Download - Fluid Flow Projects
McDouugall Schhool of Peetroleum Engineeering
Fluiid Floww Projects
EEightie Board
Pre
eth Se d Mee esenta
A
emi-A eting B ation S
April 17
Annual Brochu Slide C
2013
l Advi ure an Copy
isory nd
Tulsa University Fluid Flow Projects Eightieth Semi-Annual Advisory Board Meeting
April 16 - 17 2013
Agenda
Tuesday April 16 2013 1200 pm TUFFP Workshop Luncheon
H A Chapman Stadium ndash OneOK Club 3112 East 8th Street Tulsa Oklahoma 74104
100 TUFFP Workshop H A Chapman Stadium ndash OneOK Club 3112 East 8th Street Tulsa Oklahoma 74104
330 TUFFP Facility Tour University of Tulsa North Campus 2450 East Marshall Tulsa Oklahoma 74110
600 TUFFP Reception H A Chapman Stadium ndash OneOK Club 3112 East 8th Street Tulsa Oklahoma 74104
Wednesday April 17 2013 TUFFP Advisory Board Meeting
Venue H A Chapman Stadium ndash OneOK Club 3112 East 8th Street Tulsa Oklahoma
800 am Breakfast
830 Introduction Cem Sarica
845 Progress Report Low Liquid Loading Three-Phase Flow Kiran Gawas
Effects of MEG on Multiphase Flow Behavior Hamid Karami
Update of 6rdquo High Pressure Facility Duc Vuong
1015 Coffee Break
1030 Progress Reports Modeling of Hydrodynamics of Gas-Liquid Pipe Flow using Energy Eduardo Pereyra Minimization Concept
Liquid Loading of Gas Wells with Deviations from 0 to 45deg Mujgan Guner
i
Liquid Loading of Gas Wells with Deviations from 45 to 90deg Yasser Alsaadi
1200 pm Lunch
115 Progress Report TUFFP Unified Model Software Improvement amp Database Development
Carlos Torres
TUFFP Experimental Database Jinho Choi
Experimental Determination of Drift Velocity in Medium Oil Viscosities for Horizontal and Upward Inclined Pipes
Jose Moreiras
Revisit of Pipe Inclination on Flow Characteristics of High Viscosity Oil-Gas Two-Phase Flow
Jaejun Kim
245 Coffee Break
300 Progress Reports Effect of High Oil Viscosity on Oil-Gas Flow Behavior in Vertical and Highly Deviated Pipes
Feras Alruhamani
Onset of Liquid Accumulation in Oil and Gas Pipelines Eduardo Pereyra and
TUHOP Facility Incorporation Cem Sarica
415 Business Report Cem Sarica
430 General Discussion
500 Adjourn
530 TUFFPTUPDP Reception Venue H A Chapman Stadium ndash OneOK Club 3112 East 8th Street Tulsa Oklahoma
ii
Table of Contents
Executive Summary 1
Introductory Presentation 5
TUFFP Progress Reports Low Liquid Loading Gas-Oil-Water Flow in Horizontal and Near-Horizontal Pipes ndash Kiran Gawas Presentation 13 Executive Summary 37
Low Liquid Loading Three-Phase Flow and Effects of MEG on Flow Behavior ndash Hamidreza Karami Presentation 41 Executive Summary 61
Update on 6 in ID High Pressure Facility Activities ndash Duc Vuong Presentation 65 Executive Summary 75
Modeling of Hydrodynamics of Gas-Liquid Pipe Flow using Energy Minimization Concept Presentation 79 Executive Summary 89
Liquid Loading of Gas Wells with Deviations from 0deg to 45deg - Mujgan Guner Presentation 93 Executive Summary 117
Liquid Loading in Deviated Pipes From 45deg to 90deg - Yasser Alsaadi Presentation 121 Executive Summary 135
Unified Model Computer Code Update ndash Carlos Torres Presentation 137 Executive Summary 145
TUFFP Experimental Database ndash Jinho Choi Presentation 147 Executive Summary 157
Unified Drift Velocity Closure Relationship for Large Bubbles Rising in Viscous Fluids ndash Jose Moreiras Presentation 161 Executive Summary 173
Characteristics of Downward Flow of High Viscosity Oil and Gas Two-Phase ndash Jaejun Kim Presentation 177 Executive Summary 187
Effect of High Oil Viscosity on Oil-Gas Flow Behavior in Vertical and High Deviated Pipes ndash Feras Alruhaimani Presentation 191
iii
Executive Summary 201
Onset of Liquid Accumulation in Oil and Gas Pipelines ndash Eduardo Pereyra Cem Sarica Presentation 203 Executive Summary 211
TUHOP Incorporation ndash Cem Sarica Eduardo Pereyra Presentation 213
TUFFP Business Report Presentation 219 Business Section 227
Appendices Appendix A ndash Personnel Contact Information 245 Appendix B ndash 2013 Fluid Flow Projects Advisory Board Representatives 247 Appendix C ndash History of Fluid Flow Projects Membership 255 Appendix D ndash Fluid Flow Projects Deliverables 261
iv
Executive Summary
Progress updates on each research project are given later in this Advisory Board Brochure A brief summary of the activities is given below
ldquoInvestigation of Gas-Oil-Water Flowrdquo Three-phase gas-oil-water flow is a common occurrence in the petroleum industry One of objectives of TUFFP for gas-oil-water research is to improve the closure relationships required for multiphase flow models such as the TUFFP unified model This objective is addressed in various projects
ldquoOil Viscosity Effects on Two-phase Flow Behaviorrdquo Earlier TUFFP studies showed that the performances of existing models are not sufficiently accurate for high viscosity oils with a viscosity range of 200 ndash 1000 cp
Our recent efforts resulted in the development of new translational velocity slug liquid holdup and slug length closure relationships Moreover the TUFFP unified model was modified for high viscosity oil two-phase flow based on the experimental findings This project continues on multiple fronts
1 Inclination Angle Effects The objective is to conduct a study for inclination angles of -2deg and +2deg A complete study was conducted by Jeyachandra (2011) Further performance analysis of the used capacitance sensors indicated that some of the holdup data of Jeyachandra needs to be retaken In addition to inclined flow data 3 in horizontal flow data will be acquired through the return line of the facility SNU scholars Mr Kim and Mr Chu are the research assistants for this project The facility was reconfigured from horizontal to inclined position Capacitance sensors have been calibrated and testing has recently started
2 Oil-Gas Flow Behavior in Vertical and Highly Deviated Pipes The objective of this study is to investigate high viscosity oil-gas flow in vertical and deviated wells for a viscosity range of 180 ndash 587 cp Mr Feras Al-Ruhaimani a PhD student is assigned to this project TUFFPrsquos 2 in ID three-phase flow facility is currently being modified for this project The capacitance sensors have been calibrated statically A signal processing macro is being developed using MATLAB Facility will be ready and testing will begin in May 2013
3 Medium Viscosity Oil Study Only a few experimental studies for medium oil viscosity
(20cPltmicroOlt200cP) have been published in the literature Furthermore current two-phase flow models are based on experimental data with low and high viscosity liquids Thus there is a need of experimental and modeling investigation for medium viscosities in order to characterize the two-phase flow behavior for the entire range of possible viscosities
Brito (2012) recently completed an experimental study for horizontal pipe flow The results were presented at Fall 2012 ABM After the completion of high viscosity inclined flow tests the medium viscosity tests will resume for inclination angles of 2deg and +2deg
Since the last ABM drift velocity experiments were completed for horizontal and upward inclined pipes Moreover a unified drift velocity closure relationship has been developed for the range of inclination angles and viscosities ranging from 1 cp to 600 cp A detailed presentation is given in this brochure by Jose Moreiras an undergraduate student in petroleum engineering
ldquoApplication of Minimum Energy Dissipation (MED) Concept in Multiphase Flow in Pipesrdquo The approach is based on the minimum energy dissipation concept postulating that a system stabilizes to its minimum total energy loss Application of this concept has been found in thermodynamics and simulation of the flow in river systems (open channel flow) Moreover the concept has recently been applied in the prediction of two-phase flow splitting in parallel pipes The application of the concept to stratified gas-liquid flow has been successfully demonstrated by Mr Hoyoung Lee during this reporting period The concept is planned to be expanded to other multiphase flow configurations and applications
ldquoUp-scaling Studiesrdquo One of the most important issues that we face in multiphase flow technology development is scaling up of small diameter and low pressure results to large diameter and high pressure conditions Studies with a large diameter facility operated at high pressures would significantly improve our understanding of flow characteristics in actual field conditions Our main objective in this study is to investigate the effect of pipe diameter and pressures on flow behavior using a larger diameter flow loop
This project is one of the main activities of TUFFP and a significant portion of the TUFFP budget is allocated to the construction of a 6 in ID high pressure flow loop The first TUFFP study to be conducted utilizing the new facility is ldquoEffect of Pressure on Liquid Loadingrdquo
1
Since the last advisory Board meeting the facility has been successfully commissioned Single phase gas tests have been completed to determine the loop characteristics Testing of wire mesh for high pressure was successfully completed by HZDR We ordered two wire meshes to be used in 6 in ID high pressure loop as one of the measurement instruments It will be delivered early Fall 2013 The Canty High Pressure Visualization Device has been tested under static conditions Mr Duc Vuong a PhD student has been assigned to the first study The testing will start in fall 2013
ldquoLow Liquid Loading Gas-Oil-Water Flow in Horizontal and Near Horizontal Pipesrdquo Low liquid loading exists widely in wet gas pipelines These pipelines often contain water and hydrocarbon condensates Small amounts of liquids can lead to a significant increase in pressure loss along a pipeline Moreover existence of water can significantly contribute to the problem of corrosion and hydrate formation problems
The main objectives of this study are to acquire detailed experimental data of low liquid loading gas-oil-water flow in horizontal and near horizontal pipes using representative fluids to check the suitability of available models for low liquid loading three phase flow and to suggest improvements if needed
The bulk of the experimental campaign was completed as reported last time Additional data were taken during this period and the data analyses have been completed to characterize the wave and droplet fields for stratified flow A simple correlation approach is suggested for entrainment of oil and water into the gas phase for stratified-atomization flow pattern which is the predominant flow pattern for low liquid loading flow conditions Mr Kiran Gawas a PhD candidate successfully defended his dissertation in March
ldquoEffect of MEG on Multiphase Flow Behaviorrdquo A 6 in ID low pressure facility is now being utilized for this project Currently Mr Hamid Karami a PhD student is conducting baseline tests with no MEG
The entrainment rate measurements were conducted using isokinetic probes for water cuts of 60 80 and 100 and superficial gas velocities of 17 19 21 23 ms The data will be used along with data from Gawas (2013) for water cuts of 40 and less to analyze the effects
of different parameters on the entrainment behavior of oil and water droplets
After completion of the tests without glycol the next phase of experiments will be conducted for different concentrations of glycol will be added to the aqueous phase and the same test matrix will be completed with glycol under steady state flowing conditions
ldquoLiquid Loading of Gas Wellsrdquo Liquid loading in the wellbore has been recognized as one of the most severe problems in gas production At early times in the production natural gas carries liquid in the form of mist since the reservoir pressure is sufficiently high As the gas well matures the reservoir pressure decreases reducing gas velocity The gas velocity may go below a critical value resulting in liquid accumulation in the well The liquid accumulation increases the bottom-hole pressure and significantly reduces the gas production rate
Although considerable effort has been made to predict the liquid loading of gas wells experimental data are very limited The objective of this project is to better understand the mechanisms causing the loading
Ms Mujgan Guner has recently completed an experimental study for the deviation angle range between 0deg and 45deg The important conclusions of the study can be briefly summarized as follows
bull Well deviation is an important variable that affects onset of liquid loading
bull The critical gas velocity increases as the well deviates from vertical
bull Well deviation promotes intermittent flow bull Available models are not in good agreement with
the experimental results especially for deviated wells
Mr Yasser Al-Saadi has started his experimental study to investigate the liquid loading for the deviation angle range between 45deg and 90deg Since the last Advisory Board meeting the literature review has been completed Moreover the facility has been prepared for the testing campaign and testing program has started
ldquoOnset of Liquid Accumulation in Oil and Gas Pipelinesrdquo Accumulation of liquid oil andor water at the bottom of an inclined pipe is known to be the source of many industrial problems such as corrosion and terrain slugging Accurate quantification of the required gas velocities to efficiently sweep the water out and prevent accumulation and accurate prediction of oil and water holdup are of great importance Currently minimum gas velocity or critical angle requirements which are often found to be very conservative are being
2
implemented with various success rates to prevent corrosion in multiphase pipelines
An experimental and theoretical modeling project has already been initiated to better quantify the accumulated liquid volumes and the critical gas velocityinclination angle During this period a research plan has been prepared to be discussed at this Advisory Board meeting and the literature review has started
During the next period the literature review will continue and facility design will be finalized with the required instrumentation to achieve the objectives of the project TUFFPrsquos 3 in ID three-phase flow facility will be used for the experimental portion of this study after the completion of the liquid loading project
ldquoUnified Mechanistic Modelrdquo TUFFP has been maintaining and continuously improving the TUFFP unified model TUFFP has decided to rewrite the unified model software with an emphasis on modularity and computation efficiency Significant progress is made in making the software modular A detailed presentation outlining the progress is given in this brochure
ldquoTUFFP Experimental Database Developmentrdquo TUFFP has 46 gas-liquid data sets including steady-state and transient experiments More than 10000 steady-state data records exist for gas-liquid flow For oil-water experiments 11 data sets with about 2800 data records have been acquired Finally 5 data sets with about 500 data records have been obtained from gas-oilshywater experiments
The main objective of this project is to construct a comprehensive multiphase flow database of TUFFP experimental data sets
Schlumberger already developed a steady-state multiphase database software using Microsoft Access which has been donated to TUFFP This software will be further developed to accommodate the diverse nature of TUFFP data
The current TUFFP membership stands at 17 Due to the sale of SPT Group to Schlumberger SPT Group terminated their membership for 2013 Moreover JOGMEC terminated their membership due to changes in their research and technology development portfolio On the other hand NTP Truboprovod Piping Systems Research amp Engineering joined as the newest member of TUFFP Efforts continue to further increase the TUFFP membership level We anticipate having one or two additional new members for 2013 A detailed report on membership and financial matters is provided in this report
Several related projects are underway The related projects involve sharing of facilities and personnel with TUFFP The Paraffin Deposition consortium TUPDP is completing its fourth three-year phase A new phase has already been started with a new three-year plan
Tulsa University High Viscosity Oil Projects (TUHOP) Joint Industry Projects has been completed An insufficient number of members displayed interest in the continuation of TUHOP at this time Therefore it is proposed to merge TUHOP into TUFFP to pursue the high viscosity oil multiphase flow research more vigorously The TUHOP deliverables generated during its existence will not be available to TUFFP members
The newly formed consortium called ldquoTulsa University Horizontal Well Artificial Lift Projectsrdquo (TUHWALP) is addressing the artificial lift needs of horizontal wells drilled into gas and oil shales TUHWALP started its activities in July 2012 The membership has grown from 11 to 16 members during this reporting period We anticipate reaching 20 members by the end of 2013 The membership fee is $50000
3
4
Fluid Flow Projects
80th Fluid Flow Projects Advisory Board Meeting
Welcome
Advisory Board Meeting April 17 2013
Safety Moment
Emergency Exits Assembly Point Tornado Shelter Emergency Call 911
Restrooms
Fluid Flow Projects Advisory Board Meeting April 17 2013
5
Introductory Remarks
80th Semi-Annual Advisory Board Meeting
Handout Combined Brochure and Slide Copy
Sign-Up List Please Leave Business Card at
Registration Table
Fluid Flow Projects Advisory Board Meeting April 17 2013
Team
Research Associates Cem Sarica (Director)
Eduardo Pereyra (Associate Director)
Carlos Torres (Research Associate)
Jinho Choi (Research Associate)
Abdel Al-Sarkhi (KFPMU ndash Visiting Research Professor)
Eissa Al-Safran (KU ndash Collaborator)
Fluid Flow Projects Advisory Board Meeting April 17 2013
6
Team hellip
Project Coordinator Linda Jones
Project Engineer Scott Graham
Research Technicians Craig Waldron Norman Stegall Don Harris Franklin Birt
Web Master Lori Watts
Fluid Flow Projects Advisory Board Meeting April 17 2013
Team hellip
TUFFP Research Assistants Feras Alruhaimani (PhD) ndash Kuwait
Yasser Alsaadi (MS) ndash Saudi Arabia
Selcuk Fidan (PhD) ndash Turkey
Kiran Gawas (PhD) ndash India
Mujgan Guner (MS) ndash Turkey
Hamid Karami (PhD) ndash Iran
Duc Vuong (PhD) ndash Vietnam
Fluid Flow Projects Advisory Board Meeting April 17 2013
7
Team hellip
Visiting Research Scholars Maher Shariff Saudi Aramco
SNU Visiting Research Assistants Mignon Chu
Jaejun Kim
Hoyoung Lee
Fluid Flow Projects Advisory Board Meeting April 17 2013
Guests
Nicolas Jauseau Kongsberg Oil amp Gas
Travis Gray Range Resources
Ken Walsh Range Resources
Steve Coleman
DSME Representative
Tod Canty JM Canty
Fluid Flow Projects Advisory Board Meeting April 17 2013
8
Agenda
830 Introductory Remarks 845 Progress Reports Low Liquid Loading in GasOilWater Pipe
Flow Effects of MEG on Multiphase Flow
Behavior
Update on 6 in High Pressure Facility
Activities
1015 Coffee Break
Fluid Flow Projects Advisory Board Meeting April 17 2013
Agenda hellip
1030 Progress Reports
Modeling of Hydrodynamics of Gas-Liquid Pipe Flow using Energy Minimization Concept
Liquid Loading of Gas Wells with Deviations from 0 to 45 Degrees
Liquid Loading of Gas Wells with Deviations from 45 to 90 Degrees
Fluid Flow Projects Advisory Board Meeting April 17 2013
9
Agenda hellip
1200 Lunch
115 Progress Reports TUFFP Unified Model Software Improvement amp
Database Development
TUFFP Experimental Database
Experimental Determination of Drift Velocity in Medium Oil Viscosities for Horizontal and Upward Inclined Pipes
Revisit of Pipe Inclination on Flow Characteristics of High Viscosity Oil-Gas Two-Phase Flow
245 Coffee Break
Fluid Flow Projects Advisory Board Meeting April 17 2013
Agenda hellip
300 Progress Reports
Effect of High Oil Viscosity on Oil-Gas Flow Behavior in Vertical and Highly Deviated Pipes
Onset of Liquid Accumulation in Oil and Gas Pipelines
TUHOP Incorporation
Fluid Flow Projects Advisory Board Meeting April 17 2013
10
Agenda hellip
415 TUFFP Business Report
430 Open Discussion
500 Adjourn
530 TUFFPTUPDP Reception
Fluid Flow Projects Advisory Board Meeting April 17 2013
Other Activities
April 16 2013 TUFFP Workshop Excellent Presentations
Facility Tour I TUFFP Reception
April 18 2013 TUPDP Meeting Facility Tour II TUHWALP Reception
April 19 2013 TUHWALP Meeting
Fluid Flow Projects Advisory Board Meeting April 17 2013
11
12
t
Fluid Flow Projects
Low Liquid Loading Gas-Oil-Water Flow In Horizontal and Near-
Horizontal Pipes
Kiran Gawas
Advisory Board Meeting April 17 2013
Outline
6 Objectives
6 I t i6 Introdduction
6 Experimental Study
6 Results and Discussion
6 Correlation Comparison
6 Conclusions
6 Recommendations
Fluid Flow Projects Advisory Board Meeting April 17 2013
13
Objectives
6 Acquire Experimental Data of Low Liquid L di G Oil W t Fl iLoading Gas-Oil-Water Flow in Horizontal and Near Horizontal Pipes Using Representative Fluids
6 Check Suitability of Available Models for Low Liquid Loading Three Phase Flow and Suggest Improvements If Needed and Suggest Improvements If Needed
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction
6 Low Liquid Loading Flows Correspond to Liquid to Gas Ratio le 1100 m3MMsm3 Liquid to Gas Ratio le 1100 m MMsm 6 Small Amounts of Liquid Influences
Pressure Distribution ndash Hydrate Formation PiggingFrequency Downstream Equipment Design etc 66 TTransportt of Additivesf Additi 6 Very Few Experiments for Large Diameter
Pipes 6 Up-scaling of Available Models
Fluid Flow Projects Advisory Board Meeting April 17 2013
14
15
Experimental Facility
Fluid Flow Projects Advisory Board Meeting April 17 2013
Test Section
46m 46m 8 2m 82m 9 1m 91m 9 1m 91m 7 1m 71m
P P DP DP
DP T
DP
QCV QCV
QCV QCV
DP T DP
QCV
DP DP P P
71m 91m 91m 82m
564m
Fluid Flow Projects Advisory Board Meeting April 17 2013
16
ndash
Test Fluids
6 Test Fluid
frac34G Aifrac34Gas ndash Air
frac34Water ndash Tap Water
ρ = 1000 kgm3
μ = 1 cP
γair = 72 dynescm 60deg F
frac34Oil ndash Isopar Lfrac34Oil Isopar L
ρ = 760 kgm3
μ = 135 cP
γair = 24 dynescm 60deg F
Fluid Flow Projects Advisory Board Meeting April 17 2013
Measurement Techniques
Glycerin
Pipe
High Speed Visualization
DAQ Light Light
Source
High Speed Camera Acrylic Box
Setup
Flow Direction
6 15
ProbeFlow Meter Meter
Pressure Gauze
Separator
Capacitance Probe Isokinetic Sampling
Fluid Flow Projects Advisory Board Meeting April 17 2013
Results and Discussion
6 Flow Pattern
6Wave Characteristics frac34Presented by Mr Mirazizi
6 Droplet Size
6 Droplet Flux
6 E t i t F ti 6 Entrainment Fraction
Fluid Flow Projects Advisory Board Meeting April 17 2013
Flow Pattern Studies
Fluid Flow Projects Advisory Board Meeting April 17 2013
17
18
Flow Pattern Studies hellip
Dong (2007)
Current Study
Fluid Flow Projects Advisory Board Meeting April 17 2013
Flow Pattern Studies hellip
6 Gas-liquid flow pattern Stratified-atomization flowflow
6 Oil-water flow pattern ndash Separated flow Semi-dispersed flow and complete dispersion of water in oil
6 Oil-water interface convex but no breakthrough of the water channel at the ggas-liqquid interface
6 Negligible effect of water cut on initiation of atomization
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Size Studies
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Size Studies hellip
25 100
5
10
15
20
25
f v (d
P ) (
)
Bottom
Middle
Top
20
40
60
80
100
F v (
d P )
()
Bottom
Middle
Top
Fluid Flow Projects Advisory Board Meeting April 17 2013
0
0 200 400 600 800
dp (microns)
0
0 200 400 600 800 dp (microns)
19
20
f v (
)
f v (d
P)
()
Droplet Size Studies hellip
25 100
90
20 80 Bottom
Bottom 70 Middle
Middle 15 Top
10 Fv (d
P)
()
Top 60
50
40
30
20 5
10
0 0 0 200 400 600 800
0 200 400 600 800 dp (microns) dp (microns)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Size Studies hellip
10020
Experimental data 18 Experimental data
Log normal 16 Log normal 80
Upper limit log normal Upper limit log normal 14
12
10
Fv
() 60
8 40
66
4 20
2
0 0
0 100 200 300 400
dp (microns)
500 600 0 100 200 300 dp (microns)
400 500
Fluid Flow Projects Advisory Board Meeting April 17 2013
Azzopardi et al (1985) Azzopardi et al (1985) adjusted 1
10 15 20 25 30
vSG (ms)
⎡ 2 minus058 ⎤ 05 036⎛ ρ v λ ⎞ ⎛ W ⎞ ⎛ ⎞ ⎛ σ ⎞L G A LE σd32 = λA ⎢154⎜ ⎟ + 35⎜⎜ ⎟⎟⎥ λA = ⎜⎜ ⎟⎟ λA = ⎜⎜ ⎟⎟⎜ ⎟⎢ σ ρ v ⎥ ρ ρ⎝ ⎠ ⎝ L G ⎠ ⎝ L g ⎠ ⎝ Lg ⎠⎣ ⎦
Droplet Size Studies hellip
1000d 3
2 (m
icro
ns)
100
10
1
Bottom Middle
Top Entire pipe cross-section
Kocamustafaogullari et al (1994) Al Sarkhi et al (2002)
Azzopardi et al (1985)
10 12 14 16 18 20 22 24 26 28 30
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Size Studies hellip
1000
100
d 32
(mic
ron
s)
Bottom Middle
Top Entire pipe cross-section
Azzopardi et al (1985) Azzopardi et al (1985) adjusted
10
Fluid Flow Projects Advisory Board Meeting April 17 2013
21
Droplet Size Studies hellip
dmax= 29155 d32
900
Rsup2 = 07358
300
500
700
d max
(mic
ron
s)
Fluid Flow Projects Advisory Board Meeting April 17 2013
100
100 150 200 250
d32(microns)
Droplet Size Studies hellip
16
4
6
8
10
12
14
f v (d
P ) (
)
Fluid Flow Projects Advisory Board Meeting April 17 2013
0
2
4
0 100 200 300 400 500 600
dp (microns)
22
Droplet Size Studies hellip
6 Upper Limit Log Normal Distribution Used to Fit Droplet Size DistributionDroplet Size Distribution
6 Volume PDF and CDFs Shift to Lower Drop Size with Increasing Distance from Bottom of the Pipe - Influences Concentration Distribution of Entrained Drops
6 Characteristic Drop Size Decreases with Distance from Bottom from Bottom
6 Available Correlation Need to Be Modified to Accurately Predict the Effect of Surface Tension
6 Volume PDF for Three Phase Flow Shows Bishymodal Distribution
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Flux Studies hellip
Flow
Saltation Region
Flow Direction
Turbulence Gravity
dC
Fluid Flow Projects Advisory Board Meeting April 17 2013
)( yaCudy
dC T =+ε
Turbulent Diffusion Gravity Settling
SourceSink
(Paras SV and Karabelas A J Int J Multiphase Flow 17 455-468 1991)
23
24
Droplet Flux Studies hellip
vSL = 001 ms θ = -2deg air-oil flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Flux Studies hellip
1
VSG = 23 ms vSg=
08 Pan and Hanratty (2002)
Skartlien et al (2011) 06
Eq (449) yD 04
02
0
001 01 1 10Ex (kgm2s)
Fluid Flow Projects Advisory Board Meeting April 17 2013
25
Droplet Flux Studies hellip
1 01 vSL = 002 msVSL = 002 ms vSG = 23 ms -2deg VSG = 23 ms -2 vSL = 0015 msVSG = 0015 ms vSG = 19 ms -2deg VSG = 19 ms -2 00808 vSL = 001 msVSL = 001 ms vSG = 167 ms -2degVSG = 167 ms -2 vSL = 0005 msVSL = 0005 ms
06
yD 04 W
LE
(kg
s)
006
004
02 002
00 0
001 01
Ex (kgm2s) 1 10 0 0005 001 0015
vSL (ms) 002 0025
vSG = 19 ms θ = -2deg air-oil flow θ = -2deg air-oil flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Flux Studies hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Flux Studies hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Flux Studies hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
26
27
Droplet Flux Studies hellip
vSG = 19 ms vSL = 002 ms 2deg
11 WC = 01 Water
WC = 01 Oil 08
WC = 02 Water
WC = 02 Oil 06
WC = 04 Water
yD WC = 04 Oil 04
02
0
001 01 1 10 Ex (kgm2s)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Flux Studies hellip
1 1
WC = 1 WC = 1
08 08 WC = 01 Water
WC = 02 Water
06 WC = 04 Water 06
yD yD04 04
WC = 0
WC = 01 02 02
WC = 02
WC = 04
0 00 0
001 01 1 001 01 1 (Ex) (Ex0 )water(kgm2s)(Ex) (Ex0 )oil(kgm2s)
Oil droplet flux profile Water droplet flux profile for vSG = 23 ms vSL = 001 ms for vSG = 23 ms vSL = 001 ms
Fluid Flow Projects Advisory Board Meeting April 17 2013
28
Droplet Flux Studies hellip
1
WC = 01
08 WC = 02
WC = 04 06
yD 04
0 202
0
0 005 01 015 02 025
fw
Fluid Flow Projects Advisory Board Meeting April 17 2013
Droplet Flux Studies hellip
6 Droplet Flux Profile Along Vertical Axis M dMeasured
6 Accurate Prediction of Concentration Profile Needs Accounting for Exact Distribution of Drop Sizes
6 Entrainment of Liquid Most Sensitive to G Fl RGas Flow Rattes
6 Effect of Inclination Diminishes with Increase in Gas Flow Rate
Fluid Flow Projects Advisory Board Meeting April 17 2013
VSG = 23 ms 2 VSG 19 ms 2 SG 165 ms 2
VSG = 23 ms 2 VSG 19 ms 2 SG 165 ms 2
Droplet Flux Studies hellip
6 Entrainment Controlled by the CConti tinuous Oil PhaseOil Ph
6 Enhancement in Entrainment of Water in Three Phase Flow
6 No Interaction Between Entrained Oil and Water Drops
6 Fraction of Water in the Entrained Phase Decreases with Distance from the Bottom of the Pipe
Fluid Flow Projects Advisory Board Meeting April 17 2013
Entrainment Fraction Correlation
( )LELFLELLE WWWWWE +==
0 4
06
08
1
E
- = - V = -
= V =
vSG = 23 ms -2deg
vSG = 23 ms 2deg
vSG = 165 ms -2deg
vSG = 165 ms 2deg
vSG = 19 ms -2deg
vSG = 19 ms 2deg
Fluid Flow Projects Advisory Board Meeting April 17 2013
0
02
04
0 0005 001 0015 002 0025 vSL (ms)
29
LFCLFGLGA
θθ Ck
Entrainment Fraction Correlation hellip
Da RR =
⎞⎛502 )( Wvk ρρ ⎟⎞
⎜⎛ minusWWvk
Ra LFCLFGLGA ρρ 502 )( ⎟ ⎠ ⎞
⎜ ⎝ ⎛ Γminus= )(
C LFGLGA
P
WvkRa
σ ρρ ⎟
⎠ ⎜ ⎝
= P
Ra σ
P = SIP = πD
2
0211 ⎟ ⎠ ⎞
⎜ ⎝ ⎛ minusminus=
D
hDS I
Fluid Flow Projects Advisory Board Meeting April 17 2013
θC θC
Si
Two-fluid model
Entrainment Fraction Correlation hellip
)()( θθ WDD CkR = B
W DD C
CkR
)()(
θθ= )()( WDD B
B DD C
CkR )(θ
02
03
04
Cor
rela
tion
Fluid Flow Projects Advisory Board Meeting April 17 2013
0
01
0 01 02 03 04
E C
ERigorous
30
31
Entrainment Fraction Correlation hellip
11 ExperimentsExperiments Pan and Hanratty (2002)Pan and Hanratty (2002) 08 Mantilla (2008)08 Mantilla (2008) Current Current
0606
E E
0404
0202
00 0 0005 001 0015 002 0025 0030 0005 001 0015 002 0025 003 vSL (ms) vSL (ms)
vSG = 19 ms air-oil flow vSG = 23 ms air-oil flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
Entrainment Fraction Correlation hellip
( ) = WC b (R ) (Ra ) = (1 minusWCRa a b )(Ra )water Oil
2 0 5k v ( ρ ρ ) ⎛ W minus W ⎞A G m G LF LFCRa = ⎜ ⎟σ ⎝ P ⎠
1 WC = 01
08 WC = 02
WC = 04 06
WC = 11WC
yD 04
02
vSG = 19 ms vSL = 002 ms 0deg 0
001 01 1 10 (Ex) WCm (kgm2s)
Fluid Flow Projects Advisory Board Meeting April 17 2013
CC CWCW= C = CRD kD RD k DB waer B oilwater oilCB C Bwater oil
Entrainment Fraction Correlation hellip
( ) ( )G
mwaterL Twab vDS
WCEW uRWC
24π = ( ) ( )G
oilmL Toab vDS
EWCW uRWC
24
)1()1(
π minus
=minus
)1()1(
)1(m
W
O m
m b
WC E
EWC
WCWC
minus minus
minus +
= ⎥ ⎦
⎤ ⎢ ⎣
⎡ minus +minus=
m
o womLLF WC
EEEWCWW
)1()(
Fluid Flow Projects Advisory Board Meeting April 17 2013
Entrainment Fraction Correlation hellip
1 Vsg = 23 ms Vsl = 002 ms - Correlation V 19 V l 0 02 C l ti
001
01
(WL
E )
Wate
r [k
gs]
Vsg = 19 ms Vsl = 002 ms - Correlation Vsg = 167 ms Vsl = 001 ms - Correaltion Vsg = 23 ms Vsl = 002 ms Vsg = 19 ms Vsl = 002 ms Vsg = 167 ms Vsl = 001 ms
00001
0001
0 005 01 015 02 025 03 035 04 045 WC [-]
Fluid Flow Projects Advisory Board Meeting April 17 2013
32
33
Entrainment Fraction Correlation hellip
06 WC = 01
WC = 02
WC = 04 04
yD
02
0
001 01 1 (Ex) WCm (kgm2s)
vSG = 165 ms vSL = 002 ms 0deg
Fluid Flow Projects Advisory Board Meeting April 17 2013
Entrainment Fraction Correlation hellip
06 vsg = 167 ms Experiment
Vsg = 19 ms Experiments 05
Vsg = 23 ms Experiments
vsg = 167 ms Correlation 04 Vsg = 19 ms Correlation
Vsg = 23 ms Correlation 03
02
01
0
0 01 02 03 04 05 06 WCm
WC
b
Fluid Flow Projects Advisory Board Meeting April 17 2013
Conclusions
6 Correlation Approach Accounting for Asymmetry of Liquid Filmof Liquid Film
6 Better Prediction of Functional Relationship of Entrainment Fraction on Liquid Velocity
6 Correlation for Entrainment Fraction in Three Phase Flow Assuming Uniform Distribution of Water in the Liquid Film
6 Close Match With Data for Amount of Water Entrained Except for Lowest Gas Velocity Studied
Fluid Flow Projects Advisory Board Meeting April 17 2013
Recommendations
6 Measurement of Axial Gas Velocity Profile
6 M t f D l t Fl t Diff t R di l 6 Measurement of Droplet Flux at Different Radial Locations
6 Measurement of Distribution of Water in the Liquid Phase
6 Visualization System to Distinguish Between Oil and Water Drops
6 Experiments in Three Phase Flow at Higher Pressure
Fluid Flow Projects Advisory Board Meeting April 17 2013
34
Recommendations hellip
6 Incorporating Wave Characteristics Studied to Improve Model for AtomizationImprove Model for Atomization
6 Model for Distribution of Water in the Liquid Phase
6 Accounting for Effect of Variation of Turbulent Diffusivity Across the Pipe Cross-section ndash Secondary Flow
6 Model That Accounts for Curvature Effect for Better Prediction of Interfacial Perimeter
6 Transition to Annular Flow Based on Droplet Deposition
Fluid Flow Projects Advisory Board Meeting April 17 2013
Thank You
Fluid Flow Projects Advisory Board Meeting April 17 2013
35
36
Low Liquid Loading in Gas-Oil-Water Pipe Flow Kiran Gawas
Project Completion Dates Final Report April 2013
Objectives The main objectives of this study are
Acquire experimental data of low liquid loading gas-oil-water flow in horizontal and near horizontal pipes using representative fluids
Check suitability of available models for low liquid loading three-phase flow and suggest improvements if needed
Introduction Low liquid loading gas-oil-water flow is widely encountered in wet gas pipelines Even though the pipeline is fed with single phase gas the condensation of the gas along with traces of water results in three-phase flow The presence of these liquids can result in significant changes in pressure distribution Hydrate formation pigging frequency and downstream facility design which are strongly dependent on pressure and holdup distribution in the pipeline will also be thus affected Several authors have published papers on flow pattern identification and modeling of three-phase flow However most of them do not cover the range of low liquid loading flow which is the main focus of this study The experimental program is conducted in a 6 in ID flow loop The main focus of this study is measurement of droplet flux droplet size distribution and wave characteristics for horizontal and near-horizontal pipes Additionally oil-water flow pattern in the liquid phase are studied for different liquid loading levels and waters cuts
Activities Summary Experimental Study
Experimental Program Preliminary experiments were conducted with representative fluids in order to investigate the flow patterns existing in case of gasoilwater pipe flows Droplet flux studies were conducted for superficial gas velocity in the range of 165 ms to 23 ms superficial liquid velocity in the range of 0005 ms and 002 ms inclinations +2 -2 and 0deg from horizontal and water cut of 0 10 20 40 and 100 Isokinetic sampling system was used to measure flux of oil and water drops at different locations along the vertical axis of the pipe cross-section
Characteristics of waves at gas-liquid interface for the case of air-oil two phase flow was studied for superficial gas velocity in the range of 12 ms to 22 ms superficial liquid velocity in the range of 0005 to 002 ms and inclinations of +2 -2 and 0deg from the horizontal A new capacitance probe system was developed for this purpose which provides insights into the interfacial behavior To our knowledge no wave characteristics data for air-oil flow exists in literature Most of the work on interfacial waves is for air-water two phase flows
Since the transport of entrained liquid drops is influenced by their size a high speed visualization system was developed to measure droplet size distribution Droplet sizes were measured for three different gas flow rates for air-oil flow and airoilwater flow at 40 water cut Measurements were done at three different locations from bottom of the pipe
Finally a simple correlation approach is suggested for entrainment of oil and water into the gas phase for stratified-atomization flow pattern which is the predominant flow pattern for low liquid loading flow conditions
Experimental Results Flow pattern studies
The predominant gas-liquid flow pattern in low-liquid loading flows is stratified-atomization flow Although the inception of atomization starts at superficial gas velocity of 10 ms the entrained drops do not reach top of the pipe until superficial gas velocity reaches 15 ms for air-oil flow and 20 ms for air-water flow respectively No appreciable change was observed in the gas velocity for inception with increasing water cut in the case of airoilwater three-phase flow
The oil-water interface showed a distinct convex curvature in case of airoilwater three phase flow However breakthrough of the water channel to the gas-liquid interface as reported by Dong (2007) could not be ascertained for the test fluids used in this study
The water drops appear to be completely dispersed in the continuous oil phase for vSG gt 19 ms up to 40 water cut However for vSG lt 19 ms a small continuous water film is observed at the bottom
37
of the pipe which indicates a non-uniform dispersion of water drops in the liquid film
Wave characteristic studies The different characteristics of interfacial waves such as wave celerity wave amplitude and wave frequency were correlated to X which represents ratio of Froude numbers of the liquid and gas phase respectively The correlation was tested for a comprehensive data set based on wave data available in literature over a range of liquid film thickness
The correlation was also compared with model predictions for wave celerity using mechanistic model proposed by Watson (1989) Similarity of results obtained using both the model predictions and the correlation implies that X combines all the important parameters that determine wave behavior
Droplet size studies Upper-limit lognormal (ULLN) and lognormal distributions were used to represent the measured droplet size distribution data ULLN showed better overall fit than lognormal distribution especially for larger drop sizes The difference between the two is however small
The characteristic drop size decreases from bottom of the pipe to the top The spatial variation of size however decreases with increase in gas velocity The available correlations for characteristic droplet sizes do not match with the current data set since these correlations rely on experiments conducted for air-water flow which is high surface tension system
The method used in this study cannot distinguish between oil and water drops However droplet size distribution for three-phase flow case shows a bimodal distribution function Since careful examination of the recorded images does not indicate presence of complex drops the two modes observed in the distribution function can be attributed to individual oil and water drops
Droplet flux studies Measurements at different locations along the vertical axis of the pipe cross-section show that the droplet flux decreases almost exponentially with increasing distance from bottom of the pipe Modeling of concentration profile of droplets based on a balance between turbulent diffusion forces and gravity (Paras and Karabelas 1990 Pan and Hanratty 2002) predict behavior close to the gas-liquid interface but deviates from the observed behavior towards top of the pipe The entrainment fraction is highly sensitive to gas flow rate and varies as (vSG)5 The effect of liquid flow rate and inclination is less significant Although entrainment fraction tends to increase as the inclination changes from -2 to +2deg the effect
diminishes as gas flow rate increases The entrainment fraction tends to decrease with increasing liquid flow rate and this effect is more prominent for the higher gas flow rate and at lower liquid flow rates
Measurement of droplet flux of oil and water for the case of airoilwater three-phase flow indicates that entrainment of water which is the dispersed phase is enhanced by the presence of oil which is the continuous phase This leads to higher flux of water than in the case of air-water two-phase flow
The slope of the droplet flux profiles indicates that the water and oil drops are distributed across the pipe cross-section independent of each other Thus changing water cut changes only the rate at which oil and water is atomized with no interaction between the two thereafter The fraction of water in the entrained liquid decreases with increasing distance from bottom of the pipe due to higher settling velocity of water compared to that of oil
Correlation for entrainment of water and oil in gasoilwater three-phase flow The correlations used for estimation of entrainment fraction in horizontal flow are based on annular flow data Annular flow conditions would rarely be attained for low-liquid loading flows The asymmetry of liquid film should therefore be accounted for in determination of entrainment fraction The approach suggested in current study fairs better than the available correlations in describing the functional dependence of entrainment fraction on superficial liquid velocity
This approach is extended to three-phase flow by assuming that the deposition of the entrained water and oil drops takes place independent of each other Uniform distribution of water in oil is assumed to predict rate of atomization of water and oil at the gas-liquid interface These assumptions match experimental observations except at lower gas velocity For low gas flow rate investigated in this study the proposed correlation over predicts amount of water entrained in the gas phase
Recommendations Experimental determination of concentration
distribution of water drops in the liquid film Visualization system to distinguish between
entrained water and oil drops Measurement of axial gas velocity along the
vertical axis of the pipe to accurately predict the concentration of entrained drops and for better estimation of drop diffusivity
Incorporating the wave characteristics studied to improve modeling of rate of atomization
38
Incorporating the effect of entrained liquid experimental data on entrainment is for low drops on turbulent diffusivity in the gas pressure phase Variation of diffusivity across the Model that accounts for curvature of the pipe cross-section also needs to be gas-liquid film is required for prediction of considered interfacial perimeter and film thickness
Effect of secondary flow on droplet Better prediction for transition from distribution needs to be considered to stratified-atomization flow to annular flow improve the prediction of droplet transport based on droplet deposition is required towards the top and sides of the pipe Experiments at higher pressure are needed to
Comparison of the predictions of current investigate the effect of pressure on approach with experimental data at high entrainment of oil and water pressure is needed Most of the available
References Dong H-K ldquoLow Liquid Loading Gas-Oil-Water Flow in Horizontal Pipesrdquo U of Tulsa OK 2007 Pan L Hanratty TJ ldquoCorrelation of entrainment for annular flow in horizontal pipesrdquo Int J Multiphase Flow
28 385-408 2002 Paras SV Karabelas AJ ldquoDroplet entrainment and deposition in horizontal annular flowrdquo Int J Multiphase
Flow 17 455-468 1991 Watson M ldquoWavy stratified flow and the transition to slug flowrdquo Proceedings of the 4th International Conference
in Multi-phase Flows Nice France 1989
39
40
Fluid Flow Projects
Low Liquid Loading Three-Phase Flow and Effects of
MEG on Flow Behavior
Hamidreza Karami
Advisory Board Meeting April 17 2013
Outline
6 Introduction
6 Objectives
6 Experimental Work
6 Preliminary Experimental Results frac34Wave Characteristics
frac34E t i t R frac34Entrainment Ratte
6 Future Activities
Fluid Flow Projects Advisory Board Meeting April 17 2013
41
Introduction
6 Low Liquid Loading Flow Influences Different Flow CharacteristicsFlow Characteristics
6 Very Few Experiments For Large Diameter Pipes
6 MEG is Injected Continuously as Hydrate Inhibitor in Offshore Systems
6 Its Impact on Flow Pattern Holdup Pressure6 Its Impact on Flow Pattern Holdup Pressure Drop Predictions is not Well Understood
6 Need to Generate Experimental Data and Improve Model Predictions
Fluid Flow Projects Advisory Board Meeting April 17 2013
Objectives
6 Collect Flow Pattern Holdup Wave Characteristics and Entrainment Data Using TUFFPrsquos 6 in ID Low Pressure Test Facility With and Without MEG under Different Flow Conditions
6 Benchmark Existing Models Document Di iDiscrepancies
6 Propose Improvements If Needed
Fluid Flow Projects Advisory Board Meeting April 17 2013
42
Experimental Facility
6-in ID Low Liquid Loading Facility
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Program hellip
6 Low Liquid Loading Facility Used (6 in ID)
6 Testing Fluids IsoPar-L Oil Tap Water Air Mono Ethylene Glycol (MEG)
6 Initial Tests Under Steady State Conditions
6 Aqueous Phase ρ μ σ hellip to Be Investigated for Different Temperatures and MEG
Fluid Flow Projects Advisory Board Meeting April 17 2013
43
Measurement Techniques hellip
6 Pressure and Temperature PTs DPs and TTTTs
6 Holdup Quick Closing Valves and Pigging System
6 Entrainment Rate Iso-kinetic Sampling
6 Droplet Size Distribution
6 Capacitance Sensor
6 Portable Densitometer
Fluid Flow Projects Advisory Board Meeting April 17 2013
6 Densito 30PX
Density Calibration hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
44
Density Calibration hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
Preliminary Test Matrix hellip
6 Proposed Tests
Parameter Different Cases Number
MEG (wt) 0 10 25 50 4
Inclination (deg) 0 2 -2 3
Water Cut () 10 20 40 60 80 100 6
Mixing Condition Mixing Condition Steady StateSteady State 11
Vsl (cms) 1 2 2
Vsg (ms) 15 17 19 21 23 5
Total 720
Fluid Flow Projects Advisory Board Meeting April 17 2013
45
Preliminary Test Matrix hellip
6 Horizontal Cases First
6 Cases without Glycol First
6 50 Glycol Concentration
6 Properties to Be Investigated frac34 Entrainment Rate
frac34 Liquid Holdup
frac34Wave Characteristics
frac34 Droplet Size Distribution
frac34 Dispersion of Liquid Phases
Fluid Flow Projects Advisory Board Meeting April 17 2013
Testing Range
Temperature Range
Fluid Flow Projects Advisory Board Meeting April 17 2013
46
6 Isokinetic Probes
6
Flow Direction
03 15
7
Pressure Gauge
Separator
Fluid Flow Projects Advisory Board Meeting April 17 2013
47
Entrainment Rate hellip
Entrainment Rate hellip
Probe Position P9 h1 = 1primeprime h2 = 125 primeprime
P8 h3 = 15 primeprime h4 = 175 primeprime
P7 h5 = 2primeprime
P6 h6 = 225primeprime
P5 hh7 = 33primeprime 7 P4
P3 h8 = 45primeprime P2
P1 h9 = 6primeprime
Fluid Flow Projects Advisory Board Meeting April 16 2013
Holdups QCVs amp Pigging System
Fluid Flow Projects Advisory Board Meeting April 16 2013
Wave Characteristics hellip
6 Insulated Probes Used for WaterAir
6 Effects of Glycol on Wave Characteristics
6 Tests Will Be Tried for High Water Cut 3shyPhase Flow
6 Characteristics frac34 Length
frac34 Celerity
frac34 Frequency
frac34 Amplitude
0deg 2 D
60deg
30deg
90deg
Fluid Flow Projects Advisory Board Meeting April 17 2013
48
Preliminary Experimental Results
6 Wave Characteristics frac34GasOil 2-Phase Low Liquid Loading Flow
frac34Combine Effort between Previous Project (Kiran Gawas) and Current Study (Hamidreza Karami)
6 Entrainment Rate W C i Th Ph Fl frac34Water Continuous Three Phase Flow
frac34Results Obtained for 2 Gas Rates (17 and 19 ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Wave Characteristics
h0 = 17802(V) - 16739
30
35
40
45
mm
)
Fluid Flow Projects Advisory Board Meeting April 17 2013
h0 = 17636(V) - 34508
0
5
10
15
20
25
30
1 15 2 25 3 35 4
Fil
m T
hic
knes
s (m
Voltage (V)
Static Calibration
Dynamic Calibration
49
11
06
07
08
09
1
VV
max
[]
Vsg 145 m s Vsl 0 01 m s WC 0
VV
ma
x [
]
0 02 04 06 08 1 12 14 16 18 204
05
t [s]
t [s]
Wave Characteristics hellip
11
-
= = =
06
07
08
09
1
-
Vsg = 145 ms Vsl = 001 ms WC = 0
VV
max
Fluid Flow Projects Advisory Board Meeting April 17 2013
0 02 04 06 08 1 12 14 16 18 204
05
t (s)
Wave Characteristics hellip
6 Wave Celerity Cross-Correlation
rela
tion
coe
ffic
ient
Fluid Flow Projects Advisory Board Meeting April 17 2013
Δt C = Δ xΔt
Time Lag (ms)
Cro
ss-c
orr
50
ρ V FrρG mamp L L SL SLX = = = ρ mamp ρ V FV FrL G G SG SG
Wave Characteristics hellip
Author (Year)
Test Fluids Pipe
Diameter
Liquid Viscosity
(Pas)
Liquid Surface Tension (Nm)
Superficial Gas Velocity
Range
Superficial Liquid Velocity Range
Andritsos (1986)
Air -Water 00508 00953
0001 - 008 0072 6 - 19 ms 001 - 006
ms
Paras (1991 1994)
Air -Water 00508 0001 0072 10 - 66 ms 002 - 02 ms
Mantilla (2008)
Ai W tAir -Water 0 0508 0 152 00508 0152 0001 -00071
0 072 0 035 0072 - 0035 5 80 5 - 80 ms 00035 - 01
ms Magrini (2009)
Air -Water 0076 0001 0072 40 - 80 ms 00035 - 004
ms Mantilla (2012)
Air -Water 00508 0001 0072 5 - 20 ms 0001 - 001
ms Johnson (2005)
SF6 - Water 01 0001 0072 05 - 45 ms 01 - 1 ms
Current Study Air-Oil 0152 000135 0024 0005 - 002
ms 10 - 20 ms
Fluid Flow Projects Advisory Board Meeting April 17 2013
Wave Characteristics hellip
10000 Andritsos et al (1992)
Paras et al (1991)
Mantilla (2008) - D = 00508 m
100
1000
CvSL
( )
Current Study
Johnson (2005)
Mantilla (2008) - Surface Tension = 0035 Nm
Mantilla (2008) - Viscosity = 71 cP
Mantilla et al (2012)
Al Sarkhi et al (2011)
Proposed Correlation
Fluid Flow Projects Advisory Board Meeting April 17 2013
1
10
00001 0001 001 01 1X
51
Wave Characteristics hellip
6 Non-linear Roll-wave Solution (Dressler 1949 W t 1989)1949 Watson 1989)
β
Fluid Flow Projects Advisory Board Meeting April 17 2013
Wave Characteristics hellip
6 Non-linear Roll-wave Solution (Dressler 1949 W t 1989)1949 Watson 1989)
Disturbance Waves
Disturbance Waves
Fluid Flow Projects Advisory Board Meeting April 17 2013
52
Wave Characteristics hellip
1000
(CVsl)model
10
100
CvSL
(CVsl)model
Correlation
Fluid Flow Projects Advisory Board Meeting April 17 2013
1
00001 0001 001 01 1X
Thick film ndash Transition to slug flow
Wave Characteristics hellip
6 Wave Frequency frac34 Power Spectrum frac34 Power Spectrum
frac34 Physical Counting of Waves ndash Mean plusmn σ
er
Fluid Flow Projects Advisory Board Meeting April 17 2013 f (Hz)
Pow
e
53
54
Wave Characteristics hellip
St
6 Wave Frequency (St=fDvsl) 10000
1000
100
10 Paras et al (1991 1994) Johnson et al (2005) Magrini (2008) Magrini (2008) Mantilla (2008) - 0152 m Mantilla (2008) - 00508 m Mantilla (2008) - ST = 035 Nm Mantilla (2008) - Viscosity = 71 cP
1
01 Mantilla et al (2012) Current Al Sarkhi et al (2011)
001
00001 0001 001 X
01 1
Fluid Flow Projects Advisory Board Meeting April 17 2013
Wave Characteristics hellip
6 Wave Amplitude hellip Δhw = 2 2σ
1 Andritsos (1992) Paras et al (1991)Paras et al (1994) Magrini (2008) Mantilla (2008) - D = 0152 m Mantilla (2008) - D = 00508 m Mantilla (2008) - ST = 0035 Nm Mantilla (2008) - Viscosity = 71 cP Johnson (2005) 01
ΔhwD
001
00001
00001 0001 001 01 1 h0D
Fluid Flow Projects Advisory Board Meeting April 17 2013
0001
55
Δh
wD
Δ
hwD
Wave Characteristics hellip
03 Paras et al (1991) Paras et al (1994) Paras et al (1994) Magrini (2008) Mantilla (2008) - D = 0152 m Mantilla (2008) - D = 00508 m
025
Mantilla (2008) - ST = 0035 Nm Mantilla (2008) - Viscosity = 71 cP Correlation
02
015
01 )071 ΔhW DD = 067(h 0 DΔh = 0 67(h D) 005
0
0 005 01 015 02 025 h0D
Fluid Flow Projects Advisory Board Meeting April 17 2013
Wave Characteristics hellip
06
05
)053ΔhW D = 058(X 04
03 Paras et al (1992 1994)
Mantilla (2008)02
Mantilla (2008) 0 0508 m Mantilla (2008) - 00508 m
Manitlla (2008) - ST = 0035 Nm 01
Mantilla (2008) - Viscosity = 71 cP
Correlation
0
0 01 02 03 04 05 06 07 08
X
Fluid Flow Projects Advisory Board Meeting April 17 2013
Wave Characteristics hellip
6 Capacitance Probe for Measurement of WWave ChCh aracteriistics iin Air-oil T il Two-phaset ti Ai h Flow
6 Wave Celerity Wave Amplitude Wave Frequency Correlated with X
6 Correlation Compared for Air-water Data S t A il bl i Lit tSet Available in Literature
6 Comparison with Mechanistic Model for Roll-waves Proposed by Watson (1989)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Entrainment Rate Results hellip
6 Oil Entrainment Rate Vsg=168 ms
Fluid Flow Projects Advisory Board Meeting April 17 2013
56
Entrainment Rate Results hellip
6 Oil Entrainment Rate Vsl= 1 cms
Fluid Flow Projects Advisory Board Meeting April 17 2013
Entrainment Rate Results hellip
6 Water Entrainment Rate Vsg=188 ms
Fluid Flow Projects Advisory Board Meeting April 17 2013
57
Entrainment Rate Results hellip
6 Water Entrainment Rate Vsl = 2 cms
Fluid Flow Projects Advisory Board Meeting April 17 2013
Entrainment Rate Results hellip
6 Water Ratio in Entrained Droplets Vsl =1 cms
Fluid Flow Projects Advisory Board Meeting April 17 2013
58
Entrainment Rate Results hellip
6 Water Ratio in Entrained Droplets Vsl =2 cms
Fluid Flow Projects Advisory Board Meeting April 17 2013
Near Future Activities
6 Literature Review (Ongoing)
6 Modeling Efforts (Starting at Summer 2013)
6 Holdup Measurements (Spring 2013)
6 Wave Characteristics Measurements (Summer 2013)
6 Expperiments with Glyycol ((Fall 2013))
Fluid Flow Projects Advisory Board Meeting April 17 2013
59
Research Schedule
Activity 2011 2012 2013 2014
O N D J F M A M J J A S O N D J F M A M J J A S O N D J F M A M J J A S O N D
Literature Review
Facility Training
Facility Preparation
Test Matrix
Main Tests
Additional Tests
Data Analysis
Modeling Study
PhD Proposal
Dissertation Preparing
Defense
Fluid Flow Projects Advisory Board Meeting April 17 2013
Questions and Comments
Fluid Flow Projects Advisory Board Meeting April 17 2013
60
Three-Phase Low Liquid Loading Flow and Effects of MEG on Flow Behavior
Hamidreza Karami Mirazizi
Project Completion Dates Literature Review Ongoing PhD Proposal Defense October 2013 Data Acquisition January 2014 Data Analysis February 2014 Model Comparison and Development October 2014
Objectives The objectives of this study are Acquire flow pattern holdup wave
characteristics and entrainment data using a 6ndash in ID pipe with and without mono-ethylene glycol MEG under different flow conditions
Benchmark existing models document discrepancies
Propose improvements if needed
Introduction One of the most common phenomena in wet gas pipelines is the low liquid loading three-phase flow of gas-oil and water Presence of these liquids in the pipeline although in very small amounts can influence different flow characteristics such as pressure distribution
Mono-ethylene glycol (MEG) is used continuously in deep water gas production systems as a hydrate inhibitor It is injected at the subsea tree upstream of the choke Some work has been done at The University of Tulsa Hydrates Flow Performance and Southwest Research Institute on settling and effectiveness of MEG injection under quiescent conditions However MEG mixing in multiphase flow and its effect on flow parameters such as liquid holdup flow pattern pressure gradient and entrainment rate are not well understood
Considering the significance of liquid inventory and hydrate management on these large gas tie-backs there is a need to generate datasets for open literature that can be used by model developers
In this study experiments are conducted in a 6 in ID flow loop The targeted flow characteristics are the entrainment rate liquid holdup wave characteristics and droplet size distribution Adopting Gawas (2013) test matrix tests are conducted firstly without Glycol and then repeated by adding MEG to the aqueous phase New experimental data considering MEG effect in multiphase flow behavior will increase the efficacy of production management systems
Experimental Facility The flow loop consists of two parallel sections with 6 in (015 m) ID pipes Each section is 564 m long Acrylic visualization sections about 8 m long are provided at the end of each section The inclination angle can change from 0deg horizontal case to plusmn2deg in inclined case
IsoPar-L which poses similar properties as wet gas pipelines (low viscosity and specific gravity) is selected as the oil phase The oil density viscosity and surface tension at standard conditions are 760 kgm3 00013 Pamiddots and 0024 Nm respectively In addition tap water and mono ethylene glycol are forming the aqueous phase and air is flowing into the test section as the gas phase through two different compressors
Aqueous phase properties are function of MEG concentration The phase density increases slightly with the increase in MEG concentration However the change in viscosity is more drastic and makes the viscosity of the denser phase (aqueous) larger than the oil phase This may result in different flow characteristics such as the droplet entrainment rate A portable densitometer Densito 30PX will be used to confirm glycol concentration in the aqueous phase during the tests The instrument can measure the density of the aqueous mixture and temperature in an easy and fast manner For this purpose the mixture density for different temperature values and different glycol concentrations was measured and recorded in a calibration plot This plot will be used every day to back estimate the glycol concentration in the tank
Gas flow rate is measured using the micro motion flow meter CMF300 while CMF100 and CMF050 are used to measure oil and water flow rates An isokinetic sampling system is used to determine droplet flux entrained in the gas phase The system consists of an isokinetic probe a separator and air flow meter It can be traversed vertically across the pipe cross section and entrainment rate at different positions can be recorded Two isokinetic systems one foot apart are used to increase measurement speed Vertical
61
sampling positions include 9 different spots ranging from 1 in away from the bottom to the top of the section
Five quick-closing valves (QCV) are used to bypass the flow and at the same time trap the liquid in the test sections The reaction time of the QCV is less than 1 second The liquid trapped in the QCV is pigged out with a specially designed pigging system and is drained into graduated cylinders to measure the oil and water volumes The system is installed in the testing section with a launching position and a receiving position at each end of the QCV section An air line with a maximum pressure of 25 psig and adjustable air flow rate is used to push the pig through The pigging efficiency tests will be carried out to determine the uncertainties
New capacitance system including multiple insulated capacitance probes around the pipe periphery will be used to measure wave characteristics Film thickness wave length celerity frequency and amplitude will be reported for all experimental conditions These probes are in the design phase
Preliminary Experimental Results Preliminary results in entrainment rate and wave characteristics are presented in this section
Wave Characteristics Analysis This work was conducted as a common effort between previous project (Gawas 2013) and this study Pairs of capacitance probes set about 4 inches apart were used to analyze wave characteristics in oilair two-phase flow Static and dynamic calibration of the probes was conducted prior to main experiments Wave characteristics for horizontal downward (-2deg) and upward (+2deg) flow were determined from the capacitance sensorrsquos time series The voltage signal from the capacitance probe is measured at 200 Hz for 10 ndash 20 seconds The signal was filtered by using a low-pass filter with cutoff frequency of 25 Hz
Wave celerity is calculated using cross-correlation between signals recorded simultaneously by the two capacitance probes placed a known distance apart Based on the experimental results wave celerity seems to increase almost linearly with gas velocity and it also increases slightly with liquid velocity Al-Sarkhi et al (2011) found that entrainment fraction and wave celerity were strong functions of the modified Lockhart-Martinelli parameter X or the Froude number ratio based on the superficial liquid and gas velocities and pipe inclination angle Therefore X can be used to correlate wave celerity for separated flow patterns (stratified and annular flows) The correlation
developed by Al-Sarkhi et al (2011) was compared with a set of experimental results for wave celerity including works of several different authors Although the correlation gives good agreement over a wide range of flow conditions it over-predicts for low X values and under-predicts for higher values of X X is ratio of only inertial forces between liquid and gas phase For thinner liquid films wall effect would also be a contributing factor which is not accounted for in X Two distinct trends of CvSL
with X were observed and a new correlation was proposed based on X
A mathematical model for roll wave in two-phase flow pipelines has been proposed by Watson (1989) He assumes that any disturbance wave travels at the same constant velocity (C) which is determined as part of the solution He suggested a solution procedure through non-linear analysis of governing transient momentum equations and used the conclusion from Dressler who had shown that a continuous solution for this system is not possible Thus we can assume that a continuous solution is obtained by fitting together piecewise continuous solutions The model shows a fair performance with the experimental data An under-prediction is observed for downward inclined pipes while it tends to over-predict in upward inclined flow Discrepancy can be attributed to two sources the constant friction factor assumption and the liquid entrainment which has been neglected in the Watson (1989) formulation Wave celerity data using the model were compared with correlation It can be seen that wave celerity predicted by the model also tends to follow similar trend as by the correlation with respect to X
Frequency of interfacial waves can be determined by window crossing method (actual counting of waves) or using power spectrum of the time series signal In the case of power spectrum the frequency of the wave is equal to the value of the most dominant frequency For counting of wave frequency standard deviation of the time trace is considered as the threshold Signal above the threshold is considered as crest of the wave while signal below this threshold is counted as trough of the wave In the subsequent analysis the frequency obtained by window crossing technique is used
Azzopardi et al (2008) suggested using the Strouhal number to correlate wave frequency with X where Strouhal Number is defined as St=fDvSL The variation of Strouhal number with X for different experimental conditions was analyzed and compared to the correlation developed by Al-Sarkhi et al (2011) There is considerable uncertainty associated with measurement of wave frequency Different methods have been used by different
62
authors for determination of wave frequency from wave signal data
Different methods have been used for the determination of wave amplitude For the experimental conditions used in the current study the wave amplitude was found to be almost independent of the superficial liquid velocity and was found to increase with an increase in gas velocity Moreover the effect of inclination on wave amplitude was found to be negligible
Wave amplitude is a strong function of the film thickness When normalized wave amplitude is plotted against normalized measured film thickness two distinct behaviors can be observed For the higher gas velocities in stratified-atomization and annular flow region where the gas-liquid interface is dominated by large disturbance waves a linear trend is observed However considerable deviation is observed for the experiments restricted to lower gas and higher liquid flow rates with long 2D waves at the gas-liquid interface Neglecting these data points a correlation was developed to predict the normalized wave amplitude by means of the normalized film thickness For cases in which disturbance waves exist (stratified-atomization and annular flow) a correlation was also developed predicting the wave amplitude normalized by pipe diameter with respect to X A fairly good match was observed with the experimental data
Entrainment Rate The entrainment rate measurements were conducted with isokinetic probes from January to April 2013 The measurements are obtained for water cuts of 60 80 and 100 (not included in Gawas 2013 study) and superficial gas velocities of 17 19 21 23 ms These data can be used along with data from Gawas (2013) for water cuts of 40 and less to analyze the effects of different parameters on the entrainment behavior of oil and water droplets
After initial analysis of the tests conducted with vsg of 17 and 19 ms it can be observed that both vsl
and vsg have direct influence on the entrainment rate The highest entrainment rate of water at a fixed
value of vsl was observed at water cut of 80 where apparently there is still a continuous oil phase at the surface dragging water droplets and increasing the entrainment rate The ratio of water entrainment rate to the total value is very low even for the case of 80 water cut and has a peak value of about 042 for vsg=19 ms vsl=2 cms and WC=80
Future Work First phase of the experiments are conducted without glycol and over similar test matrix as in Gawas (2013) This includes low liquid loading three-phase experiments Four independent variables are considered for the test matrix namely liquid and gas superficial velocities inclination angle and water cut Primarily all the experiments will be conducted in horizontal conditions Two different superficial liquid velocities (1 and 2 cms) five superficial gas velocities (15 17 19 21 and 23 ms) and six different water cuts (10 20 40 60 80 and 100) are going to be considered
After completion of entrainment rate measurements from May to July 2013 liquid holdup measurements will be taken by QCVs and pigging system The measurements will be obtained for the whole test matrix with water cuts ranging from 0 to 100
Finally the newly acquired insulated capacitance probes will be utilized to measure the wave characteristics These measurements are initially targeted for waterair experiments and they will be used later with glycol in the aqueous phase This will help estimate the effects of change in viscosity of the liquid phase via glycol in wave characteristics In addition capacitance probe measurements will be tried for 3-phase oilwaterair flow experiments
After completion of all the tests without glycol the next phase of experiments is going to be conducted from September 2013 to January 2014 At this stage different concentrations of glycol will be added to the aqueous phase and the same test matrix will be completed only in the presence of glycol All the tests are conducted under steady state conditions
References Al Sarkhi A Sarica C and Magrini K ldquoInclination Effects on Wave Characteristics in Annular Gas-liquid
Flowsrdquo AIChE J 58 1018-1029 2011 Azzopardi B J ldquoGas-Liquid Flowsrdquo New York Begell House Inc 2006 Dong H-K ldquoLow Liquid Loading Gas-Oil-Water Flow in Horizontal Pipesrdquo MS Thesis U Tulsa Tulsa OK
2007 Gawas K ldquoLow Liquid Loading in Gas-Oil-Water Pipe Flowrdquo PhD Dissertation The University of Tulsa 2013 Watson M ldquoWavy Stratified Flow and the Transition to Slug Flowrdquo Multi-Phase Flow Proceedings of the 4th
International Conference BHRA 1989 Bedford UK pp 495ndash512
63
64
Fluid Flow Projects
Update on 6 in ID High Pressure Facility Activities
Duc Vuong
Advisory Board Meeting April 17 2013
Outline
Objectives
Facility
Instrumentation Basic
Special
Single Phase Tests
Two Phase Tests
Future Work
Fluid Flow Projects Advisory Board Meeting April 17 2013
65
Objectives
Scale-up of Small Diameter and Low Pressure Results to the Large Diameter and High Pressure Conditions
Fluid Flow Projects Advisory Board Meeting April 17 2013
Facility
Test section need special instruments for flow characteristic measurements
= Not available
Fluid Flow Projects Advisory Board Meeting April 17 2013
66
Facility hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Facility hellip
67
Fluid Flow Projects Advisory Board Meeting April 17 2013
Facility hellip
Basic Instrumentation
Fluid Flow Projects Advisory Board Meeting April 17 2013
68
Special Instrumentation
Canty Tubular System
Holdup Measurement QCVs
Wire Mesh Sensor
Iso-kinetic Sampling
Fluid Flow Projects Advisory Board Meeting April 17 2013
Canty Tubular System
High Speed Camera
Still Picture Camera
Light
Fluid Flow Projects Advisory Board Meeting April 17 2013
69
Canty Tubular System hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
High Speed Camera
Still Picture Camera
Lights
Fluid Flow Projects Advisory Board Meeting April 17 2013
Canty Tubular System hellip
70
Holdup Measurement QCVs
Calibration Methodology is Currently Under Development
భభ మ ൌ యሺభାሻ
PT1
PT2TT2
TT1
Nitrogen
QCV QCV
V1
V2
భ మ య+
ଶെ ொ ൌ ݑݍܮ ܪݑ
ொx100
Fluid Flow Projects Advisory Board Meeting April 17 2013
Capacitance Sensors
Wire Mesh Sensor Ordered from HDZR Pressure Rated up to over 1000 psi Plans to Evaluate the System on Fall 2013 Wave Characterization
Fluid Flow Projects Advisory Board Meeting April 17 2013
71
Fluid Flow Projects Advisory Board Meeting April 17 2013
Iso-kinetic Sampling
Flow
Gas Control Valve 1
2
4
Liquid Flow Meter
3
Collecting Flask
Supporting block
Swivel Joint
Gas Flow Meter
Multiple Probe Design Will be Constructed and Tested in Fall 2013
Single Phase Tests
Estimate Pipe Roughness
Instrument Validation
Fluid Flow Projects Advisory Board Meeting April 17 2013
72
Two Phase Tests
Test matrices Fan (2005) Future Study v (ms)sg 75 - 21 75 - 21 vso (ms) 0005-005 0005-005
Angle -2o 0o 2o Horizontal Pressure (psi) Atmospheric pressure 2 Pressure
NOTE upper and lower limit will depend on facility limitations
Fluid Flow Projects Advisory Board Meeting April 17 2013
Future Work
Completion Dates HAZOP Modifications Completed
Basic Instrumentation Completed
Gas single phase test May 2013
Holdup Measurement System June 2013
Wire Mesh Sensor Sept 2013
Preliminary Testing Oct 2013
Iso-kinetic Sampling Nov 2013
Two-phase flow tests Nov 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
73
Fluid Flow Projects Advisory Board Meeting April 17 2013
QuestionsComments
74
Update on 6rdquo High Pressure Facility Activities Duc Vuong
Project Completion Dates HAZOP modification Completed Basic Instrumentations Completed Special Instrumentations May - Nov 2013 Preliminary Test September 2013
Objective The main objective of TUFFP in utilization of the 6 in ID high pressure facility is to conduct up-scaling studies of multiphase flow in pipes The first study to be conducted in this facility is the investigation of pressure up-scaling of two-phase gas-liquid flow under low liquid loading conditions
Introduction Gas-liquid pipe flow characteristics such as flow patterns pressure drop and liquid holdup have been mostly investigated with small diameter pipes (2 or 3 in) and low pressure conditions (lower than 100 psig) Two-phase flow behavior at high pressure and large pipe diameters may differ from that of at low pressure and small pipe diameters Thus validation and improvement for high pressure conditions is required
TUFFP has been constructing a new high pressure and large pipe diameter facility Experimental results from this facility will be used to evaluate and improve the available models and correlation
This report presents the progress made in construction of the facility since the last Advisory Board meeting as well as the plans for the first experimental study in this facility
Facility Description The facility is designed for gas-oil-water three-phase flow Mineral oil (Isopar L) and distilled water are the liquid phases The facility is designed to operate with either natural gas (provided by Oklahoma Natural Gas) or nitrogen Initially nitrogen is planned to be used due to its relatively low safety risk Later the gas phase will be switched to natural gas This requires the modification of the existing north campus flare system to accommodate the larger gas volumes of the new facility This will be addressed when natural gas is considered as the gas phase Several quick closing valves will be used to isolate the sections of the facility in case of an emergency or leakage in some part of the flow loop
The facility is composed of gas oil and water systems separation systems and the test section In gas water and oil systems two progressive cavity
pumps and a turbine compressor boost the pressure of the single phases which flows through the metering system before they mix at the inlet of the flow loop After flowing through the test section the fluid mixture is separated through the separation system and the phases are returned to corresponding vessels
The stainless steel Schedule 40 test section has a length of 523 ft and internal diameter of 6-in The last section can be inclined 3deg downward For upward flow studies the direction of the flow will be reversed Thus the fluid can circulate clockwise and counter-clockwise
The inclinable section length is 279 ft (558xD) In the counter-clockwise direction the developing region is 410xD the test section is 52xD long followed by a 65xD long section before the first sharp bend In the clockwise direction the developing region is 351xD the test section 52xD followed by a 74xD long section before the first bend These distances are expected to facilitate fully developed flow at the test section
The maximum operating pressure is 500 psi The loop operates at ambient temperature The compressor nominal flow rate discharge and suction pressures are 18 MMSCFD 500 psig and 400 psig respectively The pumps are able to deliver 200 GPM with the same discharge and suction pressures (500 psig and 400 psig) Temperature and pressure transducers are installed to operate under the given conditions Coriollis flow meters are used for gas and liquid flow rate measurements
Currently the facility is completed for the oil and gas systems as well as the separation systems The test section needs instrumentations for characteristic studies of the flow in order to conduct liquid-gas two-phase experiments A water system will be added later for three-phase flow studies
Specialty Instrumentation This facility was initially designed for low-liquid loading studies Special instrumentation required to analyze the multiphase flow behavior under these conditions is presented in this section
75
Quick Closing Valves Two quick closing valves are used to trap the gas and liquid flows to measure the average holdup For low liquid loading flows in comparison to the size of the section the liquid inventory is small Thus calculation of the gas-liquid ratio by draining the liquid may result in great uncertainty Therefore the measurement technique used by Kora (2010) is suggested for this application This approach is based on equalizing pressure with a known reservoir When the sample is trapped the pressure and temperature of the section is recorded A valve connected to a nitrogen recipient (with known volume pressure and temperature) is opened The gas-liquid ratio is obtained by measuring the final pressure and temperature and comparing it with a calibration curve For three-phase flow a two-wire capacitance will be utilized to measure the oil-water interface and the oil-water fractions will be calculated from geometrical relationships This system requires prior calibration and verification to ensure low uncertainty in the gas-liquid ratio measurements
Visual Observation A custom-made visualization system with no disturbance to the flow was designed and constructed by JMCanty Company An acrylic section is fused with two steel pipe pieces A chamber surrounds the acrylic section and is welded to the steel pipe pieces The chamber is pressurized keeping the stress over the acrylic section below a critical value Lights and cameras are located around the circumference of the pipe The two light sources (HYL 250 Watt) are located at a 90deg angle from each other A JMCanty still picture process camera is located at 90deg from the lights The system is equipped with a side window located at 90deg from the camera where the high-speed video system (Ultima 120kc) can be connected
Capacitance Sensor Wire mesh sensor is proposed to measure wave characteristics and phase distribution in the cross-sectional area
The wire mesh sensor consists of a grid of wire electrodes stretched across a flow cross section For a wire mesh sensor operated in a pipe the wire grid is mounted on a pressure-tight circular frame which is inserted between two flanges Typical wire separation is 23 mm in-plane and 15 mm between planes Fast electronics interrogate the electrical properties of the medium in the cross section at all wire crossings Electrical conductivity or relative electrical permittivity can be measured Both of these are phase indicators for multiphase flow The sensor securely discriminates gas from oil gas from water and oil from water
Wire mesh sensors have been successfully employed in pipe flows especially fast flows between 1 and 10 ms mixture velocity They are well suited to discriminate liquids from gases and liquids with different electrical permittivity Operating two consecutively placed sensors can be useful to measure phase velocities
Isokinetic Sampling The droplet entrainment can be measured using the isokinetic probe The isokinetic condition can be reached by controlling the gas flow rate using a control valve mounted at the gas outlet Isokinetic sampling nozzles from Jones Inc have a pressure rating up to 5000 psig and temperature up to 1200 degF No traverse mechanism to change the position of the sampling point is considered For safety and time concerns four sampling nozzles will be welded at different heights in the pipe The sampling station will be mounted between two stainless high pressure swivel joints By rotating the sampling section most of the cross-sectional area can be covered ensureing more accurate entrainment data
A high efficiency separator is needed a stainless steel high pressure filter (Walker Filtration) is proposed A gas flow meter is required to assure the isokinetic conditions The liquid can be collected in a bottle The liquid flow rate at a given position is determined by measuring the collecting time
Experimental Program Single Phase Tests Gas single-phase tests are necessary to estimate the pipe roughness It is crucial to perform the gas single-phase tests before the pipe is wetted by experimental oil
Oil single-phase tests will be conducted after all instrumentations are ready for the preliminary tests The results are used to reconfirm the DP measurement and oil viscosity and density
Two Phase Tests Fan (2005) conducted an experimental study on low liquid loading gas-liquid two-phase flow in the 6-in flow loop at low pressure conditions The superficial gas velocity ranged from 75 to 21 ms the superficial liquid velocity ranged from 0005 to 005 ms
In order to study the effect of high pressure and large scale pipe diameter on low liquid loading gas-liquid two-phase horizontal flow the same sets of gas and liquid superficial velocities as Fan (2005) are proposed The tests will be conducted at three different system pressure conditions specifically 300 400 and 500 psi
76
Future Work Basic instrumentations and HOZOP modification were completed in spring 2013 Installation and calibration of special instrumentations will be carried
References
out through May to September 2013 and preliminary tests are expected by October 2013 Two-phase tests are anticipated to start by November 2013 after the installation of the isokinetic sampling system
Kora C Effects of High Oil Viscosity on Slug Liquid Holdup in Horizontal Pipes Master Thesis The University of Tulsa 2010
Fan Y An Investigation of Low Liquid Loading Gas- Liquid Stratified Flow in Near-Horizontal Pipes PhD Dissertation The University of Tulsa 2005
77
78
Fluid Flow Projects
Modeling of Hydrodynamics of Gas-Liquid Pipe Flow using
Energy Minimization Concept
Lee H Al-Sarkhi A Pereyra E Sarica C
Advisory Board Meeting April 17 2013
Outline
Objectives
Introduction
Modeling
Model Validation
Future Tasks
Fluid Flow Projects Advisory Board Meeting April 17 2013
79
Objective
Develop a Stratified Gas-liquid Flow Model Using Energy Minimization Concept
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction
Theorem of Minimum Entropy Production (Prigogine 1961)
Stationary Non-Equilibrium State
System not in Thermodynamic Equilibrium (Entropy Production Different than Zero)
System Settles Down to the State of ldquoLeast Dissipationrdquo
Fluid Flow Projects Advisory Board Meeting April 17 2013
80
Introduction hellip
Quemada (1977)
Rheological Model for a Dispersed System Using the Minimum Energy Dissipation Principle
All Entropy Production Comes from Viscous Dissipation
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction hellip
Xu and Li (1998) and Liu et al (2001)
Multi Scale Minimum Energy Consumption Model in Two Phase Gas-solid Two Phase Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
81
Introduction hellip
Taitel et al (2003)
Infinite Steady State Solutions Splitting Ratios
One Seen in Practice Corresponds to Minimum Pressure Drop
Dabirian (2012)
Applied Minimum Energy Dissipation to Predict Splitting Ratio in Parallel Pipelines
Fair Agreement with Experimental Results
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction hellip
Rinaldo et al (1998)
Explained the Organization of River Networks as ldquoLeast Energy Structuresrdquo
Fluid Flow Projects Advisory Board Meeting April 17 2013
82
Introduction hellip
Yang and Song (1998)
Alluvial Channels Adjust Its Velocity Slope Depth and Roughness in Such Manner That Minimum Energy is Used to Transport the Water and Sediments
Fluid Flow Projects Advisory Board Meeting April 17 2013
Modeling
Energy Dissipated Two-Fluid Model
dPE v A D L L dx
dP v A G G dxL
G Assuming Same Pressure Drop for Both
Phases dP
ED AP vSG vSL dx
Minimum Energy Correspond to The Minimum Pressure Drop
Fluid Flow Projects Advisory Board Meeting April 17 2013
83
Modeling hellip
Gas and Liquid Momentum Equation dp
A S S 0G WG G i idx
dp A S S 0L WL L i idx
Adding the Two Equations
dp 1 S SG WL L WGdx AP
Fluid Flow Projects Advisory Board Meeting April 17 2013
Modeling hellip
Liquid Level of the System Satisfies the Minimum Dissipated Rate as Follows
dp d 1 dx d AP WL SL WG SG 0d h d hL L
Wall Shear Stress and Geometrical Relationships are Calculated Similarly to Taitel and Dukler (1976)
Fluid Flow Projects Advisory Board Meeting April 17 2013
84
Model Validation
1000000 Energy Minimum Point
D 00254m100000 1000 kg m3
L
G 118kg m3
(Pa
m) 10000
L 00001Pa s
1000
dL
G 00000184Pa s
vSL 0017m
dP
s
100 vSG 245m s
10
1 0 02 04 06 08 1
hLD (-)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Validation hellip
Andritsos (1986) Pressure Gradient Experimental Data for Stratified-smooth Flow
0
20
40
60
80
0 20 40 60 80
dP
dL
Pre
dic
tio
n (
Pa
m)
dPdL Experimental (Pam)
Energy Minimization Model TUFFP Unified Model STR TUFFP Unified Model INT
85
Model Validationhellip
Andritsos (1986) Pressure Gradient Experimental Data for Stratified-wavy Flow
200
dP
dL
Pre
dic
tio
n (
Pa
m)
160
120
80
40
0
Energy Minimization Model TUTU
FFP Unified MFFP Unified M
odel STR odel INT
0 40 80 120 160 200 dPdL Experimental (Pam)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Validation hellip
Andritsos (1986) Holdup Experimental Data for Stratified-smooth Flow
07
06
Pre
dic
tio
n (
-)
05
04
03
L 02
H
Energy Minimization Model 01 TUFFP Unified Model STR
TUFFP Unified Model INT 0
0 01 02 03 04 05 06 07 HL Experimental (-)
Fluid Flow Projects Advisory Board Meeting April 17 2013
86
Model Validation hellip
Anditsos (1986) Holdup Experimental Data for Stratified-wavy Flow
HL
Pre
dic
tio
n (
-)
08
06
04
02
0
Energy MiniTUFFP UnifTUFFP Unif
mization Model ied Model STR ied Model INT
0 02 04 06 08 HL Experimental (-)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Conclusions
New Stratified Model Using the Minimum Entropy Production Approach is Proposed in This Study
New Model does not Need Interfacial Friction Factor Closure Relationship
Friction is Assumed to Be the Only Source of Entropy Production
The Model is Validated Against Experimental Data of Andritsos (1986)
Fluid Flow Projects Advisory Board Meeting April 17 2013
87
Future Work
Apply Dissipated Energy Minimization Approach to Different Flow Patterns Identify Energy Equation
Identify Constrains
Combine All Flow Pattern Model to Propose a New Unified Model Based on Energy Minimization
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Questions
88
Modeling of Hydrodynamics of Gas-Liquid Pipe Flow using Energy Minimization Concept
Lee H Al-Sarkhi A Pereyra E Sarica C
Project Completion Dates Literature Review Completed Model Development Completed
Model Validation Completed Report Completed
Objective The main objective of this study is to develop a novel stratified gas-liquid flow model using energy minimization concept
Introduction Two-phase gas-liquid flow in pipes is encountered in many industries particularly in petroleum production Accurate predictions of gas-liquid flow characteristics such as flow patterns liquid holdup gas void fraction and pressure gradient are important in engineering applications A large number of experimental and theoretical gas-liquid flow investigations have been conducted However the physics of the phenomena have not been completely understood and existing models are usually quite complex Gas-liquid pipe flow has been studied since the 1970s Predictive models have evolved over several decades from empirical correlations to comprehensive mechanistic models and finally to unified mechanistic models Taitel and Dukler (1976) constructed a traditional model for stratified flow in horizontal and slightly inclined pipes based on equilibrium stratified flow Barnea (1987) developed a unified model for all inclination angles Xiao (1990) developed a comprehensive mechanistic model for near-horizontal pipes Gomez (2000) proposed a unified mechanistic model for all inclination angles Zhang et al (2003) developed a unified mechanistic model based on slug dynamics Unified models are applicable for all inclination angles and flow patterns In general these widely used models consider mass and momentum equations which require auxiliary relationships to fully close the models
Only a few attempts have been made to include energy equations in the available mechanistic models Brauner et al (1996) predicted interface curvature in stratified two-phase system considering potential and surface energy Chakrabarti et al (2005) developed a liquid-liquid horizontal flow model for segregate flow patterns using the minimum energy concept and combined momentum equation This model predicts pressure gradients for stratified smooth (SS) and
stratified wavy (SW) flow patterns The model prediction was validated with their own kerosene-water experimental results and Lovick amp Angeli (2004) data Sharma et al (2011) developed a comprehensive model for the oil-water two-phase flow using energy minimization concept Trallero et al (1997) described a model that predicts all flow patterns very well as well as liquid holdup and pressure gradient The model calculates total energy for all flow patterns selecting the flow pattern corresponding to the minimum energy However energy minimization models listed above satisfied not only the energy minimization concept but also the combined momentum equation
Quemada (1977) proposed a rheological model for a dispersed system using the minimum energy dissipation principle The author considered that all entropy production came from viscous dissipation Xu and Li (1998) and Liu et al (2001) applied a multi-scale minimum energy consumption model to predict the heterogeneous structures in gas-solid two-phase flow Rinaldo et al (1998) employed thermodynamics to explain the organization of river networks as least energy structures Yang and Song (1985) postulated that alluvial channels accommodate its velocity slope depth and roughness in such a way that a minimum energy dissipation rate is spent to transport water and sediments The authors successfully applied this theory to laboratory and actual river data reporting a correlation coefficient between measured and calculated values of 0997
The gas-liquid stratified flow in a pipe can be considered as a dissipative process in an open non-equilibrium thermodynamic system Based on the minimum entropy production theorem (Prigogine and Nicolis 1977) the structure of gas-liquid stratified flow must be the one that minimizes the dissipated energy within a given control volume of a pipe The entropy production can be estimated by frictional pressure losses in the given control volume This study presents a novel modeling approach for gas-liquid stratified flow based on minimum entropy production The proposed model has been validated against the available models and experimental data
89
Based on the validation results it is concluded that the minimum entropy production concept can easily be applied in modeling of other multiphase flows in pipes
Taitel et al (2003) presented a study of gas-liquid flow in parallel pipes Their theoretical calculations showed that there are infinite steady state solutions to the splitting ratios but the observed one is the one that gives a minimum pressure drop Recently Dabirian (2012) successfully applied the minimum energy dissipation to predict the splitting ration in parallel pipelines The proposed model was compared with experimental data from a new facility equipped with compact separators to measure the splitting fraction
Modeling For single phase flow the energy dissipated in a pipe is given by the product between pipe cross-sectional area fluid velocity and pressure gradient Considering the two-fluid model the dissipated energy of two-phase pipe flow is given by addition of the single phase gas and liquid dissipated energy This approach neglects energy dissipated by the momentum transfer between the gas and the liquid Further inspection of the dissipated equation demonstrated that the minimum dissipated energy corresponds to the minimum pressure gradient in a pipe section
The addition of this new equation (minimum energy dissipation) allows the computation of the liquid level in stratified flow without the use of a closure relationship for the interfacial friction factor Gas and liquid momentum equations are combined canceling the interfacial shear stress providing the pressure gradient equation The liquid level which makes the pressure gradient minimum is the solution of the system Wall shear stress and geometrical relationships are calculated similarly to Taitel and Dukler (1976)
Model Validation The main objective of this model is to predict pressure gradient and liquid holdup in stratified flow Model predictions are compared with the experimental data from Andritsos (1986) which include 56 data points for stratified-smooth and 92 data points of stratified-wavy The average absolute error between Andritsos (1986) and the proposed model is 1994 for stratified smooth and 2843 for stratified wavy Energy minimization model overestimates the measured liquid holdup but follows the experimental data trend The reason for the larger discrepancy in holdup predictions can be related with a proper definition of the wall shear stresses (τWL τWG) or the efficiency of the energy transfer between the phases An extension of the methodology sugested by Vlachos (2003) to determine the shear stresses in stratified flow is recommended to improve the accuracy of the proposed model
Conclusions A new stratified model using the minimum entropy production approach is proposed in this study Friction is assumed to be the only source of entropy production Owing to the addition of a new equation (minimum energy) the interfacial friction factor closure relationship is not required in the new model The model is validated against the experimental data of Andritsos (1986) showing fair agreement
Future Work Minimum energy dissipation approach can be further applied to gas-liquid flow problems This approach can be applied to different flow patterns by identifying the energy equation and constrains Finally all flow pattern models can be combined to propose a new unified model base
References Andritsos N 1986 ldquoEffect of Pipe Diameter and Liquid Velocity on Horizontal Stratified Flowrdquo PhD Dissertation
Dept of Chem Engng U of Illinois Urbana Barnea D 1987 ldquoA Unified Model for Predicting Flow-Pattern Transitions for the Whole Range of Pipe
Inclinationsrdquo International J Multiphase Flow 13 pp1-12 Brauner N Rovinsky J and Moalem Maron D 1996 ldquoDetermination of the interface Curvature in Stratified
Two-Phase Systems by Energy Considerationsrdquo International Journal of Multiphase Flow 22(6) pp 1167-1185
Chakrabarti DP Das G and Ray S 2005 ldquoPressure Drop in Liquid-Liquid Two Phase Horizontal Flow Experiment and Predictionrdquo Chem Eng amp Tech 28 pp 1003-1009
Dabirian R 2012 ldquoPrediction of Two-Phase Flow Splitting in Looped Lines Based on Energy Minimizationrdquo MS Thesis U of Tulsa Tulsa OK
90
Gomez LE Shoham O and Schmidt Z 2000 ldquoUnified Mechanistic Model for Steady-State Two Phase Flow Horizontal to Vertical upward Flowrdquo SPE Journal 5(3) pp 339-350
Liu M Li J Kwauk M 2001 ldquoApplication of the Energy-Minimization Multi-Scale Method to GasndashLiquidndash Solid Fluidized Bedsrdquo Chemical Engineering Science 56(24) pp 6807-6812
Lovick P and Angeli P 2004 ldquoExperimental Studies on the Dual continuous Flow Pattern in Oil-Water Flowsrdquo International Journal of Multiphase Flow 30 pp 139-157
Prigogine I and Nicolis G 1977 Self-Organization in Non-Equilibrium Systems Wiley ISBN 0-471-02401-5 Quemada D 1977 ldquoRheology of Concentrated Disperse Systems and Minimum Energy Dissipation Principlerdquo
Rheologica Acta 16(1) pp 82-94 Rinaldo A Rodriguez-Iturbe I and Rigon R 1998 ldquoChannel Networksrdquo Annu Rev Earth Planet Sci 26 pp
289ndash327 Sharma A Al-Sarkhi A Sarica C and Zhang H Q 2011 ldquoModeling of Oil-Water Flow using Energy
Minimization Conceptrdquo International Journal of Multiphase Flow 37 pp 326-335 Taitel Y and Dukler A E 1976 ldquoA Model for Predicting Flow Regime Transitions in Horizontal and near
Horizontal Gas-Liquid Flowrdquo AIChE J 22 pp 47-55 Trallero JL Sarica C and Brill J 1997 ldquoA Study of OilWater Flow Patterns in Horizontal Pipesrdquo SPE
Production amp Facilities 12(3) pp 165-172 Xiao J J 1990 ldquoA Comprehensive Mechanistic Model for Two-Phase Flow in Pipelinesrdquo MS Thesis U of
Tulsa Tulsa OK Xu G and Li J 1998 ldquoAnalytical Solution of the Energy-Minimization Multi-Scale Model for GasndashSolid Two-
Phase Flowrdquo Chemical Engineering Science 53(7) pp 1349ndash1366 Zhang H-Q Wang Q Sarica C and Brill J P 2003 ldquoUnified Model for Gas-Liquid Pipe Flow via Slug
Dynamics ndash Part I Model Developmentrdquo ASME J Energy Res Tech 125(12) pp 266-273 Fan Y An Investigation of Low Liquid Loading Gas- Liquid Stratified Flow in Near-Horizontal Pipes PhD
Dissertation U of Tulsa 2005 Vlachos N 2003 Studies of Wavy Stratified and StratifiedAtomization Gas-Liquid Flowrdquo ASME J Energy Res
Tech 125(2) pp 131-137 Yang C and Song C 1985 Theory of Minimum Energy and Energy Dissipation Rate Encyclopedia of Fluid
Mechanics v 1 Chapter 11 Edited by Cheremisinoff Gulf Publishing Company Taitel Y Pustylnik L Tshuva M and Barnea D 2003 ldquoFlow Distribution of Gas and Liquid in Parallel Pipesrdquo
International Journal of Multiphase Flow 29 1193ndash1202
91
92
Fluid Flow Projects
Liquid Loading of Gas Wells with Deviations from 0deg to 45deg
Mujgan Guner
Advisory Board Meeting April 17 2013
Outline
Introduction
Experimental Program
Experimental Results
Model Comparison
Model Analysis
CFD Simulations
Conclusions
Fluid Flow Projects Advisory Board Meeting April 17 2013
93
Introduction
GAS
Decreasing Gas Flow Rate
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction
Liquid Loading Symptoms (Lea et al 2003)
Presence of Orifice Pressure Spikes
Erratic Production
Tubing Pressure Decreases as Casing Pressure Increases
Distinct Change in Pressure Gradient
Annular Heading
Liquid Production Ceases
Fluid Flow Projects Advisory Board Meeting April 17 2013
94
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Program
Test Section
Experimental Program hellip
Testing Fluids Air and Tap Water
Test Configuration 0deg 15deg 30deg and 45deg Deviation Angles
Experimental Parameters Pressure Temperature Pressure Gradient
Average Liquid Holdup Visual Observation with High Speed Camera and Surveillance Cameras
Fluid Flow Projects Advisory Board Meeting April 17 2013
95
Fluid Flow Projects Advisory Board Meeting April 17 2013
0001
001
01
1
10
1 10 100
v SL
(ms
)
vSG (ms)
Taitel Model
Barnea Model
Unified Model
Test Points Annular
Experimental Program hellip
Testing Range (Vertical)
Intermittent
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Results
Pressure Gradient and Flow Patterns Vertical
96
Experimental Results hellip
High Speed Videos vSL=001 ms Vertical
3000 P
ress
ure
Gra
die
nt (
Pa
m)
2500
2000
1500
1000
500
0
vSL
vSL =001 ms (No Film Reversal)
=001 ms (Film Reversal)
0 5 10 15 20 25 30 35 40
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Results hellip
Pressure Gradient Fluctuations vSL=01ms Vertical
Pre
ssu
re G
rad
ien
t (P
am
)
2500
2300
2100
1900
1700
1500
1300
1100
900
700
500
Slug Flow
Annular Flow
Annular Flow with Film Reversal
=367 ms
=1601 ms
=406 ms
vSG
vSG
vSG
00 05 10 15
Time (min)
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97
Liquid Holdup Vertical
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Experimental Results hellip
000
005
010
015
020
025
030
0 5 10 15 20 25 30 35 40
Liq
uid
Hol
dup
(-)
vSG (ms)
=01 ms
=005 ms
=001 ms
Onset of Film Reversal
Complete Film Reversal
Slug Flow Transition
vSL
vSL
vSL
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Results hellip
Pressure Gradient and Flow Patterns 45deg Deviated
98
Experimental Results hellip
Pressure Gradient All Deviation Angles vSL=01 ms
Pre
ssu
re G
rad
ien
t (P
am
)
3500
3000
2500
2000
1500
1000
500
0
Vertical
15deg Deviated
30deg Deviated
45deg Deviated
Onset of Film Reversal
Complete Film Reversal
0 5 10 15 20 25 30 35 40
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Results hellip
High Speed Videos vSL=01 ms vSG=18-175 ms
0deg Pipe 15deg Pipe
30deg Pipe 45deg Pipe
Fluid Flow Projects Advisory Board Meeting April 17 2013
99
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Results hellip
Critical Gas Velocity Complete Film Reversal
0
5
10
15
20
25
30
0 5 10 15 20 25 30 35 40 45 50
Cri
tica
l Sup
erfi
cial
Gas
Vel
ocit
y (m
s)
Deviation Angles (deg)
=01 ms
=005 ms
=001 ms
vSL
vSL
vSL
Model Comparison
Experimental Results are Compared with Model Predictions TUFFP Unified Model (2011 v1)
Beggs and Brill
OLGA (v72)
Critical Gas Velocities are Compared with TUFFP Unified Model and Modified Turner Criterion
Fluid Flow Projects Advisory Board Meeting April 17 2013
100
Model Comparison hellip
Vertical vSL=01 ms
Pre
ssur
e G
rad
ient
(P
am
) 3000
2500
2000
1500
1000
500
0
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Comparison hellip
Vertical vSL=01 ms
Liq
uid
Hol
du
p (
-)
030
025
020
015
010
005
000
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
101
Model Comparison hellip
Vertical vSL=001 ms P
ress
ure
Gra
dien
t (P
am
) 3000
2500
2000
1500
1000
500
0
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40 45
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Comparison hellip
Vertical vSL=001 ms
Liq
uid
Hol
du
p (
-)
030
025
020
015
010
005
000
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40 45
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
102
Model Comparison hellip
45deg Deviated vSL=01 ms P
ress
ure
Gra
die
nt
(Pa
m)
3000
2500
2000
1500
1000
500
0
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Comparison hellip
45deg Deviated vSL=01 ms
Liq
uid
Hol
du
p (
-)
045
040
035
030
025
020
015
010
005
000
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
103
Model Comparison hellip
45deg Deviated vSL=001 ms
Pre
ssu
re G
rad
ien
t (P
am
) 1800
1600
1400
1200
1000
800
600
400
200
0
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40 45
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Comparison hellip
45deg Deviated vSL=001 ms
Liq
uid
Hol
du
p (
-)
035
030
025
020
015
010
005
000
Experimental Data
TUFFP Unified Model
BeggsampBrill
OLGA v72
0 5 10 15 20 25 30 35 40 45
vSG (ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
104
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Comparison hellip
Critical Gas Velocity
0
5
10
15
20
25
30
35
0 5 10 15 20 25 30 35 40 45 50
Cri
tica
l Sup
erfi
cial
Gas
Vel
ocit
y (m
s)
Deviation Angles (deg)
Modified Turner Crit
TUFFP Unified Model
=01 ms (Complete Film Reversal)
=005 ms (Complete Film Reversal)
=001 ms (Complete Film Reversal)
vSL
vSL
vSL
Model Analysis
Assumptions Gas Phase Flows in the Center of the Pipe with
Liquid Entrainment
Pipe Periphery is Only Wetted by Liquid Film
Pressure Gradients of the Gas Core and Liquid Film are the Same at a Given Cross Section of the Pipe
Film Thickness is Symmetric Around Circumference
Fluid Flow Projects Advisory Board Meeting April 17 2013
105
Model Analysis hellip
Back Calculations Governing Equations
dp (1) A S S A g sin( ) 0F WF F I I F FdL F
dp (2) AC I SI C AC g sin( ) 0
dL C
Adding Equations (1) and (2)
dp WF SF (3) 1 H H 0g sin θC L L LdL A
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Analysis hellip
Solving Equation (3) for Wall Shear Stress
dp H 1 H g sinL L G LdLWF
4 d
Friction Factor Calculated with Wall Shear Stress
2WFf L 2 vL F
Fluid Flow Projects Advisory Board Meeting April 17 2013
106
Model Analysis hellip
Solving Equation (2) for Interfacial Shear Stress
A dp I C C g sin SI dL
Friction Factor Calculated with Interfacial Shear Stress
2 I If
C vC vF 2
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Analysis hellip
Forward Model Subtracting Equations (1) and (2)
SF 1 1 WF I SI F C g sin( ) 0
A A AF F C
Wall and Interfacial Shear Stresses
2 L v F C vC vF 2
WF f L 2 I f I 2
Fluid Flow Projects Advisory Board Meeting April 17 2013
107
Model Analysis hellip
Wall Friction Factor Correlation (fL) Blasius Equation
ൌ ܨ ܥ
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Analysis hellip
Most Common Interfacial Friction Factor Correlations
Author Correlation
Wallis (1969)
dfcfi
L3001
Henstock and Hanratty (1976)
fc d
fifcfi
L2121
Asali et al (1985)
40451 0 2
fc d
fiReRefcfi L
C
C
Fore (2000)
0 0015
1750013001
dRe
fcfi L
C
Fluid Flow Projects Advisory Board Meeting April 17 2013
108
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Analysis hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Analysis hellip
Pressure Gradient and Interfacial Shear Stress Predictions and Comparison with Back Calculations Vertical Pipe
0
10
20
30
40
50
60
70
80
0 5 10 15 20 25 30 35 40
τ I (P
a)
vSG (ms)
Data (Back Calculation =001 ms)
Data (Back Calculation =01 ms)
Forward Model ( =001 ms)
Forward Model ( =01 ms)
vSL
vSL
vSL
vSL
0
1000
2000
3000
4000
5000
6000
7000
8000
0 5 10 15 20 25 30 35 40
dpd
l (P
a m
)
vSG (ms)
Forward Model ( =01 ms)
Data ( =01 ms)
Forward Model ( =001 ms)
Data ( =001 ms)
vSL
vSL
vSL
vSL
109
Annular Flow
ComFil
Reve
plete m rsal
y v F
Slug Flow
y v
F
y v F
0 5 10 15 20 25 30 35
30
25
20
15
10
5
0
-5
40
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Analysis hellip
Liquid Holdup Comparison Vertical Pipe
0000
0100
0200
0300
0400
0500
0600
0700
0800
0 5 10 15 20 25 30 35 40
H L
(-)
vSG (ms)
Data ( =01 ms)
Forward Model ( =01 ms)
Data ( =001 ms)
Forward Model ( =001 ms)
vSL
vSL
vSL
vSL
Model Analysis hellip
Wall Shear Stress Comparison Vertical Pipe
35
τ W
F (P
a)
vSG (ms) Data (Back Calculation vSL =01 ms) Forward Model ( vSL =01 ms) Data (Back Calculation vSL =001 ms) Forward Model ( vSL =001 ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
110
CFD Simulations
Geometry Construction 2D Axisymmetric Geometry
Created in Gambit
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Fluid Flow Projects Advisory Board Meeting April 17 2013
CFD Simulations hellip
Mesh Generation Performed in Gambit
96000 Control Volumes
111
CFD Simulations hellip
Fluent Setup Axial Velocity and Volumetric Phase
Distribution
Vertical Pipe Gravity Direction is Defined Opposite of Flow Direction
vSL=01 ms vSG=20 ms
vSG=18 ms
vSG=9 ms
Fluid Flow Projects Advisory Board Meeting April 17 2013
CFD Simulations hellip
Fluent Setup Transient Flow
VOF Model with First Order Implicit Time Scheme
HRIC to Capture Gas Liquid Interface
k-ε Turbulent Model with Enhanced Wall Treatment
Convection Terms were Discretized by Second Order Upwind and Diffusion Terms by Second Order Scheme
PISO for Pressure Momentum Coupling and PRESTO for Pressure Equation Discretization
Fluid Flow Projects Advisory Board Meeting April 17 2013
112
Fluid Flow Projects Advisory Board Meeting April 17 2013
CFD Simulations hellip
Axial Velocity Distribution (vSL=01 ms vSG=20 ms)
Fluid Flow Projects Advisory Board Meeting April 17 2013
CFD Simulations hellip
Volumetric Distribution (vSL=01 ms vSG=20 ms)
113
Fluid Flow Projects Advisory Board Meeting April 17 2013
CFD Simulations hellip
Volumetric Distribution (vSL=01 ms vSG=9 ms)
Conclusions
Critical Gas Velocity Increases as Well Deviation Increases
Pressure Gradient Fluctuations Increase From Annular to Slug Flow
Liquid Holdup Rate of Change Increases on the Left of Complete Film Reversal Transition
Fluid Flow Projects Advisory Board Meeting April 17 2013
114
Conclusions hellip
Slug and Churn Flow are Promoted in Deviated Wells Due to Thicker Film Thickness at the Bottom of the Pipe
Model Predictions can be Improved by Correct Flow Pattern Predictions
CFD Simulations are Able to Capture Characteristics of Annular Flow Qualitatively
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Questions amp Comments
115
116
Liquid Loading of Gas Wells with Deviations from 0deg to 45deg Mujgan Guner
Project Completion Dates Literature Review Completed Instrumentation Completed Experimentation Completed CFD Modeling Completed Data Analysis and Model Comparison Completed
Final Report Completed
Objectives The main objective of this study is to investigate mechanisms controlling onset of liquid loading in vertical and deviated pipe wells
Introduction Liquid loading of a gas well is the inability of the gas to remove the liquids from the well Liquid loading in gas wells have been recognized one of the most important problems in gas production Natural gas condensate and water are often produced simultaneously in gas wells In the early stages of a gas well the gas flow rate is high enough to carry the liquid phase to the surface As the gas well matures the gas flow rate reduces and the liquid carrying capability of gas decreases As a result liquid begins accumulating in the well and eventually the accumulated liquid blocks further production
Prediction of liquid loading is very important from operational stand point Since available models cannot predict liquid loading initiation accurately in deviated wells further investigation of mechanisms which control liquid loading is very crucial in order to improve current models or develop new ones
In this study liquid loading mechanisms were investigated experimentally and experimental results were compared with the available models in the literature
Activities Summary The activities carried out during this period are experimental testing in deviated pipes data analysis model comparison and CFD simulations The final report of the study was submitted The summary of each particular activity are presented below
Experiments The experimental study was conducted to investigate effects of deviation angles on the onset of liquid loading in 3-in ID pipes For each data point pressure gradient liquid holdup and high speed videos were acquired A total of 156 test points were collected at the well deviations of 0deg 15deg 30deg and 45deg from vertical
Test Results for Vertical Pipe Liquid loading has been studied by considering three different superficial liquid velocities 001 005 and 01 ms For each superficial liquid velocity 13 superficial gas velocities starting from 40 ms to 18 ms were tested
Analysis of the experimental data showed that pressure gradient decreases as the gas flow rate decreases to a minimum at a certain superficial gas velocity vSG(MIN) Further decrease of gas flow rate increases the pressure gradient Pressure gradient fluctuations are considered as liquid loading symptoms As gas flow rate decreases pressure gradient fluctuations increase
Flow pattern and the local film behavior were observed with high speed and low speed videos In annular flow region decrease in gas flow rate initiates liquid film reversal Further decrease of the gas flow rate promotes waviness and oscillations in the flow When the waves get larger the liquid phase block the pipe cross section and it is called churn flow At the lowest gas velocity of the test matrix slug flow is observed In the churn flow region liquid discharge at the outlet of the pipe is oscillatory and very low compared to annular flow Therefore churn flow can be strongly related to the onset of liquid loading
Liquid holdup investigations showed that as the gas flow rate is decreased liquid holdup increases
Test Results for 15deg Deviated Pipe The same gas and liquid flow rates were tested for 15deg deviated pipe Similar shape in pressure gradient was observed For 15deg deviation angle the minimum pressure gradient occurs at higher superficial gas velocities than for vertical pipes Pressure gradient fluctuations increase as the gas flow rate decreases
The liquid film at the bottom of the pipe gets thicker because of the deviation from the vertical Comparison with the vertical case shows that for 15deg deviated pipes churn and slug flow patterns occur in a broader range of superficial gas velocities while annular flow covers a narrower range
Liquid holdup shows similar trend as the vertical pipe
117
Test Results for 30deg Deviated Pipe Increase in the deviation in the pipe increases the liquid film thickness at the bottom of the pipe further The minimum pressure gradient occurs at higher superficial gas velocities than for the vertical and 15deg deviated cases
Observation of flow patterns in 30deg deviated pipes shows that churn and slug flow patterns cover a larger range than vertical and 15deg deviated cases In annular flow region 30deg deviated pipe has a wavier gas-liquid interface as compared to vertical and 15deg deviated cases The waviness at the interface and the oscillatory behavior of the flow causes more pressure gradient fluctuations as compared to vertical and 15deg deviated cases
Test Results for 45deg Deviated Pipe Experiments and analysis have been conducted to investigate liquid loading for 45deg pipe As the deviation increases the gravitational pressure drop is less dominant as compared to the vertical 15deg and 30deg deviated cases Therefore the pressure gradient does not increase sharply as the gas velocity decreases
In the range of test matrix the flow is dominated by intermittent flow patterns namely churn and slug flow
Well Deviation Effect on Liquid Loading In this study flow patterns and the liquid film behavior were investigated based on videos and observations The transitions in the flow characteristics are named as onset of film reversal complete film reversal wavy annular flow and slug flow transitions
The onset of film reversal is where the first bubble entrained in the liquid film starts changing its direction of flow It is a local reversal indication in the liquid film the liquid film still flows upwards In the complete film reversal region the visual observation indicates that liquid film completely flows downwards At the outlet of the pipe liquid flows intermittently In this region gas-liquid interface is very wavy and when the liquid inventory is enough the waves completely block the pipe cross section at some instances Further decrease in the gas flow rate results in slug flow
In this study analysis showed that the onset of liquid loading is likely to match with the complete film reversal transition boundary Experiments showed that as the well deviation increases the critical gas velocity to initiate liquid loading increases
Model Comparisons and Analyses Experimental results were compared with the model predictions The Beggs and Brill correlation TUFFP
Unified Model and OLGA v72 models were evaluated Critical gas velocities were compared with the modified Turner criterion and the TUFFP unified model flow pattern transition
Analyses showed that the models and the experimental data are not in good agreement Still model comparisons are closer with the experimental data for lower liquid rates As the liquid rate increases the discrepancies in model predictions increase
The critical gas velocities are over predicted by the TUFFP unified model transition criterion and under predicted by the modified Turner model For the vertical and 15deg deviated case the modified Turner criterion predicts the critical velocity better
The discrepancies in the model and the experimental data led to further investigations The wall and interfacial shear stresses were back calculated from the experimental results The calculations showed that for deviated cases symmetry assumption should be removed and the closure relationships should be modified accordingly
CFD Modeling CFD modeling can be utilized to estimate the velocity profile and phase distributions in unloading conditions The Volume of Fluid (VOF) model implemented in Fluent is utilized to simulate two phase air-water flow in vertical pipes The geometry was constructed based on the test section The mesh size gets finer close to the pipe wall (liquid region) while coarser in through the center of the pipe This particular geometry has 96000 control volumes after meshing
Exploratory CFD simulations were tested for vertical case where the superficial gas velocities were 20 18 and 9 ms for superficial liquid velocity 01 ms
The simulations were able to capture qualitatively the major mechanisms associated with annular flow including generation of instabilities at the gas-liquid interface
Conclusions The important conclusions of the study can be briefly summarized as follows Well deviation is an important variable that
affects onset of liquid loading The critical gas velocity increases as the well
deviates from vertical Well deviation promotes intermittent flow Available models are not in good agreement with
the experimental results especially for deviated wells
118
References Guner M ldquoLiquid Loading of Gas Wells with Deviations from 0deg to 45degrdquo MS Thesis The University of Tulsa
(2012)
119
120
Fluid Flow Projects
Liquid Loading In Deviated Pipes From 45deg to 90deg
Yasser Alsaadi
Advisory Board Meeting April 17 2013
Outline
Objectives
Introduction
Literature Review
Experimental Program
Model Comparison and Development
Project Schedule
Fluid Flow Projects Advisory Board Meeting April 17 2013
121
Objectives
Study the Onset of Liquid Loading in Deviated Pipes from 45deg to 90deg
Investigate the Effect of Highly Deviated Angles on Liquid Loading
Compare Experiment Results with Existing Models
Improve or Develop a Model to Include the Effect of Deviation Angle
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction
Liquid Loading ndash Accumulation of Liquid in Wells Owing to Insufficient Gas Rate to Carry the Liquid
Mechanism of Liquid Loading Flow Reversal of Droplets
Flow Reversal of Liquid Film
Fluid Flow Projects Advisory Board Meeting April 17 2013
122
Introduction hellip
In Deviated Wells Other Mechanisms are Important Thicker Liquid Film at the Bottom of the
Pipe Wall
Secondary Gas Flow in the Cross-Section
Fluid Flow Projects Advisory Board Meeting April 17 2013
Literature Review
Belfroid et al (2008) Turner (1969) Model is only for Vertical
Wells
Fiedler (2004) Model Accounts for Deviation Angle
Proposed TNO-Shell Model ndash Modified Turner (1965) Model Using Fiedler (2004) Angle Correction Term
Fluid Flow Projects Advisory Board Meeting April 17 2013
123
Literature Review hellip
Westende (2008) Critical Gas Velocity as a Function of
Deviation Angle
Fluid Flow Projects Advisory Board Meeting April 17 2013
Literature Review hellip
Yuan (2011) Well Deviations 0ordm 15ordm 30ordm Pressure Gradient Holdup and High
Speed Video Recordings Liquid Loading is Due to Film Reversal Minimum Pressure Gradient at Onset of
Liquid Loading Critical Gas Velocity Increases with
Deviation for the Same vSL
TNO-Shell Model has Good Agreementwith Experimental Data
Fluid Flow Projects Advisory Board Meeting April 17 2013
124
Literature Review hellip
Guner (2012) Well Deviations from 0deg to 45deg
Pressure Gradient Holdup and High Speed Video Recording Observations
Onset of Liquid Loading is Due to Reversal Flow of Liquid Film
Critical Gas Velocity Increases as Well Deviation Increases
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Program
Experimental Matrix
Test Facility
Test Fluids
Instrumentation
Data Processing
Fluid Flow Projects Advisory Board Meeting April 17 2013
125
Experimental Matrix
Well Deviation Angle
45deg 70deg 80deg 85deg and 88deg
Superficial Gas Velocity
2 to 40 ms
Superficial Liquid Velocity
001 002 005 and 01 ms
Total of 240 Test Points
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Matrix hellip
45deg Deviation
126
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Matrix hellip
70deg Deviation
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Matrix hellip
80deg Deviation
127
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Matrix hellip
85deg Deviation
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Matrix hellip
88deg Deviation
128
Fluid Flow Projects Advisory Board Meeting April 17 2013
Test Facility
Test Section Design
3 in x 175 m
Test Fluids
Gas ndash Compressed Air
Density ndash Pressure amp Temperature
Viscosity ndash 18E-5 Pamiddots
Liquid ndash Tulsa Tap Water
Density ndash 998 Kgm3
Viscosity ndash 0001 Pamiddots
Surface Tension ndash 0073 Nm
Fluid Flow Projects Advisory Board Meeting April 17 2013
129
Instrumentation
Instruments Flow Meters with PID Controllers
Pressure and Temperature Transducers Pressure and Temperature
Two Trap Sections with Quick Closing Valves Holdup
Conductivity Sensors Wave Characteristics
Fluid Flow Projects Advisory Board Meeting April 17 2013
Instrumentation hellip
Visual Observation High Speed Camera Liquid Film Flow Direction
Surveillance Cameras Flow Pattern
Boroscope Flow Pattern
Transition to Slug Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
130
Holdup Measurement
Holdup Calculation Ta Pa Te Pe
Air Cylinder (Va)
Pipe Trap Section (Vt)
Tt Pt
Air Cylinder (Va)
Pipe Trap Section (Vt)
Te Pe
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Holdup Calibration
131
Boroscope
Identification of ldquoLiquid Bridgingrdquo at the Onset of Liquid Loading
Will be Used With Selected Test Points
Useable at Near Horizontal
Fluid Flow Projects Advisory Board Meeting April 17 2013
Data Processing
Input Three Different Raw Data Files Pressure Temperature and Flow Rates
Holdup
Wave Characteristics
Output Average Results and Uncertainties for All Variables
Provide Quick Tools for Calculating and Checking Test Results
Fluid Flow Projects Advisory Board Meeting April 17 2013
132
Data Processing hellip
Experiment Results Summary
Pressure and Temperature
Data Processing Using Excel
PampT
Raw Data
Holdup
Data Processing Using Excel
Trap Section
Raw Data
Wave Characteristics
Data Processing Using Matlab
ConductivitySensor Raw Data
Results for Each Test Point
Test Point
Fluid Flow Projects Advisory Board Meeting April 17 2013
Model Comparison and Development
Compare Data with Predictions from Existing Models Pressure Gradient
Flow Pattern Prediction
Critical Gas Velocity
Improve or Develop a Model to Include Deviation Angle Effect
Fluid Flow Projects Advisory Board Meeting April 17 2013
133
Project Schedule
Literature Review Completed
Experimental Testing May 2013
Data Analysis June 2013
Model Comparison and July 2013 Development
Final Report August 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Questions amp
Comments
Fluid Flow Projects Advisory Board Meeting April 17 2013
134
Liquid Loading in Deviated Pipes From 45deg to 90deg
Yasser Alsaadi
Project Completion Dates Literature Review Completed
Experimental Testing May 2013 Data Analysis June 2013 Model Comparison July 2013 Final Report August 2013
Objective The main objective of this study is to investigate the mechanism of liquid loading in highly deviated wells and pipes from 45deg to 90deg
Introduction Liquid loading is a common production problem that occurs in matured gas wells It starts when the gas flow rate becomes insufficient to lift the liquid to the surface and results in accumulation of liquid at the bottom of the wellbore The buildup of liquid column in the well creates a back pressure which further reduces the well production and eventually kills the well
The onset of liquid loading can be identified when the gas reaches a critical velocity at which the liquid falls back When the gas velocity drops below this critical value liquid loading is initiated Two mechanisms have been proposed to explain the liquid falls back The first mechanism was proposed by Turner (1969) and states that liquid loading is due to the fallen of liquid droplet This happens when the gravity force on the droplet is greater than the drag force exerted on the droplet by the gas The second mechanism was proposed later and it is based on the reversal flow of the liquid film Turner (1969) model is still widely used in the industry and proven to give good prediction for vertical wells
The liquid loading mechanism can be different in deviated and vertical wells The gravity effect on the droplet decreases with deviation and a thicker liquid film exists at the bottom of the pipe In addition secondary gas flow in the cross section of the pipe affects the film distribution and droplets entrainment
Activities Summary A summary of the most relevant activities during this period is presented in this section
Literature Review Turner et al (1969) developed a model to predict the critical gas velocity in vertical wells The model is derived on the basis that liquid loading occur when
the gravity force on the liquid droplet is more than the drag force by the gas The Turner expression is widely used in the industry and found to give good prediction for vertical wells However there is no angle dependent term in this model The TNO-Shell correlation developed by Belfroid et al (2008) modified Turner et al (1969) model to include angle effect They studied the deviation effect on the liquid loading onset for deviated wells Field data were used to test several proposed models for critical gas velocity A modified Turner model that accounts for angle effect was proposed and found to give better prediction than existing models
Yuan (2011) explored the mechanism of the factor controlling the onset of liquid loading and the effect of deviation angle from 0deg to 30deg The pressure gradient and holdup were measured and the critical gas velocity of the onset of liquid film was observed by high speed videos His observations supported the film reversal mechanism controls the liquid loading initiation For a constant liquid flow rate the minimum pressure gradient was found to occur at the critical gas velocity Higher critical velocities were observed as the pipe deviation increases
In highly deviated pipes rolling waves and multiple solution region are observed Rolling waves are coherent structures which can affect erosion rates solid transport and pipe fatigue The multiple solution region corresponds to an area where the models provide three possible solutions The selection of the correct solution is still debated In this study rolling waves and multiple solution region will be considered
Experimental Facility The 762-mm (3-in) diameter multiphase flow facility of the Tulsa University Fluid Flow Projects (TUFFP) will be utilized for this project The facility is capable of being inclined from horizontal to vertical Pressure and temperature transducers are placed near the test section to obtain fluid properties and other flowing characteristics Compressed air
135
and Tulsa city tap water will be used as working fluids
Instrumentation The facility is equipped with state of the art instrumentations
Trapping sections with quick closing valves are used to measure the average liquid holdup Each trap section is connected to pressurized air tank equipped with pressure and temperature transducers The amount of water volume in the trap section is calculated by equating the total air mass in the trap and air cylinders In addition two pressure and temperature transducers and one pressure differential device are used to record the pressure and temperature of the flowing fluid Moreover capacitance sensors are installed to capture the wave characteristics and average film thickness
A high speed video camera is used to observe the flow direction at the test section of the pipe Additionally six observation cameras will record the flow behavior at the entrance and test sections A Boroscope will also be used to capture the flow behavior from inside the pipe
Experimental Program The experiments will be conducted at different flow rate conditions and deviation angles The superficial air velocities will range from 5 to 40 ms The superficial water velocity will be 0005 001 005 and 01 ms The pipe deviation angles of interest are 45deg 70deg 80deg 85deg and 88deg from vertical The test range should cover the onset of liquid loading area For each test run liquid flow rate will be kept constant and gas flow rates will be decreased by steps
The process of the data analysis will be optimized by using computer processing programs The programs are able to process the raw data from the instruments providing average results with uncertainties This will accelerate the speed of the data analysis and provide a quick tool to identify errors in the experimental campaign
Project Schedule Future activities with culmination dates are presented in this section
Experimental Testing ndash May 2013 Experiment testing range will be conducted Data will be recorded and documented for each test run
Data Analysis ndash June 2013 The raw data from instruments will be process using the computer programs Test results with odd trends will be repeated in the experiment to ensure the reproducibility of the results The recorded observation videos will be used to identify the flow direction of the liquid film and the flow regime of the test conditions Selected test conditions near the onset of liquid loading will be chosen for Boroscope video recording
Model Comparison ndash July 2013 Test results will be compared against different models such as Turnerrsquos model TUFFP Unified Model Barnearsquos model and OLGA simulation
Final Report ndash July 2013 Final report will be submitted and thesis will be defended
References Belfroid SPC Schiferli W Alberts GJN Veeken CAM and Biezen E ldquoPrediction Onset and Dynamic
Behavior of Liquid Loading Gas Wellsrdquo SPE paper 115567 presented at 2008 SPE ATCE Denver CO 21-24 September 2008
Belt RJ ldquoOn the Liquid Film in Inclined Annular Flowrdquo PhD Dissertation TU Delft 2008 Guner M ldquoLiquid Loading Of Gas Wells With Deviations From 0deg To 45degrdquo MSc Thesis University of Tulsa
2012 Coleman SB Clay HB McCurdy DG and Lee Norris H III ldquoA New Look at Predicting Gas-Well Load
Uprdquo J Pet Tech pp 329-333 March 1991 Turner RG Hubbard MG and Dukler AE ldquoAnalysis and Prediction of Minimum Flow Rate for the
Continuous Removal of Liquids from Gas Wellsrdquo J Pet Tech pp 1475-1482 Nov 1969 Westenende J Vanlsquot ldquoDroplets in Annular-Dispersed Gas-Liquid Pipe Flowsrdquo PhD Dissertation TU Delft 2008 Yuan G Liquid Loading of Gas Wells MSc Thesis University of Tulsa 2011
136
Fluid Flow Projects
Unified Model Computer Code Update
Carlos F Torres
Advisory Board Meeting April 17 2013
Outline
Status Unified Model ndash Solution Technique Slug to StratifiedAnnular Flow Transition
ndash Actual Approach Slug to StratifiedAnnular Flow Transition
ndash New Approach Example Slug to StratifiedAnnular Flow Future Tasks Recommendations
Fluid Flow Projects Advisory Board Meeting April 17 2013
137
Status
Information Gathering Completed
New Code Layout Completed
Layout Test Completed
Unified Flow Pattern On going
Unified Flow Pressure Gradient On going
Testing August 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Unified Model Solution Technique
Sequential Process Characteristics Calculate Transition
Superficial Liquid Velocity for In-situ Superficial Gas Velocity by Solving the Proper Model
Compare the Transition Liquid Superficial Velocity With the In-situ Liquid Superficial Velocity
Fluid Flow Projects Advisory Board Meeting April 17 2013
138
Slug to StratifiedAnnular Flow Transition ndash Actual Approach
Solves a Set of Three Non-linear Equations Momentum Equation for the Gas and the Liquid
Kinematic Condition for the Slug Stability Fix
dp I SI CSC vsg C g sindz (1 H LF ) A Unknowns
Hlf dp dz vsldp S SI I F F g sindz H A L Closures Relationships
LF
Fe Hls f f f i c f
(H (v v ) v )(v v F ) v v FLS T S SL SG SL E T SL EH LF v vT SG
Fluid Flow Projects Advisory Board Meeting April 17 2013
Slug to StratifiedAnnular Flow Transition ndash Original Approach
Transition is Solved by Fixing the Gas Superficial Velocity
Implementing a Fix-point Iterative Technique
Sequential Substitution for CME Closure Relations and the Kinematic Condition
Guessing for Transition Liquid Superficial Velocity and Slug Liquid Holdup
Iterating Until Convergence is Achieved
Comparing Transition Liquid Superficial Velocity With In-situ Liquid Superficial Velocity
Details in Zhang (2009) TUFFP Report
Fluid Flow Projects Advisory Board Meeting April 17 2013
139
Slug to StratifiedAnnular Flow Transition ndash New Approach
Transition is Predicted by Implementing Robust Technique for Solving
CME with Its Closure Relationships Calculate Hydrodynamics Variables Calculate Slug Liquid Holdup and the
Transition Liquid Holdup Using the Kinematic Condition
Compare Transition Liquid Holdup and the Liquid Holdup Obtained from CME
Analogous Process to Taitel and Dukler(1976) Stability Model for Stratified Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
Example Slug to Stratified Flow
Air and Water
Inclination Angle 0 deg
Liquid Density 998 kgm3
Gas Density 1225 kgm3
Liquid Viscosity 1 cp
Gas Viscosity 0000018 Pa s
Surface Tension 72 dynescm
Diameter 2 in
Roughness 0002 mm
Fluid Flow Projects Advisory Board Meeting April 17 2013
140
Fluid Flow Projects Advisory Board Meeting April 17 2013
Example Slug to Stratified Flow hellip
0001
001
01
1
10
001 01 1 10 100
v SL
(ms
)
vSG (ms)
Example Slug to Stratified Flow hellip
Solve Combined Momentum Equation
S S 1 1 F F C C I S I ( L C )g sin 0H A (1 H )A H A (1 H )A LF LF LF LF
Closure Relationships Used Oliemans et al (1986) for Entrainment Fraction Andritsos amp Hanraty (1987) for Interfacial
Friction Factor Churchill (1977) for Friction Factor Grolman (1994) for Wettability
Fluid Flow Projects Advisory Board Meeting April 17 2013
141
Example Slug to Stratified Flow hellip
Transition Liquid Film Holdup
(H (v v ) v )(v v F ) v v FLS T S SL SG SL E T SL EH LF v vT SG
Additional Models Zhang et al (2003) for Slug Liquid Holdup
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Example Slug to Stratified Flow hellip
0001
001
01
1
10
001 01 1 10 100
v SL
(ms
)
vSG (ms)
Vsg=02ms Vsl = 00915ms Hlf=08651 Hlft=008651
Vsg=02ms Vsl = 007ms Hlf=08512 Hlft=08641
Vsg=02ms Vsl = 01ms Hlf= 08738 Hlft= 08657
142
Future Tasks
Finish Basic Coding
Select and Test the Available Closure Relationship
Testing With Database
Fluid Flow Projects Advisory Board Meeting April 17 2013
Recommendations
Research is Required to the AnnularStratified Model
Seamless Transition from Stratified to Annular
Unified Interfacial Friction Factor and Liquid Film Distribution Circumferential Variations
Droplet Entrainment
Fluid Flow Projects Advisory Board Meeting April 17 2013
143
Comments and Suggestions
Fluid Flow Projects Advisory Board Meeting April 17 2013
144
r
f
Unified MModel Coomputer CCode - Uppdate Carlos F Torres
Project CCompletion DDates
Objectivee The objecctive of this project is to develop andd implementt a new codinng structure foor the Unifiedd Model
Introducttion Several iimprovements in unifiedd mechanisticc modeling and closure relationshipss have beenn incorporateed in the Unifiied Model Commputer Code too extend andd increase its prediction cappabilities Thee code structture has been uupgraded allowwing advancedd users to mmodify write orr include new correlations orr closure rellationships AAdditionally a new approachh to solve tthe Unified MModel is propposed and thee results aree compared wwith the previoous technique This new approach cou ld increase thhe computationn speed and simplify the uunderstanding of the Unifiedd Model for Gas-Liquid
Unified MModel ndash Soluttion Techniqque Zhang et aal (2003) prop osed a techniqque to solve thee Unified MModel as a seqquential processs presented inn Fig 1
Figure 1 Soolution algorithhm
Information Gatheering Completed Neew Code Layout Completed Laayout Test Completed Unified Model - Floow Pattern Ongoing Unified Model - Floow Pressure Graadient OngoingFinal Testing August 2013
The mmain characterristics of this seequential proceess are as follows 1 TThe transitionnal superficiall liquid veloccity is
ccalculated for the in-situ supperficial gas veelocity ffor the actual flow pattern teested (see Fig 1) by ssolving the prroper model sset of equationns per ttransition bounndary
2 CCompares thhe predicted transition liquid ssuperficial vellocity in step 1 with the in-situ lliquid superficcial velocity If the criterrion is ssatisfied all thee final hydrodyynamicsrsquo parammeters aare calculated for the predictted flow patterrn On tthe other handd if the criterioon is not satis fied a nnew flow patteern is tested (sttep 1)
3 TThis criterion is applied for all the flow paatterns eexcept bubble flow Instead of superficial liquid vvelocity superrficial gas veloocity is used ffor the ccomparison
4 TThe last transiition tested in Fig 1 is the sslug to sstratifiedannullar flow transi tion This trannsition rrequires the soolution of a se t of three non -linear eequations onee momentum eequation for thhe gas oone momentumm equation forr the liquid annd one kkinematic conddition for the stability of thee slug AAll of the equations and their cclosure rrelationships depend on pressure graadient hholdup and thee superficial veelocities
5 TThe non-linearr system of eqquations is solvved by ffixing the supperficial veloccity of the gaas and iimplementing a fix-point iterrative techniquue over aa sequential substitution of the non-linear eequations Thiis solution techhnique is reliabble but sslow and requiires a guessed starting point ffor the lliquid superficcial velocity annd slug holdupp The mmechanistic mmodel used ffor the slug liquid hholdup is solveed in the same iterative loop
Slugg to StratifieddAnnular Floow Transitioon ndash Neww Solution Teechnique The superficial veelocity comparrison criterion given by Zhhang et al (20003) can be avvoided for the sslug to stratiifiedannular fllow transition The new soolution technnique for the Unified Mod el is carried oout as followws
145
f
1 Solve the set of two non-linnear equationss Figurre 2 shows an example of thiis technique wwith the (mome by the to pre numer
entum equatio e traditional co dict the liquid rical technique
n for the gas a mbined mome holdup by a r
e such as the B
and the liquid) entum equation robust and fast
Brent or Muumlller
) n t r
label super holdu cond
ls that presen rficial veloci ups and the tr
ditions All the
nt the values ities and co ransition liqui e points have
of gas and orresponding d holdups for the same supe
liquid liquid
r those erficial
methoods gas vvelocity The bblack dot in thee flow pattern mmap is 2 Using the liquid ho ldup from stepp 1 determinee the transition point betwween slug and
the fi holdup
ilm velocity p (iteration r
core velocity equired if th
y slug liquid he mechanistic
d c
strati liquid
ifiedannular fl d superficial th
low The gre han the transiti
een dot has a ion and the gr
higher rey dot
modell is used) aand finally calculate thee has aa smaller liquuid superficial than the trannsition transittion holdup by the kinematic condition As ccan be observeed the holdup is higher and lower
3 Comp are the transittion holdup wiith the holdup than the transitionn holdup for the green andd gray If the the flo
transition hold ow is stratified
dup is higher th d if it is smal
han the holdup ler the flow is
s
pointts respectivelyy
slug fllow If they arre equal the trransition line iss prediccted
Figurre 2 Example oof the new soluution techniquee
Referencces Zhang HQQ Wang Q CC Sarica C aand Brill JP ldquoUnified Moddel for Gas-Liqquid Pipe Floww via Slug Dynnamics
Paart IrdquoASME JJ of Energy RRes Tech Vol 125 4 pp 2666-273 2003 Zhang HQQ Wang Q CC Sarica C aand Brill JP ldquoUnified Moddel for Gas-Liqquid Pipe Floww via Slug Dynnamics
Paart IIrdquoASME J of Energy RRes Tech Voll 125 4 pp 2774-283 2003
146
Fluid Flow Projects
TUFFP Experimental Database
Jinho Choi
Advisory Board Meeting April 17 2013
Outline
Objective Purpose Introduction TUFFP Experimental Data Gas-Liquid Oil-Water Gas-Oil-Water
MS Access Database Description Issues
Future Work
Fluid Flow Projects Advisory Board Meeting April 17 2013
147
Objective
Development of Multiphase Flow Database 2-Phase Gas-Liquid Liquid-Liquid
3-Phase Gas-Liquid-Liquid
Steady-State Flow Data
Transient Flow Data
Fluid Flow Projects Advisory Board Meeting April 17 2013
Purpose
Validate Developed Models for Multiphase Pipe Flow
Export Data into a Required Format for Testing
Import New and Undefined Data Sets
Usability Applicability Extensibility
Fluid Flow Projects Advisory Board Meeting April 17 2013
148
Introduction
Experimental Database Time-averaged Measurements of Pressure Pressure
Gradients Volume Fractions Shear Stresses Entrainment Fractions and System Parameters Associated With Each Run
For Some Cases Additional Data Such As Individual Flow Pattern Characteristics
Fluid Flow Projects Advisory Board Meeting April 17 2013
TUFFP Experimental Data
Gas-Liquid Experimental Data 46 Experimental Data Sets by Various Authors Steady-State
Transient Hilly Terrain
About 10500 Steady-State Data Ready to Read Data File ndash txt xls etc
Reports Including Data as Appendix ndash pdf
Fluid Flow Projects Advisory Board Meeting April 17 2013
149
TUFFP Experimental Data hellip
Oil-Water Experimental Data 11 Experimental Data Sets
About 2800 Steady-State Data Ready to Read Data File ndash txt xls etc
Report including Data as Appendix ndash pdf
Gas-Oil-Water Experimental Data 5 Experimental Data Sets
About 400 Data Ready to Read Data File ndash txt xls etc
Report including Data as Appendix ndash pdf
Fluid Flow Projects Advisory Board Meeting April 17 2013
MS Access Database
Steady-State Multiphase Database by Schlumberger Limitations of Excel Database Too Fragile to Keep the Data Easy to Delete Data
Easy to Inject Unit Errors
Hard to Maintain a Consistent Format New as yet Undefined Data Fields
Presence of ldquoData Holesrdquo
Problematic When Exporting Data into a Required Format for Testing
Fluid Flow Projects Advisory Board Meeting April 17 2013
150
MS Access Database hellip
Steady-State Multiphase Database by Schlumberger
Data Import
Formatted Excel File
Raw Table
Raw Archive Table (Unit Conversion)
Database Master Table
Data Export
Excel in PipeSim OpenLink
Format
Excel in General Format
Fluid Flow Projects Advisory Board Meeting April 17 2013
MS Access Database hellip
Current Data Sets included in Database No Author No of Record Year Phase
1 Khor 412 1998 Gas-Oil-Water
2 Mukherjee 1400 1979 Gas-Liquid
3 Minami 111 1987 Gas-Liquid
4 Abdul 88 1994 Gas-Liquid
5 Eaton 238 1966 Gas-Liquid
6 Beggs 58 1973 Gas-Liquid
7 Atmaca 296 1973 Oil-Water
8 Dong 156 2007 Gas-Oil-Water
9 Gokcal 173 2008 Gas-Liquid
10 Magrini 140 2009 Gas-Liquid
11 Johnson 984 2005 Gas-Liquid
12 Yuan 153 2011 Gas-Liquid
13 Andritsos 535 1986 Gas-Liquid
14 Beggs 188 1972 Gas-Liquid
15 Cheremisinoff 174 1977 Gas-Liquid
16 Kokal 140 1987 Gas-Liquid
17 Roth 39 1986 Gas-Liquid
18 Fan 351 2005 Gas-Liquid
19 Gokcal 183 2005 Gas-Liquid
Data Sets Included in SLB DB Version 10
March 2013
bull 19 Data Sets
bull 5819 Data Records
Added TUFFP Data Sets Until March 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
151
MS Access Database hellip
Current Status and Update Schedule
Activities of This Period bull List-up of TUFFP
Projects bull List-up of Available
Data Sets bull Update of Database
Fluid Flow Projects Advisory Board Meeting April 17 2013
MS Access Database hellip
Difficulties to Import Experimental Data
Diversity of Data Formats Units Names of Variables Data File Formats
Data given as PDF Tables Specially Old Data Hard to Read
Variables that can be Found ONLY in text ie Pipe Diameter Length etc
Same Variable Names but Different Values ie Pressure Inlet Pressure Separator Pressure Pressure at
Test Sections etc
Fluid Flow Projects Advisory Board Meeting April 17 2013
152
Fluid Flow Projects Advisory Board Meeting April 17 2013
MS Access Database hellip
Difficulties
Diversity of Data Formats Units Names of Variables Data File Formats
Fan (2005) Data
MS Access Database hellip
Difficulties
Diversity of Data Formats Units Names of Variables Data File Formats
Formatted Excel File for Raw Table of Database
56 Columns
Fluid Flow Projects Advisory Board Meeting April 17 2013
153
Fluid Flow Projects Advisory Board Meeting April 17 2013
MS Access Database hellip
Difficulties Data given as PDF Tables Specially Old Data Hard to Read
Roumazeilles (1994)
Fluid Flow Projects Advisory Board Meeting April 17 2013
MS Access Database hellip
Difficulties Variables that can be Found ONLY in text ie Pipe Diameter Length etc
Magrini (2009)
154
MS Access Database hellip
Difficulties
Same Variable Names but Different Values ie Pressure Inlet Pressure Separator Pressure Pressure at
Test Sections etc
Fluid Flow Projects Advisory Board Meeting April 17 2013
Future Work
Collecting and Re-Formatting of Experimental Data
Extracting Data from PDF Tables
Re-Formatting Collected Data to Import File Format
Updating of MS Access DB User Interface
Fluid Flow Projects Advisory Board Meeting April 17 2013
155
Thank you for listening
Fluid Flow Projects Advisory Board Meeting April 17 2013
156
TUFFP Experimental Database Jinho Choi
Project Completion Dates TUFFP Experimental Data List Up Complete
Collecting and Reformatting Data Sets for DB October 2013 Final Report December 2013
Objectives The main objective of this project is to construct a multiphase flow database of TUFFP experimental data sets
Introduction TUFFP experimental database will contain the measurements of pressure pressure gradients volume fractions shear stresses entrainment fractions and the system parameters associated with each run In some instances additional data like individual flow pattern characteristics are also included
Usually experimental data sets have their own specific formats Moreover they are sometimes provided as tables in pdf format which need to be digitized Having all of the experimental data sets in a unified format makes the experimental data more usable and applicable In other words the database can be easily used to validate newly developed models for multiphase flow by exporting data into required formats for testing
TUFFP Experimental Data Multiphase flow experimental data sets are divided into three categories Gas-liquid Oil-water (liquid-liquid) and Gas-oil-water The lists of experimental data sets are given by Tables 1-3
TUFFP has 46 gas-liquid data sets including steady-state and transient experiments More than 10000 steady-state data records have been provided for gas-liquid flow For oil-water experiments 11 data sets with about 2800 data records have been acquired Finally 5 data sets with about 500 data records have been obtained from gas-oil-water experiments
Some of the data sets are given in MS Excel files (xls) or text files (txt dat etc) which can be directly copied and imported into database However others are provided by tables in pdf documents For those digitization or manual typing is necessary
Microsoft Access Database Schlumberger had developed the steady-state multiphase database using Microsoft Access which has been donated to TUFFP MS Access is selected to replace MS Excel database MS Excel is easy to use and easy to access but it has limitations for database It is too fragile to keep the data too easy to delete data too easy to inject unit errors and hard to maintain a consistent format New or undefined data fields may destroy the existing format and lead to lsquodata holesrsquo Furthermore it can be problematic when exporting data into required formats for testing
Schlumberger multiphase steady-state database can import experimental data records with a specific format Data records are initially imported into lsquoRaw Tablersquo from the formatted excel file The data records of lsquoRaw Tablersquo move to final lsquoDatabase Tablersquo after unit conversions through lsquoRaw Archive Tablersquo The database can export data records to excel files in PipeSim OpenLink format or in general format
Future Work All the available data records will be imported into MS Access Database And the user interface of database will be improved to be more useable and convenient
157
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46
Table 1 List of TUFFP Gas-Liquid Experimental Data Sets No Project Author Year
2 Charles Martin Palmer 1975 3 George Andrew Payne 1975 4 Zelimer Schmidt 1976 5 Sirisak Juprasert 1976 12 Myles Wilson Scoggins Jr 1977 13 Zelimir Schmidt 1977 14 N D Sylvester R Dowling H Paz-y-Mino and J P Brill 1977 16 Hemanta Mukherjee 1979 21 Imoh Boniface Akpan 1980 29 Orlando E Fernandez 1982
33 Santanu Barua 1982 36 Kazuioshi Minami 1983 44 Kunal Dutta-Roy 1984
45 Elisio Caetano Filho 1984 52 Elisio Filho Caetano 1985 63 Stuart L Scott 1989
64 Guohua Zheng 1989 67 Carlos Alfredo Daza 1990
72 Masaru Ihara 1991 73 Guohua Zheng 1991
74 Ibere Nascentes Alves 1991 75 Kazuioshi Minami 1991 77 Hector Felizola 1992
80 Rafael Jose Paz Gonzalez 1993 81 Philippe Roumazeilles 1994 82 Fabrice Vigneron 1995
86 James P Brill X Tom Chen Jose Flores and Robert Marcano 1995 89 Jiede Yang 1996 90 Robert Marcano 1996 95 Weihong Meng 1999 96 Eissa Mohammed Al-Safran 1999 NA Jarl Tengesdal 2002 101 Qian Wang 2003 102 Eissa Mohammed Al-Safran 2003 103 Yongqian Fan 2005
104 Pipeline Databank 104 Wellbore Databank
106 Bahadir Gokcal 2005 110 Bahadir Gokcal 2008
111 TingTing Yu 2009 113 Kyle Magrini 2009 115 Ceyda Kora 2010
116 Benin Chelinsky Jeyachandra 2011 117 Ge Yuan 2011 119 Rosmer Brito 2012 120 Mujgan Guner 2012
158
Table 2 List of TUFFP Oil-Water Experimental Data Sets No Project Author Year 1 1 Mark Steven Malinowski 1975 2 9 George Clarence Laflin and Kenneth Doyle Oglesby 1976 3 11 Hemanta Mukhopadhyay 1977 4 17 Kenneth D Oglesby 1979 5 37 Srihasak Arirachakaran 1983 6 51 Alberto E Martinez 1985 7 88 Jose Luis Trallero 1995 8 91 Jose Gonzalo Flores 1997 9 97 Banu Alkaya 2000 10 107 Maria Andreina Vielma Paredes 2007 11 108 Serdar Atmaca 2007
Table 3 List of TUFFP Gas-Oil-Water Experimental Data Sets No Project Author Year 1 1 Mark Steven Malinowski 1975 2 9 George Clarence Laflin and Kenneth Doyle Oglesby 1976 3 104 Carlos Beltran 2005 4 109 Hongkun Dong 2007 5 114 Gizem Ersoy Gokcal 2010
159
160
Fluid Flow Projects
Unified Drift Velocity Closure Relationship for Large Bubbles
Rising in Viscous Fluids
Jose Moreiras
Advisory Board Meeting April 17 2013
Outline
Objective
Introduction
Experimental Study
Modeling Approach
Conclusions
Fluid Flow Projects Advisory Board Meeting April 17 2013
161
Objective
Analyze Drift Velocity for Medium Viscosity Oils (39 cP lt microO lt 166 cP) Inclination Angle from 0ordm to 90ordm
Pipe Diameter 2-in
Develop a Unified Drift Velocity Correlation which Considers Viscosity Effects
Inclination Angle Effects
Pipe Diameter Effects
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction
TUFFP Oil Viscosity Effect Effort
High Viscosity (180 cP lt microO lt 576 cP) Gokcal (2005)
Gokcal (2008)
Kora (2010)
Jeyachandra (2011)
Medium Viscosity (39 cP lt microO lt 166 cP) Brito (2012)
Fluid Flow Projects Advisory Board Meeting April 17 2013
162
Introduction hellip
Expression for Translational Velocity and Drift Velocity
Nicklin et al (1962)
v = C v +vt o M d
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction hellip
Potential Flow Analysis for Drift Velocity
Vertical Flow ndash Dumitrescu (1943) Davies and Taylor (1950)
vd 0351 gD
Horizontal Flow ndash Benjamin (1968)
vd 0542 gD
Fluid Flow Projects Advisory Board Meeting April 17 2013
163
Introduction hellip
Dimensionless Numbers Froude Number
05 05Fr v g D ( )d L L G
Eotvos Number
2 1N g D ( )Eo L G
Viscosity Number 053N g D ( ) L G L
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Study
Test Liquid DN-20 Mineral Oil Gravity 305 degAPI
Density 873 kgm3 60 degF
Surface Tension 275 dynescm
Test Gas Air
High Speed Video Recording
Fluid Flow Projects Advisory Board Meeting April 17 2013
164
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Study hellip
Experimental Facility Layout
High Speed Camera
Experimental Study hellip
Pipe Diameter 2-in
Viscosities 39 66 108 166 cP
Inclinations 0o10o 20o 30ohellip90deg
Uncertainty Analysis ASME Uncertainty Model
Five Repetitions per Condition
Fluid Flow Projects Advisory Board Meeting April 17 2013
165
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Result
0deg 2-in ID microO=39 cP 0deg 2-in ID microO=166 cP
Fluid Flow Projects Advisory Board Meeting April 17 2013
01
02
03
04
05
0 10 20 30 40 50 60 70 80 90
Vd
[ms
]
θ [ordm] Bendiksen (1984) 166 cp 66 cp 39 cp Gokcal (2008)-1cp Gokcal (2008)-185cp Gokcal (2008)-1287cp
Experimental Result hellip
Inclined (2-in Pipe) )cos(gD)sin(gD 54203510
166
Modeling Approach
Extended Database Author Fluid Properties Pipe Geometry
Zukoski (1966) ρL=1000 kgm3
microL=0001 Pa s σ=0072 Nm
θ= 0 to 90ordm D=0055 and 0178-m
Webber et al (1986) ρL=1280 to 1410 kgm3
microL=00511 to 612 Pa s σ=0078 to 0087 Nm
θ= 0 to 90ordm D=00373-m
Gokcal (2008) ρL=889 kgm3
microL=0104 to 0692 Pa s σ=0029 Nm
θ= 0 to 90ordm D=00508-m
Jeyachandra et al (2012) ρL=889 kgm3
microL=0154 to 0574 Pa s σ=0029 Nm
θ= 0 to 90ordm D=00762-m
This Study ρL=870 kgm3
microL=0039 to 0166 Pa s σ=00275 Nm
θ= 0 to 90ordm D=00508-m
Fluid Flow Projects Advisory Board Meeting April 17 2013
Modeling Approach hellip
Minimum Eotvos Number (NEo) = 220
Wallis (1969) Surface Tension Effects are Negligible for NEo gt100
Universal Correlation is Subdivided Horizontal Flow
Vertical Flow
Inclined Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
167
Modeling Approach hellip
Horizontal Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
Nba
NFr
540
00350
1a
014430
250886
89602
b
r
Modeling Approach hellip
Vertical Flow Potential flow solution for cap shaped
bubbles extended to long bubbles (Taylor Bubbles) by Davis and Taylor (1950)
Viscous potential flow solution for cap shaped bubbles by Joseph (2003) is extended to long bubbles in this study
Davis and Taylor (1950)
Fluid Flow Projects Advisory Board Meeting April 17 2013
168
Fluid Flow Projects Advisory Board Meeting April 17 2013
Modeling Approach hellip
Vertical Flow
0
02
04
06
08
0 02 04 06 08
v d C
alcu
late
d [m
s]
vd Experimental [ms]
2
2
9
64
9
2
3
8
D Dg
Dv
L
L
L
L d
Original Cap Shaped Bubble Long Taylor Bubble
Dg
D Dg
Dv
L
L
L
L d
350
3
2
9
64
9
2
3
8 2
2
0
02
04
06
08
0 02 04 06 08
v d C
alcu
late
d [
ms
]
vd Experimental [ms]
Modeling Approach hellip
Inclined Flow
Fr Fr cos( )a Fr sin( )b QH V
0 FrV FrH 0
Q dc Fr Fr sin( ) (1 sin( )) Fr Fr 0 V H V H
Parameter Value 95 Confidence Interval a 12391 00872 b 12315 01150 c 21589 14764 d 070412 02926
Fluid Flow Projects Advisory Board Meeting April 17 2013
169
2 in Oil
Modeling Approach hellip
1st Step-Horizontal Flow FrH 054 N
a b N
2nd Step-Vertical Flow 8 L 2 64 L
2 2 vd g D 2 035 g D 3 D 9 9 D 3L L
05 05Fr v g D ( )V d L L G
a b 3rd Step-Inclined Flow Fr Fr cos( ) Fr sin( ) QH V
4th Step-Drift Velocity Fr d 05 05v
g D ( )L L G
Fluid Flow Projects Advisory Board Meeting April 17 2013
Modeling Approach hellip
- Air- System
Fluid Flow Projects Advisory Board Meeting April 17 2013
170
Conclusions
Increase in Liquid Viscosity Reduces the Drift Velocity
A New Correlation is Proposed
Valid for Dgt003-m and from 0deg to 90deg Inclination Angles
Additional Experimental Data is Required for 10-4ltNlt10-3
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Questions
171
172
Unified Drift Velocity Closure Relationship for Large Bubbles Rising in Viscous Fluids
Jose Moreiras
Project Completion Dates Data Acquisition Completed Data Analysis Completed Unified Correlation Completed Final Report May 2013
Objective The main objective of the study is
To Analyze Drift Velocity for Medium Viscosity Oils (39 cP lt microO lt 166 cP)
o Inclination Angle from 0ordm to 90ordm o Pipe Diameter 2-in
Develop a Universal Drift Velocity Correlation which Considers
o Viscosity Effects o Inclination Angle Effects o Pipe Diameter Effects
Introduction Nearly 70 of the available oil reserves correspond to heavy oils which possess high density and viscosity Depletion of lighter hydrocarbon resources has increased the importance of high viscosity oils A thorough knowledge on the flow behavior of high viscosity oils is required to design and optimize production facilities The existing multiphase flow models were developed using data collected for low viscosity oils Hence these models inherently neglect the effect of viscosity on flow characteristics of multiphase flow
TUFFP initiated a research campaign to further understand the gas-liquid behavior in 2003 Gokcal (2005) experimentally studied the effects of high viscosity on two phase oil-gas flow He observed a marked difference between the experimental results and the model predictions Intermittent slug and elongated bubble flow were observed to be the dominant flow pattern Later Gokcal (2008) conducted experiments and developed correlations for two phase slug flow characteristics taking into account the effects of viscosity The parameters studied were pressure gradient drift velocity transitional velocity and slug length and frequency All tests were conducted for horizontal flow and oil viscosities range from 121 cp to 1000 cP Kora (2010) conducted experiments and developed correlations for slug liquid holdup in horizontal high viscosity oil-gas flow Jeyachandra (2011) studied the effect of the inclination angle for horizontal and near horizontal flow
In general all the previous studies in high viscosity oils (180 cP lt microO lt 587 cP) demonstrated big difference in two-phase flow behavior as compared to low viscosity oils Brito (2012) carried out an experimental study to analyze the medium viscosity oil (39 cP lt microO lt 166 cP) effect on two-phase flow behavior She analyzed the change in pressure drop flow pattern liquid holdup and flow characteristics in a 2-in ID horizontal pipe Drift velocity corresponds to an important parameter for slug characterization which has not been measured before in the viscosity range considered by Brito (2012) The current study is part of the TUFFP effort to understand the medium oil viscosity effect in two-phase flow investigating the drift velocity under this viscosity range for horizontal and inclined flow
Experimental StudyThe experimental study is composed of the experimental facility our test fluid and an experimental matrix
Facility The experimental facility consists of an oil storage tank a 20 HP screw pump a 305-m (10 ft) long acrylic pipe with 1524-mm (6 in) ID heating and cooling loops transfer hoses and instrumentation Additional experiments will be conducted by replacing the 6 in with 2 in ID pipe The acrylic pipe is located close to the storage tank The inclination of the pipe can be varied using a pulley arrangement The pipe inclination can be changed from 0deg to 90deg The heating and cooling loops are used to maintain the desired temperature and thereby control the viscosity of the oil
The oil pump supplies the pipe with oil Then the main inlet valve and the auxiliary inlet valve are closed The drainage valve is opened to drain the residual oil captured and thus create a gas pocket Next the drainage valve is closed and the main inlet valve is opened to release the gas bubble into the stagnant oil column The drift velocity is measured by high speed video recordings A modification was carried out for the horizontal case The pipe end was removed and it was replaced with plug The removal
173
of the plug after the pipe is filled drains the oil out and a gas bubble penetrates into the pipe enabling the measurement of drift velocity in a horizontal pipe
Test Fluids Compressed air has been considered for the gas phase and typical properties of the DN-20 mineral oil used in these tests are given as follows
Gravity 305 degAPI
Viscosity 0166 Pamiddots 211degC
Density 873 kgm3 156degC
Surface tension 00275 Nm 40degC
Experimental Matrix Drift velocity will be acquired for the following conditions
Pipe diameter 2-in Inclination angle 0deg 10deg 20deg 30deg 40deg 50deg
60deg 70deg 80deg and 90deg Oil Viscosity 39 cP 66 cP 108 cP and 166
cP For a given pipe diameter inclination angle and
oil viscosity the average drift velocity is collected after five repetitions Uncertainty is estimated by the ASME model where the bias term is neglected and the random component is estimated based on five repetitions
Modeling ApproachDrift velocity in inclined pipes described a convex curve as function of inclination angle The shape of this curve is defined by the values of the drift velocity in horizontal and vertical flow Drift velocity correlations for horizontal and vertical flow are proposed and extended to inclined flow The experimental data collected in this study is combined with literature data Only pipe diameters larger than 003-m has been considered form the following Authors
1 Zukoski (1966) 2 Webber et al (1986) 3 Gokcal (2008) 4 Jeycandra (2011)
Horizontal Flow In the extended experimental data base presented the Eotvos number varies from 220 to 800 The minimum Eo is at least two times larger than the critical value proposed by Wallis (1969) to define the region where surface tension effects can be neglected (Eogt100) Based on Zukoski (1966) observations this critical value is even smaller (Eogt40) thus in this study the surface tension effect is neglected
A correlation for the Froude number as function of Viscosity number has been developed As the Viscosity number tends to zero the Froude number tend to the potential flow solution On the other hand as the Viscosity number increases the drift velocity tends asymptotically to zero Thus this correlation can be utilized for low and high liquid viscosities
Vertical Flow Joseph (2003) extended Davis and Taylor (1950) analysis in cap bubbles using viscous potential flow analysis The proposed model is function of viscosity density and pipe diameter For long bubble (Taylor bubble type) Joseph (2003) shows a systematic bias with respect to experimental data in vertical flow As the viscosity tends to zero Joseph (2003) solution tends to Davis and Taylor (1950) solution (constant Froude number) who also proposed an extension of cap model to long bubbles The extension results in a modification of the final Froude number This difference in the potential flow solution from cap to long bubble can explain the bias presented by Joseph (2003) where the discrepancy can be corrected in similar way than Davis and Taylor (1950) by subtracting the difference of potential solution
Inclined Flow The Froude number in any inclination can be predicted by a combined effect of horizontal and vertical Froude A correlation for Froude number as function of inclination angle horizontal and vertical Froude numbers are estimated using the two previous correlations
Conclusion This study presents new drift velocity experimental data for medium oil viscosities (39 lt microLlt166 cP) and all inclination angles The new set of data has been combined with other data available in the literature to develop a universal correlation for drift velocity The correlation is subdivided into three parts as function of inclination angle namely horizontal vertical and inclined In general the minimum Eotvos number is 220 thus all data points are laid in a region where surface tension effect can be neglected (Wallis 1969) The proposed horizontal correlation for Froude number is a unique function of viscosity number and as the viscosity tends to zero the solution tends to potential flow For the verical case Joseph (2003) solution for caps bubbles has been modified to long bubbles following a similar procedure as Davis and Taylor (1950) Finally a general correlation for Froude number in inclined pipes is proposed which
174
depends on the estimated Froude number for horizontal and vertical flow
References Brito R Effect of Medium Oil Viscosity on Two-Phase Oil-Gas Flow Behavior in Horizontal Pipes MS Thesis
The University of Tulsa Tulsa OK (2012) Davies R M and Taylor G I ldquoThe Mechanics of Large Bubbles Rising Through Liquids in Tubesrdquo Proc Royal
Soc London A 200 pp 375-390 (1950) Gokcal B ldquoAn Experimental and Theoretical Investigation of Slug Flow for High Oil Viscosity in Horizontal
Pipesrdquo PhD Dissertation The University of Tulsa Tulsa OK (2008) Gokcal B ldquoEffects of High Oil Viscosity on Two-Phase Oil-Gas Flow Behavior in Horizontal Pipesrdquo MS Thesis
The University of Tulsa Tulsa OK (2005) Jeyachandra B ldquoEffect of Pipe Inclination on Flow Characteristics of High Viscosity Oil-Gas Two-Phase Flow
MS Thesis The University of Tulsa Tulsa OK (2011) Joseph D D ldquoRise velocity of a Spherical Cap Bubblerdquo J Fluid Mech Vol 488 pp 213-223 (2003) Kora Effects of high oil viscosity on slug liquid holdup in horizontal pipes MS Thesis The University of Tulsa
2010 Weber ME Alarie A and Ryan M E ldquoVelocities of Extended Bubbles in Inclined Tubesrdquo Chem Eng Sci
Vol 41 pp 2235-2240 (1986) Zukoski E E ldquoInfluence of Viscosity Surface Tension and Inclination Angle on Motion of Long Bubbles in
Closed Tubesrdquo J Fluid Mech Vol 25 pp 821-837 (1966) Gokcal B Al-Sarkhi A and Sarica C Effects of High Oil Viscosity on Drift Velocity for Horizontal Pipes
Presented at BHR Conference of Multiphase Production Technology Banff June 4-6 (2008) Kora Y Effects of high oil viscosity on slug liquid holdup in horizontal pipes MS Thesis The University of
Tulsa Tulsa OK (2010) Benjamin TB ldquoGravity Currents and Related Phenomenardquo J Fluid Mech (1968) 31 (2) 209-248
175
176
Fluid Flow Projects
Characteristics of Downward Flow of High Viscosity Oil and
Gas Two-Phase
Jaejun Kim
Advisory Board Meeting April 17 2013
Outline
Objective
Introduction
Experimental Program
Static Calibration
Dynamic Calibration
Future Work
Fluid Flow Projects Advisory Board Meeting April 17 2013
177
Objective
Acquire Experimental Data on Flow Characteristics for High Viscosity Oil-Gas Two-Phase Flow in Downward Inclined Pipes Viscosity Effects
Validate ModelsCorrelation with Experimental Results
Fluid Flow Projects Advisory Board Meeting April 17 2013
Introduction
Increase in High Viscosity Oil Offshore Discoveries Current Multiphase Flow Models
Developed for Low Viscosity Oils Multiphase Flows May Exhibit
Significantly Different Behavior for Higher Viscosity Oils Horizontal Flow Experiments ndash Gokcal
(2005 2008) and Kora (2010)
Fluid Flow Projects Advisory Board Meeting April 17 2013
178
179
Introduction hellip
Jeyachandra (2011) Carried Out Experiments for plusmn2deg Repeatability has not been Verified by
Jeyachandra (2011)
Repeat Tests are Necessary to Improve the Confidence on the Collected Data
Facility Instrumentation and Uncertainty Analysis has been Upgraded by Brito (2012)
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Facility
CPU
Air
12345
Ma x
Mi n Z er o C onf ig E nt e r
Air Valves Laser Capacitance
Probe Probe
Fluid Flow Projects Advisory Board Meeting April 17 2013
Experimental Matrix
Superficial Liquid Velocity 01 ndash 08 ms
Superficial Gas Velocity 01 ndash 35 ms
Temperatures 70 ndash 100 degF (211 ndash 378 degC ) 585 ndash 181 cP
Inclination -2deg from Horizontal
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Downward Inclined Flow vs TUFFP Model Prediction
0001
001
01
1
10
001 01 1 10 100
v SL
(m
s)
vSG (ms)
Elongated Bubble
Slug Flow
Dispersed
Intermittent
Stratified Annular
0001
001
01
1
10
001 01 1 10 100
v SL
(m
s)
vSG (ms)
Elongated Bubble
Slug Flow
Stratified
Dispersed Bubble
Intermittent
Stratified
Annular
585 cP 181 cP
180
Fluid Flow Projects Advisory Board Meeting April 17 2013
Downward Inclined Flow vs Barnea Model Prediction
0001
001
01
1
10
001 01 1 10 100
v SL
(m
s)
vSG (ms)
Slug
Elongated Bubble
Dispersed Bubble
Elongated Bubble
Stratified
Slug
Annular
0001
001
01
1
10
001 01 1 10 100
v SL
(m
s)
vSG (ms)
Slug Flow
STRATIFIED
Elongated Bubble
Dispersed Bubble
Elongated Bubble
Stratified
Slug
Annular
585 cP 181 cP
Two Phase Flow Characteristics
Flow Pattern Pressure Gradient Average Liquid Holdup Slug Characteristics Slug Length Slug Frequency Slug Liquid Holdup Translational Velocity Drift Velocity
Fluid Flow Projects Advisory Board Meeting April 17 2013
181
Fluid Flow Projects Advisory Board Meeting April 17 2013
Capacitance Sensor
Two-wire
Capacitance Sensor
Capacitance Sensors Location
0030 DIA
025
200
Fluid Flow Projects Advisory Board Meeting April 17 2013
Capacitance Sensor Static Calibration hellip
Static Calibration
0
01
02
03
04
05
06
07
08
09
1
0 02 04 06 08 1
Cap 2
Cap 3
H L
V
182
Fluid Flow Projects Advisory Board Meeting April 17 2013
Static Calibration at 70 degF and 90 degF
0 02 04 06 08
1
0 05 1
H LS
V 90F 70F
0 02 04 06 08
1
0 1
H L
V
90F 70F
0 02 04 06 08
1
0 1
H L
V
90F 70F
0 02 04 06 08
1
0 05 1
H L
V 90F 70F
0 02 04 06 08
1
0 1
H L
V
90F 70F
0 02 04 06 08
1
0 1
H L
V
90F 70F
Cap 2 Cap 3 Cap 4
Cap 5 Cap 6 Cap 7
Fluid Flow Projects Advisory Board Meeting April 17 2013
Dynamic Calibration
Quick Closing valve
183
Future Work
Data Collection May 2013
Data Analysis May 2013
Model Comparison June 2013
Report June 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Thanks hellip
Fluid Flow Projects Advisory Board Meeting April 17 2013
184
Questions
Fluid Flow Projects Advisory Board Meeting April 17 2013
185
186
Characteristics of Downward Flow of High Viscosity Oil and Gas Jaejun Kim
Project Completion Dates Static Calibration February 2013 Dynamic Calibration March 2013 Data Collection April 2013 Data Analysis May 2013 Modeling Comparison May 2013 Report June 2013
Objectives The objective of this study is to investigate the flow characteristics of downward flow of high-viscosity oil and gas A complete study was conducted by Jeyachandra (2011) The repeat tests are needed to verify Jeyachandra results
Introduction One of the most important phenomena in the petroleum industry is gas-liquid two phase flow in pipes which commonly occurs during production and transportation Various arrangements of two phases flowing in the pipe are called lsquoflow patternsrsquo The type of the flow pattern depends on the flow rate of gas and liquid diameter of the pipe inclination angle of the pipe and properties of fluid such as viscosities densities of gas and liquid and surface tension Typical flow patterns for downward flow are stratified stratified wavy slug elongated bubble annular and dispersed bubble flow Since flow patterns have an influence on design parameters and operations it is vital to understand their behavior
The slug flow is the most common flow pattern in high viscosity oil gas-liquid two phase flow (Gokcal et al 2005) The slug flow is divided into slug (liquid) liquid film (bubble) regions There is a great difference between liquid holdup of film and slug regions Thus the liquid holdup of the slug flow is classified as HLslug (liquid holdup of slug region) and HLfilm (liquid holdup of film region) For the measurement of the liquid holdup of slug flow capacitance sensors which are based on the difference in the dielectric constants of the two phases can be used By using this difference capacitance sensors can detect the liquid fraction in a gas-liquid two phase flow in pipes
The experiments will be performed for the inclination angle of -2deg and oil viscosities from 0585 Pamiddots to 0181 Pamiddots
Experimental Study Facility The indoor high viscosity oil-gas facility is being modified to perform experiments to study the
inclination effects The capacity of the oil storage tank is 303m3 A 20 HP screw pump is used to push the liquid through the loop Air is delivered through a dry rotary screw type compressor The oil and the air mix in a tee junction before proceeding to the test section
The facility is comprised of a metering section a test section a heating system and a cooling system The test section is 189 m (62 ft) long 508 mm (2 in) ID pipe Nearly half of the pipe is made of a clear PVC pipe section and the rest is transparent acrylic pipe section
A 915-m (30 ft) long transparent acrylic pipe section is used to observe the flow behavior visually A flexible hose connects the test section with the 762 mm (3 in) ID return pipe An oil transfer tank (132 m3) is located at the end of return pipe Return pipe is connected to this tank with a flexible hose 3-hp progressing cavity pump is used to pump the oil from the new tank back to the main tank through the riser The oil flow rates are measured at the inlet of the facility using Micro Motion mass flow meters (CMF025 CMF100 and CMF300) The air is measured at the inlet of the facility using Micro Motion mass flow meters (CMF025 and CMF050)
Separation is accomplished by gravity segregation of air and oil The separated air is removed through the ventilation system The test section is supported on stands and the inclination of the test section can be set from -2deg to 2deg from horizontal by adjusting the heights of the stands
The viscosity of the oil is controlled by controlling the temperature of oil at the tank A 20 KW Chromalox heater capable of heating the heavy oil from 70degF to 140degF is used The heating and the cooling section thus play a major part in the experiment to control the viscosities Resistance Temperature Detector (RTD) transducers measure the temperatures during experiments Pressure transducers and differential pressure transducers are located at different places to measure pressure and pressure drop in the loop
187
Test Fluids The high viscosity oil of this study is CITGO Sentry 220 The gas phase used is compressed air Following are the typical properties of the oil Gravity 276 degAPI Viscosity 0220 Pamiddots 40 degC Density 889 kgm3 156 degC Surface tension 003 Nm 40 degC
Instrumentation and Measurement Flow Patterns
TUFFP high speed video system is used to identify the flow patterns
Differential Pressure (DP) There are 4 differential pressure transducers on the flow loop DP1 and DP2 are located at the PVC section of the loop and are used for monitoring the development of flow DP3 and DP4 located at the acrylic section are used for measuring the differential pressure
Slug Length Slug Frequency and Translational Velocity
The acrylic section has provision for 2 laser sensors which when coupled with data acquisition system provide the data for slug length slug frequency and translational velocity
Liquid Holdup The most challenging part of this study is to measure gas void fraction in liquid slugs For the measurement of slug liquid holdup capacitance sensor has been used A summary of the capacitance sensor and the static calibration that was conducted is given below
Capacitance Sensor The two-wire capacitance sensor is used in this study This sensor consists of two parallel copper wires positioned perpendicular to the flow at a distance of 025 in This sensor requires an electronic circuit to filter amplify and convert the measured capacitance to a voltage The MS3110 Universal Capacitive Readout IC has been utilized to convert the capacitance of the mixture to a 0 to 5 volt signal It is equipped with a low pass filter providing an ultra-low noise and high resolution capacitive readout
Static Calibration Static calibration of CS was accomplished by placing different amounts of liquid volumes in an acrylic pipe tester with the CS in the middle and measuring the height of the fluid in the pipe then recording the corresponding sensor output voltage The actual
voltage reading was then converted to a dimensionless voltage
The corresponding liquid holdup was calculated as the ratio of the volume of the liquid injected and the total volume of the tester A graph of dimensionless voltage vs liquid holdup was plotted and the resulting curve is the static calibration curve The shape of the curve is S-shaped and is expected because of the shape effect of the pipe During the initial phase and final phase of injection oil wets the perimeter of the pipe quickly compared to the middle phase where the wetting is almost linear
Effect of the Oil Temperature on the Output Signal
In addition to the conventional static calibration procedure the effect on the oil temperature on the capacitance sensor output signal has to be evaluated For this several oil volumes at different temperatures are placed in an acrylic pipe connected to the capacitance sensor As a result it was observed that output voltage has no relation with oil temperature This justifies that there is no necessity to read the each fluid temperature in order to predict and accurate liquid holdup
Dynamic Calibration Dynamic calibration of CS will be conducted using existing quick-closing valve system (QCV) CS QCV and high speed video camera should be synchronized CS will be placed 15 ft before the quick-closing valve system Shortly before capturing the slug body with QCV data collection process with CS will be started High speed video camera is used to verify the trapped part of the slug body for the analysis of the CS reading The dynamic calibration plot should be generated by plotting the actual liquid holdup data (QCV measurement) versus the calculated liquid holdup data (capacitance sensor output) at different test conditions Finally in order to calculate the liquid holdup in the slug body numerical integration is used to estimate the area under the curve and it is divided by the area as if the liquid slug is pure oil
Data Processing An excel macro was develop by Brito (2012) to process the raw data and verify its quality through an uncertainty analysis This excel macro calculates the average standard deviation and uncertainty of the all measured and estimated parameters The considered parameters are pressure gradient absolute pressure liquid temperature mass flow rate fluid properties (density and viscosity) superficial velocities mixture velocity mixture Reynolds number and average liquid holdup In addition if the slug flow is
188
observed additional parameters are calculated namely average liquid holdup in the film region average liquid holdup in the slug region number of slugs slug frequency translational velocity slug length and slug length distribution
Future Work The static and dynamic calibration has already been completed Data collection will be carried out during April Data analysis and modeling comparison will be finalized in May
References Dieck R Measurement Uncertainty Method and Applications Fourth Edition (2007) Hernandez V Gas-liquid Two-phase Flow in Inclined Pipes The University of Nottingham School of Chemical
Environmental and Mining Engineering (2007) Al-safran E An Experimental Study of Two-Phase Flow in a Hilly-Terrain Pipeline MS Thesis The University
of Tulsa (1999) Gokcal B Al-Sarkhi A S Sarica C and Al-Safran M E Prediction of Slug Frequency for High-Viscosity
Oils in Horizontal Pipes SPE Projects Facilities amp Construction Vol 5 (2010)
189
190
Fluid Flow Projects
Effect of High Oil Viscosity on Oil-Gas Flow Behavior in Vertical and
Highly Deviated Pipes
Feras Alruhaimani
Advisory Board Meeting April 17 2013
Outline
Objectives
Facility
Test Fluid
Test Matrix
Data Gathering amp Processing
Future Activities
Fluid Flow Projects Advisory Board Meeting April 17 2013
191
Objectives
Conduct Experimental and Modeling Study on High Oil Viscosity (gt180 cP) Two-phase Flow in Vertical and Highly Deviated Pipes
Improve Existing Closure Relationships Used in Available Mechanistic Models
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Three-phase Flow Facility
192
Fluid Flow Projects Advisory Board Meeting April 17 2013
Three-phase Flow Facility hellip
Test Section Two (2 in ID) 212-m (693-ft) Long Pipes
Connected with U-shaped Bend
Three-phase Flow Facility hellip
Test Section
QCV System
Visua lizatio n Box
Fluid Flow Projects Advisory Board Meeting April 17 2013
193
Three-phase Flow Facility hellip
Return Pipe
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Test Fluids
Lubsoil ND 50 (ISO 220)
194
Test Matrix
Viscosity 181 ndash 587 cP
Inclination Vertical Highly Deviated (90deg to 75deg)
Superficial Liquid Velocity 005 ndash 2 ms
Superficial Gas Velocity 05 ndash 5 ms
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Flow Pattern
= 378 cp = 90o
0001
001
01
1
10
001 01 1 10 100
v SL
(ms
)
vSG (ms)
INTANN
INTD-B
INTBUB
Inlet Condition
195
Fluid Flow Projects Advisory Board Meeting April 17 2013
Flow Pattern
= 378 cp = 75o
0001
001
01
1
10
001 01 1 10 100
v SL
(ms
)
vSG (ms)
INTANN
INTD-B
INTBUB
Inlet Condition
Data Gathering amp Processing
Low Speed Data
(1 to 10 Hz)
Pressure
Pressure Gradient
Temperature
Mass Flow-rates
Densities
Viscosities
Superficial Velocities
High Speed Data
(1000 Hz) ldquoCapacitance Sensorsrdquo
Translation Velocity
Average Slug Length
Slug Length Distribution
Slug Frequency
Slug Liquid Holdup
Film Liquid Holdup
Average Liquid Holdup
Videos
Digital
High Speed
Fluid Flow Projects Advisory Board Meeting April 17 2013
196
Low Speed Data
A Matlab Macro has been Created to Calculate Average and Uncertainty for All The Low Speed Raw Data
Uncertainty is Calculated Using ISO Uncertainty Model
Fluid Flow Projects Advisory Board Meeting April 17 2013
High Speed Data
High Speed Data is Required for Slug Characterization
Capacitance Sensor Must be Properly Calibrated Static Calibration
Dynamic Calibration
A Matlab Macro is being Created to Process Capacitance Sensor Signals
Fluid Flow Projects Advisory Board Meeting April 17 2013
197
Fluid Flow Projects Advisory Board Meeting April 17 2013
High Speed Signal Processing
2 Capacitance Sensors
distance L
CS1CS2
Fluid Flow Projects Advisory Board Meeting April 17 2013
High Speed Signal Processing hellip
Slug Region Identification Threshold
Derivative
198
Static Calibration
Performed Static Calibration on 10 Capacitance Sensors
To Find Best Repeatable Sensors to Be Used in Test Section
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Static Calibrationhellip
199
Future Activities
Completion Dates
Literature Review Ongoing
Sensor Calibration Ongoing
Signal Processing Macros Ongoing
Facility Modifications April 2013
Experimental Program May 2014
Final Report December 2014
Fluid Flow Projects Advisory Board Meeting April 17 2013
Questions amp
Comments
Fluid Flow Projects Advisory Board Meeting April 17 2013
200
Effect of High Oil Viscosity on Oil-Gas Flow Behavior in Vertical and Highly Deviated Pipes Feras Alruhaimani
Project Completion Dates Literature Review Ongoing Sensor Calibration Ongoing Signal Processing Macros Ongoing Facility Modification April 2013 Experimental Program May 2014 Final Report December 2014
Objective The objective of this study is to conduct experimental and modeling study on oil-gas two-phase flow using high oil viscosity (180 cPlt microOlt 587 cP) in vertical and highly deviated pipes Acquired data will be used to verify and improve the closure relationships used for the existing mechanistic models
Introduction With the continuous need of hydrocarbon resources and decline in light oil reserves heavy oils became a very important source of hydrocarbons Most two-phase flow models in literature were based on experimental data using low viscosity oils (microO lt 20 cP) Therefore studies on the effect of high oil viscosity on two-phase flow parameters are necessary to verify the performance of available mechanistic models for high viscosity oils
TUFFP conducted experimental studies on two-phase gas-liquid flow using high oil viscosity (microO gt 180 cP) for horizontal and slightly inclined pipes (plusmn2o) These studies investigated the effect of oil viscosity on two-phase flow parameters such as flow pattern pressure drop liquid holdup and slug characteristics The results from these studies were used to improve existing mechanistic models for high oil viscosity multiphase flow
Other studies on high oil viscosity were conducted by TUHOP for two-phase gas-oil flow in vertical pipes (Akhiyarov 2010) and three-phase gasshyoil-water flow in horizontal and upward vertical pipes (Wang 2012) In the experimental work of these studies pressure drop and average liquid holdup were measured but no slug characteristics were acquired
This study is part of the high oil viscosity efforts initiated by TUFFP and is focused on the effect of high liquid viscosity on vertical and highly deviated gas-liquid two-phase flow In addition to pressure drop flow pattern and liquid holdup slug characteristics are studied
Experimental Work Experimental work is subdivided into experimental facility test fluids and experimental program as follows
Experimental Facility The experimental work will be carried out in the TUFFP 2 in ID three-phase flow facility The facility consists of a closed circuit loop with storage tanks separator progressive cavity pumps heat exchangers metering and test sections The metering sections are equipped with Micro Motiontrade Corriolis flow meters to measure mass flow rates and densities of the fluids and with temperature transducers for monitoring temperatures The test section is attached to an inclinable boom that can be raised to upward vertical position
The new test section is designed as a 508-mm (2-in) ID 211-m (693-ft) long pipe consisting of a transparent polycarbonate pipe section to visually observe flow behavior It is connected to a 211-m (693-ft) long 508-mm (2-in) ID return pipe which is set parallel to the test section at the same height The instrumentations are mounted on the pipe section for detailed measurements of the flow characteristics
Test Fluids The fluids used in the experiments are mineral oil and compressed air Lubsoil ND-50 is selected due to its high viscosity and Newtonian behavior in the testing range The physical properties of the oil are given below
API gravity 285deg Pour and flash point temperatures -15 degC (5
degF) and 265 degC (510 degF) respectively Surface tension 3575 dynescm at 198 degC
(68 degF) and atmospheric pressure Density 8844 kgm3 standard condition
Experimental Program The experiments will be conducted using air and oil in vertical and highly deviated pipe (90o to 75o) The
201
oil viscosity will vary from 181 to 587 cP The ranges of superficial liquid and gas velocities are 005 to 2 ms and 05 to 3 ms respectively
Experiments will be conducted to acquire flow pattern measure pressure drop liquid holdup and slug characteristics The experimental results will be used to validate the performance of existing models New closure relationships will be developed as needed
Instrumentation The test section is equipped with two differential pressure transducers for pressure gradient measurements Additionally four quick closing valves are installed for holdup measurement and bypassing Two of these quick closing valves are utilized to capture either the slug body or bubble region Two optical sensors are used to distinguish between the two regions Slug characteristics are obtained from the two wire type capacitance sensors Moreover high speed video camera and surveillance cameras will be used to observe the slug flow development and monitor the oil and air mixing status
The return pipe has one differential pressure transducer two quick closing valves and two wire type capacitance sensors
Capacitance Sensor Seven capacitance sensors will be installed in the test section two at the entrance two in the middle two toward the end and one at the end of the test section They are used to analyze the evolution of the slug characteristics as well as the average liquid holdup
Two additional capacitance sensors will be placed in the return pipe to study also the downward flow
Data Gathering and Processing The generated data can be divided as follows low speed high speed and video recording
Low speed data include pressure pressure gradient temperature mass flow rates densities viscosities and superficial velocities High speed data are voltage readings from the capacitance sensors To ensure the accuracy of the high speed data capacitance sensors must be properly calibrated
Static calibration has been conducted on ten capacitance sensors to determine best sensors to be used in the test section The best sensors are the ones in which the signals are stable and repeatable Dynamic calibration will also be conducted on the capacitance sensors to obtain a relation between the voltage signal and liquid holdup for each sensor
Data management is a major challenge for this study due to the large amount of data acquired Therefore the data processing has to be automated Two MATLAB macros have been developed the first one is to calculate the average and uncertainty of all the low speed data and the second one is for the determination of slug characteristic
In case of slug flow the high speed MATLAB macro will be used to calculate the slug characteristics translation velocity average slug length slug length distribution slug frequency slug liquid holdup film liquid holdup and average liquid holdup
Near Future Work bull Finish Signal processing macro in
MATLAB bull Dynamic Calibration of capacitance sensors bull Quick-closing valve system calibration bull Write facility operating procedure
References Gokcal B Effect of High Oil Viscosity on Two-Phase Oil-Gas Flow Behavior in Horizontal Pipes MS Thesis The University of Tulsa Tulsa OK 2005 Gokcal B An Experimental and Theoretical Investigation of Slug Flow for High Oil Viscosity in Horizontal
Pipes PhD Dissertation The University of Tulsa Tulsa OK 2008 Kora C Effect of High Oil Viscosity on Slug Liquid Holdup in Horizontal Pipes MS Thesis The University
of Tulsa Tulsa OK 2010 Jeyachandra B Effect of Pipe Inclination on Flow Characteristics of High Viscosity Oil-Gas Two-Phase Flow
MS Thesis The University of Tulsa Tulsa OK 2011 Brito R Effect of Medium Oil Viscosity on Two-Phase Oil-Gas Flow Behavior in Horizontal Pipes MS
Thesis The University of Tulsa Tulsa OK 2012 Akhiyarov D High-Viscosity OilGas Flow in Vertical Pipe MS Thesis The University of Tulsa Tulsa OK
2010 Wang S High-Viscosity OilWaterGas Flow in Horizontal and Upward Vertical Pipes Slug Liquid Holdup
Modeling PhD Dissertation The University of Tulsa Tulsa OK (2012)
202
Fluid Flow Projects
Onset of Liquid Accumulation in Oil and Gas Pipelines
Eduardo Pereyra Cem Sarica
Advisory Board Meeting April 17 2013
Outline
Motivation
Objectives
Literature Review
Project Scope
Near Future Tasks
Fluid Flow Projects Advisory Board Meeting April 17 2013
203
Fluid Flow Projects Advisory Board Meeting April 17 2013
Motivation
Liquid Accumulation in Inclined Pipes is Source of Corrosion and Terrain Slugging
Accumulation Occurs Below Critical Gas Rates
Critical Gas Rate Depends on Inclination Angle
Oil and Water Flow Rates
Liquid Properties
Motivation hellip
Role Waves Near Liquid Accumulation Region
Flow Simulators Do Not Consider This Type of Flow
Solid Transport
Pipeline Fatigue
Fluid Flow Projects Advisory Board Meeting April 17 2013
Regular Slug
Rolling Wave
204
Objectives
Literature Study of Available Data for Onset of Liquid Accumulation and Velocity Profiles
2 and3-phase Experimental Study in Available Flow Loop to Quantify Onset of Liquid Accumulation
Comparison With the Available Models That can Predict the Onset of Liquid Accumulation and Develop New Models If Necessary
Fluid Flow Projects Advisory Board Meeting April 17 2013
Literature Review
Internal Corrosion Transmission Pipelines
Susceptible Areas No Flow Regions
Water andor Solid Accumulation
Corrosion Management Methodologies Flow Simulators to Predict Water
Accumulation
Uses Langsholt and Holm (2007) Results for Water Accumulation Regions Determination
Fluid Flow Projects Advisory Board Meeting April 17 2013
205
Literature Review hellip
Langsholt and Holm (2007) Study for Slightly Upward Inclined Pipes
Experimentally Determined the Region Where Liquid Holdup Increases Like a Discontinuity with Decreasing Gas Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Literature Review hellip
Langsholt and Holm (2007) Results
(ρG=226 kgm3)
206
Fluid Flow Projects Advisory Board Meeting April 17 2013
Literature Review hellip
Holdup Discontinuity is Related With Multiple Solution Region
0
02
04
06
08
1
0 2 4 6 8
h L d
[‐]
vSG [ms]
Low Holdup Solution High Holdup Solution
Taitel amp Dukler (1976) ρG=226 kgm3
vSL=0001 ms θ=24deg
Project Scope
Experimentally Study Phase 1 Straight Pipe Pipe Diameter 3-in and 6-in (Only for 2deg)
Water Cuts from 0 to 100
Inclinations of 1deg 25deg 5deg 10deg 15deg and 20deg
Liquid Superficial Velocities of 001 005 and 01 ms
Shear Stress and Velocity Profile Measurements
Fluid Flow Projects Advisory Board Meeting April 17 2013
207
Project Scope hellip
Phase 2 Interaction of Multiple Sections with Different Inclinations Study the Interaction and Its Effect on Critical
Gas Rate
θ1
θ2
θ1 θ2
Fluid Flow Projects Advisory Board Meeting April 17 2013
Project Scope hellip
Phase 3 Pressure Effect Effect of Pressure on Critical Gas Velocity
New 6-in High Pressure Facility Will Be Used
Fluid Flow Projects Advisory Board Meeting April 17 2013
208
Near Future Tasks
Literature Review on Liquid Accumulation
Review of Velocity Profile Measurement Techniques
Facility Design
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Questions
209
210
Onset of Liquid Accumulation in Oil and Gas Pipelines Eduardo Pereyra and Cem Sarica
Project Completion Dates Literature Review Ongoing Review of Velocity Profile Measurement Techniques Nov 2013
Facility Design Nov 2013
Objective The main objectives of the study are
Literature study of available data for onset of liquid accumulation and velocity profiles
Two- and three-phase experimental study in the available flow loop to quantify onset of liquid accumulation
Comparison with the available models that can predict the onset of liquid accumulation and develop new models if necessary
Motivation Accumulation of liquid oil andor water at the bottom of an inclined pipe is known to be the source of many industrial problems such as corrosion and terrain slugging The accumulation of liquid takes place when the momentum transfer from the gas is too low to overcome the typical opposing forces of the gravity of the liquid and to some extent friction and is thus a function of several parameters Accurate quantification of the required gas velocities to efficiently sweep the water out and prevent accumulation is of great importance as is also accurate prediction of oil and water holdup Parameters believed to impact the required gas velocity are in particular inclination angle oil and water flow rates gas densities (pressure) and liquid properties (density viscosity surface tension)
Currently minimum gas velocity or critical angle requirements are being implemented with various success rates to prevent corrosion in multiphase pipelines Those criteria are often found to be very conservative
An experimental and theoretical modeling project is proposed to better quantify the accumulated liquid volumes and the critical gas velocityinclination angle especially in large diameter pipelines
Literature Review The most susceptible areas for internal corrosion in pipelines correspond to no-flow and water andor solid accumulation regions All the methods proposed for internal corrosion management require the use of flow simulators to predict the water
accumulation regions (Mogohissi et al 2002 Carimalo et al 2008 Lagad et al 2004 Moghissi et al 2007 and Hauguel et al 2008)
For wet gas systems liquid holdup strongly depends on inclination angle and gas velocity For low flow rates the liquid holdup can increase by two orders of magnitude either with a small change in inclination angle or gas velocity This region can only be predicted by mechanistic models thus flow simulators equipped with mechanistic models are required for internal corrosion evaluation
Langsholt and Holm (2007) presented an experimental study to determine the critical gas velocity where the holdup change occurs Their experimental results have been used to evaluate and tune the critical gas velocity prediction by flow simulators The tests were carried out in 01-m ID pipe diameter and four pipe inclinations between 05 and 5deg The experimental matrix consists of several water cuts (WC) covering the entire range from 0shy100 WC keeping the liquid superficial velocity at 0001 ms Two different gas densities were considered namely 226 and 469 kgm3
Some of the study cases related with internal corrosion reported in the literature consider inclination angles up to 20deg (see Mogohissi et al 2002) Langsholt and Holmrsquos (2007) experimental data are limited to inclination angles less than 5deg thus further experimental analysis is required for larger inclination angles
The critical gas flow rate where the holdup suddenly changes is related to the existence of multiple roots in the two fluid model stratified flow solution Three different solutions can be found in this region the lowest and highest both being stable Which of these two stable solutions should be selected is still being debated and further experimental results are required to determine the correct one
Project Scope The project is divided into three phases as follows
211
Phase 1 (Straight Pipe) In this phase the straight pipe experiments as reported by Langsholt and Holm (2007) will be signifcantly expanded The 3 GasOilWater Flow Loop will be used for this effort Three different superficial liquid velocities (001 005 and 01 ms) will be consiered In adition six inclination angles (1deg 25deg 5deg 10deg 15deg and 20deg) in combination with five different water cuts will be included in the experimental matrix Pressure drop average liquid holdup and wave characteristics will be acquired Velocity profile andor wall shear stress measurement devices are still under consideration Flow charcateristics will be recorded using high speed and high definition cameras
Phase 2 (Slopes Interaction) The objective of this phase is to analyze the interaction between two or more consecutive section with different pipe inclinations Geometries and experimental matrix for this phase still need to be determined
Phase 3 (Pressure Effect) The new 6-in high pressure facility will be used for this effort Three inclination angles will be considered (1deg 2deg and 5deg) in combination with three pressure levels Start date of this phase will depend on facility availability
Modeling Approach Experimental data from 3-in straight pipe experiments will be used to calibrate the interfacial and wall shear stresses in the two fluid model Final model will be validated with 6-in straight pipe and Langsholt and Holm (2007) experimental data
Near Future Tasks During the next period the literature review will continue as well as a review of all posible techniques for velocity profile and wall shear stress measurements A preliminary facility design will be carried out with the required instrumentation to achieve the objectives of the project
References Carimalo F Foucheacute I Hauguel R Campaignolle X Chreacutetien T and Meyer M Flow Modeling to Optimize
Wet Gas Pipeline Water Management Paper No 08137 Corrosion 2008 March 16 - 20 2008 New Orleans LA
Hauguel R Lajoie A Carimalo F Campaignolle X Chreacutetien T and Meyer M Water Accumulation Assessment In Wet Gas Pipelines Paper No 08138 Corrosion 2008 March 16 - 20 2008 New Orleans LA
Lagad V Srinivasan S and Kane R Software System for Automating Internal Corrosion Direct Assessment of Pipelines Paper No 04197 Corrosion 2004 March 28 - April 1 2004 New Orleans LA
Langsholt M and Holm H Liquid Accumulation in Gas-Condensate Pipelines ndash An Experimental Study International Conference on Multiphase Production Technology 13 Edinburgh 2007
Moghissi O Norris L Dusek P and Cookingham B Internal Corrosion Direct Assessment of Gas Transmission Pipelines Paper No 02087 Corrosion02 Denver Colorado April 2002
Moghissi O Sun W Mendez C and Vera J Internal Corrosion Direct Assessment Methodology for Liquid Petroleum Pipelines Paper No 07169 Corrosion 2007 March 11 - 15 2007 Nashville Tennessee
212
Fluid Flow Projects
TUHOP Incorporation
Cem Sarica
Eduardo Pereyra
Advisory Board Meeting April 17 2013
TUHOP Review
TUHOP was Established in 2007 as 5shyyear JIP to Investigate High Viscosity Oil Multiphase Flow Behavior in Pipes
JIP was Completed in 2012
Needed 5 Members to Fully Fund as a Stand Alone JIP
Only 2 Members of TUHOP Indicated to Continue
Fluid Flow Projects Advisory Board Meeting April 17 2013
213
TUHOP Review hellip
Significant Investment Made TowardsConstruction of a New 3 in ID High Pressure High Viscosity Oil Facility $1000000 in Construction amp Equipment Man Time not Included
Completion of the Facility Requires $500000 There is $300000 Available as Balance
from TUHOP Need to Invest Additional $200000 to
Complete the Facility
Fluid Flow Projects Advisory Board Meeting April 17 2013
Proposal to TUFFP Membership
Incorporation of TUHOP into TUFFP Complete the Construction of the 3 in
ID High Pressure-High Viscosity Oil Facility
Investigate Oilwater Flow as the First Project
Significant Value to TUFFP Will Enhance TUFFP Efforts in High
Viscosity Oil Multiphase Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
214
Terms of the Incorporation
Existing TUHOP Deliverables will not Be Made Available to TUFFP Members
TUFFP members will have the Rights to the Deliverables Generated with the New Facility
Fluid Flow Projects Advisory Board Meeting April 17 2013
Status
TU Administration has Given Permission to Propose This Incorporation
Fluid Flow Projects Advisory Board Meeting April 17 2013
215
Way Forward
Membership Voting on Proposal by a Ballot through e-mail
Over 50 Majority of the Votes Will be Used as the Group Decision
Fluid Flow Projects Advisory Board Meeting April 17 2013
Way Forward hellip
If Advisory Board Approves the Proposal Facility Construction will Be Completed
by the End of 2013
Testing will Start in Spring 2014
Fluid Flow Projects Advisory Board Meeting April 17 2013
216
Proposed Project Oil-Water Flow
Highly Viscous Oil-Water Flow Objective Experimental Study of Highly Viscous
Oil-Water 3-in pipe (microO = 180 260 and 380cP) Effect of Inclination Angle (0+2deg and shy
2deg) Mechanistic Model Development for
Highly Viscous Oil-Water Flow
Fluid Flow Projects Advisory Board Meeting April 17 2013
Oil-Water Flow
Few Experimental Points in Previous Studies
vS
W (m
s)
10
1
01
001
SOW
SOW-DOW
SOW-DOW-OF
CAOF
001 01 1 10 vSO (ms)
Shridhar (2011) Experimental Flow Pattern Maps for Horizontal Pipe μο = 021 Pamiddots
Fluid Flow Projects Advisory Board Meeting April 17 2013
217
Fluid Flow Projects Advisory Board Meeting April 17 2013
Oil-Water Flow
Poor Visualization for High Pressure Conditions
Oil-Water Flow
Parameters to Be Measured Flow Pattern (Better Visualization)
Film Thickness and Profile
Pressure Drop
Water Fraction
Film Thickness Meter
Fluid Flow Projects Advisory Board Meeting April 17 2013
218
Fluid Flow Projects
Business Report
Cem Sarica
Advisory Board Meeting April 17 2013
Membership and Collaboration Status
Current Membership Status 2013 Membership Declines by One
SchlumbergerSPT Merger
JOGMEC Termination
NTP Truboprovod Piping Systems Research amp Engineering Company of Russia Joins
16 Industrial Members and BSEE
Efforts Continue to Increase TUFFP Membership Interest from Several Companies
DragOilUNAM Group
DSME of South Korea
Kongsberg
Repsol
PDVSA
SNU Collaboration Continues
Fluid Flow Projects Advisory Board Meeting April 17 2013
219
Publications and Papers
Choi J Pereyra P Sarica C Park C and Kang J M An Efficient Drift-Flux Closure Relationship to Estimate Liquid Holdups of Gas-Liquid Two-Phase Flow in Pipes Scheduled for a future issue of the Journal Energies
Choi J Pereyra P Sarica C Lee H Jang I S and Kang J M Development of a Fast Transient Simulator for Gas-Liquid Two-phase Flow in Pipes Scheduled for a future issue of Journal of Petroleum Science and Engineering
Yuan G Pereyra E Sarica C and Sutton R P An Experimental Study on Liquid Loading of Vertical and Deviated Gas Wells SPE 164516-MS Presented at the SPE Production and Operations Symposium held in Oklahoma City Oklahoma USA 23-26 March 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
Next Advisory Board Meetings
Tentative Schedule September 24 2013 TUPDP Meeting TUFFP Workshop Facility Tour I TUPDPTUFFP Reception
September 25 2013 TUFFP Meeting TUFFPTUHWALP Reception
September 26 2013 TUHWALP Reception Facility Tour II
Venue to be Determined
Fluid Flow Projects Advisory Board Meeting April 17 2013
220
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fall Meeting Date Tally
September 24 ‐ 27 October 8 ‐ 11
Aspen Tech Baker Hughes ‐ Shawn Wang 1 BP ‐ Yongqian Fan 1 Chevron ‐ Hari Subramani 1 ConocoPhillips 1
Steve Appleyard 0 (At this point ‐ either date might work) Bahadir Gokcal 0 Tom Danielson 0
ExxonMobil ‐ Nader Berchane 1 GE ‐ Rogier Blom 1 KOC ‐ Eissa Alsafran 1 Marathon ‐ Rob Sutton 1 Pemex
Tomas Eduardo Perez 1 Eduardo War 1
Petrobras Piping Systems Research Saudi Aramco Schumberger ‐William Bailey 1 Shell ‐ Rusty Lacy 1 Total
Sum 7 5
Financial Report
Year 2012 Closing TUFFP Industrial Account
TUFFP BSEE Account
Year 2013 Update TUFFP Industrial Account
TUFFP BSEE Account
Fluid Flow Projects Advisory Board Meeting April 17 2013
221
2012 Industrial Account Summary (Prepared March 22 2013)
Reserve Fund Balance on January 1 2012 $211154 Income for 2012
2012 Membership Fees (17 $55000 - exludes MMS) 935000 Facility Utilization Fee (SNU) 55000
Total Budget $ 1201154
BudgetExpenditures for 2012
Projected Revised Revised Budget Budget Budget 2012 100111 April 2012 October 2012 Expenditures
90101 - 90103 Faculty Salaries 3071247 1662114 1662818 90600 - 90609 Professional Salaries 11719822 5350100 4626032 5882664 90700 - 90703 Staff Salaries 3459760 1291400 3977003 4266491
90800 Part-timeTemporary 2400000 2000000 2116880 91000 Student Salaries - Monthly 5405000 3535000 4100000 4027500 91100 Student Salaries - Hourly 1500000 1500000 641760 874060 91800 Fringe Benefits 6387790 2324500 3540817 4082205 92102 Fringe Benefits (Students) 282800 328000 322200 81801 Tuition amp Student Fees 1868610 735000 1048700 985300 93100 General Supplies 300000 300000 330000 366654 93101 Research Supplies 12000000 15000000 27000000 26340099 93102 CopierPrinter Supplies 75000 75000 15000 11088 93103 Component Parts 220000 93104 Computer Software 400000 400000 35050 50222 93106 Office Supplies 200000 200000 300000 350801 93150 Computers ($1000 - $4999) 680845 903986 93200 Postage and Shipping 50000 50000 30000 135463 93300 Printing and Duplicating 300000 300000 300000 232629 93400 Telecommunications 250000 250000 100000 127456 93500 Membership 100000 100000 50000 80600 93601 Travel - Domestic 1000000 1000000 1500000 1060094 93602 Travel - Foreign 1000000 1000000 559929 929826 93700 Entertainment 1600000 2000000 2000000 2473468 94803 Consultant 1000000 115000 115000 94813 Outside Services 2000000 2000000 4000000 4675321 95103 Equipment Rental 2000000 158900 158900 95200 FampA (556) 14439255 7376100 9190300 10145816 98901 Employee Recruiting 300000 300000 272765 272765 99001 Equipment 30000000 30000000 813373 813373 99002 Computers 800000 800000 -99300 Bank Charges 4000 4000 3000 3000
Total Expenditures 98230484 81573900 69378588 73686680
Reserve as of 123112 46428732 $
2012 BSEE Account Summary
(Prepared March 22 2013)
Reserve Balance as of 123111 237635 2012 Budget 4800000
Total Budget 5037635
Projected BudgetExpenditures for 2012
2012 Budget Expenditures
91000 Students - Monthly 2812500 2940000 91202 Student Fringe Benefits 225000 235200 95200 FampA 1563750 1634640
Total Anticipated Expenditures as of 123111 4601250 4809840
Total Anticipated Reserve Fund Balance as of 123112 227795
Fluid Flow Projects Advisory Board Meeting April 17 2013
222
2013 Industrial Account Budget (Prepared April 6 2013)
Reserve Fund Balance on January 1 2012 46428732 Income for 2013
2013 Membership Fees (16 $55000 - excludes BSEE) 88000000 2013 Anticipated Memership (1 $55000) 5500000 Facility Utilization Fee (SNU) 5500000
Total Income 145428732
Projected 2013 Revised
2013 Anticipated Expenditures Budget Expenditures Budget 31313
10152012 33113 90101-90103 Faculty Salaries 2182931 873892 423500 90600-90609 Professional Salaries 4611687 8484081 2809012 90700-90703 Staff Salaries 5667308 9031600 1106084
90800 Part-timeTemporary Staff 2500000 2500000 -91000 Graduate Students 3960000 3147500 875000 91100 Undergraduate Students 1500000 1500000 30000 91800 Fringe Benefits (36) 4361674 6620247 1518503 92102 Fringe Benefits Students (8) 316800 251800 56000 81801 TuitionStudent Fees 4009500 2991600 1015500 93100 General Supplies 300000 300000 -93101 Research Supplies 25000000 25000000 1697709 93102 CopierPrinter Supplies 50000 50000 -93104 Computer Software 200000 200000 49500 93106 Office Supplies 300000 300000 155994 93150 Computers Under $5000 1000000 1000000 463702 93200 PostageShipping 50000 50000 9281 93300 PrintingDuplicating 300000 300000 1389 93400 Telecommunications 100000 100000 -93500 MembershipsSubscriptions 50000 50000 -93601 Travel - Domestic 1000000 1000000 20282 93602 Travel - Foreign 1000000 1000000 -93700 Entertainment (Advisory Board Meetings) 2000000 2000000 100836 94803 Consultants 200000 200000 -94813 Outside Services 4000000 4000000 1776761 95103 Equipment Rental 2000000 2000000 328405 95200 Indirect Costs (524) 10701089 13381427 2287746 98901 Employee Recruiting 300000 300000 -99001 Equipment 30000000 30000000 -99300 Bank Charges 4000 4000 -
Total Expenditures 107664989 116636147 14725204
Anticipated Reserve Fund Balance on December 31 2013 28792585
2013 BSEE Account Budget
(Prepared March 22 2013)
Account Balance - January 1 2013 $227795 Income for 2013
2013 Membership Fee $5500000
Total Income for 2013 $5727795
2009 Anticipated Expenditures Projected Budget 90101-90103 Faculty Salaries -90600-90609 Professional Salaries -90700-90703 Staff Salaries -
91000 Graduate Students 2887500 92102 Student Fringe Benefits (8) 231000 95200 Indirect Costs (556) 1605450
Total Expenditures $4723950
Anticipated Reserve Fund Balance on December 31 2013 $1003845
Fluid Flow Projects Advisory Board Meeting April 17 2013
223
Oil
Pr
ce
$
History ndash Membership
i
0
20
40
60
80
100
120
140
160
0
5
10
15
20
25
30
35
40
45
50
1973 1975 1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
OIl
Pri
ce
$
Nu
mb
er
of
Me
mb
ers
Year
Members Oil Price
Fluid Flow Projects Advisory Board Meeting April 17 2013
Fluid Flow Projects Advisory Board Meeting April 17 2013
History ndash Membership Fees
224
Fluid Flow Projects Advisory Board Meeting April 17 2013
History - Expenditures
Membership Fees
2012 Membership Dues All Paid
Thanks
2013 Membership Dues 13 Paid
4 Unpaid
Fluid Flow Projects Advisory Board Meeting April 17 2013
225
226
Introduction
This semi-annual report is submitted to Tulsa University Fluid Flow Projects (TUFFP) members to summarize activities since the October 16 2012 Advisory Board meeting and to assist in planning for the next six months It also serves as a basis for reporting progress and generating discussion at the 80th semi-annual Advisory Board meeting to be held in OneOK Club of H A Chapman Stadium of the University of Tulsa Main Campus 3112 East 8th Street Tulsa Oklahoma on Wednesday April 17 2013
The activities will start with TUFFP workshop on April 16 2013 between 100 pm and 300 pm in OneOK Club Several presentations will be made by TUFFP member companies Between 330 and 530 there will be a facility tour Several facilities will be operating during the tour Following the tour there will be a TUFFP reception between 600 pm and 930 pm in OneOK Club
TUFFP Advisory Board meeting will convene at 800 am on April 17 in OneOK Club of H A Chapman
Stadium and will adjourn at approximately 530 pm Following the meeting there will be a joint TUFFPTUPDP reception between 600 and 900 pm in OneOK Club
The Tulsa University Paraffin Deposition Projects (TUPDP) Advisory Board meeting will be held on April 18 in OneOK Club between 830 am and 230 pm Following the meeting between 300 and 500 pm there will be a facility tour Activities on April 18 will end with the reception of Tulsa University Horizontal Well Artificial Lift Projects (TUHWALP) between 600 and 900 pm in OneOK Club
TUHWALP meeting will convene at 830 am on April 19 in OneOK Club and will adjourn at approximately 300 pm
The following dates have tentatively been established for Fall 2013 Advisory Board meetings The venue for Fall 2013 Advisory Board meetings has not yet been determined
2013 Fall Meetings September 24 2013 TUPDP Advisory Board Meeting
Facility Tour ndash I TUFFP Workshop TUPDPTUFFP Reception
September 25 2013 TUFFP Advisory Board Meeting TUFFPTUHWALP Reception
September 26 2013 TUHWALP Advisory Board Meeting Facility Tour - II
227
228
Personnel
Dr Cem Sarica Professor of Petroleum Engineering continues as the Director of TUFFP TUPDP and TUHWALP
Dr Eduardo Pereyra continues to serve as the Associate Director of TUFFP Dr Pereyra will start serving as Assistant Professor of McDougall School of Petroleum Engineering effective fall 2013
Dr Brill continues to be involved as the director emeritus on a voluntary basis
Dr Carlos F Torres continues as Post-Doctoral Research Associate of TUFFP and TUHWALP consortia
Dr Jinho Choi has joined the staff as post-doctoral research associate effective Jan 2 2013 He is assigned to work on model development and software improvement for both TUFFP and TUPDP
Dr Abdel Al-Sarkhi of King Fahd University of Petroleum and Minerals serves as Research Associate Professor
Mr Scott Graham continues to serve as Project Engineer Scott oversees all of the facility operations and continues to be the senior electronics technician
Mr Craig Waldron continues as Research Technician addressing our needs in mechanical areas He also serves as a flow loop operator for TUPDP and Health Safety and Environment (HSE) officer
Mr Norman Stegall continues as the electro-mechanical technician
Mr Don Harris continues as the electronic research technician Don has been with TU for 23 years working for the College of Engineering and Natural Sciences as instrumentation technician
Mr Franklin Birt continues as the electronic research technician Franklin worked for Hydrates group for three years before joining our group
Ms Linda Jones continues as Project Coordinator She keeps the project accounts in addition to other responsibilities such as external communications providing computer support for graduate students publishing and distributing all research reports and deliverables
Ms Sherri Alexander has resigned from her position of Assistant to Project Coordinator effective February 7th
2013 due to health reasons
Ms Lori Watts of Petroleum Engineering is the web master for consortia websites
Table 1 updates the current status of all graduate students conducting research on TUFFP projects for the last six months
Mr Kiran Gawas from India has successfully completed his PhD degree requirements in Petroleum Engineering He studied Low Liquid Loading Three-phase Flow He has already started to work for Halliburton ndash MultiChem
Ms Mujgan Guner has successfully completed her MS degree requirements in Petroleum Engineering Mujgan studied Liquid Loading in Gas Wells She has started to work for Schlumberger - SPT after the completion of her studies
Mr Feras Al-Ruhaimani from Kuwait is pursuing a PhD Degree in Petroleum Engineering Mr Al-Ruhaimani has BS and MS degrees in Petroleum Engineering from Kuwait University He has also worked as petroleum engineer for Kuwait Oil Company for six years He is studying High Viscosity Oil Multiphase Flow
Mr Hamid Karami from Iran is pursuing his PhD degree in Petroleum Engineering Hamid has an MS degree in Petroleum Engineering from The University of Tulsa He is investigating the Effects of MEG on Multiphase Flow as part of his PhD study
Mr Yasser Al-Saadi from Saudi Arabia continues as a research assistant pursuing an MS degree in Petroleum Engineering He has worked for Saudi Aramco as a petroleum engineer prior to starting his MS degree program at the University of Tulsa He is studying Liquid Loading in Highly Deviated Gas Wells
Mr Hoyoung Lee has completed his studies in TUFFP by investigating minimum energy dissipation concept in modeling of two-phase stratified flow This was a part of the research collaboration between Seoul National University (SNU) and TUFFP Mr Lee has successfully completed PhD degree requirements of the department of Energy Resources Engineering at SNU
Two new SNU researchers Mr Jaejun Kim an MS student of SNU and Mr Mingon Chu a PhD student joined the team in August 2012 and December 2012
229
respectively They are assigned to High Viscosity Oil and Gas Flow in Inclined Pipes
Mr Selcuk Fidan of Turkey a PhD student is assigned to the High Viscosity Oil Research Currently he is focusing on his course work
Mr Duc Vuong rejoined the team as a PhD student at the beginning of Spring 2013 semester Duc has already BS and MS degrees from the University of
Tulsa His MS thesis work was completed under auspices of TUHOP studying high viscosity oil and water Duc is assigned to the project titled ldquoPressure Effects on Low Liquid Loading Two-phase Oil-Gas Flowrdquo This project requires the utilization of the new 6 in ID high pressure facility
A list of all telephone numbers and e-mail addresses for TUFFP personnel are given in Appendix A
230
Table 1
2013 Spring Research Assistant Status Name Origin Stipend Tuition Degree
Pursued TUFFP Project Completion
Date Alruhaimani Feras Kuwait Kuwait
University Kuwait
University PhD PE High Viscosity Oil
Multiphase Flow Spring 2014
Alsaadi Yasser Saudi Arabia
Saudi Aramco
Saudi Aramco
MS ndash PE Liquid Loading in Highly Deviated Gas Wells
Fall 2013
Chu Mingon South Korea
SNU SNU PhD ndash PE High Viscosity Oil Multiphase Flow
Fall 2014
Fidan Selcuk Turkey TU TU PhD ndash PE High Viscosity Oil Multiphase Flow
Spring 2016
Gawas Kiran India Yes ndash TUFFP
Waived (TU)
PhD ndash PE Three-phase Gas-Oil-Water Low Liquid Loading
Completed
Guner Mujgan Turkey Yes ndash TUFFP
Waived ndash (BSEE)
PhD ndash PE Liquid Loading of Gas Wells
Completed
Karami Hamid Iran Yes
TUFFP
Yes
TUFFP
PhD PE Effects of MEG on Multiphase Flow
Fall 2014
Kim Jaejun South Korea
SNU NA MS (SNU) High Viscosity Oil Multiphase Flow
Fall 2013
Lee Hoyoung South Korea
SNU NA PhD (SNU) Two-phase Gas-Liquid Flow Modeling Using Minimization Energy Dissipation Concept
Completed
Vuong Duc Vietnam TUFFP TUFFP PhD ndash PE Pressure Effects on Low Liquid Loading Two-phase Oil-Gas Flow
Fall 2016
231
232
Membership
The current membership of TUFFP is down from 18 to 17 for 2013 16 industrial members and Bureau of Safety and Environmental Enforcement (BSEE) We have lost two members SPT due to the sale of SPT Group to Schlumberger and JOGMEC due to changes in their research and technology development portfolio Our efforts to increase the TUFFP membership level will continue NTP Truboprovod Piping Systems Research amp Engineering Co of Russia has recently joined TUFFP DragOilUNAM Group DSME of South Korea Kongsberg and Repsol have shown interest in becoming a member
Table 2
Table 2 lists all the current 2013 TUFFP members A list of all Advisory Board representatives for these members with pertinent contact information appears in Appendix B A detailed history of TUFFP membership is given in Appendix C
The collaboration with Seoul National University is underway We are in year three of a three-year period We will work towards extending the collaboration for two more years Through the collaboration TUFFP receives about $55000year and visiting research scholars
2013 Fluid Flow Projects Membership
Aspen Tech Marathon Oil Company
Baker Atlas PEMEX
BSEE Petrobras
BP Piping Systems Research amp Engineering Co (NTP Truboprovod)
Chevron Saudi Aramco
ConocoPhillips Schlumberger
Exxon Mobil Shell Global Solutions
General Electric Total
KOC
233
234
Equipment and Facilities Status
Test Facilities
The 6 in ID High Pressure Facility has already been commissioned The Canty Visualization Device has been tested A high pressure wire mesh device has been ordered to be custom built
Three-phase 2 in ID facility test section is being modified for to study high viscosity oil multiphase flow in vertical and deviated pipe studies
The 2 in ID oil-gas facility has been changed from horizontal to inclined three-phase flow facility to continue to be used in high viscosity oil-gas research
A new clamp on capacitance sensor development is successfully completed and started to be used in our facilities
Detailed descriptions of these modification efforts appear in progress presentations given in this brochure A site plan showing the location of the various TUFFP and TUPDP test facilities on the North Campus is given in Fig 1
235
236
TO L
EWIS
AVE
M
ARSH
ALL
STR
EET
Spe
cial
Pro
ject
s Bui
ldin
g
N
TUD
CP
TUSTP
TUD
RP-
PEACTS
JIP
-PE
PARKIN
GTU
PDP-
PETU
ECP-
ME
TUSM
P-M
E
PE Lab Trailer
TUSTP Control Room
Bld
g Pr
oces
sTU
FFP-
PE
CO
LLEG
E O
F
TUH
FP-P
EChE
TEST
WEL
L
TUSTP
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ME
MU
LTIP
HASE
ALP
INE
PERFO
RM
AN
CE
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Bui
ldin
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DCP-
ChE
Hydrate Loop
ENG
INEE
RIN
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D N
ATU
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SCIE
NCES
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Ps
LOO
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TUALP
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PETR
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CAM
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HIL
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ERRAIN
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GAS L
IFT
VALV
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STFA
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SMALL SCALE FLOW LOOP
ME
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YBRID
TU
ECRC
ELEC
TRIC
CARS
TUSM
P
PARKING
DRILL BUILDING
DRILL LAB
PARAFF
IN
MU
LTIP
HASE
LOO
P
TUPD
PFL
OW
ASSU
RAN
CE
LAB
LOW
LIQ
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LO
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E
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ILD
ING
G
ASO
ILW
ATE
R L
OO
P
TUM
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PARAFF
IN S
ING
LE P
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SEVERE SLUGGING LOOP
BP 6 - INCH FLOW LOOP
LOW
PRES
SU
RE
LOO
P
ARC
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G
ACTS
JIP
HIG
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FFP
SH
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INE
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OP
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Figure
1 ‐Site
Plan
for the North
Cam
pus Research
Facilties
Financial Status
TUFFP maintains separate accounts for industrial and US government members Thus separate accounts are maintained for BSEE funds
Table 3 presents a financial analysis of income and expenditures for the 2012 Industrial member account as of March 22 2013 Also shown are previous 2012 budgets that have been reported to the members The total industry expenditures for 2012 are $736867 This results in a carryover of $464287 to 2013 fiscal year
Table 4 presents a financial analysis of expenditures and income for the BSEE Account for 2012 This account is used primarily for graduate student stipends A balance of $2278 is carried over to 2013 The University of Tulsa waives up to 19 hours
of tuition for each graduate student that is paid a stipend from the United States government BSEE funds
Tables 5 and 6 present the budgets and income for the Industrial and BSEE accounts for 2013 The 2013 TUFFP industrial budged is based on 17 members This provides $93500000 of industrial membership income for 2013 In addition TUFFP will receive facility utilization fee from SNU totaling $5500000 The total of the 2013 income and the reserve account is projected to be $1454287 The expenses for the industrial member account are proposed to be $1166361 leaving a carryover balance of $287926 to 2014 The BSEE account is expected to have a carryover of $10038 to 2014
237
Table 3 2012 Industrial Budget Summary
(Prepared March 22 2013) Reserve Fund Balance on January 1 2012 $211154 Income for 2012
2012 Membership Fees (17 $55000 - exludes MMS) 935000 Facility Utilization Fee (SNU) 55000
Total Budget $ 1201154
BudgetExpenditures for 2012
Projected Revised Revised Budget Budget Budget 2012 100111 April 2012 October 2012 Expenditures
90101 - 90103 Faculty Salaries 3071247 1662114 1662818 90600 - 90609 Professional Salaries 11719822 5350100 4626032 5882664 90700 - 90703 Staff Salaries 3459760 1291400 3977003 4266491
90800 Part-timeTemporary 2400000 2000000 2116880 91000 Student Salaries - Monthly 5405000 3535000 4100000 4027500 91100 Student Salaries - Hourly 1500000 1500000 641760 874060 91800 Fringe Benefits 6387790 2324500 3540817 4082205 92102 Fringe Benefits (Students) 282800 328000 322200 81801 Tuition amp Student Fees 1868610 735000 1048700 985300 93100 General Supplies 300000 300000 330000 366654 93101 Research Supplies 12000000 15000000 27000000 26340099 93102 CopierPrinter Supplies 75000 75000 15000 11088 93103 Component Parts 220000 93104 Computer Software 400000 400000 35050 50222 93106 Office Supplies 200000 200000 300000 350801 93150 Computers ($1000 - $4999) 680845 903986 93200 Postage and Shipping 50000 50000 30000 135463 93300 Printing and Duplicating 300000 300000 300000 232629 93400 Telecommunications 250000 250000 100000 127456 93500 Membership 100000 100000 50000 80600 93601 Travel - Domestic 1000000 1000000 1500000 1060094 93602 Travel - Foreign 1000000 1000000 559929 929826 93700 Entertainment 1600000 2000000 2000000 2473468 94803 Consultant 1000000 115000 115000 94813 Outside Services 2000000 2000000 4000000 4675321 95103 Equipment Rental 2000000 158900 158900 95200 FampA (556) 14439255 7376100 9190300 10145816 98901 Employee Recruiting 300000 300000 272765 272765 99001 Equipment 30000000 30000000 813373 813373 99002 Computers 800000 800000 -99300 Bank Charges 4000 4000 3000 3000
Total Expenditures 98230484 81573900 69378588 73686680
Reserve as of 123112 $ 46428732
238
Table 4 2012 BSEE Budget Summary
(Prepared March 22 2013)
Reserve Balance as of 123111 2012 Budget
237635 4800000
Total Budget 5037635
Projected BudgetExpenditures for 2012
91000 Students - Monthly 91202 Student Fringe Benefits 95200 FampA
Budget 2812500 225000
1563750
2012 Expenditures
2940000 235200
1634640
Total Anticipated Expenditures as of 123111 4601250 4809840
Total Anticipated Reserve Fund Balance as of 123112 227795
239
Table 5 2013 Industrial Budget
(Prepared April 6 2013)
Reserve Fund Balance on January 1 2012 46428732 Income for 2013
2013 Membership Fees (16 $55000 - excludes BSEE) 88000000 2013 Anticipated Memership (1 $55000) 5500000 Facility Utilization Fee (SNU) 5500000
Total Income 145428732
Projected 2013 Revised
2013 Anticipated Expenditures Budget Expenditures Budget 31313
10152012 33113 90101-90103 Faculty Salaries 2182931 873892 423500 90600-90609 Professional Salaries 4611687 8484081 2809012 90700-90703 Staff Salaries 5667308 9031600 1106084
90800 Part-timeTemporary Staff 2500000 2500000 -91000 Graduate Students 3960000 3147500 875000 91100 Undergraduate Students 1500000 1500000 30000 91800 Fringe Benefits (36) 4361674 6620247 1518503 92102 Fringe Benefits Students (8) 316800 251800 56000 81801 TuitionStudent Fees 4009500 2991600 1015500 93100 General Supplies 300000 300000 -93101 Research Supplies 25000000 25000000 1697709 93102 CopierPrinter Supplies 50000 50000 -93104 Computer Software 200000 200000 49500 93106 Office Supplies 300000 300000 155994 93150 Computers Under $5000 1000000 1000000 463702 93200 PostageShipping 50000 50000 9281 93300 PrintingDuplicating 300000 300000 1389 93400 Telecommunications 100000 100000 -93500 MembershipsSubscriptions 50000 50000 -93601 Travel - Domestic 1000000 1000000 20282 93602 Travel - Foreign 1000000 1000000 -93700 Entertainment (Advisory Board Meetings) 2000000 2000000 100836 94803 Consultants 200000 200000 -94813 Outside Services 4000000 4000000 1776761 95103 Equipment Rental 2000000 2000000 328405 95200 Indirect Costs (524) 10701089 13381427 2287746 98901 Employee Recruiting 300000 300000 -99001 Equipment 30000000 30000000 -99300 Bank Charges 4000 4000 -
Total Expenditures 107664989 116636147 14725204
Anticipated Reserve Fund Balance on December 31 2013 28792585
240
Table 6 2013 BSEE Budget
(Prepared March 22 2013)
Account Balance - January 1 2013 $227795 Income for 2013
2013 Membership Fee $5500000
Total Income for 2013 $5727795
2009 Anticipated Expenditures Projected Budget 90101-90103 Faculty Salaries -90600-90609 Professional Salaries -90700-90703 Staff Salaries -
91000 Graduate Students 2887500 92102 Student Fringe Benefits (8) 231000 95200 Indirect Costs (556) 1605450
Total Expenditures $4723950
Anticipated Reserve Fund Balance on December 31 2013 $1003845
241
242
Miscellaneous Information
Fluid Flow Projects Short Course
The 38th TUFFP ldquoTwo-Phase Flow in Pipesrdquo short course will be taught April 29 ndash May 3 2013 There are currently 15 enrollees
Dr Abdel Al-Sarkhi Returns to TUFFP
Once again Dr Abdel Al-Sarkhi will be spending his summer with TUFFP research associates and research assistants helping them in their research projects
Jim Brill Receives OTC 2013 Heritage Award
Along with Dendy Sloan Professor Emeritus of Colorado School of Mines Jim Brill has been selected as a recipient of the 2013 Heritage Award of Offshore Technology Conference (OTC)
The Heritage Award recognizes long-term continuous distinguished service by an individual in one or more of the following areas of offshore technology (1) exploration (2) development and production (3) management and leadership and (4) research and development
We congratulate Jim on this well-deserved recognition We are proud to be part of his legacy
BHR Group Conference on Multiphase Technology
Since 1991 TUFFP has participated as a co-supporter of BHR Group Conferences on Multiphase Production TUFFP personnel participate in reviewing papers serving as session chairs and advertising the conference to our members This conference is one of the premier international event providing delegates with opportunities to discuss new research and developments to consider innovative solutions in multiphase production area
16th International Conference on Multiphase Technology supported by IFP IFE NEOTEC and TUFFP will be held 12-14 of June 2013 in Cannes France The conference will benefit anyone engaged in the application development and research of multiphase technology for the oil and gas industry Applications in the oil and gas industry will also be of interest to engineers from other industries for which multiphase technology offers a novel solution to their problems The conference will also be of particular value to designers facility and operations
engineers consultants and researchers from operating contracting consultancy and technology companies The conference brings together experts from across the American Continents and Worldwide The detailed information about the conference can be found in BHRgrsquos (wwwbrhgroupcom)
Two papers from the past TUFFP research are accepted to be presented at the conference
Publications amp Presentations
Since the last Advisory Board meeting the following publications and presentations are made
1) Choi J Pereyra P Sarica C Park C and Kang J M An Efficient Drift-Flux Closure Relationship to Estimate Liquid Holdups of Gas-Liquid Two-Phase Flow in Pipes Scheduled for publication in a future issue of the Journal Energies
2) Choi J Pereyra P Sarica C Lee H Jang I S and Kang J M Development of a Fast Transient Simulator for Gas-Liquid Two-phase Flow in Pipes Scheduled for publication in a future issue of Journal of Petroleum Science and Engineering
3) Yuan G Pereyra E Sarica C and Sutton R P An Experimental Study on Liquid Loading of Vertical and Deviated Gas Wells SPE 164516-MS Presented at the SPE Production and Operations Symposium held in Oklahoma City Oklahoma USA 23-26 March 2013
Tulsa University Paraffin Deposition Projects (TUPDP)
The forth three year phase of TUPDP has recently been completed and the fifth three-year phase has been started effective April 1 2013 The new phase studies concentrate on the paraffin deposition characterization of single-phase turbulent flow with new oils gas-oil-water paraffin deposition and field verification
Tulsa University Heavy Oil Projects (TUHOP)
Tulsa University High Viscosity Oil Projects (TUHOP) Joint Industry Projects has been completed Not enough members have shown interest in continuation of TUHOP at this time Therefore it is proposed to merge TUHOP into TUFFP to pursue the high viscosity oil multiphase flow research more vigorously The TUHOP
243
deliverables generated during its existence will not be available to TUFFP members
Tulsa University Foam Flow Conditions (TUFFCP) Joint Industry Project (JIP)
This JIP investigates unloading of vertical gas wells using surfactants for a period of three years The JIP is funded by Research Partnership to Secure Energy for America (RPSEA) which is an organization managing DOE funds and various oil and gas operating and service companies Current industrial members of the JIP are Chevron ConocoPhillips Marathon Shell Nalco and Multichem
Tulsa University Horizontal Well Artificial Lift Projects (TUHWALP)
TUHWALP consortium has been founded on July 1 2012 TUHWALP primarily addresses the artificial lift needs of horizontal wells drilled into gas and oil shales The membership fee is $50000 Current
members are ALDRC Anadarko (pending) BP Chesapeake Chevron ConocoPhillips Devon EnCana GE Marathon Norris Production Solutions Range Resources Shell SWN Weatherford and XTO
TUHWALPrsquos mission is to Advance the knowledge and effectiveness of
people who design and operate horizontal wells Develop recommended practices for artificial lift
of horizontal wells Make recommendations to improve the design
and operability of artificial lift for horizontal wells
Make recommendations to improve the selection deployment operation monitoring control and maintenance of artificial lift equipment and
Recommend artificial lift practices to optimize recovery of natural gas and associated liquids from horizontal wells
244