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Separation and Capture of Carbon Dioxide from CO2/H2 Syngas
Mixture Using Semi-Clathrate Hydrates
Jebraeel Gholinezhad, Antonin Chapoy*, Bahman Tohidi
Centre for Gas Hydrate Research, Institute of Petroleum Engineering, Heriot-Watt
University, Edinburgh EH14 4AS, Scotland, U.K.
The relation between anthropogenic emissions of CO2 and its increased levels in the
atmosphere with global warming and climate change has been well established and
accepted. Major portion of carbon dioxide released to the atmosphere, originates from
combustion of fossil fuels. Integrated Gasification Combined Cycle (IGCC) offers a
promising fossil fuel technology considered as a clean coal-based process for power
generation particularly if accompanied by precombustion capture. The latter includes
separation of carbon dioxide from a synthesis gas mixture containing 40 mole% CO2 and
60 mole% H2.
A novel approach for capturing CO2 from the above gas mixture is to use gas hydrate
formation. This process is based on selective partition of CO2 between hydrate phase and
gas phase and has already been studied with promising results. However high-pressure
requirement for hydrate formation is a major problem.
We have used semiclathrate formation from tetrabutylammonium bromide (TBAB) to
experimentally investigate CO2 capture from a mixture containing 40.2 mole% of CO2
and 59.8 mole% of H2. The results shows that in one stage of gas hydrate formation and
dissociation, CO2 can be enriched from 40 mole% to 86 mole% while the concentration
of CO2 in equilibrium gas phase is reduced to 18%. While separation efficiency of
processes based on hydrates and semi-clathrates are comparable, the presence of TBAB
improves the operating conditions significantly. Furthermore, CO2 concentration could be
increased to 96 mole% by separating CO2 in two stages.
Keywords: gas hydrates, TBAB, gas separation, CO2 capture, hydrogen
* Corresponding author. Tel.: +44 0 131 451 3797; fax: +44 0 131 451 3127.
E-mail address: [email protected]
1. Introduction
It is now widely accepted that anthropogenic CO2 emissions from burning of fossil fuels
are largely responsible for the rapid rise in global temperatures recorded over the past
century. Worldwide concerns over the threat of global warming have led industrialised
countries to agree to reduce carbon emissions. In order to meet this goal, the research
communities are trying to develop new solutions for reducing CO2 (and other greenhouse
gas) emissions from existing and new fossil fuel usage.
Integrated Gasification Combined Cycle (IGCC) is rapidly emerging as one of the most
promising technologies in power generation, hydrocarbons (gas, coal and oil) are broken
down to yield a high value natural gas type fuel also called synthesis gas (Barchas and
Davis, 1992). This synthesis gas can be converted (by a shift reaction) into a mixture of
CO2 and H2. A typical synthesis gas from an IGCC power station consists approximately
of a 40 mole% CO2 and 60 mole% H2 mixture at a total pressure of 2.5 to 5 MPa (Klara
and Srivastava, 2002). The separation of carbon dioxide from this mixture, also called
“pre-combustion capture”, is an essential element of these processes. The resultant stream
of H2 could be used in fuel cells or in a gas turbine and the carbon dioxide could be
geologically sequestered. There is an ongoing effort to reduce operating cost of an IGCC
plant, particularly for CO2 capture.
A novel method for CO2 capture and storage is to use gas hydrates (Spencer, 1997; Aaron
and Tsouris, 2005; Linga et al., 2007a; Kumar et al., 2009; Zhang et al., 2009). The basis
for the separation is the selective partition of CO2 between the hydrate phase and the
gaseous phase. The kinetics of hydrate formation in the system CO2/H2-water was studied
by Linga et. al. at 273.7 K and 7.5 MPa (Linga et al., 2007a). However, the 7.5 MPa
operating pressure was higher than the typical pressure of the fuel gas. There is an
ongoing interest in using additives to reduce the operating pressure. Several additives
have been used for this purpose including tetrahydrofuran, hereafter THF (Lee et al.,
2009), propane (Kumar et al., 2009), cyclopentane (Zhang et al., 2009).
Recently, Tetra-n-Butyl Ammonium Bromide (TBAB) has attracted significant attention
as a suitable additive for different hydrate applications such as hydrogen storage (Chapoy
et al., 2007; Struzhkin et al., 2007; Tohidi et al., Int. patent, 2006), air conditioning
(Darbouret et al., 2005; Delahaye et al., 2008; Daitoku and Utaka, 2009) and CO2 capture
(Kang and Lee, 2000; Klara and Srivastava, 2002; Aaron and Tsouris, 2005). This is due
to the fact that small gas molecules (CH4, CO2) could be encaged into the dodecahedral
cavities (S-cage, 512) of TBAB hydrate at favourable pressure and temperature conditions
(Shimada et al., 2005; Arjmandi et al., 2007). TBAB forms semi-clathrates that could
offer greater benefits for CO2H2 separation: operating pressures could be lowered
significantly and therefore less cooling being required for hydrate formation.
TBAB forms semi-clathrate hydrates with water at ambient conditions, i.e. at 1 atm and
12 oC (Jeffrey and McMullan, 1967; Dyadin and Udachin, 1984; Oyama et al., 2005). If a
gas or mixture of gases is associated with these hydrates, the thermodynamic stability of
the mixture becomes even more favourable (Hashimoto et al., 2006; Arjmandi et al.,
2007; Li et al., 2007). Li et. al. measured the dissociation conditions for the system
CO2/H2-TBAB-water for a 39.2% CO2 and 60.8% H2 gas mixture with different
concentrations of TBAB (Li et al., 2009). They found that with the addition of 5 wt%
TBAB, the equilibrium hydrate formation pressure for the typical gas mixture reduces
from 11.01 MPa at 278.75 in the case of pure water to 0.85 MPa at the same temperature
which shows an approximate reduction of 92.3% in the equilibrium pressure. TBAB
semi-clathrates have more stable structures than normal hydrates and forms at lower
pressures. However, no data are given by Li et al. on the separation efficiency and gas
compositions after hydrate formation.
In this study, we have used TBAB to investigate the capture efficiency of CO2 from
CO2/H2 mixture and the kinetics of gas uptake by semi-clathrates formed in the systems
CO2/H2-TBAB-water for TBAB concentrations of 5% and 10% in aqueous solutions. The
results have been compared with systems in which other additives have been used.
2. Experimental section
2.1. Materials
Tetra-n-butylammonium bromide, 50 weight percent in water, was purchased from
Aldrich. Deionised water was used to dilute the tetrabutylammonium bromide solution to
different desired mass fractions in the experiments. Hydrogen was purchased from BOC
gases with a certified purity greater than 99.995 vol. %. Carbon dioxide (> 99.9 % purity)
was purchased from Air Product Ltd.
2.2. Apparatus
The setup used in this work, is shown in Figure 1 The equilibrium cell has an inner
volume of 527 ml and a maximum working pressure of 40 MPa and is hosted in a cooling
jacket. The cell temperature is measured by means of platinum resistance thermometer,
PRT within a precision of 0.01 K. The pressure is measured by a DRUCK pressure
transducer within a precision of 0.008 MPa for the complete operating range of 0-138
MPa. The cell temperature is controlled by a programmable cryostat, which can be kept
stable to within 0.02 K. The stirrer is used to agitate the test fluids. A Varian CP-3800
gas chromatograph (GC) equipped with a thermal conductivity detector, TCD was used
to determine the composition of the gas samples. The temperature and pressure are
continuously monitored and recorded by a computer. The piston vessel containing the gas
mixture is connected to the cell while a pump is used to keep the pressure constant.
2.3. Procedures
In a typical separation experiment, the cell was first vacuumed and a known amount of
TBAB aqueous solution (5 wt% or 10 wt%) was then loaded into the cell to occupy up to
50% of its volume. A certain amount of the CO2/H2 gas mixture was injected to reach the
desired pressure. A piston vessel was kept connected to the cell to maintain the pressure
by injecting water to the bottom of piston vessel with a high-precision Quizix pump. The
number of moles of gas in the cell and the vessel can be determined and controlled by the
amount of fluid injected behind the piston. During the experiment, temperature and
pressure in the system were recorded. The stirrer was started to operate with the speed of
600-700rpm. The cap gas was sampled and compositionally analyzed by GC in order to
determine the amount of gas dissolved in the liquid at equilibrium before hydrate
formation.
When loaded and equilibrated, the cell temperature was lowered until clathrate formation
began. This was confirmed by a rapid rise in the cell temperature as well as an increase of
the rate of fluid injection. When there was no further clathrate formation and the injection
of pump fluid was stopped, the gas in equilibrium with hydrates was sampled and
analyzed by GC in order to determine its composition. The residual gas was rapidly
vented to the atmosphere and hydrates were dissociated by increasing the temperature of
the cell. The gas released from hydrates (including the dissolved gas) was collected,
sampled and analyzed by GC, thus giving the composition of the gas in hydrate.
3. Results and Discussion
The separation tests were carried out with 5 wt% and 10 wt% TBAB aqueous solutions
and volumetric calculations were performed for each concentration. The number of moles
of gas consumed at any time during hydrate formation (nH) can be calculated by the
following equation:
tGG
tGGHzRT
PV
zRT
PVnnn
,0,
,0,
(1)
where nG,0 and nG,t are the number of moles of free gas in the cell before and after hydrate
formation, respectively. P, T, V, z, and R are the system pressure (constant in these
experiments), the system temperature, the volume of the cell occupied by free gas, the
gas compressibility factor and the universal gas constant, respectively. Figures 2 and 3
show the changes in temperature and moles of gas consumed during hydrate formation in
5 and 10 wt% TBAB aqueous solutions, respectively. The pressure is maintained constant
at 3.8 MPa during the process. The trend of gas consumption was similar in both cases.
Initially there is a short period of slow gas uptake which could be mainly due to the
reduction in the system temperature. Then there is a sharp increase in the amount of gas
consumed (trapped in the cages of clathrates) due to hydrate formation. Hydrates
continue to form slowly before it stops and no more gas is consumed.
Figure 4 compares the gas uptake of the two cases. The amounts of gas consumed at the
end of the process are 0.0502 and 0.08604 moles for the 5 wt% and 10 wt% TBAB
aqueous solutions, respectively.
Parameters by which the separation efficiency can be evaluated are: CO2 mole fractions
in different phases, CO2 Recovery (R) and CO2 Separation Factor (S). The CO2 recovery
or split fraction is calculated as (Linga et al., 2007b):
Feed
CO
H
CO
n
nR
2
2 (2)
where Feed
COn2
is defined as number of moles of CO2 in feed gas (feed gas is the sum of the
number of moles of gas present in the gas phase of the cell at the start of the experiment
and the number of moles of gas consumed during hydrate formation from the supply
vessel); and H
COn2
is the number of moles of CO2 in the hydrate phase at the end of the
experiment which accounts for the dissolved gas as well.
The separation factor is determined as (Linga et al., 2007b):
22
11
/
/
/
/
22
22
yx
yx
nn
nnS
gas
H
gas
CO
H
H
H
CO (3)
where gas
Hn2
= number of moles of H2 in the gas phase at the end of the experiment;
H
Hn2
= number of moles of H2 in the hydrate phase; and gas
COn2
= number of moles of CO2
in the gas phase at the end of the experiment.
In addition, x1 and y1 are concentrations of CO2 in hydrate and gas phases at the end of
the experiment, respectively. x2 and y2 are concentrations of H2 in hydrate and gas phases
at the end of the experiment, respectively.
The bar chart in Figure 5 shows the values obtained for CO2 mole fraction in the feed gas
before hydrate formation and in the hydrate phase and gas phase in equilibrium after
semi-clathrate formation. For comparison, results on other systems including CO2/H2
(Linga et al., 2007b), CO2/H2/C3H8 (Kumar et al., 2009), CO2/H2/Cyclopentane (Zhang et
al., 2009) and CO2/H2/THF (Lee et al., 2009) are also given in Figure 5. CO2
concentrations in hydrate phase in all cases seem to be comparable. In other words, for a
single stage hydrate process, the CO2 content of the gas mixture can be enriched from
40% to about 86%. The values of CO2 recovery and separation efficiency for the system
CO2/H2/TBAB in our experiments as well as CO2/H2 systems (Linga et al., 2007b) and
CO2/H2/C3H8 (Kumar et al., 2009) are shown in Table 1. CO2 recovery for the tests with
TBAB is found to be 0.41 and 0.47 for 5 wt% and 10 wt% TBAB aqueous solutions,
respectively. This indicates a better capture of CO2 in the hydrate crystals formed from
10 wt% TBAB. Separation factor is also higher for the 10 wt% solution (28.0 compared
to 15.7 for the 5 wt% solution). However, it is not enough to conclude that the recovery
can be increased with increasing the TBAB concentration. It has also been reported that
with the increase of pressure, the separation efficiency decreases due to the fact that at
higher pressures more H2 molecules occupies the hydrate cages, hence reduces the
amount of CO2 that can be captured (Fan et al., 2009). Therefore, it is recommended to
carry out more experiments in the future to seek the optimum pressure as well as the
optimum TBAB concentration for these separation tests.
Although the separation efficiency of these experiments are not very different from the
results of other workers that have used alternative additives, the dissociation pressure for
TBAB semi-clathrates at a given temperature (as mentioned before) are much lower than
other systems (Li et al., 2009).
Material balance calculations were performed to calculate the difference between the
amount of initial gas and the final gas at different phases. The value of error associated
with the experiments hence was found to be less than %2 .
A series of experiments simulating two-stage capture were conducted by taking the gas
mixture coming out of hydrates in the first stage (CO2-rich stream) as feed for the second
stage. In these experiments, a mixture of CO2/H2 with a typical composition of 80.5
mole% CO2 and 19.5 mole% H2 were prepared and injected into the cell containing
TBAB aqueous solution with 5 wt% TBAB. The operating pressure and temperature
were 3.31 MPa and 276.7 K, respectively. The results of this experiment are presented in
Table 2. It can be seen that the CO2 content of the gas in hydrate phase is as high as 96
mole%. This demonstrates that with two-stage hydrate formation, CO2-rich stream could
be enriched further to more than 95 mole% of CO2 which could ultimately be
geologically sequestered or utilized for enhanced oil recovery projects. It has been
suggested to use an integrated membrane separation unit to separate H2 and CO2 from the
remaining gas mixtures above hydrate (CO2-lean stream) (Linga et al., 2007b).
4. Conclusions
In this work we used semi-clathrate hydrate formation for capturing carbon dioxide from
simulated syngas systems. The results showed that with the addition of 5 wt% TBAB, the
CO2 recovery and separation factor are not compromised compared to the system without
TBAB while the thermodynamic conditions are more favourable in the presence of
TBAB. The corresponding values for CO2 recovery and separation factor were found to
be 0.41 and 15.7, respectively. These values were 0.47 and 28 in the case of addition of
10 wt% TBAB. CO2 concentration reached 86 mole% in the hydrate phase in one stage,
while it can be enriched to 96 mole% with two stage hydrate formation and CO2 capture.
Acknowledgements
This work is part of a project supported by the UK Engineering and Physical Science
Research Council (EPSRC Grant EP/E04803X/1), which is gratefully acknowledged.
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Table 1. CO2 recovery and separation factor in hydrate formation process in different
systems
Clathrate type operating P, MPa operating T, K R S
CO2/H2 a 7.5 273.7 0.42 98.7
CO2/H2/5wt% TBAB 3.9 273.5 0.41 15.7
CO2/H2/10wt% TBAB 3.8 273.9 0.47 28.0
CO2/H2/C3H8 b 3.8 273.7 0.48 27.8
a data from Linga et. al. (Linga et al., 2007) b data from Kumar et. al. (Kumar et al., 2009)
Table 2. Results of second stage of CO2 separation
CO2 (80.5%)/H2 (19.5%)/5wt% TBAB
CO2 in Feed, mol% 80.5
CO2 in gas phase, mol% 61.6
CO2 in hydrate phase, mol% 96.0
CO2 Recovery, R 0.35
Separation factor, S 15.0
Figure 1: Schematic diagram of the experimental apparatus used in this work for CO2
capture via semi-clathrate hydrate formation
0.0000
0.0100
0.0200
0.0300
0.0400
0.0500
0.0600
0 10 20 30 40 50
Time, min
gas c
on
su
med
, m
ol
269.15
270.15
271.15
272.15
273.15
274.15
275.15
Tem
pera
ture
, K
moles of gas consumed
Temperature profile
Figure 2: Gas consumption during semi-clathrates formation in the system with 5 wt%
TBAB in the aqueous solution; : total moles of gas consumed; : changes in the cell
temperature
0.0000
0.0100
0.0200
0.0300
0.0400
0.0500
0.0600
0.0700
0.0800
0.0900
0.1000
0 10 20 30 40 50 60
Time, min
ga
s c
on
su
me
d,
mo
l
271.15
272.15
273.15
274.15
275.15
276.15
277.15
278.15
279.15
280.15
281.15
Te
mp
era
ture
, K
moles of gas consumed
Temperature profile
Figure 3: Gas consumption duing semi-clathrates formation in the system with 10 wt%
TBAB in the aqueous solution; : total moles of gas consumed; : changes in the cell
temperature
0.0000
0.0100
0.0200
0.0300
0.0400
0.0500
0.0600
0.0700
0.0800
0.0900
0.1000
0 10 20 30 40 50 60 70
time, min
ga
s c
on
su
me
d,
mo
l
TBAB 5wt%
TBAB 10wt%
Figure 4: comparison of gas uptake by semi-clathrates in the system with 5 wt % and 10
wt% TBAB in aqueous solution; : total moles of gas consumed with TBAB
concentration of 5 wt% ; : total moles of gas consumed with TBAB concentration of 10
wt%.
39.2 4038.1
40 39.9
86.5 8683.6 84
88
20.318
24.1
0
10
20
30
40
50
60
70
80
90
100
CO2/H2 CO2/H2/TBAB CO2/H2/C3H8 CO2/H2/CP CO2/H2/THF
Carb
on
dio
xid
e,
mo
le %
Feed Gas Hydrate Equilibrium Gas
Figure 5: Comparison of CO2 content in the feed and different phases after clathrate
formation in; CO2/H2: data from Linga et. al. (Linga et al., 2007); CO2/H2/TBAB: this
work; CO2/H2/C3H8: data from Kumar et. al. (Kumar et al., 2009); CO2/H2/CP: data from
Zhang et. al. (Zhang et al., 2009); CO2/H2/THF: data from Lee et. al. (Lee et al., 2009).
No reported CO2 concentration in the equilibrium gas after hydrate formation for the last
two systems.