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Relevance of Natural Gas Hydrate
• Gas kick in offshore drilling!!!• Deposits in oil & gas pipelines!!
• Storage and transport of gas!• Cold flow in subsea pipelines?
• Gas resource (big claims)??• Global warming (hyd. melting)???
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A: Drilling Unit, B: Production and Injection Wells, C: Process (Separationand Compression etc.), D: Storage, E: Off-Loading, F: Living Quarters,
G: Riser Base, H: Template, I: Flare, J: Flowlines and Pipelines.
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Flowlines and PipelinesNatural Gas Production
Natural gas, Sour gases, Hydrocarboncondensate, Condensed water, Formationwater, Liquid slugging
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Flow Assurance
Flow assurance is a concept used to
describe the phenomena of precipitationand deposition of solids (and multiphase
flow, not discussed here) in flowlines and
pipelines. Flow assurance offers technical
solutions at reasonable costs without risk
to installations, operators and theenvironment.
Precipitation is not the same as deposition…
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Flow Assurance Solids
• Asphaltene (pressure changes)
– Heavy, polar molecules, amorphous solid
• Paraffin wax (pipeline cooling)
– Normal paraffin C20 to C40• Gas hydrate (pipeline cooling)
– Methane, ethane, propane and butane
• Inorganic scale (fluid mixing…)
– Carbonates and sulphates
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Hydrocarbon Solids
A: Phase envelope, B: Gas hydrate, C: Paraffin wax, D: Asphaltene, E: Multiphase flow
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Siljuberg 2012 (from Rønningsen 2006)
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Asphaltene• Precipitates from crude oil when reservoir
pressure falls during production• Crude oil density reduces when reservoir
pressure falls, causing precipitation
• Crude oil density increases again when lightcomponents have bubbled out (associated gas)
• Precipitation envelope, light crude main problem
• Deposition prevented by additives (wells and
flowlines) to hinder agglomeration of particles
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Asphaltene Precipitation
[MPa]
[kg/m3]
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Temperature in Pipelines
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Temperature in Pipelines
LMTDTUAq
)TT(Cmq 21 p
T T
T T
T T T T
T LMTD
2
1
21
ln
)()(
T T
T T
T T T LMTD
2
1
21
ln
T T
T T
T T Ld U T T C m p
2
1
2121
ln
)()()(
L
mC
d U T T T T
p
exp)( 12
)( Ld A
T = Constant = Sea Temperature
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Temperature and Distance
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Temperature in Pipelines
L
mC
d U T T T T
p
exp)( 12
Insulated pipeline on seafloor: 1 < U (W/m2.K) < 2
Non-insulated pipeline on seafloor: 15 < U (W/m2.K) < 25
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Calculation Example
What is temperature at 20 km?
m=67 kg/s
Cp=3500 J/kg.KU=2 W/m2.K
d=0.370 m
T=5 C
T1=86 C
C T 711020350067
370.01416.32exp)586(5 32
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Temperature and Distance
Booster compressor duty: 15.5 MW (most likely roughness)
Åsgard Transport (69.4 vs. 76.9 MSm³/d)
110
120
130
140
150
160
170
180
190
200
210
0 200 400 600 800
Distance KP (km)
P r e s s u r e ( b a r g )
0
5
10
15
20
25
30
35
40
45
50
T e m p e r a t u r e ( ° C )
Pressure Booster_press Temperature Booster_temp
Aamodt (2006)
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Wax Appearance Temperature
Crude oil and condensate WAT (=cloud point) typically at 30-40 [C]. Pour
point typically 15 [C] below cloud point. Wax crystals in oil increase viscosity.
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Botne 2012
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Paraffin WaxCloud point (WAT) and pour point
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Wax Build-UpWith time and distance
xk k dt dx
21
)exp(1 2
2
1 t k k
k x
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Botne 2012
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Botne 2012
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Botne 2012
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Water Vapour at 10 (Top), 20
Middle) and 30 (Bottom) MPa
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
20000
0 20 40 60 80 100 120 140
T [C]
c [ m g
/ S m 3 ]
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Gas Hydrate•Major obstacle to production of oil and gas through
subsea pipelines (due to cooling). Blocks pipelines.
•Form when liquid water (condensed out from moistreservoir gas) and natural gas are present at “wrong” side
of equilibrium line (typically 20 C and 100 bara).
•Water molecules are stabilized by small gas moleculessuch that hydrates form (physical process, not chemical
reaction).
•Antifreeze chemical used/injected to lower the T at whichhydrates form (lower “freezing” point of hydrate).
•Typically, 50 % antifreeze (in liquid phase) required to
prevent hydrate formation. Expensive, very expensive.
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Equilibrium & Flow Assurance
Carroll 2003
L
mC
d Uexp)TT(TT
p
u1u2
Cooling w. distance
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A: Gas reservoir,B: Oil reservoir,
C: Aquifer,
D: Cap rock,
E: Sealing fault.
A/B: Gas-oil-contact.
B/C: Oil-water-contact.
Gas in A saturated withwater vapour (condenses
out at surface).
Oil formation B contains
formation water (saline).
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Gas Molecules Trapped in Cages12-sided, 14-sided and 16-sided polyhedra
Small non-polar molecules, methane, ethane, propane and butane form gas
hydrate. Carbon dioxide, hydrogen sulphide and nitrogen also form hydrate.
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Gas Inside Ice Crystal Cages
Carroll 2003
Skalle 2009
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Structure II Gas Hydrate
O H X 213624
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Dissociation Pressure
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Hydrate Equilibrium (Dissociation Pressure)
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Dissociation Pressure Gas Hydrate
0
5000
10000
15000
20000
25000
30000
35000
40000
45000
0 5 10 15 20 25 30 35
T [C]
p
[ k P a ]
Lower line natural gas mixture; upper line with CO2 and N2
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Christiansen 2012
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Hammerschmidt’s Equation
)1( x
x
M
K T
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Hydrate Equilibrium Midgard Field Gas
Lunde (2005): Design av flerfasesystemer for olje og gass, Tekna
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Natural Gas Resource?Hydrate Zone Limited by Subsurface Temperature
Senger 2009
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Subsurface Gas Hydrate
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Mary Boatman, unknown reference
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Krey et al. 2009
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Global Warming & Gas Resource
William Dillon, USGS
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Gas Kick in Drilling
Skalle 2009
Deepwater Horizon, GoM, Teknisk
Ukeblad, May 6, 2010
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NTNU Cold Flow
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Sintef Cold Flow
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Sintef Cold Flow
Sintef 2010
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Summary
– More than natural gas flows in gas flowlines
– Asphaltene problem in oil production. Paraffin wax problem in
crude oil and condensate. Gas hydrate problem in oil and gas
production. Inorganic solids when saline water.
– Temperature drop equation does not include the Joule-
Thomson effect (small in large diameter pipelines). U values
based on experience.
– Hydrates form when liquid water and natural gas are in
contact at low temperature and high pressure, as in subsea
production of oil and gas.
– Hammerschmidt’s and similar equations can be used to
estimated the mass fraction of antifreeze required to preventhydrate formation. Hysys gives dissociation pressure.
– Hydrates important in drilling operations and environmental
considerations (global warming).