Scandpower Petroleum Technology
Flow Assurance and Multiphase flow part III Prof. Rune W. Time Depart Dep artmen mentt of Pet Petrol roleum eum Engin Engineer eering ing Univ Un iver ersi sity ty of of St Stav avan ange gerr
Seminar Seminar at Aker Solutions, Solutions, Stavanger Stavanger – May 31st, 2011
ut ine an time sc e u e
I : 8.3 8.30 0 – 9.15 9.15
Flow regimes and impact on phase slippage, fluid concentrations and pressure drop in
II : 9.25 9.25 – 10.1 10.15 5 Hydrates, wax and asphaltenes
III: 10.25 -11.00 Multi Multipha phase se flow flow – in influ fluenc encee from from n er aces, compress on e ec s an waves
2 Seminar at Aker Solutions, Solutions, Stavanger Stavanger - May31st, 201 2011 1
PART III Multiphase flow , compression effects and waves
3 Seminar at Aker Solutions, Stavanger - May31st, 2011
Slug types • Hydrodynamic slugging (Horizontal pipes)
-
•
• Severe slugging (stronger version of terrain slugging)
Severe slu in , or terrain induced slu in , ma occur at low flowrates when a downwards inclined or horizontal pipeline is connected to a vertical riser. for the receiving process, followed by periods of very high oil and production rates. 4 Seminar at Aker Solutions, Stavanger - May31st, 2011
Terrain induced slugging
http://pipeliner.com.au/ news/super_cooper_sa n os_cooper_ as n_p peline_network/012082
Gas
Cond
5 Seminar at Aker Solutions, Stavanger - May31st, 2011
Slug catcher facility - Melkøya
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Severe slugging . REF: Rune W. Time: Multiphase compendium
http://www.ljll.math.upm c.fr/gallery/files/coquel_ slugging-en.htm
7 Seminar at Aker Solutions, Stavanger - May31st, 2011
Structural damages due to high flows
to slug loading
IAF Das: “The Characteristics and Forces due to ugs n an ape ser , es s Cranfield 2003
Flexible riser configurations with severe slugging
Seminar at Aker Solutions, Stavanger - May31st, 2011
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Mechanical loads on bends due to severe slugging en
Flow Resultant force on bend: FR
2 Av
2
9 Seminar at Aker Solutions, Stavanger - May31st, 2011
Minimizing Severe slugging
REF: Rune W. Time: Multiphase compendium Figure 8.3: Pressure drop in riser, choke and combined riser + choke, for fixed liquid f low rate. From Schmidt et al.,1985
Other solutions: - Riser gas lift ? .. .. 10 Seminar at Aker Solutions, Stavanger - May31st, 2011
Wave propagation in two-phase flow • Surface waves: • Stratified flow Interface friction • Slu flow see movie - later
Liquid transport
• Concentration waves in bubbly systems
(wave speed may influence cross correlation flowmeters) • Pressure waves – sound speed – choked flow
11 Seminar at Aker Solutions, Stavanger - May31st, 2011
Stratified interface drag - I http://www.thermopedia.co m/video/2/stratified_wave
• For stratified flow in pipelines the interface is found to be smooth for
water for gas velocities less than approximately 3 m/s. At this velocity small amplitude regular Jeffrey waves appear at the interface. • Above about 5 m/s Kelvin-Helmholtz waves are generated. For
velocities of about 10 m/s droplets are spewed from the crest of the . • For liquids with a viscosity greater than 15 centipoise the interface is
smooth for gas velocities less than 5 m/s and Kelvin-Hetmholtz waves are generated above this velocity. • The appearance of Kelvin-Helmholtz waves is accompanied by a large
. R. V. A. Oliemans (ed.), Computational fluid Dynamics for the Petrochemical Process Industry. ”Separated flow modelling and interfacial transport phenomena”, THOMAS J. HANRATTY
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Strati ie inter ace rag - II e wave e g s or s ra e ows n p pe nes are roug y o e order of 0.5 to 5 mm so they protrude into the gas space an appreciable distance. •
• The magnitude of the form drag should increase linearly with the wave
height, h, and with the number of waves per unit length. corre a on y n r sos ase on measuremen s or . cm an cm pipelines and for liquids with viscosities of 1-70 centipoise is: h i fi 1 18 , where fi 2 •
s
2
.
G
Here fs is the friction factor for a smooth interface.
Example: h = 5mm, = 2cm
fi / fs = 5.5
More than five times higher interfacial drag! 13 Seminar at Aker Solutions, Stavanger - May31st, 2011
Hydrodynamic slugging Kadri Mudde, Oliemans, Bonizzi, Andreussi : ”Prediction of the transition from stratified to slug flow or roll-waves in gas–liquid horizontal pipes”, International Journal of Multiphase Flow 35 (2009) 1001–
Kelvin-Helmholtz instability Slug flow
Video: K-H Ugs4p4 Uls 0p3 later2
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Seminar at Aker Solutions, Stavanger - May31st, 2011
Interfaces - liquid accumulation, wall wetting, and corrosion CO2 and H2S may attack ”washed” pipeline parts lacking inhibitor .
Transportability ang ng rop e
Flattened dro let
y org an ugs a : Gas Pipelines”, 2007:
op o
ne
orros on an
a er
on ensa on
a es n
e
Water condensing in the top of a wet gas pipeline will form small droplets or a thin film on the s ee sur ace. e con ense wa er can ecome rap y supersa ura e w corros on products, resulting in increased pH and iron carbonate film formation. 15
Seminar at Aker Solutions, Stavanger - May31st, 2011
Pressure waves, choked flow - and process control challenge
Case: The pipeline carries a dispersed bubble flow. Valve A is opened 1:100 (relative i e). The flow does not change when valve B is regulated. What is going on? Flow upstream A; Qmix = 15 L/s , Gas fraction 10%, pipeline D = 10cm , =19 Valve opening (ratio area to pipe area): 1:100
Mix velocity in pipe restriction Flow velocity in valve A 190 m/s. suc g gas rac on s ea s o c o e son c ow Choked flow can give loss of “conventional control”. However, w en va ve s su c en y c o e , va ve ex s e c o ng condition, and B gets back control. Seminar at Aker Solutions, Stavanger - May31st, 2011
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): Flow speed cannot exceed sound speed in the relevant fluid
Chung, Park, and Lee: “ for two-phase critical flow”, Journal of Sound and Vibration 276 (2004) 13–26
17 Seminar at Aker Solutions, Stavanger - May31st, 2011
The challenge of calculating pressure drop in long traverses T e pressure gra ient varies a ong t e pipe due to variation in pipe diameter, inclination and mixture density (pressure dependent)
Pout
in
Pressure at exit:
P
P P
Sum of pressure drop in all pipe segment
Challenge in multiphase flow: • The pressure profile depends on the pressure !
. 18 Seminar at Aker Solutions, Stavanger - May31st, 2011
Numerical simulators available Steady-state: • PIPESIM (Schlumberger) • PIPEFLOW (SPT Group)
Dynamic , transient: •
, • TACITE, 1D • OLGA, 1D • LEDA 2D-3D
ttp: www.aspentec .com core aspen- ysys.aspx (http://www.ann.jussieu.fr/ERTint/pdf/Tacite.pdf) (IFE 1908, Scandpower 89-92, WOLGA,SPT Group) (TotalFinaElf,Conoco and SINTEF)
Well flow and drilling : Drillbench (IRIS) Quality assurance in using commercial packages: - Make sure to have simple inhouse models (semianalytical + numerical) for
checking and comparisons (”common sense”), e.g. mec anistic mo e s a a aite an u er - nee e
or transparency 19
Seminar at Aker Solutions, Stavanger - May31st, 2011
Taitel and u er mo e Ph sics based
Liquid holdup
Flow regime models e.g. slug (K-H):
Pressure gradient 20
Model output
– Taitel and Dukler ”in-house” program 1 0.9
Liquid height for stratified flow case
X = 23.5829 hL /D = 0.87219
0.8 0.7 0.6
D / . L h
=
0.4 0.3 0.2 0.1 0
-2
10
2
10
4
10
UGS = 0.01 m/s
80 n j s k n u f r e l k u D g o l e t i a T l a u d i s e R
0
10
X
100 ULS = 0.01 m/s
60
Y=0 X = 556.152 X = 23.5829
uG = 0.13419 m/s uL = 0.010805 m/s
40
Flow regime determination and pressure gradient
ReG = 65.8739
20
ReL = 137.2857
0
hlt = 0.87219
Flow re ime determination: - Stratified Smooth - Stratified Wavy
-20 -40
FINAL REGIME: Stratified Wavy
-60
Pressure gradient: 0.47121 (Pa/m]
-
-100
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
h /D L
Seminar at Aker Solutions, Stavanger - May31st, 2011
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QUIZ: A simple(st) case of two-phase flow Equal inflow QL = QG
Horizontal pipeline
Gas
3 1
Stabilized interface ?
qu
• • Any guideline principles after all ….. ? Previous slide showed a calculation with Stratified flow, and equal flowrates of gas and liquid : Liquid height = 0.87. Pipe diameter - Liquid level rises! 22 Seminar at Aker Solutions, Stavanger - May31st, 2011
Flow assurance and multi hase flow at UIS Staff members • Malcolm Kelland (Hydrate LCI, production chemicals)
,
,
gas) •
,
,
,
,
injection . , sequestration, multiphase metering and advanced flow instrumentation •
In addition several PhD’s and postdocs 23 Seminar at Aker Solutions, Stavanger - May31st, 2011
Multiphase flow laboratory
24 Seminar at Aker Solutions, Stavanger - May31st, 2011
Multiphase Projects at UIS - I S an researc and IRIS -
ac t es at
S
ttp: www.u s.no
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- medium scale (20 m pipelines oil+air, 10 m water + air) - flow regime analysis of gas-liquid flows in horisontal pipes (oil-air) - terrain and severe slugging (with Iris) Minneapolis) - drag reducers for oil-water production systems
.
- underbalanced drilling and managed pressure drilling (with Iris and Petrobras) - down-hole metering systems (Aker Maritime, IPCsystem) - hole cleaning and cuttings transport (particle transport) in near horisontal pipes (10 m slightly flow loop - with Statoil) - erosion by particles in wells and production lines 25 Seminar at Aker Solutions, Stavanger - May31st, 2011
Mu tip ase Projects at UIS - II Multiphase flow metering techniques in our laboratory - , - Capacitance and impedance techniques (tomography - with Texaco, and norwegian research institutes) - Ultrasonics for measurement of thin liquid layers in pipes (for Conoco Phillips) - PIV and LDA (Dantecdynamics systems) - High speed video and PIV (Financed by NRC) - Microwave multiphase flowmeters (with MPM – MultiPhase Meters) ( http://www.mpm.biz/Portals/39/Performance%20Oct%2005.pdf )
:
,
In addition projects within combustion and gas-dynamics - CO2 capture in oxy-fuel processes (with IRIS, NRC, StatoilHydro and Shell) 26 Seminar at Aker Solutions, Stavanger - May31st, 2011
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