Fluid Phase Equilibria 220 (2004) 113–121
Gas solubility measurement and modeling for methane–water and
methane–ethane–n-butane–water systems at low temperature conditions
Antonin Chapoy a , Amir H. Mohammadi b , Dominique Richon a , Bahman Tohidi b,∗
a
Centre d’Energétique, Ecole Nationale Supérieure des Mines de Paris CENERG/TEP, 35 Rue Saint Honoré, 77305 Fontainebleau, France
b Centre for Gas Hydrate Research, Institute of Petroleum Engineering, Heriot-Watt University, Edinburgh EH14 4AS, Scotland, UK
Received 1 October 2003; received in revised form 13 February 2004; accepted 25 February 2004
Available online 12 May 2004
Abstract
In this communication, experimental measurements and thermodynamic modeling of solubilities of methane and a hydrocarbon gas mixture
(94% methane + 4% ethane + 2% n-butane) in water at low temperature conditions are reported. Methane solubility measurements have been
conducted at a temperature range of 275.11–313.11 K and pressures up to 18 MPa. The solubility of the individual components in the gas
mixture was measured from 278.14 to 313.12 K and pressures up to 14.407 MPa. A static–analytic apparatus, taking advantage of a pneumatic
capillary sampler is used for fluid sampling. The Valderrama modification of the Patel–Teja equation of state combining with non-density
dependent mixing rules were used for modeling gas solubilities in water. The data generated in this work are compared with the literature
data and the predictions of the thermodynamic model, demonstrating the reliability of the techniques used in this work.
© 2004 Elsevier B.V. All rights reserved.
Keywords: Gas solubility; Methane; Ethane; n-Butane; Water; Equation of state
1. Introduction
Natural gases are normally in contact with water in reservoirs. During production and transportation, dissolved water in the gas phase may form condensate, ice and/or gas
hydrate. Forming a condensed water phase may lead to corrosion and/or two-phase flow problems. Also, a condensed
water phase in a compressor may lead to damaging of impeller blades. Ice and/or gas hydrate formation may cause
blockage during production and transportation. To give a
qualified estimate of the amount of water in the gas phase,
thermodynamic models are required. Accurate gas solubility data, especially at low temperature conditions, are necessary to develop and validate thermodynamic models. The
gas solubility in water is also an important issue from an
Abbreviations: AAD, average absolute deviation; BIP, binary interaction parameter; FID, flame ionization detector; FOB, objective function;
NDD, non-density dependent mixing rules; PID, proportional integrator derivative controller; TCD, thermal conductivity detector; VPT-EoS,
Valderrama modification of Patel–Teja equation of state
∗ Corresponding author. Tel.: +44-131-451-3672;
fax: +44-131-451-3127.
E-mail address: Bahman.Tohidi@pet.hw.ac.uk (B. Tohidi).
0378-3812/$ – see front matter © 2004 Elsevier B.V. All rights reserved.
doi:10.1016/j.fluid.2004.02.010
environmental aspect, due to new legislations and restrictions on the hydrocarbon content in water disposal. Unfortunately, gas solubility data for most light hydrocarbons at low
temperature conditions are scarce and often rather dispersed.
The main objective of this work is to provide the much
needed solubility data at the above mentioned conditions.
In this work, experimental data for the solubility of
methane, ethane and n-butane have been assembled from
the literature and examined for consistency. Then new solubility measurements of methane and of a gas mixture (94%
methane + 4% ethane + 2% n-butane) in water have been
generated at low and ambient temperatures. The different
isotherms presented herein were obtained using an apparatus based on a static–analytic method taking advantage of a
capillary sampler.
The Valderrama modification of the Patel–Teja equation
of state (VPT-EoS) [1] with non-density dependent mixing
rules (NDD) [2] were used to model the gas solubilities
in water. The binary interaction parameters (BIPs) between
methane and water were tuned using the new experimental results on methane solubility data. Using the previously
reported binary interaction parameters [3] for ethane and
n-butane, the solubilities of each gas of the mixtures were
predicted. Predictions were found to be in good agreement
114
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
with the experimental data, demonstrating the reliability of
the experimental technique and model used in this work.
Liquide is pure grade with traces of water (3 ppm) and of
hydrocarbons (0.5 ppm). The gas mixture, 94% methane, 4%
ethane (±2%) and 2% n-butane (±2%) was purchased by
Messer Griesheim.
2. Literature review
2.1. Methane
Bunsen [4] conducted the first study of the solubility of
methane in water in 1855. The solubilities of several gases
including methane were measured at atmospheric pressures.
The first study reporting intermediate and high-pressure solubility data for methane in water was the study of Frolich
et al. [5]. Since then, many studies have been performed,
e.g. Michels et al. [6], Culberson et al. [7], Culberson and
Mc Ketta [8], Davis and Mc Ketta [9], Duffy et al. [10],
O’Sullivan and Smith [11], Sultanov et al. [12], Amirijafari
and Campbell [13], Sanchez and De Meer [14], Price [15],
Stoessel and Byrne [16] and Abdulgatov et al. [17]. All these
authors have measured solubility of methane at intermediate and high-pressures, but only at high temperatures. The
number of researcher reporting data of methane solubility
in water at low temperature conditions (T ≤ 298.15 K) is
rather limited but the more recent ones are, e.g. Cramer [18],
Yarym-Agaev et al. [19], Yokoyama et al. [20], Toplak [21],
Wang et al. [22], Lekvam and Bishnoi [23], Song et al. [24],
Yang et al. [25], Servio and Englezos [26],Wang et al. [27]
and Kim et al. [28].
2.2. Ethane
This system has not been so widely examined; only a few
authors have conducted the solubility experiments on this
system at intermediate/high-pressure conditions. The majority of the authors have reported solubility measurements at
temperatures higher than 298.15 K, e.g. Culberson and Mc
Ketta [29], Culberson et al. [30], Anthony and Mc Ketta
[31,32] and Danneil et al. [33], Sparks and Sloan [34]. Again,
the number of authors who have reported data at low temperature conditions is rather limited, e.g. Wang et al. [27]
and Kim et al. [28].
2.3. n-Butane
The solubility data for n-butane–water system at
intermediate/high-pressure conditions is limited to only a
few authors, e.g. Brooks et al. [35], Reamer et al. [36], Le
Breton and McKetta [37], Yiling et al. [38] and Carroll
et al. [39].
3. Experimental
3.1. Materials
Methane was purchased from Messer Griesheim with a
certified purity greater than 99.995 vol.%. Helium from Air
3.2. Apparatus and experimental procedures
The apparatus used in this work (Fig. 1) is based on a
static–analytic method with fluid phase sampling. This apparatus is similar to that described by Laugier and Richon [40].
The phase equilibrium is achieved in a cylindrical cell
made of Hastelloy C276, the cell volume is about 34 cm3
(internal diameter = 25 mm, height = 69.76 mm) and it can
be operated up to 40 MPa between 223.15 and 473.15 K.
The cell is immersed in an ULTRA-KRYOMAT LAUDA
constant-temperature liquid bath that controls and maintains the desired temperature within ±0.01 K. In order to
perform accurate temperature measurements in the equilibrium cell and to check for thermal gradients, temperature is
measured at two locations corresponding to the vapor and
liquid phases through two 100 ohms platinum resistance
thermometer devices (Pt100) connected to an HP data acquisition unit (HP34970A). These two Pt100 are carefully
and periodically calibrated against a 25 ohms reference
platinum resistance thermometer (TINSLEY precision instruments). The resulting uncertainty is less than ±0.02 K.
The 25 ohms reference platinum resistance thermometer
was calibrated by the Laboratoire National d’Essais (Paris)
based on the 1990 International Temperature Scale (ITS
90). Pressures are measured by means of two Druck pressure transducers (type PTX 610 range 0–30 MPa and type
PTX611, range 0–1.6 MPa) connected to the HP data acquisition unit (HP34970A). The pressure transducers are
maintained at a constant temperature (temperature higher
than the highest temperature of the study) by means of a
specially-made air-thermostat, which is controlled using a
PID regulator (WEST, model 6100). Both pressure transducers are calibrated against a dead weights pressure balance
(Desgranges & Huot 5202S, CP 0.3–40 MPa, Aubervilliers,
France). Pressure measurement uncertainties are estimated
to be within ±0.5 kPa in the 0–2.5 MPa range using the
0–1.6 MPa pressure transducer and within ±5 kPa in the
2.5–38 MPa range using the 0–30 MPa pressure transducer.
The HP on-line data acquisition unit is connected to a
personal computer through a RS-232 interface. This system
allows real time readings and storage of temperatures and
pressures throughout the different isothermal runs.
The analytical work was carried out using a gas chromatograph (VARIAN model CP-3800) equipped with two
detectors in series, a thermal conductivity detector (TCD)
and a flame ionization detector (FID), connected to a data
acquisition system (BORWIN ver 1.5, from JMBS, Le
Fontanil, France). The analytical column is a Hayesep C
80/100 Mesh column (silcosteel tube, length: 2 m, diameter: 1/8 in.). The TCD was used to detect the water; it was
repeatedly calibrated by injecting known amount of water
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
115
Fig. 1. Flow diagram of the equipment. C: carrier gas; d.a.s.: data acquisition system; DH2 O: degassed water; EC: equilibrium cell; FV: feeding valve;
GCy: gas cylinder; HPC: high-pressure compressor; HT: hastelloy tube; LB: liquid bath; LS: liquid sampler; PD: pressure display; PP: platinum resistance
thermometer probe; PTh and PTl: high- and low-pressure transducers; SM: sampler monitoring; SV: special valve; Th: thermocouple; TR: temperature
regulator; Vi: valve number i; VS: vapor sampler; VSS: variable speed stirrer; VP: vacuum pump.
through liquid syringes. The FID was used to detect the
hydrocarbons. It was first calibrated by introducing known
amounts of methane, ethane, n-butane through a gas syringe
in the injector of the gas chromatograph, and then different
gas mixtures of known amount of each gas were prepared
and loaded in the cell before sampling in order to calibrate
the FID in different small proportion for each gas.
present in the equilibrium cell (around 10 cm3 ), it is possible to withdraw many samples without disturbing the phase
equilibrium. The temperature of the sampling device is set
at 473.15 K to avoid condensation of any of the components.
3.3. Experimental procedures
4.1. Pure compound properties
The equilibrium cell and its loading lines were evacuated
down to 0.1 Pa and the necessary quantity of the preliminary degassed water (approximately 10 cm3 ) was introduced using an auxiliary cell. Then, the desired amount of
gas was introduced into the cell directly from the commercial cylinder or via a gas compressor to reach the desired
pressure.
For each equilibrium condition, at least 10 samples are
withdrawn using the pneumatic samplers ROLSITM [41] and
analyzed in order to check for measurement repeatability. As
the quantity of the withdrawn samples (less than 0.5–2 g)
is very small compared to the volume of the liquid phase
The critical temperature (Tc ), critical pressure (Pc ), critical volume (vc ) and acentric factor (ω), for each of the four
pure compounds are provided in Table 1.
4. Thermodynamic model
Table 1
Critical properties and acentric factors [42]
Compound
Pc (MPa)
Tc (K)
vc (m3 kg mole−1 )
ω
Water
Methane
Ethane
n-Butane
22.048
4.604
4.880
3.797
647.30
190.58
305.42
425.18
0.056
0.0992
0.1479
0.255
0.3442
0.0108
0.09896
0.1931
116
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
4.2. Model
F = 0.46283 + 3.58230(ωZc ) + 8.19417(ωZc )2
A general phase equilibrium model based on uniformity
of the fugacity of each component throughout all the phases
[42,43] was used to model the gas solubility. The VPT-EoS
[1] with the NDD mixing rules [2] was employed in calculating fugacities in fluid phases. This combination has proved
to be a strong tool in modeling systems with polar as well
as non-polar components [2].
The VPT-EoS [1] is given by
where Zc is the critical compressibility factor, and ω is the
acentric factor. Tohidi-Kalorazi [3] relaxed the α function
for water, αw , using experimental water vapor pressure data
in the range of 258.15–374.15 K, in order to improve the
predicted water fugacity:
P=
RT
a
−
v − b v(v + b) + c(v − b)
ā =
b=
c=
2 2
a R Tc
Pc
b RTc
(2)
a = aC + aA
(3)
where aC is given by the classical quadratic mixing rules as
follows:
aC =
xi xj aij
(13)
i
c∗ RTc
(5)
Pc
α(Tr ) = [1 + F(1 − TrΨ )]2
(11)
The above relation is used in the present work.
In this work, the NDD mixing rules developed by
Avlonitis et al. [2] are applied to describe mixing in the
a-parameter:
(4)
Pc
αw (Tr ) = 2.4968 − 3.0661Tr + 2.7048Tr 2 − 1.2219Tr 3
(1)
with
a = āα(Tr )
(10)
(6)
where P is the pressure, T the temperature, v the molar
volume, R the universal gas constant and Ψ = 0.5. The
subscripts c and r denote critical and reduced properties,
respectively.
The coefficients Ωa , Ωb and Ωc∗ , and F are given by
Ωa = 0.66121 − 0.76105Zc
(7)
Ωb = 0.02207 + 0.20868Zc
(8)
Ωc∗ = 0.57765 − 1.87080Zc
(9)
(12)
j
and b, c and aij parameters are expressed by
b=
xi bi
(14)
i
c=
x i ci
(15)
√
aij = (1 − kij ) ai aj
(16)
i
where kij is the standard binary interaction parameter.
The term aA corrects for asymmetric interaction, which
cannot be efficiently accounted for by classical mixing rules:
aA =
xp2
xi api lpi
(17)
p
i
Table 2
Experimental and calculated methane mole fractions in the liquid phase of the methane–water system
T (K)
Pexp (MPa)
xexp (×103 )
xcal (×103 )
x (%)
275.11
275.11
275.11
275.11
0.973
1.565
2.323
2.820
0.399
0.631
0.901
1.061
0.361
0.567
0.815
0.969
9.52
10.14
9.54
8.67
283.13
283.12
283.13
283.13
1.039
1.810
2.756
5.977
0.329
0.558
0.772
1.496
0.327
0.553
0.812
1.561
0.61
0.90
−5.18
−4.34
298.16
298.16
298.15
298.13
0.977
2.542
5.922
15.907
0.238
0.613
1.238
2.459
0.238
0.589
1.233
2.498
0.00
3.92
0.40
−1.59
313.11
313.11
313.11
313.11
1.025
2.534
7.798
17.998
0.204
0.443
1.305
2.325
0.205
0.486
1.295
2.346
−0.49
−9.71
0.77
−0.90
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
117
Table 3
Experimental and predicted methane, ethane and n-butane mole fractions in the liquid phase of the gas mixture–water system
T (K)
Pexp (MPa)
x(1) exp (×103 )
x(1) prd (×103 )
x (%)
x(2) exp (×104 )
x(2) prd (×104 )
x (%)
x(3)exp × 105
x(3)prd × (105 )
x (%)
278.14
278.15
1.032
2.004
0.339
0.646
0.337
0.629
0.59
2.63
0.199
0.387
0.207
0.364
−4.02
5.94
0.703
1.121
0.707
1.115
−0.57
0.54
283.14
283.16
283.16
283.15
283.15
283.14
283.15
0.987
1.038
1.988
2.077
3.079
3.413
3.415
0.295
0.300
0.566
0.593
0.826
0.891
0.896
0.292
0.306
0.566
0.59
0.841
0.921
0.922
1.02
−2.00
0.00
0.51
−1.82
−3.37
−2.90
0.172
0.165
0.285
0.302
0.385
0.428
0.436
0.160
0.168
0.294
0.305
0.411
0.441
0.441
6.98
−1.82
−3.16
−0.99
−6.75
−3.04
−1.15
0.512
0.482
0.754
0.941
1.063
1.121
1.048
0.487
0.507
0.809
0.831
1.013
1.052
1.053
4.88
−5.19
−7.29
11.69
4.70
6.16
−0.48
288.16
288.17
1.038
3.068
0.282
0.755
0.279
0.768
1.06
−1.72
0.172
0.399
0.168
0.43
2.33
−7.77
0.577
0.734
0.507
0.773
12.13
−5.31
298.14
298.14
298.14
298.14
298.14
0.994
2.964
7.257
11.749
14.407
0.218
0.637
1.359
2.014
2.191
0.228
0.637
1.364
1.939
2.215
−4.59
0.00
−0.37
3.72
−1.10
0.147
0.33
0.562
0.674
0.672
0.134
0.338
0.574
0.648
0.657
8.84
−2.42
−2.14
3.86
2.23
0.387
0.811
0.991
0.366
0.773
0.893
5.43
4.69
9.89
313.12
313.12
7.460
12.624
1.157
1.817
1.176
1.748
−1.64
3.80
0.406
0.586
0.498
0.594
−22.66
−1.37
0.694
0.725
−4.47
(18)
1
ln φi =
RT
api =
√
ap ai
0
1
lpi = lpi
− lpi
(T − T0 )
∞
V
∂P
∂ni
(19)
where p is the index of polar components.
Using the VPT-EoS [1] and the NDD mixing rules [2], the
fugacity of each component in all fluid phases is calculated
from:
T,V,nj =i
RT
−
V
dV − ln Z
for i = 1, 2, . . . , M
fi = xi φi P
(20)
(21)
where φi , V, M, ni , Z and fi are the fugacity coefficient
of component i in the fluid phases, volume, number of
0.003
Methane Mole Fraction
0.0025
0.002
0.0015
0.001
0.0005
0
0
2
4
6
8
10
12
14
16
18
20
Pressure / MPa
Fig. 2. Methane mole fraction in water rich phase in the methane–water binary system as a function of pressure at various isotherms. (䊐) 275.11 K;
(䉫) 283.12 and 283.13 K; (△) 298.13, 298.15 and 298.16 K; (䊊)313.11 K; solid lines, calculated with the VPT-EoS [1] and NDD mixing rules [2] with
parameters from Table 4.
118
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
0.0025
Methane Mole Fraction
0.002
0.0015
0.001
0.0005
0
0
2
4
6
8
10
12
14
16
Pressure /MPa
Fig. 3. Methane solubilities in the gas mixture–water system as a function of pressure at various isotherms. (×) 278.14 and 278.15 K; (䊊) 283.14,
283.15 and 283.16 K; (䊐) 288.16 and 288.17 K; (䉬) 298.14 K; (△) 313.12 K; solid lines, predicted with the VPT-EoS [1] and NDD mixing rules [2]
with parameters from Table 4.
components, number of moles of component i, the compressibility factor of the system and the fugacity of component i
in the fluid phases, respectively.
and for the gas mixture–water systems, respectively, and
plotted in Figs. 2 and 3.
As mentioned before, the BIPs between methane–water
are adjusted directly to the measured methane solubility data
through a Simplex algorithm using the objective function,
FOB, displayed in Eq. (22):
N
1 xi,exp − xi,cal
FOB =
(22)
N
x
5. Results and discussions
The experimental and the calculated/predicted gas solubility data are reported in Tables 2 and 3 for the methane–water
i,exp
1
0.0025
(a)
0.0013
Methane Mole Fraction
Methane Mole Fraction
0.0015
0.0011
0.0009
0.0007
0.0005
0.0003
(b)
0.002
0.0015
0.001
0.0005
0
0.0001
0
0.5
1
1.5
2
2.5
3
3.5
0
4
2
Pressure /MPa
6
8
10
Pressure /MPa
0.003
Methane Mole Fraction
0.003
Methane Mole Fraction
4
(c)
0.0025
0.002
0.0015
0.001
0.0005
(d)
0.0025
0.002
0.0015
0.001
0.0005
0
0
0
2
4
6
8
10
12
Pressure / MPa
14
16
18
20
0
5
10
15
20
25
Pressure / MPa
Fig. 4. Comparison of experimental methane solubilities in water in the methane–water binary system. (a) (䊐) 275.11 K; (䊊) 274.15 K from [24]; (䉬)
274.29 K from [23]. (b) (䉫) 283.13 K; (䊉) 283.15 K from [22]; (△) 283.2 K from [23]; ( ) 283.2 K from [27]; (䉱) 285.65 K from [23]. (c) (△)
298.15 K; (䉱) 298.15 K from [7]; (×) 298.15 K from [8]; (△) 298.15 from [17]; (+) 298.1 from [25]; (䊉) 298.15 K from [6]; (䉬) 298.2 K from [19];
(䊏) 298.15 from [20]; (䊊) 298.15 K from [21]; (䉬) 298.15 K from [20]; (䉫) 298.15 K from [28]. (d) (䊊) 313.11 K; (×) 310.93 from [12]; (䊏) 310.93
from [17]; (△) 313.2 K from [18]; dashed lines, predicted with the VPT-EoS [1] and NDD mixing rules [2] with parameters from Table 4.
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
Table 4
BIPs between hydrocarbons, hc and water, w for the VPT-EoS [1] and
NDD mixing rules [2]
System
kw–hc
0
lw−hc
l1w−hc (×104 )
Methane–watera
Ethane–waterb
n-butane–waterb
0.5044
0.4974
0.5800
1.8302
1.4870
1.6885
51.72
45.4
33.57
a For improved accuracy it is recommended to use the following BIPs
between water and methane at 273.15 < T ≤ 277.13 K, while continuity
conditions for gas solubility at 277.13 K is assured:kw–hc = 0.4969,
l0w−hc = 1.8332 and l1w−hc (×104 ) = 58.13.
b From [3].
where N is the number of data points, xi,exp the measured solubility and xi,cal the calculated solubility. The binary interaction parameters between ethane–water and n-butane–water
are set to those reported by Tohidi-Kalorazi [3]. All the BIPs
for hydrocarbon–hydrocarbon are set to zero. Table 4 reports
all non-zero BIPs values used in this work.
Our isothermal P, x data sets for the methane–water are
well represented with the VPT-EoS [1] and NDD mixing
rules [2]. Methane solubility data reported in the literature
at a temperature range 274.15 and 313.2 K are plotted in
Fig. 4. As can be shown, the isotherms in the figures are
not exactly identical, but sufficiently close for comparison
purposes. At the low temperature conditions (i.e. below
276 K and also around 283.15 K) and at high temperature
conditions (i.e. around 313.15 K), there is good agreement
between the different authors, with the exception of the
data reported by Wang et al. [22] at 283.15 K. Several authors have reported solubility measurements at 298.15 K
isotherm. However, some of the reported data show deviations with other authors and with the model predictions,
in particular at pressures higher than 6 MPa (e.g. Michels
et al. [6] and Kim et al. [28]). The data of Yang et al. [25]
are dispersed at this temperature.
Our isothermal P, x data sets for the gas mixture–water
are also well represented with the VPT-EoS [1] and NDD
mixing rules [2] for the majority of the experimental results
(Average absolute deviation (AAD) of 1.82% for methane
solubilities, AAD of 4.86% for ethane solubilities, and AAD
of 5.56% for n-butane solubilities). An increase in AAD
with an increase in carbon number is expected, due to low
solubility of ethane and n-butane and hence the analytical
work is more difficult (higher uncertainty in the calibration
of the detector).
6. Conclusions
Accurate gas solubility data especially at low temperature conditions are necessary for developing and validating thermodynamic models for water–hydrocarbon
systems. New experimental data on the solubility of
methane in water were generated at low temperature conditions (i.e. 275.11–313.11 K) and pressures up to 18 MPa
119
using a static–analytic apparatus, taking advantage of a
high-pressure capillary sampler.
The new experimental data were employed in tuning the
BIPs between methane and water, with the aim of improving
the reliability of a thermodynamic model. Another set of
gas solubility data was generated on a ternary gas mixture
containing methane (94%), ethane (4%) and n-butane (2%)
at low temperature conditions (i.e. 278.14–313.12 K) and
pressures up to 14.407 MPa.
Using the tuned BIPs for the methane–water system and
the previously reported BIPs for the other compounds, the
solubility of each gas in water were predicted. The predictions were in good agreement with the experimental data,
demonstrating the reliability of the techniques and model
used in this work.
List of
a
b
c
f
F
ITS
k
l
M
n
N
P
R
T
u
v
V
w
x
Z
symbols
attractive parameter of the equation of state
parameter of the equation of state
parameter of the equation of state
fugacity
parameter of the equation of state
international temperature scale
binary interaction parameter for the classical
mixing rules
dimensionless constant for binary interaction
parameter for the asymmetric term
number of components
number of moles
number of experimental points
pressure
universal gas constant
temperature
parameter of the equation of state in general
form
molar volume
volume
parameter of the equation of state in general form
mole fraction
compressibility factor
Greek letters
α
temperature dependent function
∆
deviation
φ
fugacity coefficient
Ψ
power parameter in the VPT-EoS
Ω
parameter in the VPT-EoS
ω
acentric factor
Superscripts
A
asymmetric properties
C
classical properties
0
non-temperature dependent term in NDD mixing
rules
1
temperature dependent term in NDD mixing
rules
120
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
Subscripts
a
index for properties
b
index for properties
c
critical property
c∗
index for properties
cal
calculated property
exp
experimental property
i, j
molecular species
hc
hydrocarbon compound
p
polar compound
prd
predicted property
r
reduced property
w
water
0
reference property
(1)
methane
(2)
ethane
(3)
n-butane
W=
Pw
RT
(A.6)
Z=
Pv
RT
(A.7)
and
A′i =
1 ∂(n2 a)
na
∂ni
Bi′ =
1 ∂(nb)
b ∂ni
Ui′ =
1 ∂(nu)
u ∂ni
Wi′ =
1 ∂(nw)
w
∂ni
(A.8)
T,nj =i
(A.9)
T,nj =i
(A.10)
T,nj =i
(A.11)
T,nj =i
The compressibility factor Z is given by the following
dimensionless equation [44]:
Acknowledgements
The financial support by the European Infrastructure for
Energy Reserve Optimization (EIERO) provided the opportunity for this joint work which is gratefully acknowledged.
Z3 −(1 + B − U)Z2 + (A − BU − U − W 2 )Z
Appendix. Calculation of fugacity coefficient using
an EoS
References
The following general form can be used for expressing
any cubic equation of state [44]:
RT
a
P=
(A.1)
− 2
v − b v + uv − w2
The fugacity coefficient for component i in a mixture can
be expressed as [44]:
Bi′ B
A
ln φi = −ln(Z − B) +
+√
2
Z−B
U + 4W 2
U ′ U 2 + 4Wi′ W 2
× A′i − i 2
U + 4W 2
√
2Z + U − U 2 + 4W 2
×ln
√
2Z + U + U 2 + 4W 2
2 (2Z + U) Wi′ W 2 + UZ − 2W 2 Ui′ U
2
−A
Z2 + UZ − W 2 U 2 + 4W 2
(A.2)
where
A=
Pa
(RT)2
Pb
RT
Pu
U=
RT
B=
(A.3)
(A.4)
(A.5)
−(AB − BW2 − W 2 ) = 0
(A.12)
[1] J.O. Valderrama, J. Chem. Eng. Jpn. 231 (1990) 87–91.
[2] D. Avlonitis, A. Danesh, A.C. Todd, Fluid Phase Equilib. 94 (1994)
181–216.
[3] B. Tohidi-Kalorazi, Ph.D. Thesis, Heriot-Watt University, 1995.
[4] R. Bunsen, Ann. Chem. Pharm. 93 (1855) 1–50.
[5] P.K. Frolich, E.J. Tauch, J.J. Hogan, A.A. Peer, Ind. Eng. Chem.
23 (5) (1931) 548–550.
[6] A. Michels, J. Gerver, A. Bijl, Physica III (1936) 797–808.
[7] O.L. Culberson, A.B. Horn, J.J. Mc Ketta Jr., Petroleum Trans.
AIME 189 (1950) 1–6.
[8] O.L. Culberson, J.J. Mc Ketta Jr., Petroleum Trans. AIME 192
(1951) 223–226.
[9] J.E. Davis, J.J. Mc Ketta Jr., Petrol. Refiner 39 (1960) 205.
[10] J.R. Duffy, N.O. Smith, B. Nagy, Geochim. Cosmochim. Acta 24
(1961) 23–31.
[11] T.D. O’Sullivan, N.O. Smith, J. Phys. Chem. 747 (1970) 1460–
1466.
[12] R.G. Sultanov, V.G. Skripka, A.Y. Namiot, Gaz. Prom. 17 (1972)
6–7.
[13] B. Amirijafari, J.M. Campbell, SPE J. (February) (1972) 21–27.
[14] M. Sanchez, F. De Meer, Ann. Quim. 74 (1978) 1325–1328.
[15] L.C. Price, Am. Assoc. Pet. Geo. Bull. 63/9 (1979) 1527–1533.
[16] R.K. Stoessell, P.A. Byrne, Geochim. Cosmochim. Acta 46 (1982)
1327–1332.
[17] I.M. Abdulgatov, A.R. Bazaev, A.E. Ramazanova, J. Chem. Therm.
25 (1993) 249–259.
[18] S.D. Cramer, Ind. Eng. Chem. Pr. Des. Dev. 23 (1984) 533–
538.
[19] N.L. Yarym-Agaev, R.P. Sinyavskaya, I.I. Koliushko, L.Ya. Levinton,
Zh. Prikl. Khim. 581 (1985) 165–168 (in Russian).
[20] C. Yokoyama, S. Wakana, G.I. Kaminishi, S. Takahashi, J. Chem.
Eng. Data 33 (1988) 274–276.
[21] G. J. Toplak, MS Thesis, University of Pittsburgh, Pittsburgh, PA,
1989.
A. Chapoy et al. / Fluid Phase Equilibria 220 (2004) 113–121
[22] Y. Wang, B. Han, H. Yan, R. Liu, Thermochim. Acta 253 (1995)
327–334.
[23] K. Lekvam, P.R. Bishnoi, Fluid Phase Equilib. 131 (1997) 297–
309.
[24] K.Y. Song, G. Feneyrou, F. Fleyfel, R. Martin, J. Lievois, R.
Kobayashi, Fluid Phase Equilib. 128 (1997) 249–260.
[25] S.O. Yang, S.H. Cho, H. Lee, C.S. Lee, Fluid Phase Equilib. 185
(2001) 53–63.
[26] P. Servio, P. Englezos, J. Chem. Eng. Data 47 (2002) 87–90.
[27] L.-K. Wang, G.-J. Chen, G.-H. Han, X.-Q. Guo, T-M. Guo, Fluid
Phase Equilib. 5180 (2003) 1–12.
[28] Y.S. Kim, S.K. Ryu, S.O. Yang, C.S. Lee, Ind. Eng. Chem. Res. 42
(2003) 2409–2414.
[29] O.L. Culberson, J.J. Mc Ketta Jr., Trans. AIME 189 (1950) 319–322.
[30] O.L. Culberson, A.B. Horn, J.J. Mc Ketta Jr., Trans. AIME 189
(1950) 1–6.
[31] R.G. Anthony, J.J. McKetta Jr., J. Chem. Eng. Data. 121 (1967)
17–20.
[32] R.G. Anthony, J.J. McKetta Jr., J. Chem. Eng. Data. 121 (1967)
21–28.
[33] A. Danneil, K. Toedheide, E.U. Franck, Chem. Ing. Tech. 39 (1967)
816–821.
121
[34] K.A. Sparks, E.D. Sloan, Research Report (RR-71), GPA, Tulsa,
OK, 1983.
[35] W.B. Brooks, G.B. Gibbs, J.J. McKetta Jr., Petrol. Refiner 3010
(1951) 118–120.
[36] H.H. Reamer, B.H. Sage, W.N. Lacey, Ind. Eng. Chem. 443 (1952)
609–615.
[37] J.G. Le Breton, J.J. McKetta Jr, Hydrocarb. Proc. Petrol. Ref. 43 (6)
(1964) 136–138.
[38] T. Yiling, T. Michelberger, E.U. Franck, J. Chem. Thermodyn. 23
(1991) 105.
[39] J.J. Carroll, F.Y. Jou, A.E. Mather, Fluid Phase Equilib. 140 (1997)
157–169.
[40] S. Laugier, D. Richon, Rev. Sci. Instrum. 57 (1986) 469–472.
[41] P. Guilbot, A. Valtz, H. Legendre, D. Richon, Analusis 28 (2000)
426–431.
[42] D.A. Avlonitis, Ph.D. Thesis, Heriot-Watt University, 1992;
D.A. Avlonitis, MSc Thesis, Heriot-Watt University, 1988.
[43] B. Tohidi, R.W. Burgass, A. Danesh, A. C. Todd, SPE 26701,
in: Proceedings of the SPE Offshore Europe’93 Conference, 1993,
pp. 255–264.
[44] A. Danesh, PVT and Phase Behaviour of Petroleum Reservoir Fluids,
first ed., Elsevier, Amsterdam, 1998.