Delta Purification`s Solvent Reclaimer Operation and

September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
1
DELTA PURIFICATION’S SOLVENT RECLAIMER
OPERATION AND PERFORMANCE IN THE CLEAN-UP OF
DEGRADED SOLVENTS USED IN CO2 CAPTURE FROM
COAL-FIRED POWER PLANT FLUE GASES
Dr. Ahmed Aboudheir, P.Eng.
President, Delta Purification, Regina, SK, Canada
D W
Dr.
Walid
lid ElMoudir,
ElM di P.Eng.
PE
Senior Process Engineer, HTC CO2 Systems, Regina, SK, Canada
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
2
Delta Technology for
Cleanup Degraded Solvents and Glycols
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
3
R l i
Reclaimer
•R
Reclaimer
l i
unit
it iis designed
d i
d tto remove ffrom th
the solvent:
l
t
• high-boiling degradation products,
• ionic species (heat stable salts, HSS),
• impurities and fine suspended solids.
• The type of degradation products is a function of:
• the impurities in the gaseous streams,
• the solvent type,
• the operating conditions of the acid gas absorption plant
plant.
• The type of reclaiming processes
• Ion Exchange; capable of removing HSS only
• Electro-dialysis; capable of removing HSS only
• Thermal distillation, capable of removing of HSS, degradation
products, and solids
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
4
T
Types
off Thermal
Th
l Reclaimers
R l i
iin U
Use
• Kettle
K ttl reclaimer
l i
ffor primary
i
amines;
i
MEA and
d DGA
solvents. Operated at the stripper pressure in order to
return the reclaimer p
product vapour
p
to the stripper.
pp Main
disadvantages:
• Extensive Energy use
• Large
L
volume
l
off waste,
t which
hi h iinclude
l d solvent
l
t
• Reclaimer unit operated under reduced pressure for
secondary and tertiary amines; DEA, DIPA and MDEA.
Main disadvantage:
• Amines reclaimed on a contract basis on-site using mobile units or
off-site
off
site at high cost
• Use of complex design units (High CAPEX & OPEX)
• Require highly experienced operators
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
5
Potential Problems from Accumulation of
Degradation Products in Solvents
• Reduction
R d ti iin solvent
l
t absorption
b
ti capacity
it
• Change of solvent physical properties leads to change
the solvent characteristics and performance.
performance
• Foaming and increased solvent foaming tendency in
absorber/stripper
pp reduce the contact area between g
gas
and liquid phases.
• Increasing solvent corrosivity due to accumulation of
corrosive species
species, such as Heat Stable Salts.
Salts
• Degradation products and heat stable salts lead to
increase the replacement/change
replacement/change-out
out of mechanical and
activated carbon filters and solvents makeup, which will
increase the operating and maintenance costs.
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
6
Delta Reclaimer™
Reclaimer Advantages Compared to
Existing Technologies
• Less capital cost
• Less operating cost
• Less waste for disposal
• Less utility consumptions
• Simple to operate and
maintain
a ta
• Higher recovery rate for
solvent
• Reclaims single, mixed, and
formulated solvents
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
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D lt R
Delta
Reclaimer
l i
IIntegration
t
ti att the
th SVM CO2 Capture
C t
Plant
Pl t
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
Delta Reclaimer
Reclaimer™ Process Diagram;
Patented Technology
8
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
9
Delta Reclaimer Main Operating Parameters
• Saturated low pressure
steam at 40 psig
• Reclaimer
R l i
operating
ti att an
absolute pressure of 190
mmHg (Torr)
• Reclaimer operating
temperature 180 to 205
205°F
F
• Cooling water at 75 °F
• Chemical injection
• 28 wt% Soda ash or
• 50 wt% Caustic soda
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
10
Samples of the Main Process Streams
• Colours of the Samples from right to
left; Reclaimer Feed, Reclaimer
Product, and Process Fluid
• Collected concentrated Waste for
Disposal on a Continues Basis
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
11
Solvent recovery rate and energy consumption
Process Data
Reclaimer Operating Pressure,
mmHg
Reclaimer Operating
Temperature °F
Temperature,
F
Chemical Injection for
neutralization
Run No. 1 Run No. 2
Run No. 3
190
190
190
185 ±5
185 ±5
200 ±5
28 wt%
Na2CO3
28 wt%
Na2CO3
50 wt% NaOH
Average total impurities, wt%
1.45
5.80
8.50
Total Solvent Recovery
Recovery, %
98%
95%
91%
lb saturated steam (40 psig)
per lb product
0.97
1.1
0.95
September 8, 2015
12
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
R #1
Run
1: S
Sample
l analysis
l i
Process Streams
MEA Concentration, wt%
CO2 loading, mol/mol
Feed
17.51
0.085
Product
17
0.128
Specific gravity
1.0393
1.013
1.3636
1
3636
10.4
10.91
1.24
846
793
289
372
8,656
6,452
68
3 874
3,874
1.352
1
352
10.65
11.39
0.15
13
9
78
78
25
16
0
0
15
0
5
03
0.3
Refractive
R
f ti Index
I d att 20 oC
pH with CO2
pH without CO2
) wt% as MEA
Heat stable salts ((HSS),
T. Formate, ppm
T. Acetate, ppm
Organic
HSS
T. Glycolate, ppm
T Oxalate,
T.
Oxalate ppm
Sulfate, ppm
Inorganic HSS
Chloride, ppm
Nitrite, ppm
N (hydroxyethyl) glycine ppm
N-(hydroxyethyl)-glycine,
Degradation
N-(N-hydroxyethyl-ethylamine)Products
ethylenediamine, ppm
Heavy metals
Fe ppm
Fe,
September 8, 2015
13
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
R #2
Run
2: S
Sample
l analysis
l i
Process Streams
MEA C
Concentration,
t ti
wt%
t%
CO2 loading, mol/mol
Feed
16 75
16.75
0.100
Product
17 04
17.04
0.120
Specific gravity
1.0485
1.0145
1.3673
1
3673
10.42
10.91
1.18
915
917
424
356
10,575
10,263
61
4 771
4,771
1.3493
1
3493
10.57
11.25
0.23
0
35
11
185
76
23
0
16
7
‐
7
0.1
Refractive Index at 20 oC
pH with CO2
pH without CO2
Heat stable salts (HSS), wt% as MEA
T. Formate, ppm
T. Acetate, ppm
Organic
HSS
T. Glycolate, ppm
T. Oxalate, pp
ppm
Sulfate, ppm
Inorganic HSS
Chloride, ppm
Nitrite, ppm
N-(hydroxyethyl)-glycine ppm
N-(hydroxyethyl)-glycine,
Degradation
N-(N-hydroxyethyl-ethylamine)Products
ethylenediamine, ppm
y metals
Heavy
Fe,, ppm
pp
September 8, 2015
14
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
R #3
Run
3: S
Sample
l analysis
l i
Process Streams
MEA C
Concentration,
t ti
wt%
t%
CO2 loading, mol/mol
Feed
17 25
17.25
0.070
Product
16 87
16.87
0.055
Specific gravity
1.0705
1.023
1.3701
1
3701
10.51
‐
1.105
644
673
477
284
11,183
17,193
56
4 291
4,291
1.3492
1
3492
10.94
11.17
0.1
30
9
141
94
23
21
0
0
‐
‐
4.8
0.1
Refractive Index at 20 oC
pH with CO2
pH without CO2
Heat stable salts (HSS), wt% as MEA
T. Formate, ppm
T. Acetate, ppm
Organic
HSS
T. Glycolate, ppm
T. Oxalate, pp
ppm
Sulfate, ppm
Inorganic HSS
Chloride, ppm
Nitrite, ppm
N-(hydroxyethyl)-glycine ppm
N-(hydroxyethyl)-glycine,
Degradation
N-(N-hydroxyethyl-ethylamine)Products
ethylenediamine, ppm
y metals
Heavy
Fe,, ppm
pp
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
15
Heat stable salts of feed and product streams
Feed ((Run 1))
Feed (Run 2)
Feed (Run 3)
Heat S
Stable
e Salts,
wt% as M
MEA
1.50
Product ((Run 1))
Product (Run 2)
Product (Run 3)
1.25
1.00
0.75
0.50
0.25
0 00
0.00
0
2
4
6
8
10 12 14 16 18 20 22 24
Data Point
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
16
R 2:
Run
2 Impurities
I
iti concentration
t ti iin main
i streams
t
Degrad
dation P
Product o
or Heat
Stable Sa
S
alt Anion
n
Co
oncentra
ation , pp
pm
1,000,000
Feed
100,000
10 000
10,000
1,000
100
10
1
MEA Trimer = N-(N-hydroxyethyl-ethylamine)-ethylenediamine
HEGly = N
N-(hydroxyethyl)-glycine
(hydroxyethyl) glycine
Product
Waste
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
17
C
Conclusion
l i & Fi
Findings
di
• Excessive contaminated solvent has been restore to almost its
original purity: colorless, 17 wt% MEA & minimum impurities.
• Low Operating Cost;
• 98% recovery rate for solvents with 1.5 wt% contaminants &
• 91% recovery rate for solvents with 8.5 wt% contaminants
• Energy consumption 1 lb steam (40 psig) per 1 lb product
• Easy to operate and maintain
• Minimum attention from the plant operator.
• Minimum waste for disposal, concentrated waste was collected
periodically while the reclaimer process was in continuous operation
operation.
• Low Capital Cost; simple process configuration and few unit
operations
• Reclaims single,
single mixed
mixed, and formulated solvents
• Assist the CO2 Capture Plants to meet the production capacity and
cleanup targets at minimum operating cost, emission to atmosphere,
and
d waste
t for
f disposal
di
l
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
18
A k
Acknowledgment
l d
• The support provided by the SVM staff, engineers
and technicians to operate the Delta Reclaimer at
SVM facility,
• The detailed lab analysis
y
of the feed, product,
and waste samples by:
• Dr. Gary Rochelle, University of Texas, Austin
• Mr. Paul Nielsen, University of Texas, Austin
September 8, 2015
PCCC3, Regina, SK, Canada, September 8 - 11, 2015
THANK YOU …
For more information:
F
i f
ti
Ahmed Aboudheir
002 – 2305 Victoria Ave
R i
Regina,
SK
SK, S4P 0S7,
0S7 Canada
C
d
[email protected]
+1-306-352-6132
+1 306 501 8227
+1-306-501-8227
19