
• 1978: Economic feasibility of oxy-coal combustion was investigated for EOR application (H. Farzan, Babcock & Wilcox / A. Wolsky, ANL)
9
Technology DevelopmentJapan’s initial conception of oxyfuel combustion application
for power generation (1974)
Oxygen
10 3rd Workshop, IEAGHG International Oxy-Combustion
Network, Yokohama, Japan
ANL - EERC StudyWorld’s 1st Oxy-Coal Combustion Industrial Pilot Scale StudyWorld s 1st Oxy Coal Combustion Industrial Pilot Scale StudyTower Furnace (~ 3MWth)
11
Convective Section of the boilerConvective Section of the boiler• heat transfer profile• ash deposition and fouling issue
Burner design issue• Ignition• flame stability• devolatilisation & char burnoutdevolatilisation & char burnout
Radiant Section of the Boiler• heat transfer profile• slagging issue
fi id i i• fireside corrosion issue
Prior to any retrofit of carbon capture technology it is essential to repowertechnology, it is essential to repower
the plant in order to achieve the highest possible efficiency
1212
Composition of Comburent(O id )(Oxidant)
Gas Composition
% (d ) P i RFG 2 d RFG
Oxy‐Coal CombustionAir Fired Case
%v (dry) Primary RFG 2ndary RFG
Nitrogen (N2) 78.1 18 ‐ 12 14 ‐ 10
Oxygen (O2) 20.9 2 ‐ 21 25 ‐ 40
Argon (ar) 0.9 3 ‐ 3.5 3 ‐ 3.5
Carbon Dioxide CO2) 0.04 78 ‐ 60 55 ‐ 40
Water (H2O) %v (wet) < 2 (depend on %RH) 8 ‐ 4 15 ‐ 5
** Calculation based on ~3% air ingress 95% O2 purity and C H O N S
1313
** Calculation based on 3% air ingress, 95% O2 purity and C6.87H5.56O0.56N0.13S0.03
Composition of Flue Gas f B ilfrom Boiler
Gas CompositionAir Fired Case Oxy‐Coal Combustion Case
%v (dry)
Nitrogen (N2) 80 ‐ 78 14 ‐ 18
Air Fired Case Oxy Coal Combustion Case
Oxygen (O2) 3 ‐ 4 (~3.5) 2 ‐ 5 (~3.5)
Argon (ar) 0.9 ‐ 0.95 3 ‐ 3.5
Carbon Dioxide CO2) 14 ‐ 16 78 ‐ 74
Water (H2O) %v (wet) 6 ‐ 8 20 ‐12
** Calculation based on ~3% air ingress, 95% O2 purity and C6.87H5.56O0.56N0.13S0.03
1414
Recyled Flue Gas RatioyImpact to the Flame Properties
RFGmR =RFGPFG mm
R+
15
Optimum Recycle Ratio(Optimum recycle ratio is defined by the amount of Recycled Flue Gas to match the heat transfer profile of conventional air fired operation)
Some of the reported results for the optimum flue gas recycle ratio
Burner Rating Type of Flue Gas Molar Ratio1
(CO2 + H2O)/O2
%O2 in Comburent2
Recycle Ratio MRFG/(MRFG + MPFG)
ANL EERC 3 MWthpartially dried RFG 2 66 26% (wet)ANL – EERC 3 MWth (~18%v moisture) 2.66 26% (wet) -
wet RFG (~35% moisture) 3.25 22% (wet) ~ 0.68
IFRF 2.5 MWthwet RFG(~ 26% moisture) ~ 2.20 48% (~41% wet) ~ 0.58
IHI 1.2 MWth wet RFG - ~34% (30%wet) -
CANMET 0.3 MWth wet RFG - 35% (dry) -1 Molar ratio of the secondary comburent (oxidant)2 % oxygen through the burner throat (volume dry basis)3 M d M th fl t f th l d fl d d t fl ti l
16
3 MRFG and MPFG are the mass flow rate of the recycled flue gas and product flue gas respectively
U i ität St tt tRecycle Rate and Oxygen Concentration
Universität Stuttgart
a) b)
Flue Gas with Fly AshFlue Gas with Fly Ash
a) b)
OxygenyO2, mixOxygenyO2, mix
tadiabatic
Coal
tadiabatic
CoalCoalHeat Output
Bottom Ash
CoalHeat Output
Bottom Ash
17Source: A. Kather, 2009
Factors affecting Recycle R tiRatio
Critical factors affecting the optim m• Critical factors affecting the optimum amount of recycled flue gas• Burner and boiler design (heat transfer and flame
stability – oxygen distribution through burner)y yg g )• Air ingress• Purity of oxygen from the ASU• Purity of oxygen from the ASU• Coal type• Level of moisture content in comburent• Comburent (oxidant) temperature
1818
Flame Description – Impact of Recycle Ratio(Courtesy of IFRF)
Figure 3(a): normal air-fired operation Figure 3(b): O2-RFG flame with recycle ratio = 0.58
19Figure 3(c): O2-RFG flame with recycle ratio = 0.76 Figure 3(d): O2-RFG flame with recycle ratio = 0.52
Coal Flame Photos:Air Fired vs Oxy-Fired(Courtesy of IHI)
Air mode（O2：21%）
2020
Oxy mode（O2：21%） Oxy mode（O2：30%）
Coal Flame Photos:Impact 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)
2121
U i ität St tt t
Effect of Different Oxygen Concentrations (and Recycle Rates) on Flame Pattern Universität Stuttgart(and Recycle Rates) on Flame Pattern
Air
Oxyfuel
28% O2
Oxyfuel
38% O2
Recycle rate 77% Recycle rate 66%
22Source: J. Smart, 2008
Ratio of Convective Heat Transfer Coefficient(C t f IFRF)(Courtesy of IFRF)
⎟⎟⎞
⎜⎜⎛
⎟⎟⎞
⎜⎜⎛
⎟⎟⎞
⎜⎜⎛
= 13
1
111 PrRe khn
⎟⎠
⎜⎝
⎟⎠
⎜⎝
⎟⎠
⎜⎝ 0000 PrRe kh
2323Effect of Recycle Ratio on Convective heat transfer coefficient [IFRF APG1 Trials]
Radiative Heat Flux Measurements(C t f IFRF)(Courtesy of IFRF)
Ellipsoidal Radiometer Results were also obtained by:y
• ANL-EERC
• CANMET
Data from Narrow Angle Radiometer is necessary for radiation modellingfor radiation modelling development
Research in the past
Radiative Flux Using Ellipsoidal Radiometer in Air (Baseline) and O2/RFG (Flames B with recycle ratio = 0.73
Research in the past decade has achieved better understanding to eh Radiation Principle of
2424
( ) 2 ( yand Flame C with recycle ratio = 0.58) – IFRF APG2 Trials oxyfuel boiler
Results: Radiative HT- South African coal – Dry R lRecycle
Furnace Heat Flux MeasurementsSouth African coal, Oxyfuel (3% O2)South African coal, Oxyfuel (3% O2)
450
500
m2
SAcoal/Air - 3% O2
Oxyfuel RR 65%
Oxyfuel RR 68%
Oxyfuel RR 70%
400
Flux
kW
/m Oxyfuel RR 72%
Oxyfuel RR 75%
300
350
tive
Hea
t F
250
300
Rad
iat
2000 500 1000 1500 2000 2500 3000 3500
Axial Distance from Burner, mm
25
Normalised Convective & Radiativeheat flux – Russian Coal - Dry Recycle
Dr O f el Operation Normalised to Air OperationDry Oxyfuel Operation Normalised to Air OperationPeak Radiation Flux, Convective heat transfer and calculated flame temperature
Russian coal1.6 1.6Normalised Flame Temperature (calculated)
Peak Normalised Heat Flux (measured)Measured Convective Heat T f C ffi i t i di t 74%
1 2
1.4
tic
e 1 2
1.4
e an
d ux
Peak Normalised Heat Flux (measured)Normalised Convective HTC (measured)
Transfer Coefficient indicates 74% Recycle is "Air-equivalent"
Measured Peak Radiative data indicates 74%
New Build Retrofit Avoid
1
1.2
ed A
diab
atem
pera
ture
1
1.2
ed R
adia
tive
ctiv
e H
eat F
ludata indicates 74% Recycle is "Air-equivalent"
0 6
0.8
Nor
mal
ise
Flam
e Te
0 6
0.8
Nor
mal
ise
Con
vec
0.4
0.6
60% 65% 70% 75% 80%0.4
0.6Calculated dry oxyfuel adiabatic flame temperatures are equivalent to air at 69% recycle
2660% 65% 70% 75% 80%
Effective Recycle Ratio
C id ti i th B il O tiConsiderations in the Boiler OperationO2 Purity and Air Ingress
(a.) Why not 99+% O2 Purity(b.) Air Ingress… A Challenge for the Operator
27
Issue of Air Ingress (Air In-leakage)
Ai I i th b il iAir Ingress in the boiler is a fact of life!!!fact of life!!!
1st Large Scale Demonstration of O Coal Comb stion (35MWth)Oxy-Coal Combustion (35MWth) – What Are the Lesson Learned...
28
Problem with Air Ingress1st Large Scale Oxy Coal Combustion1st Large Scale Oxy-Coal Combustion Burner Test Experience - International Combustion Ltd.
30 MWth Low NOx burner
Because of Air Ingress the desired CO2
composition (only ~ 28% dry basis).
Air Ingress in boilers
approx. 3 % of flue gas flow fora new conventional power plant
29
a new conventional power plant
up to 10 % over the years forpower plants in use
CO2 Recovery Depends On Feed Composition
1
0.8
1
Recovery 0.6
0.2
0.4
00 0.2 0.4 0.6 0.8
At -55°C 30 barFeed Composition
30
At 55 C, 30 bar
NOx Emissions
We have quite a good confidence in- We have quite a good confidence in knowing the trend of these emissions
NOx Emissions(Results from ANL-EERC and IFRF)
3232
Results from IFRF study (APG4)
33
SO2 Emissions
- Highly dependent on howHighly dependent on how sulphur is captured in ash...
- without the removal of SO2 in the secondary RFG, it should noted that a maximum of ~30% reduction could be expected
(on mass per unit energy input basis)
SO2 Emissions(Results from ANL-EERC and IFRF)
0.8
0.5
0.6
0.7
MMBtu)
0.3
0.4
2Emissions (lb/M
0.1
0.2
SO2
EERC‐ANL (Wet RFG)
EERC‐ANL (Dry RFG)
Air Fired Case
0
1.5 2 2.5 3 3.5 4
[CO2 + H2O]/[O2] Molar Ratio of Comburent
3535
SO2 Emissions(R lt f IFRF)(Results from IFRF)
36
Sulphur in ashSulphur in ash
3737
Fundamental question in attempt to explain the reduction of SO2…
• Red ction of SO nder o coal comb stion• Reduction of SO2 under oxy-coal combustion conditions - Could this observations due to 2 competing phenomena in the furnace and in thecompeting phenomena in the furnace and in the convective section???
Hi h t t lf ti f th h ( d b• High temperature sulfation of the ash (as proposed by Okazaki et. al.) - which could be in agreement base on the data of IFRF (APG2 Trials)the data of IFRF (APG2 Trials).
• Sulfur capture in ash at convective section enhanced by higher SO3 formation, higher deposition rate and lowerhigher SO3 formation, higher deposition rate and lower carbon in ash.
3838
3939
4040
4141
4242
4343Results from IFRF study (APG2)
Issue of SO3
- The confirmation of the ANL results- The confirmation of the ANL results as presented from the results of IVD St ttgart IHI/Calide Project VattenfallStuttgart, IHI/Calide Project, Vattenfall, Chalmers University.
- Nonetheless, there are still a lot of ,confirmation to be done!!!
Oxy-Combustion: KEY ISSUESO y Co bust o SSU S
• SO3 issue is a big missing link! (4 years ago)
• ANL study (1985) have indicated that SO3
formation is 3 to 5 times greater as compared togreater as compared to conventional air – firing mode
• We need to know more about the potential From Chemical Engineering Progress (Vol. 70)
45http://www.ieagreen.org.uk 45
operational issue.
SO3 formation is increased in the presence f i id i th hof iron oxide in the ash
4646
Marrier and Dibbs (1974) Thermochmica Act (Vol. 8)
SO2 captured along the convective part(down to 450°C) by different inlet concentrations(down to 450 C) by different inlet concentrations
KK_Captured RH_Captured LA_Captured EN_Captured
400
500
gas
300
400
d @
flue
-g[p
pm]
100
200
2 ca
ptur
edpa
th [
0
100
SO SO2 injection increased
0 1000 2000 3000 4000
SO2 measured at the end of radiative section [ppm]
47
Oxy-fuel 27 % O2
IHI – Callide Project Results (SO2 Emissions)IFRF (APG1 Trials) – Gottelborg coal
400
500
）
C oal A
Coal B
Coal C
300
ode （mg/MJ）
200
SO2, O
xy mo
0.7
0.8
ANL-EERC Trials – Blk. Thunder coal
0
100
0 100 200 300 400 500
S
0.4
0.5
0.6
ons (lb/M
MBtu)
0 100 200 300 400 500
SO 2, Air m ode (m g/M J)
0.1
0.2
0.3SO
2Em
issio
EERC‐ANL (Wet RFG)
EERC‐ANL (Dry RFG)
0
1.5 2 2.5 3 3.5 4
[CO2 + H2O]/[O2] Molar Ratio of Comburent
Air Fired Case
Would the capture of SO2 / SO3 in the ash h d b l b i h?enhanced by lower carbon in ash?
Marrier and Dibbs (1974) Thermochmica Act (Vol. 8)
E ON UK Results at 26%O2E.ON UK Results at 26%O2
49
49
Emissions – SO2
© 2004 E.ON 2012年3月29日, E.ON UK, Page 50
Ash Related IssueAsh Related Issue
Data from the trials taken by:
MBEL (Doosan Babcock), Air Products, Ulster University and Naples University (1995)
51
and Naples University (1995)
Summary SO2/SO3 and Sulphur i A h (1)in Ash – (1)• Capture of sulphur in ash at the furnace section is primarily due toCapture of sulphur in ash at the furnace section is primarily due to
the high temperature direct sulphation mechanism as suggested by Okazaki et. al. (2001) as shown in their experimental results. This is pretty much in agreement to the in flame SO2This is pretty much in agreement to the in-flame SO2measurements done by IFRF during their APG2 trials. • Okazaki et. al. suggested that this is due to promotion of capture of sulphur
by CaO species and the inhibition of the decomposition of CaSO4
• This mechanism is further supported from the results of IVD Stuttgart (Maier et. al.) and Imperial College (Wrigley et. al.) indicating the occurrence of both carbonation and sulphation in the ash collected from oxy-coal combustion trials. This could indicate that equilibrium reactions promoting the formation of CaCO3 and CaSO4 are probably favoured (or highly enhanced) under CO2
i h irich environment.• These results established the feasibility of using in-furnace SO2 reduction by
using Ca(OH)2 or CaO injection.
52
Summary SO2/SO3 and Sulphur i A h (2)in Ash – (2)• Additional sulphur capture in ash could also be• Additional sulphur capture in ash could also be
promoted by increased formation of SO3. • It should be recognised that both results from ANL-EERC and IVD s ou d be ecog sed a bo esu s o C a d
Stuttgart confirms that SO3 formation is higher (about 4-5 times – in terms of mass SO3 emissions per unit energy input) as compared to air fired case However it is not yet clear if level of recycled SO2 hasair fired case. However, it is not yet clear if level of recycled SO2 has it impact to the level of SO3 formation.
• Capture of sulphur by this mechanism would occur along the flue gas th (d i th ti ti ) h i th lt b IVDpath (during the convective section) as shown in the results by IVD-
Stuttgart.o Furthermore, IVD-Stuttgart results indicated that the higher the level of SO2 are
recycled , the capture efficiency of sulphur in ash is more efficient. o Nonetheless, it should be noted that that this observation in sulphur capture
efficiency is coal dependent.
53
Summary SO2/SO3 and Sulphur i A h (3)in Ash – (3)• Results from Marrier and Dibbs (1974) further support the observationsResults from Marrier and Dibbs (1974) further support the observations
made by IVD Sttuttgart:• maximum conversion of SO2 to SO3 would occur around 700-800oC.• Capture of sulphur in ash could be dependent on the concentration of CaO and MgOCapture of sulphur in ash could be dependent on the concentration of CaO and MgO
in the ash. (This could probably be one of the reasons why capture efficiency of sulphur becomes coal dependent)
• Iron oxides could enhanced the formation of SO3 therefore promoting the capture of p g psulphur in the ash at the convective section. (This could probably be one of the reasons why capture efficiency of sulphur becomes coal dependent).
• Carbon in ash could diminish the efficiency in the capture of sulphur in ash. This is t d b i t di i di ti l b i h d i lsupported by various studies indicating a lower carbon in ash during oxy-coal
combustion trials (IHI, IFRF, ANL-EERC) showed a lower SO2 emissions (i.e. higher degree of sulphur capture in ash). A higher carbon in ash by E.ON UK experimental results indicated a nearly similar SO2 emissions to the air fired case.results indicated a nearly similar SO2 emissions to the air fired case.
• Higher ash deposition rate under the wet RFG trials could also promote higher sulphur capture in the convective section. This should be further validated!
54
validated!
SO3 Emissions(Results from ANL-EERC, IVD Stuttgart, Callide/IHI)
20ANL ‐ Air ANL ‐ Oxy
16
18
m)
ANL ‐ Air ANL ‐ Oxy
IVD Stuttgart ‐ Air IVD Stuttgart ‐ Oxy
Callide IHI ‐ Coal A ‐ Air Callide IHI ‐ Coal A ‐ Oxy
Callide IHI ‐ Coal B ‐ Air Callide IHI ‐ Coal B ‐ Oxy
12
14
atio
n (p
pm
6
8
10
Con
cent
ra
2
4
6
SO3
00 250 500 750 1000 1250 1500 1750 2000 2250
SO C t ti ( )
55
SO2 Concentration (ppm)
My Background Analysis…My Background Analysis…
• SO2 to SO3 conversion will most likely to occur at the convective section…
5656Marrier and Dibbs (1974) Thermochmica Act (Vol. 8)
Similar SO3 Conversion Rate As Air Firing -Economizer Outlet Measurements in BSF
Illinois BituminousE i O tl t SO lt
North DakotaE i O tl t SO lt
300Air
Economizer Outlet SO3 results Economizer Outlet SO3 results
Alstom 15MWth BSFLignite SO3 Testing - Economizer Outlet
200
250
mv
AirOxy w/o SOx controlOxy w/SOx control
Lignite SO3 Testing Economizer Outlet
75
100AirOxy w/o SOx controlOxy hot FGROxy w/SO3 spike
100
150
SO3
ppm
2%
3%
50
SO3 p
pmv
3%
0
501% Conversion
0
25
1% Conversion
2%
3%
0 5,000 10,000 15,000SO2 ppmv
0 500 1,000 1,500 2,000 2,500 3,000 3,500SO2 ppmv
Similar SO2 to SO3 conversion rates
© ALSTOM 2011. All rights reserved. Information contained in this document is indicative only. No representation or warranty is given or should be relied on that it is complete or correct or will apply to any particular project. This will depend on the technical and commercial circumstances. It is provided without liability and is subject to change without notice. Reproduction, use or disclosure to third parties, without express written authority, is strictly prohibited.
Similar SO2 to SO3 conversion rates
Burner Development for Oxyfuel C b tiCombustion• Burners are critical to combustion, emissions,
and thermal efficiency / capacity of the utility boilers
• Critical importance to burner development is aCritical importance to burner development is a full scale testing• This is an important exercise to establish reference data• This is an important exercise to establish reference data
that could be used in the development and validation of different modeling tools.g
• This is also to gain experience in operating full scale burner. (i.e. start up/shut down, flame stability, efficiency,
58
( y yheat transfer, fouling and slagging, etc…).
58
Burner Development for OxyfuelC b tiCombustion
• Development of Full Scale Burner TestingDevelopment of Full Scale Burner Testing Programme could either be accomplished by:
• Retrofitting of Full Scale Burner Test Rigso B&W’s 30MWth CEDF Facility (Ohio USA)o B&W s 30MWth CEDF Facility (Ohio, USA) o Doosan Babcock’s 40MWth MBTF Facility (Renfrew, Scotland)o Alstom ‘s 15MWth BSF Facility (Connecticut, USA)
• Testing in a Full Chain Oxyfuel CCS Pilot / Demo Planto Vattenfall’s Schwarze Pumpe Pilot Plant (Cottbus, Germany)o CS Energy’s Callide Power Plant (Queensland, Australia)
TOTAL’ L F ilit (L F )
59
o TOTAL’s Lacq Facility (Lacq, France)o CIUDEN Demo Facility (El Bierzo, Spain)
Today... There are 3 Major Full Scale PC Burner Testing Facilities Worldwide Retrofitted for OxyfuelPC Burner Testing Facilities Worldwide Retrofitted for Oxyfuel
• Babcock and Wilcox (B&W) • Doosan Babcock – • Alstom Power Plant Lab. –30MWth CEDF
• Barberton, Ohio, USA• Start of Operation: Oct. 2008
40MWth in 90MWth MBTF• Renfrew, Scotland, UK• Start of Operation: Jun. 2009
15MWth in 30MWth BSF• Windsor, Connecticut, USA• Start of Operation: Nov. 2009
• Wall Fired Burner Development
• Wall Fired Burner Development
• T-Fired Burner Development
Courtesy of Alstom, B&W and Doosan Babcock
6060
OxyCoal 2 Demonstration of an Oxyfuel Combustion SystemOfficially opened on 24th July 2009 Doosan Power Systems’ 40MWth OxyCoal™ demonstration became the world’s largest demonstration of an oxyfuel combustion system.
14 September 2011 | D W Sturgeon
61
OxyCoal 2 Demonstration of an Oxyfuel Combustion SystemSafe and smooth transitions between air and oxyfuel operation were demonstrated, with realistic CO2 levels achieved (in excess of 75% v/v dry, and up to 85% v/v dry).
OilAi Fi i
Secondary Ai
Oil Ai /O f l
Oil/Coal Ai /O f lAir Firing
(TFGR, PA, SA)
Air to Secondary Flue Gas Recycle
Transition
Air/Oxyfuel Firing
(TFGR, PA, SFGR)
Air/Oxyfuel Firing
(TFGR, PA, SFGR)
Coal Coal Air/Oxyfuel
Firing (TFGR,
PA, SFGR)
Primary Air to Primary Flue Gas Recycle
Transition
Oxyfuel Firing
(TFGR, PFGR, SFGR)
14 September 2011 | D W Sturgeon
62
OxyCoal 2 Demonstration of an Oxyfuel Combustion System40MWth OxyCoal™ burner turndown proven from 100% load to 40% load.
40MW40MWt
32MW32MWt
24MWt24MWt
20MWt
Stable rooted flame maintained for all loads down to 40% with coal ignition within the burner throat/quarl.
t
16MWt
Comparable turndown to Doosan Power Systems’ commercially available air firing low NOX axial swirl
14 September 2011 | D W Sturgeon
63burners.
View on Oxyfuel Pilot Plant
64 | Lars Strömberg, IEAGHG OCC2 Australia | 2011.09.12
Results until May 2011
Operating hours 14.200Captured amount of CO2 11.500 tCO l t 93 %CO2- removal rate > 93 %CO2- purity > 99.7 %
• Stable oxyfuel operation• All emission and safety values contained• Interaction between all plant components and subsystems validated
O 50 t t ith B il ASU CO2 l t• Over 50 tests with Boiler, ASU, CO2 plant and all other components• Plant availability very high• Integration of a "cold DeNOx"• Integration of a cold DeNOx
4 different burners tested
New tail end concepts commissioned with good results
65 | Lars Strömberg, IEAGHG OCC2 Australia | 2011.09.12
Boiler and Burner
• Till now three burners tested (Jet-/spin-, pure spin burner) • Igniting burner in main burner integrates
Variable spinn during operation necessary• Variable spinn during operation necessary
Results:• Good ignition behavior• Good ignition behavior • High flame stability • Emission values are kept for certain
1 Oxidantquerschnitt 11 Oxidantquerschnitt 1
Alstom-Burner Typ A and Typ B
Dra
ll
Dra
ll
Dra
ll
45 6
2 45 6
1
2
3
4
Oxidantquerschnitt 1
Oxidantquerschnitt 2
Stauring
Oxidantquerschnitt 3D
rall
Dra
ll
Dra
ll
45 6
2 45 6
1
2
3
4
Oxidantquerschnitt 1
Oxidantquerschnitt 2
Stauring
Oxidantquerschnitt 3 HPE DS®-T Burner
1
23
41
23
45
6
Staub- / Fördergas-Querschnitt
Kernoxidant Querschnitt
Quelle: ALSTOM
1
23
41
23
45
6
Staub- / Fördergas-Querschnitt
Kernoxidant Querschnitt
Quelle: ALSTOM
66 | 2OCC, U.Burchhardt | 2011-09-13
Quelle: ALSTOMQuelle: ALSTOM
Boiler (furnace) - Temperature Comparison (Front View)
Oxy 24% Oxy 28% Oxy 32% Oxy 36% Air (21%)
• The gas temperatures increases with increased O2 in oxidant as expected
67 | 2OCC, U.Burchhardt | 2011-09-13
g p p• The temperature levels for air case corresponds to OXY28
30 MWth Oxy-Combustion Pilot Plant Burner Design Type A and B
Burner Type A Burner Type B
© ALSTOM 2011. All rights reserved. Information contained in this document is indicative only. No representation or warranty is given or should be relied on that it is complete or correct or will apply to any particular project. This will depend on the technical and commercial circumstances. It is provided without liability and is subject to change without notice. Reproduction, use or disclosure to third parties, without express written authority, is strictly prohibited.
Oxy-Combustion Testing in 30MWth Pilot Plant Schwarze Pumpe - IEA-OCC2 Yeppoon, Australia - Frank Kluger - 14 Sep 2011 - P 68
DST BDST Burnerfor indirect firing
Hours installed: 10.200 h (19th of April – 16th of June)
Oxyfuel operation: 4.760 h
2nd International Oxyfuel Combustion Conference, 12th-16th September 2011, Yeppoon, Australia © Hitachi Power Europe GmbH 69
Oxyfuel operation: 4.760 h
Air operation: 1.250 h
DST burner
2nd International Oxyfuel Combustion Conference, 12th-16th September 2011, Yeppoon, Australia © Hitachi Power Europe GmbH 70
Premixed / hybrid mode
Premixed mode Hybrid mode
DST burner DST burner
MMMMMM
Flue gasFlue gas + O2
M
O
Flue gas
O2M
M
O2
O2
O2
712nd International Oxyfuel Combustion Conference, 12th-16th September 2011, Yeppoon, Australia © Hitachi Power Europe GmbH
Oxyfuel operation - Oxyfuel flame example
Heat input: 27 MWth
O2 in oxydant: 32 % by vol. (wet) NO : 416 mg/m³ = 0 13 kg/MWh
2nd International Oxyfuel Combustion Conference, 12th-16th September 2011, Yeppoon, Australia © Hitachi Power Europe GmbH 72
NOx: 416 mg/m 0.13 kg/MWh
CS Energy/IHI Burner Testing Programme at C llid A P St tiCallide A Power Station• Callide A Project – would j
be the world’s 1st oxyfuelretrofitted power station.retrofitted power station.• First oxyfuel pilot plant that
will actually producewill actually produce electricity.I t ll ti f 2 W ll• Installation of 2 new Wall Fired Burners
• A unique position to provide information related to the
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burner – burner interaction 73
Courtesy of CS Energy, IHI
Thank you• Email: [email protected]• Website: http://www ieaghg org
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Website: http://www.ieaghg.org
