CO2 Capture by Amine Scrubbing By Gary T. Rochelle
Transcript of CO2 Capture by Amine Scrubbing By Gary T. Rochelle
CO2 Capture by Amine ScrubbingBy
Gary T. Rochelle
Luminant Carbon Management Program
Department of Chemical Engineering
The University of Texas at Austin
Workshop on CO2 Capture
UNAM, Mexico City,
March 28, 2012
Central Messages
• Amine Scrubbing is THE technology for CO2
capture from Coal Power plants
• Energy consumption by amines is approaching 20 % of the plant output, a practical lower limit.
• Solvent degradation & contamination will probably limit the chemical cost to less than $5/lb.
40% of US CO2 emissions are From Electricity Generation
78%
CO2 Capture & Storage
Boiler ESP
Flyash
FGD
CaSO4
CaCO3
Abs/Str
Disposal
Well
Turbines
150 atm CO2
Coal
Net
Power
3-6 atm stm
-NOx
NH3
12% CO2
5% O2
10 ppm SO2
40oC
Packed
Absorber
1 bar
Stripper
2 bar
Packing
or Trays
30 wt% MEA CO2
Reboiler
45 psig stm
Amine Scrubbing (Bottoms, 1930)
DT=5C
115C
Aqueous Abs/Str: Near commercial
– 100’s of plants for treating H2 & natural gas
• MEA and other amine solvents
• No oxygen
– 10’s of plants with combustion of natural gas
• Variable oxygen, little SO2
• Fluor, 30% MEA, 80 MW gas, 15% O2
• MHI, KS-1, 30 MW, <2% O2
– A few plants with coal combustion
• Abb-Lummus, 20% MEA, 6, 8, & 33 MW
• Fluor, 30% MEA, 3 small pilots, 5 MW
• CASTOR, 30% MEA, 1 MW pilot
• MHI, KS-1, <1 MW pilot, 25 MW
Tail End Technology Ideal for Development, Demonstration, & Deployment• Low risk
– Independent, separable, add-on systems
– Allows reliable operation of the existing plant
• Failures impact only Capture and Sequestration
• Low cost & less calendar time
– Develop and demonstrate with add-on systems
– Not integrated power systems as with IGCC
• Reduced capital cost and time
– Resolve problems in small pilots with real gas
– Demo Full-scale absorbers with 100 MW gas
• Ultimately 500 MW absorbers
Other Solutions for Coal• Oxy-Combustion
– O2 plant & compression require more energy
– Gas recycle, boiler modification for high CO2
– Gas cleanup, compression including air leaks
• Coal Gasification / Combined Cycle
– O2 plant, complex gasifier, cleanup, CO2 removal
– Not ready for deployment
– Relatively more expensive on PRB or lignite
– New plants only
• Neither is Tail end: More suitable for new plants
– Require higher development cost, time, and risk
– Not suitable for on/off to address peaking
Issues of absorption/stripping
Practical Problem is Cost
$40-70/ton CO2 removed = $40-70/MWh
• Energy = 20-30% of power plant output
– $20/ton CO2
– Theoretical Minimum is 11%
• Capital Cost $500-1000/kw – Absorber for 500 MW:20x20x20 m
– $20-40/ton CO2 for capital charges & maint
• Amine degradation/environmental impact
– $1-5/ton CO2
History RepeatsCaCO3 Slurry:::Amine Scrubbing
CaCO3 Event Amine
1936 1st commercial plant 1980
1958 Too commercial for Gov. support
“Nearly Insurmountable” issues
1991
1960-75 Government funds advanced alts 1990-
1970-85 Govern. & EPRI fund test facilities 2010-
1968 60-250 MW prototypes 2015
1977 500+ MW deployed per regulations
First choice dominates
2020
Messages on Energy• Reversibility is King
• Greater Capacity reduces Sensible Q
• Saturation Stripping is more reversible
• Faster Solvents Enhance Reversibility
• Greater Heat of Absorption Reduces Energy
• Greater Stripping T is more reversible
• Enhanced Stripping is more reversible
• Energy is approaching 50% of theoretical, a practical limit
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Outline
2G/3G Amine scrubbing is available, e.g. PZ at high T
Reduced Energy use requires high DHCO2 & large T swing
Inefficiency of mechanical compression eliminates membranes, P swing adsorption, and oxycombustion.
Competitive cross-exchanger efficiency will be difficult to achieve with solids and viscous liquids.
Adequate CO2 absorption & stripping mass transfer rate is achievable with aqueous amines.
Water is significant but manageable.
Aqueous amine energy performance will not be beat by advanced capture technologies.
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T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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Advanced Capture Technologies
Claim to Reduce Energy Use Separation Driven by Mechanical Compression
Membranes
Pressure Swing Adsorption
Oxycombustion
Separation Driven by Thermal Swing Heat
Amine Scrubbing with high T stripping
Thermal Swing Adsorption
Nonaqueous Solvent Scrubbing
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T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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The “MEA” 1G Standard
Amine scrubbing with absorption/stripping
Post-combustion technology
80 years experience in acid gas treating
Amine capture processes (Econamine & KS-1)
30 wt % (7 m) MEA benchmark (1st generation)
Fast, high DHabs, good capacity, low m, low cost
Not thermally or oxidatively stable
Background
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Concentrated Piperazine (8 m, 40 wt %)
Representative 2G/3G amine technology
Fastest rate of CO2 absorption
Resistant to oxidation & thermal degradation
High-T 2-stage flash process for piperazine
Twice the capacity of 7 m MEA
Acceptable DHabs = 65-70 kJ/mol
Published performance
Higher chemical cost, greater viscosity, constrained by solid precipitation
Background
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T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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PZ High Temperature 2-Stage Flash
Process Flowsheet
16
Absorber
40 °C
Flash Tank
17 bar
150 °C
Flash Tank
11 bar
150 °C
Cross-Exchanger
T Approach = 5 °C
Scrubbed Flue Gas
Flue Gas
Steam
Intercooling
High Temperature 2-Stage Flash
Concentrated Piperazine
Solvent
Energy Analysis
Ldg = 0.31
Ldg = 0.41
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Overall Energy Analysis
of Thermal Swing Regeneration
for Amine Scrubbing & Adsorption
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1. Energy analysis must consider
Regeneration P & T/P value of steam
2. Good Energy Performance requires
Greater DHCO2 abs/ads
Maximum regeneration T/P
Minimum abs/ads T (intercooled)
T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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Total Equivalent Work Single-Stage Flash
Calculate total equivalent work for generic single-stage flash
ΔHCO2 for 60, 70, 80 kJ/mol
T = 90 to 150 °C
Correlate to
DDD
Kgmol
kJ][
T
1HH H2OCO2
pumpcompequivtotal WWWW
5T
T5TQ75.0W
flash
sinkflashflashequiv
Energy Analysis
18
Thermal Compression increases Stripper P at greater DHabs &Tstrip (lower comp work)
Thermal Compression reduces heat for water vapor at greater DHabs &Tstrip (less stripping steam)
D
stripabs
abs
absCO
stripCO
TTR
H
P
P 11ln
*
,
*
,
2
2
STRIPABS
OHCO
ABSCO
OH
STRIPCO
OH
TTR
HHEXP
P
P
P
P 11)(22
2
2
2
2
T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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Maximizing T Swing & DHCO2 Swing Reduces Weq
180
240
300
360
5 10 15 20 25 30 35
Wto
tal(
kW
h/
ton
ne C
O2)
(DHCO2-DHH20)D(1/T) (kJ/gmol-K)
DHCO2=60 kJ/mole
70
80
Wtotal= Wequiv+Wcomp+Wpump
Piperazine
150 °C
MEA 120 °C
90 °C
Single-stage flash at 90-150 °C
Compression to 150 bar
Lean PCO2 = 0.5 kPa at 40 °C
Energy Analysis
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0
100
200
300
400
500
2000 2004 2008
W (
kW
h/
ton
ne C
O2)
Year
PZ
MEA
Minimum Work = 109 kWh/tonne
Estimated Total Equivalent Work 12% CO2, 90% Removal, 150 bar, 40 °C
Energy Analysis
CO2 Separation = 46 kWh/tonne
Compression = 63 kWh/tonne
pumpcomp
stm
sinkstmequiv WW
T
TTQ75.0W
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Thermodynamic Efficiency of Common Separation Processes
Process Efficiency (%)Wminimum / Wactual
CO2 Capture by Amine Scrubbing 50
Cryogenic Air Separation 25
Common Distillation 15-35
Water Desalination by Reverse Osmosis 21
Therefore it is improbable that we will be better than 200 kwh/ton CO2,with any technology.
T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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Many advanced solvents and sorbents do
not have competitive DHCO2
High DHCO2 is difficult to manage in
intercooled solid adsorber
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Irreversibilities of Two-Stage Flash
ABSORBER
40 °C
150 °C 150 °C
CO2
WIDEAL = 104 kWh/tonne, WREAL = 219 kWh/tonne
25 kWh/
tonne
14 kWh/
tonne9 kWh/tonne
34 kWh/tonne
22 kWh/tonne
Energy Analysis
24
25
Multi-stage compressor Reversibilityto 150 Bar, 40 oC Intercooling, P/P<2.0, 72% eff
5
7
9
11
13
15
17
19
2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5
Wco
mp
(kJ/
mo
l C
O2)
ln (150/Pin)
0.8 atm20 atm
MCOMP Work from Aspen Plus®
Correlation
26
Compression work, P/P<2
1.6
1.7
1.8
1.9
2 3 4 5
Wco
mp/W
idea
l
Inlet Pressure (bar)20 7.5 2.75 1
η=0.80, ε=0.2
η=0.72, ε=0η=0.72, ε=0, 2 piece eqn
Capture processes driven by mechanical compression are not energy competitive
Work(kwh/tonne)
Efficiency(%)
Minimum Work(Isothermal, ideal compression)
111 100
PZ with 2-stage regeneration at 150 °C 219 50
Ideal process driven by real compression72% eff, 40 oC cooling, Pj/Pj-1 =2
(Ideal Membranes or Pressure Swing Adsorption)
206+ 55
Oxycombustion with Ideal air separationReal compressors for Air & CO2
1.35 mol O2/mol CO2
217+ 52
Real Oxycombustion (Darde et al., 2008) 284 40
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CROSS-EXCHANGER
IRREVERSIBILITY
Thermal Swing Regeneration requires
Good Cross Exchange
Close approach T (5C)
High Capacity
Low viscosity
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11th IEA GHG Capture Network Meeting –May 20-21st, 2008 8
0.01
0.1
1
10
0.2 0.25 0.3 0.35 0.4 0.45 0.5
PC
O2
(kPa)
Loading (mol CO2/Equiv PZ)
CO2 solubility in PZ at 40oC4.0 m (Ermatchkov 2006), 3.6 to 8.0 m (This Work)
40°C
0.88 mol CO2/kg"8 m PZ"
0.48 for MEA
1.23 for 2-PE
5
0.5
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Cross-Exchanger Exergy Loss – 25 kWh/tonneSteam Make-up for Unrecovered Sensible Heat Loss
capacity/TCQ D p
)mole/kg 88.0/(K5*)KJ/mole 5.3(
C 155at Steam CO kJ/mole 20 2
stm
sinkstmloss
T
TTQ75.0W
3600*44
61
273155
40155*20*75.0
e
2CO kWh/tonne 25
Energy Analysis
30
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Significance of viscosity
T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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0.1
1
10
100
0 5 10 15
Vis
cosi
ty (
cP)
Cap
acit
y (m
ol C
O2
/kg
[H2
O +
PZ]
N alkalinity (m)
Viscosity
Capacity
Optimum PZ Concentration
T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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0.3
0.35
0.4
0.45
0.5
0.55
0.6
0 5 10 15 20 25
Cap
acit
y/m
0.2
5
(mo
lCO
2/k
g [H
2O
+ a
min
e]/
cP0
.25)
N alkalinity (m)
PZ
MEA
5 m MDEA/5 m PZ
Capacity normalized for viscosity
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Implications for Thermal Swing
advanced liquids & solid adsorbents Viscosity should be low
Hard to achieve <10-20 cP with advanced liquids
Cross-exchange should provide close approach T
Hard to achieve 5-10 oC with solid adsorbents
CO2 Working Capacity should must be high
>0.7 mol CO2/kg sorbent
Primary target of materials development
Working capacity is Dloading not rich loading
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Mass transfer coefficients
Bulk gas
Bulk
liquid
Gas film Liquid film
35 4/19/2011
KG
CO2 flux = k (∆ CO2)
PCO2, bPCO2, i
[CO2]i
[CO2]b
(=PCO2*)
∙ (PCO2,b – PCO2*)CO2 flux =
CO2 flux
= kg (PCO2,b- PCO2,i) = kl ([CO2]i – [CO2]b)
= kg’ (PCO2,i – PCO2*)
Gas-Liquid
Interface
Henry’s Law:
PCO2i= He * [CO2]i
gk
1
Gas Film Reaction Film Diffusion Film
'
gk
0
l
CO
Ek
H2
T2
*
CO
0
PRODl, ][CO
P
k
12
'
gk
1
GK
1
2
2
CO
b2CO
H
[Am]kD
Bulk Gas Bulk Liquid
PCO2,b PCO2,i
G-L Interface
[CO2]i
[CO2]b
(PCO2*)
fast chemical rxn
36 4/19/2011
'
G
1
K
1
gk
Pseudo 1st order kinetics
CO2 removal = area ∙ KG (∆PCO2) ≈ f(area, kg’)Packing Solvent
T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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2
20
10 100 1000 10000
No
rmali
zed
Flu
x
kg„
(10
-7m
ol/
s·P
a·m
2)
PCO2* @ 40 °C (Pa)
8 m PZ
7 m MEA
8
4
6
Absorber ReversibilityCO2 Mass Transfer at 40 °C (Wetted Wall Column)
Energy Analysis
5 %0.5 %
37
T H E U N I V E R S I T Y O F T E X A S A T A U S T I N
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Absorber Exergy Loss – 14 kWh/tonneEstimated Packing Area from kg‟
Ln mean kg’DP = 2.4e-3 gmol/s-m2
Lean: kg’(Pout-Plean*)= 2.2e-6 *(0.012 – 0.005)*105
Rich: kg’(Pin-Prich*) = 5e-7*(0.12-0.05)*105
Absorber packing volume
1.9e3 m3 for 800 MW, 250 m2/m3
0.9 tonne CO2 removed/MW-hr
25 x 25 x 13.5 m
1.5 m/s gas velocity
Exergy lost/mole CO2
RTln(Pg/P*bulk liq) =RTln(0.12/0.05)= 14 kwh/tonne CO2
Energy Analysis
38
Thermal Degradation PZ and its Structural Analogs
24
100 120 140 160 180
Temp to match MEA deg.(°C)
High Temperature Amines
Morpholine (Mor), 169°C
2-Amino-2-methyl-1-propanol (AMP), 139°C
Pyrrolidine (Pyr), 140°C
1-Methylpiperazine (1-MPZ), 148°C
2-Methylpiperazine (2-MPZ), 152°C
Piperazine (PZ), 164°C
Piperidine (PD), 164°C
MDEA in MDEA/PZ Blend, 139°C
HomoPZ, 137°C
Hexamethylenediamine (HMDA), 157°C
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8 m PZ Provides High P at 150 °C
50
60
70
80
90
0.1 0.15 0.2 0.25 0.3 0.35 0.4 0.45 0.5
ΔH
ab
s (k
J/m
ol
CO
2)
PC
O2 (b
ar)
CO2 Loading (moles/equiv PZ)
160 ºC
0.05
1224
6
120
80
40
0.005 ΔHabs
Energy Analysis
19
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Do anhydrous solvents reduce Energy?
Yes
Condenser Work loss results from water
No
PH2O generates valuable stripper P: Anhydrous
solvents/adsorbents generate less P at a given T.
Optimized regeneration, e.g. interheated stripping
eliminates energy loss from water.
Anhydrous solvents/adsorbents pick up water which
must be removed anyway.
41
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Ideal Anhydrous Solvents Reduce Energy
180
240
300
360
5 10 15 20 25 30 35
Wto
tal(
kW
h/
ton
ne
CO
2)
(DHCO2-DHH20)D(1/T) (kJ/gmol-K)
DHCO2
60 kJ/mole
70
80
Wtotal= Wequiv+Wcomp+Wpump
Piperazine
150 °C
MEA 120 °C
90 °C
Single-stage flash at 90-150 °C
Compression to 150 bar
Lean PCO2 = 0.5 kPa at 40 °C
Energy Analysis
42
Anhydrous
Water for reflux
CO2 Multistage, Intercooled Compressor
Lean
Rich
Stripper
Liquid drawoff
<10% H2O
30
32
34
36
38
40
42
44
0.20 0.25 0.30 0.35
Equ
ival
en
t W
ork
(kJ
/mo
l CO
2)
Lean Loading (mol CO2/mol alk)
8 m PZ
0.40 rich loading
150 °C in reboiler(s)
0.31
lean
loading
1-Stage Flash
2-Stage Flash
Simple Stripper
Adiabatic Lean Flash
Interheated Column
0
2
4
6
8
10
0 0.2 0.4 0.6 0.8 1 1.2
kg' a
vg
(x10
7m
ol/p
a∙s
∙m2)
CO2 Capacity (mol CO2/kg solvent)
4/19/201145
Amino
Acids
SarK
PZ Derivatives
Primary
Amine
MEA
EDAHindered
Amines
2-PE
5/5
MDEA/PZ
PZ based
solvents
PZ
2MPZ
Two-dimension comparison of solvents
Fast Solvents
Amine (m)Capacity
-∆Habs
@PCO2 =1.5kPa
kg,’avg x1e-7
@40 °C
Deg T (oC)
k1= 3e-6 s
mol/kg solv kJ/mol mol/s·Pa·m2 3e-9 s-1
PZ 8 0.79 70 8.5 163
1-MPZ 8 0.83 67 8.4 148
MDEA/PZ 5/5 0.99 70 8.3 138
2-MPZ/PZ 4/4 0.84 70 7.1 155
MDEA/PZ 7/2 0.80 68 6.9 138
2-MPZ 8 0.93 72 5.9 151
HEP 7.7 0.68 69 5.3 130
MEA 7 0.47 82 4.3 120
Slow Solvents
Amine (m)Capacity
-∆Habs
@PCO2 =1.5kPa
kg,’avg x1e-7
@40 °C
Deg T
k1=3e-9 s-1
mol/kg solv kJ/mol mol/s·Pa·m2 oC
PZ 8 0.79 70 8.5 163
MEA 7 0.47 82 4.3 120
DGA® 10 0.38 81 3.6 132
AEP 6 0.66 72 3.5 121
2-PE 8 1.23 73 3.5 120
MAPA 8 0.42 84 3.1 114
AMP 4.8 0.96 73 2.4 137
Conclusions
Aqueous Amine & Advanced liquid solvents
– Use solvents with DHCO2>65 kJ/mol
– Run strippers at max T with thermally stable amines
– Intercool absorbers to ambient sink
– Use configurations to recover heat from water vapor
• Anhydrous solvents lose P benefits of water
– Maximize solvent capacity/viscosity
Conclusions
• Mechanical compression is not energy competitive– Membranes
– Pressure Swing Adsorption
– Oxycombustion
• Thermal Swing Adsorption is no magic bullet– Needs DHCO2 > 65 kJ/mol with thermally stable materials
– Must Intercool adsorber
– Must cross exchange solids to 5 oC approach
– Needs Dloading >0.7 mol/kg
– Must maintain efficient mass & heat transfer rates
Solvent Management
Messages on Solvent Management• Thermal Degradation
– Limits max Stripper T
– TMEA < TMDEA <TAMP< TPZ
• Free Radical Autooxidation– If fast, in absorber:: if slow, in heat exchanger
– Alkanolamine > tertiary > Hindered > cyclic(PZ)
– Catalyze by Fe+2, Cu+2, Mn+2
– Inhibit by peroxide/radical scavengers, tertiary amine
• Volatility of amines and degradation products– Absorber water wash may work
– Reduced by hydrophilic groups & speciation
– Nitrosamines from NO2/NO2- + secondary amine
– Reclaiming required for coal impurities
Where is degradation most likely to occur?
Flue Gas
10% CO2
5-10% O2
Purified Gas
1% CO2
30% MEA
a = 0.4-0.5
1 mM Fe+3
CO2
H2O
(O2)
30% MEA
a = 0.3-0.4
Reboiler
Absorber
40 -70 oC
1 atm
Stripper
120 oC
1 atm
Cross
Exchanger
Oxidative
Degradation
Thermal Degradation
5 Mechanisms for Thermal Degradation
• 1. Carbamate Polymerization - MEA
• 2. Cyclic Urea - Ethylenediamine
• 3. Arm Switching/Elimination - Tertiary Amine
• 4. SN2 Ring Opening – Piperazine
• 5. Blend Synergism – Piperazine/MEA
Carbamate Polymerization
• ↔
MEA Carbamate Oxazolidone
→
MEA HEEDA
NHOH CO2-
NHO
O
+ O-
H
NHO
O
OHNH2 + OH
NHNH2 +
O
O
Primary & Secondary Alkanolamines Deg TAmine k1 = 2.91 × 10-8 s-1 Structure T (oC)
2-methyl-aminoethanol 103
Monoethanolamine 120
3-amino-propanol 126
2-piperidine ethanol 127
Diglycolamine® 133
2-methyl-2-amino-propanol 137
Cyclic urea
NH2
NH2 + O O
O
NHNH
1o & 2o Diamines = cyclic ureas Deg TAmine Structure T (oC)
Dimethylethylenediamine 100
Diethylenetriamine 105
Methylaminopropanolamine 114
Hydroxyethylethylenediamine 114
Ethylenediamine 121
Hexamethylenediamine 156
CH3
NH
NH
CH3
2 Tertiary ↔ Quaternary + Secondary
+
CH3
OHN
OH
CH3
OHNH
+
OH
+ OHNH
OH
CH3
CH3
OHN
+
OH
Tertiary1 + Secondary2 ↔ Tertiary2+ Secondary1
Tertiary1 + Quaternary2 ↔ Tertiary2+ Quaternary1
Elimination
CH3
CH3
OHN
+
OH ++CH3
CH3
OHNH
+
OH
OH
OH2
3o amines→2o amines + other 3o aminesAmine Structure T (oC)
Dimethylmonoethanolamine 122
Tetramethylethylenediamine 125
Methyldiethanolamine 128
N-(2-Hydroxyethyl)PZ 132
N,N’-Dimethylpiperazine 139
1-methyl-piperazine 148
CH3 N N CH3
CH3
CH3
N
CH3
CH3N
Ring Opening
NH NH2
+
NH
NH
N NH3
+
NH NH +
NH2
OOH NH O + OH2
Ring Closing
Cyclic ↔ LinearAmine Structure T (oC)
Diglycolamine® 133
Homopiperazine 133
Pyrrolidine 135
2-Methyl-Piperazine 152
Hexamethylenediamine 156
Piperazine 162
Morpholine 169
CH3
NH
NH
NH NH
Interactive Blends• Carbamate Polymerization
NHNHNH
O O+ N
NH
NH
OH
O
+
+ OHNH2
+
OH
NHNH NH+
OH OH
NNH
Secondary2 + Tertiary1 ↔ Tertiary2+ Secondary1
Total Amine Loss in BlendsAmine (m) Structure T (oC)
MEA/PZ 104
MEA/AMP 123
4 AMP/6 PZ 135
7 MDEA/2 PZ 138
4 PZ/4 2MPZ 155
3.9 PZ/3.9 1MPZ/0.2 14DMPZ
160
Oxidation
O2 solubility & Mass Transfer
0.E+0
2.E-5
4.E-5
6.E-5
2.E-04 2.E-03 2.E-02
Am
ine
Oxi
dat
ion
(m
ol/
mo
lCO
2)
Oxygen Rate Constant (s-1)
Total
Absorber
ExchangerSump
PZMEAMDEA
0.60
0.70
0.80
0.90
1.00
0 100 200 300 400
Fra
cti
on o
f In
itia
l Am
ine
Experiment Time (hrs)
8 m PZ
7 m MEA
7 m MEA +
100 mM Inhibitor A
Avoid Oxidation with PZ or Inh A
Oxidation Conditions:
55°C, 1400 rpm
98% O2 / 2% CO2
0.4 mM Fe2+
0.1 mM Cr3+
0.05 mM Ni2+
Inhibitors in MEA at 70 C, 98kPa air, 2kPa CO2
0%
20%
40%
60%
80%
100%
0 1 2 3 4 5
Inh
ibit
ion
(%
NH
3 r
ate
)
Inhibitor (wt%)
EDTA
MDEA
HP
IA
HP+DA
DA
DP
Citric acid
IA + HP
Autoxidation of MEA
InitiationMEAOOH + Fe+2
MEAO• + Fe+3
MEAOOH + Fe+3MEAOO• + Fe+2
Propagation
MEAO• + MEA MEAOH + MEA•
MEAOO• + MEA MEAOOH + MEA•
MEA• + O2MEA-OO•
Termination R• + R• mol. Prod.
Inhibition R• + Inh RH + Inh•
MEAOOH + InhMEAOH + InhO
7 m MEA with transition metalsConditions: 70 C, 98kPa air, 2kPa CO2
0
2
4
6
8
10
12
0 5 10 15 20 25 30 35 40
NH
3 R
ate
(m
mo
l/kg
/hr)
Time (hrs)
1 mM Fe2+
1 mM Cu2+ 1 mM Mn2+
Mild effect: V, Cr
No significant effect:Ti, Mo, Co, Ni, Sn, Se, Ce, Zn
9 m pilot plant MEA with HEDP70 C, 98kPa O2, 2kPa CO2, 0.5mM Fe
0
1
2
3
4
5
6
0 10 20 30 40 50
NH
3 R
ate
(m
mo
l/kg
/hr)
Time (hrs)
HEDP +0.06 to 1.5 wt%
NH3 rate stable for >48hrs →
+ 0.4 wt% DTPA
NN
N
OH
O OH
O
OH
O
OOH
O
OH
CH3 P
P
OHO OH
OH
O
OHOH
Environmental Impact of Degradation Products
Volatile ProductsRequire water wash
Nonvolatile productsRequire Reclaiming
Some Oxidation Products of MEA
Product Structure
Ammonia (V) NH3
Formaldehyde (V, NV) H2CO
Formate (NV) HCOO-
N-(2-hydroxyethyl)-formamide (V)
N-hydroxyethyl-imidazole (V)
N-(2-hydroxyethyl)-2-[(2-hydroxyethyl) amino] acetamide (NV)
OHNHO
Eide-Haugmo
7 m MDEA/2 m PZ Oxidized at 120oC
Products (CO2 carrying)C-Loss
(%)
Diethanolamine/Methylaminoethanol 40
1-methyl PZ 8.4
1,4-Dimethyl PZ 0.9
Aminoethyl PZ 3.5
N-formyl PZ (amide) 8.3
Formate & other acids 2.5
Bicine 5.3
Hydroxyethyl sarcosine 10.5
~79.5
PZ thermal products, 165oCProduct Structure N loss
(%)
N-Formyl PZ (V) 32
NH3 (V) 14
Aminoethylpiperazine(NV)
10
2-Imidazolidone (V) 6
Hydroxyethylpiperazine(NV)
4
NH N
O
O
NH
NHNH2
NH N
OH
NH
N
NH3
OHNH
NHNH2
OHNH
NH2
NNH
O
OH
NNH
O
NHOH
Degradation of 5 M MEA120oC, 0.4 mol CO2/mol MEA
NH2OH
Volatility Issues
• Amine volatility– In H2O
– In loaded solution
– As a methylated degradation product, e.g. 1.4 dimethylpiperazine, methylamine
• Oxidation products– HEI
– Formamide
– Ammonia
– Nitrosamine from sec amine and NO2/NO2-
Amine Volatility (Pa) at 40 oC
Amine Ldg = 0 Ldg: PCO2=500 Pa
@ 40oC
5m MDEA/5m PZ 0.17/3.43 0.16/0.51
7m MDEA/2m PZ 0.56/0.91 0.42/0.21
8m PZ (8.8) 0.78
12m EDA 87 1
7m MEA 10 2.7
5m AMP 14.2 11.2
Nitrosamine Characteristics• Organic compounds containing -N-N=O
• Secondary amine reacts with nitrosating agent
– Nitrous acid in acidic conditions In Vivo
– Nitrite in basic conditions for amine scrubbing
MNPZ and Decomposition at High Temperatures
0.001
0.01
0.1
1
0 2 4 6 8
No
rmal
ize
d M
NP
Z (m
olM
NP
Z/m
olN
O2
i mo
del
)
Time (Day)
120C
150C 50 mM NO2
150C 15 mM NO2
135C
Aerosols
Message on Thermal Degradation
• Stripper energy is constrained by the max T permitted by Degradation
– Linear alkanolamines and diamines degrade by polymerization & urea formation at 100-130oC
– Tertiary amines degrade by arm switching &elimination at 120-140oC
– Piperazine and related cyclic amines degrade by ring opening at 150-165oC.
•
Message on Oxidation
• As amines become more resistant, oxidation shifts from the absorber to the heat exchanger
– MEA & alkanolamines readily oxidize in the absorber unless inhibited by radical or peroxide scavengers
– Tertiary amines inhibit self oxidation, probably by scavenging peroxides
– Piperazine oxidizes only at the higher T of the heat exchanger exit
Message on Environmental Impact
• Amine degradation must be minimized to manage secondary environmental impact.
– Volatile Products can leave with flue gas• Aldehydes, formate, ammonia, volatile amines,
amides
– Nonvolatile products make up reclaimerwaste• Polyamines, Cyclic urea, amino acids
Conclusions
• Amine Scrubbing can be Deployed by 2019
• Improved Amine Solvents and Processes– Reduce Energy from 400% to 200% of Minimum W
– Provide Stable, Benign Solvents
– Simplify systems to reduce capital Cost
• As Limestone Slurry Rules FGD after 30 yrs; Amine Scrubbing will dominate CO2 capture.
• Other technologies are unlikely to compete for Post-combustion capture.