multiphase flow technology agenda 22nd of october · pdf filemultiphase flow technology agenda...
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Multiphase Flow Technology Agenda 22nd of October 2013
• Introduction to multiphase flow • Terms & regimes • Conservation equations • Stratified flow • Applications • Slug flow
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Lecture notes IFE, 2013.10.22
Jan Nossen & Karin Hald
MEK 4450 Terms & Notation
Multiphase flow – Applications Conservation equations
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A
Multiphase flow terms, notation
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gA
oA
wA
Gas
Oil Water
Void fraction:
Oil holdup:
Water holdup:
Total holdup: wo
ww
oo
g
AAAA
AA
βββββ
α
+===
=
//
/
Ug
Uo
Uw
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Multiphase flow terms, notation
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z
y
G
Name Dimension Legend . e J/kg Specific internal energy h J/kg Specific enthalpy p Pa Pressure S m Wetted length ρ kg/m3 Density α, β, γ - Gas, liquid bulk, droplet fractions τ Pa Shear stress ψE kg/(sm3) Droplet entrainment rate ψD kg/(sm3) Droplet deposition rate
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5
Real stratified flow
Continuous gas Gas bubbles in oil Gas bubbles in water Continuous oil Oil drops in gas Oil drops in water Continuous water Water drops in gas Water drops in oil Thin liquid film on upper wall
wd
w
wc
od
o
oc
w
o
g
βγββγβαααoγ
wαoα
ocβodβ wdβ
Thin film
wcβ
gα
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Flow regimes
Depend on • phase velocities • phase quantity • pipeline orientation • flow system
• gas/liquid • liquid/liquid
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oil
gas
IFE Lab data
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Flow regimes: Near horizontal Gas/liquid regimes: • Stratified • Annular
Slug • Bubble
Liquid/liquid regimes: • Stratified (separated) • Partly separated/dispersed • Dispersed oil/water flow
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Flow regimes: Near vertical Gas/liquid regimes: • (a-b) bubble flow • (c-d) slug/churn flow • (e) annular flow
Liquid/liquid regimes: Dispersed
.:.:
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a b c d e
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Transition criteria
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Large Wave Stratified
Slug
Bubble Liquid velocity
Gas velocity
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Flow regime transitions • The most important flow regime transition in pipelines
is from stratified flow to slug flow • Two conditions must be fulfilled for slug flow to exist:
• Stratified flow must be unstable (Kelvin-Helmholtz instability) • Slugs that are formed must be able to grow (Minimum slip)
• The Kelvin-Helmholtz criterion tells that the stratified flow region gets smaller with increasing pressure
• Experimental data show that the slug flow region also gets smaller with increasing pressure
• For high pressure we get a region of large wave flow in between stratified and slug
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In between
slugs are stable
stratified flow is stable
USL
USG
neither is stable
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Multiphase flow – Applications
• Acknowlegments: • Terje Sira (IFE) • Zheng Gang Xu (SPT Group) • Magnus Nordsveen (Statoil) • SINTEF Petroleum • IFE
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Multiphase Flow Main Challenges
• Pressure loss • Liquid management
• Pipeline diameter selection • Liquid inventory control
• Normal operation • Water accumulation
• Rate changes, shut-down and Restart • Pigging
• Sizing of process equipment, e.g. separators/slug catchers
• Prediction and control of slugging
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Stratified flow in horizontal gas condensate pipe
• A small stream of condensate on top of a small stream of water • The pressure gradient drives the gas which drives the condensate
which drives the water • Typical values: Gas velocity Ug = 3 m/s, liquid velocity Ul = 1 m/s Liquid holdup h = 0.01 Superficial velocities: Usg = 3 m/s Usl = hUl = 1 cm/s • Liquid transport modified by droplets in gas and water droplets in
condensate/condensate droplets in water
p1 p2
Ug
Uh Uw
Forces on gas
Forces on condensate
Forces on water
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Steady state pressure drop and holdup
• Below a certain production rate, pressure gradient and holdup start building up in the uphill sections
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Liqu
id in
vent
ory
Production rate
Friction dominated flow
Gravity dominated flow
Pres
sure
dro
p Pressure drop
Liquid inventory
1-phase pressure drop
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Pipe diameter selection
• Too small diameter: • Large pressure drop due to friction at high production rates
• Too large diameter: • Too low velocity
• High holdup and flow instabilities at low production rates • Large liquid surges during production start-up or ramp-up • Possibly even severe slugging
• More expensive pipelines
• In 1-phase flow you can just make the pipe big enough • In multiphase flow you have to balance capacity needs
with need to avoid liquid accumulation and instabilities
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Liquid surge during ramp-up
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Liqu
id in
vent
ory
Production rate Q1 Q2
Liquid flowing from pipeline into slug catcher when increasing rate from Q1 to Q2
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PIPELINE WATER HOLDUP PROFILE
0
5
10
15
20
0 20000 40000 60000 80000
Pipeline Distance
Wat
er H
oldu
p (%
)
0
400
800
1200
1600
Elevation (m)
Elevation
WaterHoldup
Liquid accumulation and water separation in low points • Increased liquid
accumulation and pressure drop
• Large water slugs disturb process
• Corrosion
• WATER
Potential problems in multiphase flow
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Potential problems in multiphase flow • SHUT-IN/RESTART and RATE CHANGES
• Liquid redistributes due to gravity during shut-in • On startup, liquid in dips can exit the pipeline as large slugs
as flow is ramped up
B-Gas and Liquid Outlet Flow
A-Liquid Distribution After ShutdownFl
owra
te
gasliquid
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Potential problems in multiphase flow • PIGGING
• Push a “pig” device through the pipe to • Push out excess liquid and/or wax on the pipe wall • Inspect the pipe for corrosion and wax using an instrumented pig
• Pigging the line can create a large liquid slug ahead of the pig
• The pigging operation can be optimized using simulations
A : S l u g b u il d - u p
B . f r o n t a r r iv a l
C . s l u g s u r fa c e
D . P ig a r r iv a lTime
Flow
rate
gasliquid
A B C D
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Potential problems in multiphase flow
• SEVERE SLUGGING • A: Low spots fills with liquid and
flow is blocked • B: Pressure builds up behind the
blockage • C&D: When pressure becomes
high enough, gas blows liquid out of the low spot as a slug
A. Slug formation
B.Slug production
C. Gas penetration
D. Gas blow-down
– Severe slugs can cause large pressure swings
and liquid surges out of pipeline. – Severe slugging requires a dynamic model
to predict and control
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Potential problems in multiphase flow • LONG SLUGS • In hydrodynamic slug flow we
have a random distribution of slug lengths
• Some slugs can be very long, creating problems (filling slug catcher)
• Long slugs difficult to predict
Slug duration distribution From Xu et al (1997)
Po
pu
lati
on
Den
sity
10
20
30
40
50
60
70
80
90
100
110
120
35%
30%
25%
20%
Olga Data Test Data
15%
10%
5%
0%
Slug Duration (s)
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Troll gas: Onshore slug-catcher
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One-dimensional multiphase pipe flow simulators
• One dimensional models for multiphase flow of gas, oil and water in wells, pipelines and networks
• Steady state and dynamic models • 1-D conservation equations for mass,
momentum and energy • Experimental experience used in
developing closure relations • Wall and interfacial friction factors • Transport of drops and bubbles
• Testing against field data important for validation
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Description of a case to be simulated
Pipe geometry Fluid properties Boundary conditions
Pipe elevation profile Pipe inner diameter Internal wall roughness Wall thickness Wall material properties
Mass fractions Densities Viscosities Surface and interfacial tensions Heat conductivities Specific enthalpies Specific heat capacities
Boundary conditions at pipe ends (Flow, pressure, temperature) External temperature Thermal properties of surroundings (water, air, soil)
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CFD models for multiphase flow • Standard CFD commercial codes are widely used for
simulating laminar and turbulent single phase flow • Multiphase flow give us several new challenges
• Where is the interface? • Large scale interfaces (stratified flow), small scale interfaces
(bubbly flow) or both at the same time • Continuous phases typically described by Euler methods
(i.e. Reynolds averaged Navier-Stokes equations) • Dispersed phases typically described by either Lagrange
methods (tracking each bubble/drop/particle) or Euler methods • More difficult when a phase is both continuous and dispersed
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Eulerian CFD methods for multiphase flow • Diffuse interface methods
• Volume of Fluid (VOF) method • Computes volume fraction of each phase in each control volume
• Level Set method • Interface given as zero level of an auxiliary function
• Phase Field method • Extra conservation equation for «phase field» across interface
• Sharp interface methods • Front tracking – explicit interface tracking
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1D versus CFD multiphase flow models
CFD models • High resolution • Fewer closure relations
• Depending on resolution • Scales not resolved must
be modelled
• Slow or VERY slow • Impractical for pipelines • Can be good for
equipment
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1D models • Low resolution • Many closure relations
• Friction factors • Entrainment/deposition • Drop/bubble properties
• Fast • Only tool today for long
pipelines
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Why are CFD models impractical for pipelines?
• Long high pressure gas condensate pipeline • 1m = 102 cm diameter, 100 km = 107 cm long
• Stratified wavy flow • Bulk flow varies over O(1 cm) length
• 1 cm grid resolution => N ~ 102102107 = 1011 grid cells • Bubbles, drops and other features will have sub-grid
scale and need to be modelled • Huge computing times – but uncertain accuracy
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Conservation equations in multiphase pipe flow
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Introduction • Basic conservation equations: Mass, momentum, energy • The conservation equations are formally similar for all
flow regimes (flow patterns) • The differences between the flow regimes manifest
themselves in different terms (closure relations) for • Wall and interfacial friction factors • Dispersion of other phases as droplets and bubbles • Momentum transfer between phases due to mass exchange
• Thermodynamics enter conservation equations through • Boundary conditions • Source terms • Mass transfer
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Conservation equations for 3-phase stratified flow
• 3 momentum equations • Gas layer with oil and water droplets • Oil layer with gas bubbles and water droplets • Water layer with gas bubbles and oil droplets
• 9 mass equations • 3 continuous phases • 6 dispersed phases
• 9 energy equations • Alternatively, 1 mixture energy equation