To highlight the research and achievements of Australian researchers, the Global CCS Institute with ANLEC R&D will hold a series of webinars throughout 2016. Each webinar highlights a specific ANLEC R&D research project and the relevant report found on the Institute’s website. The fifth webinar of the series looked at the development of an aqueous ammonia-based post-combustion capture technology for Australian conditions. CSIRO has been developing aqueous ammonia (NH3)-based post-combustion CO2 capture (PCC) technology for its application under Australian conditions since 2008. Previous pilot-plant trials at Delta Electricity’s Munmorah Power Station demonstrated the technical feasibility of the process and confirmed some of the expected benefits. With further support from the Australian Government and ANLEC R&D, CSIRO has worked closely with universities in Australia and China to develop an advanced aqueous NH3-based CO2 capture technology. The advanced technology incorporates a number of innovative features which significantly improve its economic feasibility. This webinar presented the advancements made from a recently completed project funded by ANLEC R&D, and was presented by Dr Hai Yu and Dr Kangkang Li from CSIRO Energy.

1. Development of an aqueous ammonia-based post-
combustion capture technology for Australian
conditions
Webinar – Thursday, 13 October 2016

2.  Dr Yu is a senior research scientist at CSIRO Energy. He was
awarded a PhD in Chemical Engineering from the University
of Newcastle, Australia in 2004.
 Since 2000, he has dedicated himself to research on clean
energy technologies and environmental protection, including
development of technologies for utilisation of synthetic
greenhouse gases and post combustion CO2 capture.
 He was lead researcher for the pilot plant demonstration of an
aqueous ammonia-based post-combustion capture process in
Australia, and the project leader for a number of projects
which are aimed to advance the aqueous ammonia-based
CO2 capture technology for application in Australia.
Senior Research Scientist, CSIRO Energy
Dr Hai Yu

3.  Dr Li is a postdoctoral research scientist at CSIRO Energy.
He was awarded a PhD in Chemical Engineering from Curtin
University of Technology in 2016.
 His research focuses on post combustion CO2 capture
technology and energy harvesting from CO2 capture.
 He participated in the development of an advanced aqueous-
ammonia based CO2 capture process which was funded by
ANLEC R&D, focusing on Aspen process modelling and
techno-economic assessment.
Postdoctoral Research Scientist, CSIRO Energy
Dr Kangkang Li

4. QUESTIONS
 We will collect questions during
the presentation.
 Your Webinar Host will pose
these question to the
presenters after the
presentation.
 Please submit your questions
directly into the GoToWebinar
control panel.
.

5. ANLEC R&D is a not-for-profit agency, funded by the Australian Government Department Industry, Innovation and Science through the
National Low Emissions Coal Initiative, and by the ACA Low Emissions Technologies Ltd (ACALET) through the COAL21 Fund.
Enabling research to reduce greenhouse emissions from coal technologies
Australian National Low Emissions Coal Research & Development
ANLEC R&D is an Australian National Research
Initiative to support Carbon Capture and Storage
(CCS) deployment in Australia.
$100M+ Invested
In one of the largest partnerships, the Australian
Coal Industry and the Australian Government has
deployed a research effort in over 25 institutions
nationwide since 2010.
Our present focus supports CO2 storage across
3 Australian geological basins:
Surat Basin, Gippsland Basin, Perth Basin
ANLEC R&D funded this project to test concepts that might further reduce the cost of post combustion
capture using advanced aqueous ammonia solutions
For more information please visit www.anlecrd.com.au

6. Development of an advanced aqueous-ammonia based post-
combustion capture technology for Australian Conditions
13 October 2016
CSIRO Energy
Hai Yu and Kangkang Li

7. Outline of Presentation
o Research Background
o Project Objectives
o Approaches and Methodology
o Results and Discussion
o Conclusions and Future Work

8. Levelisedcostofelectricity
AUD/MWh
0
20
40
60
80
100
120
140
160
180
Capital
O&M
Fuel
CO2 T&S
Pulverised black coal
no CCS
Pulverised black coal
MEA CCS
Project background – global state of the art in PCC
The state of the art PCC technology is based on amine solutions
o Costs are high, in particular, capital cost in Australian content
o Environmental concerns
EPRI, Australian Electricity Generation
Technology Costs-Reference Case 2010
Levelisedcostofelectricity
AUD/MWh
0
20
40
60
80
100
120
140
160
180
Capital
O&M
Fuel
CO2 T&S
Pulverised black coal
no CCS, no SOx
Pulverised black coal
amine CCS + SOx
CO2CRC, et al, Australian Power
Generation Technology Report 2015

9. PCC
Pilot plants Research & Development
Delta Electricity
AGL Loy Yang Power
China Huaneng
(Beijing)
Stanwell
Novel amines Novel processes &
equipment
Adsorbents
Environmental impacts
Learning by doing Learning by searching
Membranes
China Huaneng
(Changchun)
Project background – CSIRO PCC research program

10. Lean Solvent
Rich Solvent
CO2
Flue gas in
Flue gas out
Absorber Stripper
2HOC2H4NH2 + CO2  HOC2H4NHCOO- + HOC2H4NH3
+
(MEA) (Carbamate)
NH3 + H2O + CO2 {
NH4
+ + HCO3
- (bicarbonate)
NH4
++NH2COO- (carbamate)
NH4
+ + CO3
2- (carbonate) } 
NH4HCO3
(NH4)2CO3
NH2COONH4
Solid precipitation
Project background – Ammonia based PCC process

11. Project background – Ammonia based PCC process
• Alstom Power – Chilled ammonia process
• CSIRO, Powerspan and Korean Research Institute of Industrial
Science & Technology – Warm ammonia process

12. Project background – Ammonia PCC development in CSIRO
Trialing a basic process
at Munmorah Power Station
10
1
2185
FLUE4
10
1
5957
LEAN-INP
27
1
1830OFF-GAS
29
1
6312
RICH
107
5
6312
RICH2
45
5
113
RECYCLE
130
5
5921
LEAN1
106
5
504
TOP
29
5
6312RICH1
39
5
5921LEAN2
11
1
1756
VENT1
115
1
1756
VENT2
125
1
2272
FLUE
45
1
2272FLUE1
10
1
5853WASHWA
16
1
5927WASH1
45
5
391
PRODUCT
16
1
2192
FLUE3
10
1
6
CONDEN
45
1
2272
6
96
1
2272
FLUE2
30
1
27WATER
-50
10
9NH3
40
1
59213
16
1
5927
16
1
5927
1
26
1
5853
30
1
0
30
1
0
31
1
6007
31
1
6007
31
1
6007WASH2
31
1
5853
13
31
1
154
31
1
5853
ABSORBER
QC=0.0
QR=0.0
STRIPPER
QC=0.0
QR=307.0
PUMP
W=1.9
LIQHX2
LIQHX1
Q=-624.8
GASHX1
Q=53.0
GASHX2
Q=-53.0
SCRUBER
QC=0.0
QR=0.0
CONDENSE
Q=-77.0
GASCOOL2
Q=-8.3
BLOWER
W=33.6
LIQCOOL
Q=-197.9
WPUMP
W=0.1
Q=-108.8
WCOOLER1
Q=0.0
B5
W=0.0
B6W=0.0
B7
B8
B10
Q=-33.9
B1
Q=0.0
B3
Q=0.0
B4
Q=0.0
Temperature (C)
Pressure (bar)
Mass Flow Rate (kg/hr)
Q Duty (kW)
W Power(kW)
17
B11
Q=0.0
16
1
592718
Initial
Research 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018
Further development
Trialing an advanced process
at Vales Point Power Station

13.  Low cost, robust, more benign than other amines
 High CO2 loading capacity
 Low regeneration energy and production of high pressure CO2
 Potential to remove multi-components (SOx, NOx and CO2)
simultaneously and produce value added products
 Established technology
Project background – Ammonia based PCC process
Advantages
Areas for improvement
 Relatively low CO2 absorption rate compared to amine
based solvent
 Relatively high ammonia loss at high CO2 absorption rate.
 Formation of ammonium-bicarbonate solids
 The available process simulation models were insufficient to
support the process optimisation and scale up

14. Project Objectives
1. Develop a novel aqueous ammonia based solvent which has fast CO2
absorption rate equivalent to MEA while maintaining a low regeneration
energy requirement.
2. Further advance the combined SO2 removal and ammonia recovery
technology to eliminate additional FGD, reduce the ammonia slip in the
exiting flue gas to acceptable levels and produce a value added fertiliser,
i.e. ammonium sulphate.
3. Further develop CSIRO high pressure absorption to enhance CO2
absorption, reduce ammonia loss and cooling water consumption.
4. Develop and validate a rigorous rate based model for the capture process
and identify new process configurations to achieve further savings on
capture costs.
Ultimately, develop a process which can reduce
1. investment and running cost in the Australian context.
2. potential environmental risks resulting from the
implementation of PCC technologies.

15. Approaches and Methodology
CO2
Stripper
Steam
Reboiler
Condenser
Pretreatment
Washing
Heat
Exchanger
CO2
absorber
Flue gas
Clean gas
NH3 recycle unitPower station
CO2 capture unit
CO2 product
Combined removal
 Additives
 High pressure
absorption
 Staged absorption-
recycling solvent
Stripper configurations
Rich split
Inter-heating
Rate-based process model
Approaches

16. Approach and Methodology
2 Process model
Methodology
1 Experimental, pilot plant and bench scale facilities
A rigorous, rate-based model using Aspen Plus RateSep was used to determine
technical performance of the process improvements
3 Cost model
1 Capital cost
2 Operating & maintenance (O&M) cost including electricity cost, fixed cost and cooling water
Aspen Capital Cost Estimator for calculation of cost of each equipment
 Size of equipment, column, packing, pump, etc.
 Cooling water consumption
 Energy consumption including power loss due to steam extraction

17.  Development and validation of a rate-based model for the system of
NH3-CO2-SO2-H2O
• Pitzer based thermodynamic model
• RateSep module, a rate-based absorption and stripping unit operation model
• Two-film theory;
• Mass and heat transfer resistances;
• Liquid film is discretized into multiple film segments;
• Film segments near the interface are much thinner
Interface
XCO2
int
Tint
YCO2
int
TV
YCO2
bulk
Vapour film Liquid film
Vapour bulk phase Liquid bulk phase
Mass and heat transfer
TL
XCO2
bulk
CO2
NH3
H2O
N2
2NH COO
3HCO
2
3CO 
4NH OH
3H O
3NH
2 2CO SO
2H O
SO2
O
2
3SO 
3HSO
2
2 5S O 
Results and Discussion

18. Results and Discussion
 Model development of NH3-CO2-SO2-H2O
Equilibrium reactions
No. Reaction
Equilibrium parameter
A B C D
1 NH3 + H2O <--> NH4
+
+ OH-
-1.2566 -3335.7 1.497 -0.0370
2 2H2O <--> H3O+
+ OH-
132.899 -13445.9 -22.477 0
3 HCO3
-
+ H2O <--> CO3
2-
+ H3O+
216.049 -12431.7 -35.481 0
4 H2O + HSO3
-
<--> H3O+
+ SO3
2-
-25.290 1333.400 0 0
5 2H2O + SO2 <--> H3O+
+ HSO3
-
-5.978673 637.395 0 0
6 NH4HCO3(S) <--> NH4
+
+ HCO3
-
8.064 -5013.759 0 0
7 (NH4)2SO3(S) <--> 2 NH4
+
+ SO3
2-
Compute from Gibbs Energies built in Aspen
8 (NH4)2SO3(S)`H2O<--> 2 NH4
+
+ SO3
2-
+H2O Compute from Gibbs Energies built in Aspen
Kinetic reactions
No. Reaction
Kinetic factor
k E(cal/mol)
1 CO2 + OH-
--> HCO3
-
4.32e+13 13249
2 HCO3
-
--> CO2 + OH-
2.38e+17 29451
3 NH3 + CO2 + H2O --> NH2COO-
+ H3O+
1.35e+11 11585
4 NH2COO-
+ H3O+
--> NH3 + CO2 + H2O 4.75e+20 16529
Equilibrium
Kinetic

19. Results and Discussion
 Model validation of NH3-CO2-SO2-H2O : thermodynamic
 Comparison between experimental and simulation results
CO2 partial pressure Total pressure
Species profile Solution pH

20. Results and Discussion
 Model validation of NH3-CO2-SO2-H2O : Kinetic (1) – CO2 absorption by NH3
Average relative error
for CO2 absorption rate: ±6%
Simulation results vs pilot plant results
Average relative error
for NH3 loss rate: ±11%

21. Results and Discussion
 Model validation of NH3-CO2-SO2-H2O : Kinetic (2) – SO2 removal by NH3
08:24 09:36 10:48 12:00 13:12 14:24 15:36
0
2
4
6
8
10
12
1.8kg/hr NH3
1.0kg/hr NH3
0.5kg/hr NH3
0.2kg/hr NH3
Time
Simu.
Water
(a) Expt.
pH
SO2concentration/ppmv
Time
Expt.(b)
08:24 09:36 10:48 12:00 13:12 14:24 15:36
0
50
100
150
200
250 Simu.
1.8kg/hr NH3
1.0kg/hr NH3
0.5kg/hr NH3
0.2kg/hr NH3
Water
0
100
200
300
400
500
1.8kg/hr NH3
1.0kg/hr NH3
0.5kg/hr NH3
0.2kg/hr NH3
Water
Expt.
NH3concentration/ppmv
Time
08:24 09:36 10:48 12:00 13:12 14:24 15:36
Simu.(c)
Comparison of pilot plant data with simulation results
pH of water
Gas outlet SO2
concentration
Gas outlet NH3
concentration

22. Results and Discussion
 Process design (1): novel process for removal SO2 and CO2 and recovery of NH3
Pump
Chiller
Heater
Pretreatment
Washing
Heat
Exchanger
Pump
CO2
absorber
Vent gas
SO2
Recovery
SO2 fertilizer
Water makeup
CO2 rich
CO2 lean
Flue gas
NH3 rich
NH3 lean
Coal-fired
Power Station SO2 Removal and NH3 Recycling Process
Typical CO2
Capture Process
Flowrate, 760kg/h
T = 120oC
CO2: 10.7
SO2: 200ppm
H2O: 6.0
Flowrate, 656kg/h
T = 16.9 oC
CO2: 3.23
NH3: 1.2
SO2: 0ppm
H2O: 1.8
T= 10oC
Hot

23. Results and Discussion
 Rate based modeling results of SO2 removal and NH3 recovery
0 50 100 150 200 250 300 350
0
20
40
60
80
100
SO2 capture efficiency
Outlet SO2 concentration
Number of cycles
SO2captureefficiency/%
0
10
20
30
40
50
60
70
OutletSO2concentration/ppbv
0 50 100 150 200 250 300 350
0
10
20
30
40
(NH4)2S2O5
NH4HSO3
Mass/%
Number of cycles
(NH4)2SO3
0 50 100 150 200 250 300 350
0
20
40
60
80
100
NH3 for SO2 capture
NH3reuseefficiency,%
Number of cycles
NH3 recycle to CO2 absorber
0
5
10
15
20
25
Vent gas NH3
NH3concentration,ppmv
>99% SO2 removal
>99% NH3 reuse
(NH4)2SO3 Low energy consumption

24. Results and Discussion
 Process design (2): Staged-absorption
Staged Absorption Configuration
Inter-cooling
to 25 oC
CO2
absorption
NH3
mitigation
Benefit: >50% NH3 reduction

25. Results and Discussion
CO2 lean
Rich/lean
Heat exchanger
Stripper
Steam
Reboiler
Condenser
CO2 product
Pump
Cooler
Cooling water
CO2 rich
from absorber
CO2 lean
to absorber
Cooling water
Drum
CO2
Stripper
Steam
Reboiler
Condenser
Rich/lean
Heat exchanger
Pump
CO2 Rich
from absorber
CO2 Lean
to absorber
CO2 product
Split
unsplit
Cooling water Cooling water
Drum
Cooler
Rich split
CO2 lean
Inter-heating
Heat exchanger
Stripper
Rich/lean
Heat exchanger
CO2 lean
to absorber
CO2 rich
from absorber
Steam
Reboiler
Condenser
CO2 product
Pump
Pump
Cooling water Cooling water
Drum
Cooler
Inter-heating
Reference
 Process design (3): advanced stripper configurations

26. Results and Discussion
Base case study 500 MW power station, three process trains with
each to capture 1 MT CO2
CO2 regeneration rate =118.4 Tonne/h
NH3 = 6.8%
CO2 loading lean =0.25
CO2 loading rich = 0.42
Solvent T at inlet of absorber = 25oC
Solvent T at inlet of heat exchanger = 40oC
T difference = 10oC
Stripper P =10 bar
Stripper bottom T = 145.5oC
CO2 lean
Rich/lean
Heat exchanger
Stripper
Steam
Reboiler
Condenser
CO2 product
Pump
Cooler
Cooling water
CO2 rich
from absorber
CO2 lean
to absorber
Cooling water
Drum
Item Value
Stripper column Diameter = 6.8 m and Height = 10.75 m,
Mellapack 250Y
Reboiler duty 3.2 GJ/Tonne CO2
Condenser duty
1.5 GJ/Tonne CO2

27. Results and Discussion
Rich split process
CO2
Stripper
Steam
Reboiler
Condenser
Rich/lean
Heat exchanger
Pump
CO2 Rich
from absorber
CO2 Lean
to absorber
CO2 product
Split
unsplit
Cooling water Cooling water
Drum
Cooler
0.00 0.02 0.04 0.06 0.08 0.10
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
4.5
Heatrequirement,MJ/kgCO2
Split fraction
Heat of CO2 desorption
Heat of vaporization
Sensible heat
0.00 0.02 0.04 0.06 0.08 0.10
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
4.5
5.0
Energyduty,MJ/kgCO2
Split fraction
Reboiler duty
Condenser duty
Total duty
Rich solvent split
Less solid
formation

28. Results and Discussion
Inter-heating process
CO2 lean
Inter-heating
Heat exchanger
Stripper
Rich/lean
Heat exchanger
CO2 lean
to absorber
CO2 rich
from absorber
Steam
Reboiler
Condenser
CO2 product
Pump
Pump
Cooling water Cooling water
Drum
Cooler
0 2 4 6 8 10 12 14 16
132
134
136
138
140
142
144
146
Temperature,oC
Stage number
Reference stripper
Inter-heated stripper
Inter-heating stage 5
Inter-heating
0
500
1000
1500
2000
2500
3000
3500
4000
4500
Inter-heated stripper
Heatrequirement,kJ/kgCO2
Reference stripper
Heat of vaporisation
Sensible heat
Heat of CO2 desorption

29. Results and Discussion
Combined rich split and inter-heating
CO2 lean
Inter-heating
heat exchanger
Stripper
Rich/lean
Heat exchanger
CO2 lean
to absorber
CO2 rich
from absorber
Steam
Reboiler
Condenser
CO2 product
Pump
Pump
Cooling water
Cooling water
Split
Un-split
Stripper
Steam
Reboiler
Condenser
Pump
CO2 Rich
from absorber
CO2 Lean
to absorber
CO2 product
Split
Unsplit
Cooling water
Pump
Cooler
Condensate
Cooler
Rich/lean
Heat exchanger
Inter-heating
heat exchanger
(a) Inter-heating integrated rich-split process (b) Inter-heating integrated cold rich bypasss
Drum
Drum
0
0.5
1
1.5
2
2.5
3
3.5
Reference Rich split Inter-heating Inter-heating &
rich-split
Reboiler/Condenserduty,GJ/tonCO2
Reboiler duty
Condenser duty24.8%
83.4%

30. CO2
Stripper
Steam
CO2Compressor
For transport &
storage
Reboiler
Condenser
Cooler 3
Cooler 2
Cooler 1
Blower 1
Pump 2
Chiller
Heater
Pretreatment
Wash
Heat
Exchanger 1
Heat
Exchanger 2
Pump 1 Pump 3 Pump 5
CO2
absorber
Stage-1
Stage-2
Clean gas
Mixer
H2O and NH3
Makeup
H2O makeup
NH3 recycle &
SO2 removal unit
CO2 compressorCO2 capture unit
CO2 Rich
CO2 Lean
NH3 Rich
NH3 Lean
Water Separation
Unit
CO2 product
Pump 4
Split 1
Split 2
Heat
Exchanger 3
Blower 2
Hot flue
gas with
SO2
Water make-up
and disposal
Recovery of
sulfur
Results and Discussion
 Techno-economic assessment of an advanced aqueous ammonia-based CO2
capture technology for a 650 MW coal fired power station, 38.9% net efficiency
U.S. Energy Information Administration, 2013. Updated capital cost estimates for utility scale electricity generating plants

31. Results and Discussion
Main design parameters
Columns Packing material Packing height Actual column size
CO2 absorber
stage 1 Mellapak-250Y 15m
D=12m; H=26.5m
stage 2 Mellapak-250Y 5m
CO2 stripper Mellapak-250Y 8m D=6.8m;H=10.75m
NH3 washing column Mellapak-500Y 10m D=10m; H=13.25m
Pretreatment column Mellapak-500Y 15m D=10m; H=19.5m
Temperature
°C
Pressure
bar
Total mass flow-rate
Tonne/h
CO2 flow-rate
Tonne/h
Composition, vol/%
CO2 H2O O2 N2
120 1.01 3180 560 10.7 6.0 7.8 75.5
Flue gas properties from power station
Simulation conditions of each column in one process train (4 trains for the whole power station)
 Techno-economic assessment

32. Results and Discussion
Pulverised black coal
no CO2, no SO2
Pulverised black coal
with MEA CO2 + SO2
Pulverised black coal
with NH3 CO2 + SO2
Powerplantoutputefficiency,%
0
10
20
30
40 38.9%
28.3%
31.3%
 Techno-economic assessment
Pulverised black coal
no CO2, no SO2
Pulverised black coal
with MEA CO2 + SO2
Pulverised black coal
with NH3 CO2 + SO2
Levelisedcostofelectricity,2013US$/MWh
0
20
40
60
80
100
120
140
66
131
110

33. Conclusions
1. Development of a rigorous rate-based model for the SO2—NH3—CO2—H2O
system
2. Development of an advanced aqueous NH3 based capture process which
incorporates new features including combined SO2 removal and NH3 recycle,
staged absorption and new stripper configurations
3. Technical and economic assessment has shown the advanced process
consumes less energy and reduce capture costs significantly compared to a
reference MEA process

34. Future research
 Pilot plant trials of the advanced NH3 process to confirm the benefits
 Integration of the capture process with an Australian Power Station
including heat integration to reduce cooling duty
 Integration of SO2 removal, ammonium sulphate fertiliser production
and CO2 capture
 Environmental impact of the capture process including proper
dispersion through the stack
 Economic assessment of the capture process under Australian
conditions

35. Acknowledgments
o Dr Leigh Wardhaugh, Dr Paul Feron, Dr Merched Azzi, Dr Graeme Puxty, Dr
Will Conway @ CSIRO
o Lichun Li, Prof Marcel Maeder, Dr Robert Burns @ Newcastle University
o Prof Moses Tade @ Curtin University
o Dr Qunyang Xiang, Prof Mengxiang Fang @ Zhejiang University
o Dr Jingwen Yu, Ruize Lu, A/Prof Shujuan Wang, Prof Jian Chen @Tsinghua
University
o Dr Nan Yang, Prof Dongyao Xu @ China University of Mining and Technology
(Beijing)
The authors wish to acknowledge financial assistance provided through both CSIRO Energy and Australian
National Low Emissions Coal Research and Development (ANLEC R&D). ANLEC R&D is supported by Australian
Coal Association Low Emissions Technology Limited and the Australian Government through the Clean Energy
Initiative. The views expressed herein are not necessarily the views of the Commonwealth, and the
Commonwealth does not accept responsibility for any information or advice contained herein.

36. Publications
1. ANLEC R&D reports
http://www.anlecrd.com.au/projects/development-of-the-advanced-
aqueous-ammonia-based-post-combustion-capture-technology
2. Journal publications
1. Li et al, Techno-economic assessment of an advanced aqueous ammonia-based post-combustion capture process
integrated with a 650-MW coal-fired power station, Environmental Science &Technology, 2016, 50, 10746-10755.
2. Yu et al, Experimental studies and rate-based simulations of CO2 absorption with aqueous ammonia and piperazine
blended solutions, International Journal of Greenhouse Gas Control, 2016, 50, 135-146.
3. Li et al, Technical and Energy Performance of an Advanced, Aqueous Ammonia-Based CO2 Capture Technology for a
500 MW Coal-Fired Power Station, Environmental Science &Technology, 2015, 49, 10243-10252.
4. Li et al, Rate-based modelling of combined SO2 removal and NH3 recycling integrated with an aqueous NH3-based
CO2 capture process. Applied Energy, 2015, 148, 66-77.
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37. Thank you
Hai Yu
Senior Research Scientist
CSIRO Energy
t +61 2 4960 6021
e hai.yu@csiro.au

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