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TRANSCRIPT
Gas Hydrates in Low Water Content Gases: Experimental Measurements and ModellingUsing the CPA EoS
Antonin Chapoy, Hooman Haghighi, Rod Burgass and Bahman TohidiHydrafact Ltd. & Centre for Gas Hydrate ResearchInstitute of Petroleum Engineering
Heriot-Watt University Edinburgh EH14 4AS, UK
Ecole des Mines de Paris - Paris, France, Thursday, September 3th, 2009
Outline
• Introduction / Scope of work
• Experimental
– Materials
– Experimental setup
– Procedures
– Validation
• Thermodynamic Modelling
• Results - Discussions
• Remarks and Conclusions
Background• Natural gases are normally saturated
with water at reservoir conditions
• Reducing the water content of gas streams is commonly used as a means of preventing gas hydrate (gas lift..)
• However, severe hydrate blockages have occurred in pipelines transporting so-called dry gas
• Capability to accurately predict the water content is therefore essential to plan potential flow assurance issues associated with condensed water
• Lack of experimental data, especially for gas mixtures
What are gas hydrates ?What are gas hydrates ?
• Gas hydrates or clathrate
hydrates are:
– Ice-like crystalline
compounds
– Composed of water + gas
(e.g. methane, CO2)
– Formed under low
temperatures and elevated
pressures
– Stable well above the ice-
point of water Methane hydrate: the
burning snowball
Hydrate StructuresHydrate Structures
3
16
2
2 Methane, ethane, carbon dioxide….
Propane, iso-butane, natural gas….
Methane + neohexane, methane + mch….
6
8
1 Structure H
Structure 2
Structure 1
51268
51264
51262
512
435663
+
P T and
suitable guests
Flow Assurance- Hydrates: The problems
• Hydrate blockages are major
flow assurance problems in
offshore and deep water
operations
• Economic and safety hazard
• Challenges
– Long tiebacks
– High pipeline residence times
– Low T / high fluid P Gas hydrates removed from
a subsea transfer line
(Courtesy of Petrobras)
Avoiding Hydrate Problems - Current practice
• Increasing the system temperature- Insulation- Heating
• Reducing the system pressure
• Injection of thermodynamic inhibitors- Methanol, ethylene glycol, ethanol
• Using Low Dosage Hydrate Inhibitors- Kinetic Inhibitors (KHI)- Anti-Aggglomerants (AA)
•• Water removal (Water removal (dehydratationdehydratation))
• Combinations of the above
• New Approach: Cold Flow
P
No Hydrates
HydratesWellhead
conditions
P
No Hydrates
HydratesWellhead
conditions
P
No Hydrates
HydratesWellhead
conditions
P
No Hydrates
HydratesWellhead
conditions
Experimental
• Materials
– Methane (99.995%) from BOC
– Ethane, Propane, nButane, CO2, N2: 99.9%+ from BOC
– Distilled water
• Systems
– Made gravimetrically and checked by GC
0.5--CO2
2--N2
-3-nC4 H10
1.56-C3 H8
25-C2 H6
9486100CH4
System 3 (sII)System 2 (sII)System 1 (sI)Component
Water Content Measurements
• Experimental setup
P Transducer
T Probe
Cooling Jacket
2-way valve
2-way valve
Equilibrium Cell
Mixing Ball
Piston
Pivot
Cooling Fluid in/out
P Transducer
T Probe
Cooling Jacket
2-way valve
2-way valve
Equilibrium Cell
Mixing Ball
Piston
Pivot
Cooling Fluid in/out Main Characteristics:
Titanium piston vessel
Pmax: 70 MPa
Tmin: 193 K
Tmax: 323 K
T ±0.1K
P ±0.003 MPa
Water Content Measurements
• Schematic of the SpectraSensorsTM SS2000
TDLAS set-up
P Transducer
Sample in
Sample out
Mirror
Detector
Laser
P Transducer
Sample in
Sample out
Mirror
Detector
Laser
NLSI
I o
××=
ln
Main Characteristics:
Beer law
Standard error TDLAS
set-up is the greater of 4
ppm or 2% of the
reading.
Thermodynamic Modelling
• For VLE or VHE, we have:
• CPA EoS:
• For Hydrate: Solid solution theory of van der Waals and Platteeuw
( )∑∑ −
∂
∂+−
+−
−=
i
i
A
A
i
i
mmmm
Xxg
V
RT
bVV
Ta
bV
RTP 1
)ln(1
2
1
)(
)(
ρρ
SRK part Association part
LV ff = or HV ff =
∆−=
−
RTff
Hw
w
H
w
ββ µ
exp ∑ ∑
+=−=∆ −
m j
jmjmHww
Hw fCvRT 1lnµµµ ββ
where
Thermodynamic Modelling
• BIPs between water and gases adjusted using gas solubility data:
• Example: methane solubility in water
exp,
,exp,
1
1
i
caliin
x
xx
NFOB
−= ∑
0
0.001
0.002
0.003
0.004
0 10 20 30 40 50
P / MPa
CH
4 S
olu
bili
ty /
mo
le f
ract.
Culberson et al. (1951)Duffy et al. (1961)Yokoyama et al. (1988)Wang et al. (1995)Yang et al. (2001)Kim et al. (2003)Chapoy et al. (2004)
298.15 K
0
0.001
0.002
0.003
0.004
0.005
0 10 20 30 40 50 60 70
P / MPa
CH
4 S
olu
bili
ty /
mole
fra
ct.
Culberson et al. (1951)
Amirjafari and Campbell (1972)
344.26 K
Validations of the model
• Predictions of water content – System CH4 - Water
0
50
100
150
200
250
300
350
400
0.0001 0.001 0.01 0.1
Water content / mole fraction
P /
MP
a
Model (VLE)
Model (HSZ)
Althaus (1999)
Kosyakov and Ivchenko (1982)
Chapoy et. al (2003)
Rigby and Prausnitz (1968)
Yokoyama (1988)
Yarym-Agaev et. al (1985)
Rigby and Prausnitz (1968)
Water Content Measurements
• Validations – Water content measurements in
methane in equilibrium with liquid water
0
2
4
6
8
10
12
14
100 1000 10000
yw / ppm
P/
MP
a
288.55 K
282.65 K
278.25 K
273.15 K
Model
HSZ
Experimental Results – Model Predictions
• System 1: Methane at 3.44 MPa
10
100
1000
250 255 260 265 270 275 280 285 290
T/ K
yw /
pp
m
This work
data from Song et al. (2004)
data from Aoyagi et al. (1979)
Model Predictions
AAD = 6.1 %
Experimental Results – Model Predictions
• System 1: Methane at 6.89 MPa
10
100
1000
250 255 260 265 270 275 280 285 290
T/ K
yw /
ppm
This work
data from Song et al. (2004)
data from Aoyagi et al. (1979)
Model Predictions
AAD = 1.9 %
Experimental Results – System 2
• Experimental conditions
0
5
10
15
20
25
30
35
40
140 160 180 200 220 240 260 280 300
T/ K
P/
MP
a
Experimental Results – System 2
• Results
1
10
100
1000
250 255 260 265 270 275 280 285
T/ K
yw/
ppm
5 MPa10 MPa40 MPaModel
AAD = 2.8 %
Experimental Results – System 3
• Experimental conditions
0
5
10
15
20
25
30
35
40
150 170 190 210 230 250 270 290
T/ K
P/
MP
a
Experimental Results – System 3
• Results
1
10
100
1000
250 255 260 265 270 275 280 285
T/ K
yw/
pp
m
5 MPa
10 MPa
40 MPa
Model
AAD = 5.1 %
Experimental Results
• Correlation (GPA conference 2006)
with
TdcB
TbaA
BPAPw
+=+=
+= )exp( 2φ
))(
exp(RT
PPv
P
Py
sat
wLw
w
satw
w
−=
φ
0.0423158
-14.4573
-0.002303
0.55955
-0.0914835
15.896128
-0.02518
7.3906
0.027453
-18.76311
-0.0003318
0.17965
a
b
c
d
Hydrate - sIIHydrate - sILiquid Cst.
Conclusions - Perspectives
• New setup to measure water content in
gases down to 1 ppm
• New experimental data up to 40 MPa
for synthetic gases
• Good agreement between model
prediction in experimental results
• Future works: real North Sea natural gases, effect of compositions (i.e. CO2
content), water content in rich CO2
systems
Acknowledgements
• This work was part of a Joint Industry Project funded
by Clariant Oil Services, Petrobras, StatoilHydro, TOTAL, and the UK BERR, whose support is gratefully
acknowledged
Thank youThank you
for your attentionfor your attention