1. Baker JardineBaker Jardine
PetroleumEngineering&Software
PIPESIMPIPESIM 20002000
User Guide

2. bja9MarketingMANUALSPIPESIM 2000User Guide1.0PIPESIM 2000 User Guide.doc
PIPESIM 2000
© Copyright 2000-01 Baker Jardine. All right reserved
Although PIPESIM 2000 has been extensively tested, Baker Jardine
accept no responsibility or liability arising from the use of this manual
or the PIPESIM 2000 computer program. All material is supplied
without warranty of any kind.
Information in this document is subject to change without notice.
Companies, names and data used in examples herein are fictitious
unless otherwise noted.
No part of this document may be reproduced or transmitted in any
form or by any means, electronic or otherwise, for any purpose,
without the express written permission of Baker Jardine.
www.BakerJardine.com

3. Contents iii
PIPESIMPIPESIM 2000
DOCUMENT CONVENTIONS ...........................................XV
PIPESIM 2000 HOT KEYS .............................................. XVII
1 INTRODUCTION........................................................ 1-1
1.1 Setting up ................................................................................1-1
1.1.1 Before you run setup............................................................1-1
1.1.1.1 Hardware and system requirements.............................1-1
1.1.1.2 Check the PIPESIM 2000 package ..............................1-2
1.1.1.3 Make backup copies ......................................................1-2
1.1.1.4 Read the additional notes document............................1-2
1.1.2 Running setup ......................................................................1-3
1.1.3 Changing Options after quitting setup.................................1-3
1.2 Documentation .......................................................................1-3
1.2.1 PIPESIM 2000 additional documentation ...........................1-3
1.2.1.1 Artificial lift Performance curve .....................................1-3
1.2.1.2 User Defined Multiphase flow correlation.....................1-4
1.2.1.3 OpenLink........................................................................1-4
1.2.1.4 PVT file format ...............................................................1-4
1.2.1.5 Sentinel LM Security......................................................1-4
1.2.2 Case Studies ........................................................................1-4
1.2.3 Online Help...........................................................................1-4
1.2.3.1 Help contents.................................................................1-4
1.2.3.2 Help Search...................................................................1-5
1.2.3.3 Context-sensitive Help ..................................................1-5
1.3 PIPESIM 2000 overview.........................................................1-5
1.3.1 Modules................................................................................1-6
1.3.1.1 Pipeline & Facilities .......................................................1-6
1.3.1.2 Well Performance analysis............................................1-6
1.3.1.3 Network analysis module..............................................1-6
1.3.1.4 Production Optimization (GOAL) ..................................1-7
1.3.1.5 Multi-lateral wells (HoSim) ............................................1-8
1.3.1.6 Field Planning (FPT)......................................................1-9
1.3.2 Options..................................................................................1-9

4. iv Contents
PIPESIMPIPESIM 2000
1.3.2.1 Compositional option.....................................................1-9
1.3.2.2 OLGAS 2000................................................................1-10
1.3.2.3 ECLIPSE 100...............................................................1-10
1.3.2.4 ECLIPSE 300...............................................................1-11
1.3.2.5 Mbal..............................................................................1-11
1.4 File Management..................................................................1-11
1.5 Security .................................................................................1-12
1.5.1 Stand-alone security ..........................................................1-12
1.5.2 LAN Security.......................................................................1-13
1.6 New features.........................................................................1-13
1.7 Baker Jardine Support Services........................................1-14
1.8 What to do next....................................................................1-15
2 MODEL OVERVIEW .................................................. 2-1
2.1 Steps in building a model.....................................................2-1
2.2 Starting PIPESIM 2000...........................................................2-1
2.3 Units System...........................................................................2-1
2.4 Fluid data.................................................................................2-2
2.4.1 Black Oil................................................................................2-2
2.4.2 Compositional .......................................................................2-4
2.4.3 Steam....................................................................................2-5
2.5 Model components overview ...............................................2-5
2.5.1 Model & Component limitations ...........................................2-9
2.6 Flow correlation ...................................................................2-10
2.7 Run an operation .................................................................2-10
2.8 Saving & Closing PIPESIM 2000........................................2-11
2.9 How to build models............................................................2-11
2.9.1 Fluid calibration ..................................................................2-11

5. Contents v
PIPESIMPIPESIM 2000
2.9.1.1 Black Oil.......................................................................2-11
2.9.1.2 Compositional ..............................................................2-12
2.9.2 Pipeline & facilities .............................................................2-12
2.9.2.1 Correlation matching ...................................................2-12
2.9.2.2 Pressure/Temperature profile.....................................2-13
2.9.2.3 Equipment/Flowline sizing (1 parameter)...................2-13
2.9.2.4 Equipment/Flowline sizing (Multiple parameter) ........2-13
2.9.2.5 Multiphase booster design ..........................................2-14
2.9.3 Well Performance...............................................................2-15
2.9.3.1 Correlation matching ...................................................2-15
2.9.3.2 Nodal analysis..............................................................2-15
2.9.3.3 Pressure/Temperature profile.....................................2-16
2.9.3.4 Equipment/Tubing sizing (1 parameter) .....................2-16
2.9.3.5 Equipment/Tubing sizing (Multiple parameter) ..........2-16
2.9.3.6 Artificial Lift analysis ....................................................2-17
2.9.3.7 Well performance curves for GOAL............................2-17
2.9.3.8 Reservoir Tables..........................................................2-17
2.9.3.9 Horizontal completion length.......................................2-18
2.9.3.10 Gas Lift Rate v's Casing head pressure .....................2-18
2.9.4 Network Analysis................................................................2-18
2.9.4.1 Fluid properties ............................................................2-18
2.9.4.2 Boundary Conditions ...................................................2-18
2.9.4.3 Network model.............................................................2-19
2.9.5 Production Optimization.....................................................2-20
2.9.6 Field Planning.....................................................................2-20
2.9.7 Multi-lateral.........................................................................2-21
3 FLUID & MULTIPHASE FLOW MODELLING ........... 3-1
3.1 Black Oil ..................................................................................3-1
3.1.1 Lasater ..................................................................................3-1
3.1.1.1 Bubble point pressure ...................................................3-1
3.1.1.2 Solution gas...................................................................3-2
3.1.2 Standing................................................................................3-2
3.1.2.1 Bubble point pressure ...................................................3-2
3.1.2.2 Solution gas...................................................................3-2
3.1.2.3 Oil formation volume factor - saturated systems..........3-2
3.1.3 Vazques and Beggs.............................................................3-2

6. vi Contents
PIPESIMPIPESIM 2000
3.1.3.1 Bubble point pressure ...................................................3-3
3.1.3.2 Solution gas...................................................................3-3
3.1.3.3 Oil formation volume factor - saturated systems..........3-3
3.1.3.4 Oil formation volume factor - undersaturated systems 3-3
3.1.4 Glasø ....................................................................................3-3
3.1.4.1 Bubble point pressure and solution gas .......................3-4
3.1.4.2 Oil formation volume factor - saturated systems..........3-4
3.1.4.3 Oil formation volume factor - undersaturated systems 3-4
3.1.5 Coning...................................................................................3-4
3.1.6 Liquid Viscosity.....................................................................3-5
3.1.7 Dead Oil Viscosity................................................................3-5
3.1.7.1 Beggs and Robinson method........................................3-6
3.1.7.2 Glasø method ................................................................3-6
3.1.7.3 User's data method........................................................3-6
3.1.8 Live Oil Viscosity ..................................................................3-6
3.1.8.1 Chew and Connally .......................................................3-7
3.1.8.2 Beggs and Robinson .....................................................3-7
3.1.9 Undersaturated Oil Viscosity...............................................3-7
3.1.9.1 Vasquez and Beggs ......................................................3-7
3.1.9.2 Kousel method...............................................................3-8
3.1.9.3 No calculation ................................................................3-8
3.1.10 Oil/Water Mixture Viscosity ..................................................3-8
3.1.10.1 Inversion method ...........................................................3-8
3.1.10.2 Volume ratio method .....................................................3-8
3.1.10.3 Woelflin method.............................................................3-9
3.1.11 Gas Viscosity........................................................................3-9
3.1.11.1 Lee et al. Method ...........................................................3-9
3.2 Compositional ........................................................................3-9
3.2.1 EOS (Equations of State) ....................................................3-9
3.2.1.1 Soave-Redlich-Kwong...................................................3-9
3.2.1.2 Peng-Robinson............................................................3-10
3.2.1.3 SMIRK..........................................................................3-10
3.2.2 Viscosity model ..................................................................3-10
3.2.2.1 Lower Alkanes .............................................................3-11
3.2.2.2 Higher Alkanes ............................................................3-11
3.2.2.3 Petroleum Fractions ....................................................3-11
3.2.2.4 Water............................................................................3-11
3.2.2.5 Methanol ......................................................................3-12

7. Contents vii
PIPESIMPIPESIM 2000
3.2.2.6 Emulsion ......................................................................3-12
3.2.3 BIP (Binary Interaction Parameter) Set.............................3-12
3.2.4 Hydrates .............................................................................3-12
3.3 Pressure Drop Calculation .................................................3-14
3.3.1 Flow regimes ......................................................................3-15
3.3.2 Single Phase Flow Correlations ........................................3-18
3.3.2.1 Moody...........................................................................3-18
3.3.2.2 AGA..............................................................................3-18
3.3.2.3 Panhandle 'A'...............................................................3-19
3.3.2.4 Panhandle 'B'...............................................................3-19
3.3.2.5 Hazen-Williams ............................................................3-19
3.3.2.6 Weymouth....................................................................3-19
3.3.3 Vertical Multiphase Flow Correlations...............................3-19
3.3.3.1 Ansari ...........................................................................3-19
3.3.3.2 Baker Jardine Revised ................................................3-19
3.3.3.3 Beggs & Brill Original...................................................3-20
3.3.3.4 Beggs & Brill Original, Taitel Dukler map ...................3-20
3.3.3.5 Beggs & Brill Revised..................................................3-20
3.3.3.6 Beggs & Brill Revised, Taitel Dukler map...................3-20
3.3.3.7 Brill & Minami...............................................................3-21
3.3.3.8 Duns & Ros..................................................................3-21
3.3.3.9 Duns & Ros, Taitel Dukler map...................................3-21
3.3.3.10 Govier & Aziz...............................................................3-21
3.3.3.11 Gray..............................................................................3-22
3.3.3.12 Hagedorn & Brown ......................................................3-22
3.3.3.13 Hagedorn & Brown, Duns & Ros map........................3-22
3.3.3.14 Lockhart & Martinelli....................................................3-22
3.3.3.15 Lockhart & Martinelli, Taitel Dukler map.....................3-22
3.3.3.16 Mukherjee & Brill:.........................................................3-22
3.3.3.17 NOSLIP Correlation.....................................................3-23
3.3.3.18 OLGA-S 2000 Steady State........................................3-23
3.3.3.19 Orkiszewski..................................................................3-24
3.3.3.20 Shell SIEP Correlations ...............................................3-24
3.3.3.21 Shell SRTCA Correlations...........................................3-24
3.3.3.22 GRE Mechanistic Model BP ........................................3-24
3.3.4 Horizontal Multiphase Flow Correlations ..........................3-24
3.3.4.1 Baker Jardine Revised ................................................3-25
3.3.4.2 Beggs & Brill Original...................................................3-25

8. viii Contents
PIPESIMPIPESIM 2000
3.3.4.3 Beggs & Brill Original, Taitel Dukler map ...................3-25
3.3.4.4 Beggs & Brill Revised..................................................3-25
3.3.4.5 Beggs & Brill Revised, Taitel Dukler map...................3-26
3.3.4.6 Brill & Minami: ..............................................................3-26
3.3.4.7 Dukler, AGA + Flanagan .............................................3-26
3.3.4.8 Dukler , AGA + Flanagan (Eaton holdup)...................3-26
3.3.4.9 Duns & Ros, Taitle Dukler map...................................3-26
3.3.4.10 Lockhart & Martinelli....................................................3-27
3.3.4.11 Lockhart & Martinelli, Taitel Dukler map.....................3-27
3.3.4.12 Mukherjee & Brill..........................................................3-27
3.3.4.13 NOSLIP Correlation.....................................................3-27
3.3.4.14 OLGA-S 2000 Steady-State:.......................................3-27
3.3.4.15 Oliemans......................................................................3-28
3.3.4.16 Xiao ..............................................................................3-28
3.3.4.17 Shell SIEP Correlations ...............................................3-28
3.3.4.18 Shell SRTCA Correlations...........................................3-29
3.3.4.19 GRE Mechanistic Model BP........................................3-29
3.4 References............................................................................3-29
4 RESERVOIR, WELL & COMPLETION MODELLING 4-1
4.1 Vertical Completions.............................................................4-1
4.1.1 Liquid Reservoirs..................................................................4-1
4.1.1.1 Fetkovich / Normalized back pressure .........................4-1
4.1.1.2 Jones..............................................................................4-1
4.1.1.3 Pseudo-Steady state / Darcy ........................................4-2
4.1.1.4 (Straight line) Well productivity Index...........................4-2
4.1.1.5 (Straight line) Well productivity Index (bubble point
correction) ....................................................................................4-2
4.1.1.6 Vogel ..............................................................................4-2
4.1.1.7 Multi-rate tests ...............................................................4-3
4.1.2 Gas and Gas Condensate Reservoirs ................................4-3
4.1.2.1 Back pressure / C and n................................................4-3
4.1.2.2 Forchheimer...................................................................4-3
4.1.2.3 Jones..............................................................................4-3
4.1.2.4 Pseudo-Steady state / Darcy ........................................4-4
4.1.2.5 (Straight line) Well productivity Index...........................4-4
4.1.2.6 Multi-rate tests ...............................................................4-4

9. Contents ix
PIPESIMPIPESIM 2000
4.2 Horizontal Completions ........................................................4-4
4.2.1 Effect of Pressure Drop on Productivity..............................4-5
4.2.2 Single Phase Pressure Drop...............................................4-8
4.2.3 Multiphase Pressure Drop ...................................................4-9
4.2.4 Inflow Production Profiles....................................................4-9
4.2.5 Steady-State Productivity ..................................................4-10
4.2.6 Pseudo-Steady State Productivity.....................................4-13
4.2.7 Solution Gas-Drive IPR......................................................4-15
4.2.8 Horizontal Gas Wells..........................................................4-15
4.3 Multiple Layers / Completions ...........................................4-17
4.4 Artificial Lift ..........................................................................4-18
4.4.1 Gas Lift................................................................................4-18
4.4.2 ESP Lift ...............................................................................4-19
4.5 Tubing....................................................................................4-19
4.6 Chokes...................................................................................4-20
4.6.1 Ashford-Pierce....................................................................4-20
4.6.2 Omana ................................................................................4-21
4.6.3 Gilbert, Ros, Baxendall, Achong and Pilehvari .................4-22
4.6.3.1 PDVSA modification ....................................................4-23
4.6.4 Poettmann-Beck.................................................................4-23
4.6.5 Mechanistic Correlation, ....................................................4-24
4.6.6 API 14-B Formulation.........................................................4-26
4.7 Heat transfer.........................................................................4-27
4.8 Reservoir Depletion .............................................................4-27
4.8.1 Volume Depletion Reservoirs............................................4-27
4.8.2 Gas Condensate Reservoirs .............................................4-29
4.9 References............................................................................4-29
5 FIELD EQUIPMENT ................................................... 5-1
5.1 Compressor ............................................................................5-1
5.2 Expander .................................................................................5-2

10. x Contents
PIPESIMPIPESIM 2000
5.3 Single Phase Pump................................................................5-3
5.4 Multiphase Boosting .............................................................5-3
5.4.1 Multiphase Boosters – Positive Displacement Type ..........5-8
5.4.2 Twin Screw Type Multiphase Boosters...............................5-9
5.4.3 Progressing Cavity Type Multiphase Boosters.................5-11
5.4.4 Multiphase Boosters – Dynamic Type...............................5-12
5.4.5 Helico-Axial Type Multiphase Boosters ............................5-13
5.4.6 Contra-Rotating Axial Type Multiphase Booster...............5-15
5.4.7 Alternative approach ..........................................................5-16
5.5 Separator...............................................................................5-17
5.6 Re-injection point.................................................................5-17
5.7 Heat Transfer ........................................................................5-17
5.8 References............................................................................5-17
6 OPERATIONS ............................................................ 6-1
6.1 Check model...........................................................................6-1
6.2 No operation ...........................................................................6-1
6.3 Run model...............................................................................6-1
6.4 System Analysis.....................................................................6-2
6.5 Pressure Temperature profile ..............................................6-2
6.6 Flow correlation matching....................................................6-2
6.7 Wax Prediction .......................................................................6-3
6.8 Nodal Analysis .......................................................................6-3
6.9 Artificial Lift Performance.....................................................6-4
6.9.1 Optimization module performance curves ..........................6-5
6.9.1.1 Well head chokes ..........................................................6-5
6.10 Gas Lift Design & Diagnostics.............................................6-7

11. Contents xi
PIPESIMPIPESIM 2000
6.10.1 Check for Gas Lift instability ................................................6-7
6.11 Horizontal well analysis......................................................6-10
6.12 Reservoir tables...................................................................6-10
6.13 Network analysis..................................................................6-11
6.14 Optimization..........................................................................6-11
6.15 Field Planning.......................................................................6-12
6.15.1 Dynamic Eclipse link ..........................................................6-12
6.15.2 Look-up tables....................................................................6-14
6.15.3 Compositional tank models................................................6-15
6.15.4 Event handling....................................................................6-16
6.16 Multi-lateral well analysis ...................................................6-17
6.17 Post processor .....................................................................6-17
6.17.1 Graphical plots ...................................................................6-17
6.17.2 Tabular data .......................................................................6-18
6.17.3 Onscreen data....................................................................6-18
6.18 References............................................................................6-18
7 CASE STUDIES......................................................... 7-1
7.1 Pipeline & facilities Case Study – Condensate Pipeline ..7-3
7.1.1 Task 1. Develop a Compositional Model of the Hydrocarbon
Phases .............................................................................................7-3
7.1.2 Task 2. Identify the Hydrate Envelope ................................7-4
7.1.3 Task 3. Select a Pipeline Size .............................................7-5
7.1.4 Task 4. Determine the Pipeline Insulation Requirement....7-7
7.1.5 Task 5. Screen the Pipeline for Severe Riser Slugging .....7-9
7.1.6 Task 6. Size a Slug Catcher ..............................................7-12
7.1.7 Data Available ....................................................................7-14
7.2 Well Performance Case Study – Oil Well Design............7-16
7.2.1 Task 1. Develop a Calibrated Blackoil Model ...................7-17
7.2.2 Task 2. Develop a Well Inflow Performance Model..........7-22
7.2.3 Task 3. Select a Tubing Size for the Production String....7-22

12. xii Contents
PIPESIMPIPESIM 2000
7.2.4 Data Available ....................................................................7-24
7.3 Network Analysis Case Study – Looped Gathering
Network.............................................................................................7-27
7.3.1 Task 1. Build a Model of the Network ...............................7-27
7.3.2 Task 2. Specify the Network Boundary Conditions ..........7-31
7.3.3 Task 3. Solve the Network and Establish the deliverability..7-
32
7.3.4 Data Available ....................................................................7-33
7.4 Production Optimization.....................................................7-37
7.5 Field Planning.......................................................................7-37
7.6 Multi-lateral ...........................................................................7-37
8 INDEX..............................................................................I

13. Conventions xiii
PIPESIMPIPESIM 2000
Document conventions
<edit/copy> - used to denote commands enter into the computer from
either Microsoft Windows operating systems or PIPESIM 2000

14. xivConventions
PIPEPIPE SIMSIM 2000
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15. PIPESIM 2000 Hot Keys xv
PIPESIMPIPESIM 2000
PIPESIM 2000 Hot Keys
File
Create New Well Model CTRL+W
Create New Pipeline Model CTRL+
Create New Network model CTRL+N
Open model CTRL+O
Open engine file CTRL+T
Save model CTRL+S
Close PIPESIM 2000 ALT+F4
Text Edit CTRL+T
Export to Engine file CTRL+E
Purge Engine Files CTRL+Y
Simulation
Run model CTRL+G
Restart Model CTRL+R
Check model CTRL+E
Windows
New Model Window CTRL+W
Close Active Window CTRL+F4
Go to Next Window CTRL+F6 or CTRL+TAB
Go to Previous Window CTRL+SHIFT+F6 or
CTRL+SHIFT+ TAB
Tools
Print CTRL+P
Access Help F1
Editing/General
Access Pull-down menus ALT or F10
Cut CTRL+X
Copy CTRL+C
Paste CTRL+V
Delete Del
Select All CTRL+A
Find CTRL+F
Sticky key mode SHIFT

16. xvi PIPESIM 2000 Hot Keys
PIPESIMPIPESIM 2000
Zoom in SHIFT+Z
Zoom out SHIFT+X
Zoom Full View SHIFT+F
Restore View SHIFT+R

17. Introduction
PIPESIMPIPESIM 2000
1 INTRODUCTION........................................................ 1-1
1.1 Setting up................................................................................1-1
1.1.1 Before you run setup............................................................1-1
1.1.2 Running setup ......................................................................1-3
1.1.3 Changing Options after quitting setup.................................1-3
1.2 Documentation .......................................................................1-3
1.2.1 PIPESIM 2000 additional documentation ...........................1-3
1.2.2 Case Studies ........................................................................1-4
1.2.3 Online Help...........................................................................1-4
1.3 PIPESIM 2000 overview.........................................................1-5
1.3.1 Modules................................................................................1-6
1.3.2 Options..................................................................................1-9
1.4 File Management..................................................................1-11
1.5 Security .................................................................................1-12
1.5.1 Stand-alone security ..........................................................1-12
1.5.2 LAN Security.......................................................................1-13
1.6 New features.........................................................................1-13
1.7 Baker Jardine Support Services........................................1-14
1.8 What to do next....................................................................1-15

18. Introduction
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19. Introduction 1-1
PIPESIM 2000
1 Introduction
Welcome to Baker Jardine's PIPESIM 2000 - the integrated
Petroleum Engineer and Facilities package for; Design, Operation
and Optimization.
1.1 Setting up
You install PIPESIM 2000 on your computer by using the program
SETUP.EXE. The setup up program installs PIPESIM 2000 itself, the
Help system, sample case studies, the necessary start icons and any
other components required from the distribution disk to your local
hard disk.
Important
You can not simply copy files from the distribution disk to your hard
disk and run PIPESIM 2000. You must use the setup program. This
will decompress and installs files in the correct directory and register
the required COM objects.
1.1.1 Before you run setup
Before you install PIPESIM 2000, please make sure that your
computer meets the minimum requirements and that the PIPESIM
2000 package contains the required items.
This manual assumes that you have a basic working knowledge of
Microsoft Windows 95 or higher. If you are not familiar with Windows,
then you should refer to the Microsoft Windows User's Guide before
reading this manual or using the software.
1.1.1.1 Hardware and system requirements
To run PIPESIM 2000 you must have certain hardware and software
installed.
The minimum system requirements are:
• Any IBM Compatible PC with an Pentium processor or
higher 200MHz
• A hard disk
• At least 100Mb of free space on the hard disk
• A CD-ROM drive

20. 1-2 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
• A VGA display
• A mouse
• 16Mb of RAM
• Microsoft Windows 95 or higher
• The PC system date is set to the current date. The security
system uses the current PC date.
The recommended system requirements are:
• Pentium II processor 400MHz
• 3Gb hard disk
• A 4x CD-ROM drive
• A SVGA display running in 1024x768 and 256 colors
• A 2 button mouse
• 64Mb of RAM
• Microsoft Windows NT
1.1.1.2 Check the PIPESIM 2000 package
The following items should be in the PIPESIM 2000 package:
• PIPESIM 2000 User Guide
• PIPESIM 2000 Additional Notes
• PIPESIM 2000 Service Pack Notes
• PIPESIM 2000 CD
• Registration form (also available on our web site)
• Software license reference number. This should be quoted
on all correspondence.
If any of the above are missing then please contact your nearest
Baker Jardine office.
1.1.1.3 Make backup copies
Before you run the install procedure please back up copies of any
important data stored on your PC.
You are also encouraged to make a back up copy of the install CD.
1.1.1.4 Read the additional notes document
The additional notes' document (shipped with the package) lists any
changes to the User Guide since its publication.

21. Introduction 1-3
PIPESIM 2000
1.1.2 Running setup
When you run the setup program
To start Setup
Once you have installed PIPESIM 2000 the following links will be
created on the Programs menu;
• Baker Jardine
• PIPESIM 2000
• GOAL
• FPT
• HoSim
• Open Link documentation
• Utilities
• B26 to P2K Converter
• Security utilities
• User defined DLL registry editor
1.1.3 Changing Options after quitting setup
You can run they setup program as many times as you like to install
or remove components.
1.2 Documentation
1.2.1 PIPESIM 2000 additional documentation
In addition to this User Guide the following documentation is available
to assist users in using PIPESIM 2000 or some of its modules.
The latest versions of these documents are available from any Baker
Jardine support office or can be downloaded directly from the Baker
Jardine web site in Adobe Acrobat PDF format.
1.2.1.1 Artificial lift Performance curve
The optimizer module utilizes artificial lift performance curves to
model the wells. These can be created by a suitable Nodal analysis
software package.

22. 1-4 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
1.2.1.2 User Defined Multiphase flow correlation
The user can create their own multiphase flow correlations and link
these into PIPESIM 2000.
1.2.1.3 OpenLink
A collection of COM object that allows PIPESIM 2000 to be accessed
from 3
rd
party applications, e.g. Microsoft Excel, Visual basic, etc.
A up to date list of features and functionality can be obtained from the
Baker Jardine web site, along with the all necessary documentation.
1.2.1.4 PVT file format
The composition can be transferred from third party applications
directly into PIPESIM 2000, provide that it is supplied in the correct
format. This document details that format.
1.2.1.5 Sentinel LM Security
The LAN version of PIPESIM 2000 utilizes Sentinel LM License
manger as its security system The Sentinel LM Administrators Guide
can be of assistance to IT personnel.
Note: This User Guide does not cover the menus or dialogs that are
used within the software. These are covered, in detail, in the Help
system, supplied with PIPESIM 2000.
1.2.2 Case Studies
The PIPESIM 2000 installation installs sample models on to your
hard disk.
1.2.3 Online Help
You can access Help through
• the Help Contents command,
• by searching for specific topics with the Help Search tool
• pressing F1 to get context-sensitive Help.
1.2.3.1 Help contents
For information on Help topics, choose Contents from the Help menu
or press F1 and click the Contents button. You can use the Contents
screen to jump to topics that tell you how to use PIPESIM 2000, or to
get quick access to key reference topics.

23. Introduction 1-5
PIPESIM 2000
1.2.3.2 Help Search
The fastest way to find a particular topic in the Help system is to use
the Search dialog box. To display the Search dialog box, you can
either choose Search from the help menu or click the Search button
on the Help topic screen. The keyword or phase to search for can
then be entered.
1.2.3.3 Context-sensitive Help
Many parts of PIPESIM 2000 are context-sensitive. That means that
you can get help on these parts directly without having to go through
the Help menu.
You can press F1 from any context-sensitive part of PIPESIM 2000 to
display information about that part. The context-sensitive parts are:
• Items on the toolbar
• Objects on a dialog box
1.3 PIPESIM 2000 overview
The table below shows the minimum modules that are required to
conduct various studies.
Pipeline&Facilities
Module
WellPerformance
Module
NetworkModule
OptimizationModule
FieldPlanning
Module
Horizontal&
Multilateralmodule
Pipeline sizing 3
Equipment sizing 3
Nodal Analysis 3 3
Multiple Completions 3 3
Reservoir tables 3 3
Surface networks 3 3
Subsurface & surface networks 3 3 3
Field wide Optimization 3 3 3
Field Planning 3 3 3 3
Multi-lateral well 3

24. 1-6 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
The initial release of PIPESIM 2000 does not have all modules fully
integrated, i.e. Production Optimization (GOAL), Field Planning
(FPT), Multi-lateral well (HoSim).
1.3.1 Modules
PIPESIM 2000 consists of the following modules:
• Pipeline & Facilities
• Well Performance Analysis
• Network Analysis
• Production Optimization (GOAL)
• Field Planning (FPT)
• Multi-lateral (HoSim)
1.3.1.1 Pipeline & Facilities
A comprehensive multiphase flow model with "System Analysis"
capabilities. Typical applications of the module include:
• multiphase flow in flowlines and pipelines
• point by point generation of pressure and temperature profiles
• calculation of heat transfer coefficients
• flowline & equipment performance modelling (system analysis)
1.3.1.2 Well Performance analysis
A comprehensive multiphase flow model with "Nodal & System
Analysis" capabilities. Typical applications of the model include:
• Well design
• Well optimization
• well inflow performance modelling
• gas lift performance modelling
• ESP performance modelling
• horizontal well modelling (including optimum horizontal
completion length determination)
• injection well design
• annular and tubing flow
1.3.1.3 Network analysis module
Features of the network model include:

25. Introduction 1-7
PIPESIM 2000
• unique network solution algorithm to model wells in large
networks
• rigorous thermal modelling of all network components
• multiple looped pipeline/flowline capability
• well inflow performance modelling capabilities
• rigorous modelling of gas lifted wells in complex networks
• comprehensive pipeline equipment models
• gathering and distribution networks
1.3.1.4 Production Optimization (GOAL)
This module allows production optimization of an artificial lifted (gas
lift or ESP) oil field to be performed given a number of practical
constraints on the system.
The module will predict the optimum artificial lift quantity (lift gas or
ESP speed) so as to optimize oil production from the entire field. As
an alternative to calculations based on produced oil the optimization
can be performed on gross liquids, gross gas or revenue. The
program models the full network on a point-by-point basis, and offers
a choice of flow correlation options for multiphase flow.
In addition to being able to optimize field production it includes a
unique production prediction mode, which allows current field
production rates and pressures to be predicted and the results
compared directly against actual field data.
The module has been primarily developed for use by operations staff
in the day-to-day optimization and allocation of lift gas for complex
multi-well networked configurations.
GOAL has been designed with to allow answers to specific problems
to be easily obtained. This could be, for example, when a well is shut-
in and the extra quantity of lift gas or horse power is made available.
The module can then be used to determine the best re-allocation of
the lift gas to the remaining wells, while taking into account any
production constraints, to optimize the total production.
To allow the day-to-day modelling of the system to be performed
quickly, modelling of the wells and the optimization process have
been separated. This allows answers to specific problems, by

26. 1-8 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
examining a number of scenarios, to be generated in a very short
time.
Input is taken from individual well performance models created from a
multiphase flow simulator, in the form of well performance curves.
These performance curves should be generated and checked before
being included in the model.
To obtain the correct solution the pressure drop must be correctly
accounted for along the surface network. This is simulated by the use
of (tuned) industrial standard multiphase flow correlation's to predict
the pressure loss and liquid hold-up in the pipeline.
In its production prediction mode of operation it can be used to
validate the individual well gas lift or ESP lift performance curves by
using them to predict current production rates.
Results are displayed in tabular form, graphical plots or by utilizing
the sophisticated graphical user interface to display a variety of rates
and pressures. The solution provides a comprehensive report that
includes the required gas injection rate for each well or required
operating speed for each well, the flowrate and pressure at each
manifold in the system and economic data.
Full features of the model include:
• interfaces with the well Analysis module
• solves multi-well commingled scenarios
• allows well production performance modelling
• offers operator decision support functions
• Black Oil only
1.3.1.5 Multi-lateral wells (HoSim)
HoSim is designed to model horizontal and multilateral hetrogeneous
wells in detail. The software uses a rigorous network solution
algorithm to solve horizontal and multilateral wells as gathering
networks.
The program enables detailed horizontal well models to be built
quickly and easily through a graphical user interface. The user can

27. Introduction 1-9
PIPESIM 2000
define various IPR relationships, and specify a detailed well
description. Certain equipment models, which are common to the
pipeline and facilities module, are available such as chokes, gas lift,
ESP’s and also separators, compressors, pumps etc.
Fluid description can be either black oil or compositional and different
fluids can be specified which are mixed together using appropriate
mixing rules.
Specifying either an outlet pressure or an outlet flowrate (or a range
of values for a batch run) to run the model.
Results can be displayed either as text (point values) or graphically
for any part of the model.
1.3.1.6 Field Planning (FPT)
Allows the network module to be coupled to a “reservoir model” to
model reservoir behavior over time. In addition conditional logic
decision can be taken into account, i.e. bring well 56 on steam in year
5, etc.
The reservoir may be described as either;
• Black oil tank model
• Compositional tank model
• look-up tables
• Commercial reservoir simulator
• Commercial material balance program
1.3.2 Options
In addition to the above basic modules a number of options are
available.
1.3.2.1 Compositional option
Allows a PVT package to be used to determine the fluid properties.
Options are
• Multiflash
• SPPTS (Shell only)
The compositional options have the following features;
• Standard library of 50+ components

28. 1-10 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
• Petroleum Fraction
• Phase envelop generation
• Dew point line
• Bubble point line
• Critical point
• Hydrate formation line (if present)
• Ice formation line (if present)
• Quality lines
• EOS
• Peng-Robinson (standard and advanced)
• SRK (standard and advanced)
• Corresponding EOS
• SMIRK (limited access)
• Stand alone flash (PT, PH, etc) details
• Viscosity models
• Pederson
• LBC
In addition the Multiflash option has the following features;
• Multiple Bubble point matching
• Multiple Dew point matching
• Multiple Viscosity data matching
• Setting of BIP's
• Emulsion options
• User defined BIP's
1.3.2.2 OLGAS 2000
Utilizes the steady-state version of the multiphase flow correlation
from Scandpower as used in OLGA Transient.
This option has 2 versions;
(i) 2-phase and
(ii) 3-phase.
1.3.2.3 ECLIPSE 100
Allows the Field Planning module to use the ECLIPSE 100 (Black Oil)
reservoir simulator to model the reservoir performance. The system

29. Introduction 1-11
PIPESIM 2000
has been designed so that ECLIPSE (and its model) resides on the
UNIX machine.
1.3.2.4 ECLIPSE 300
Allows the Field Planning module to use the ECLIPSE 300 reservoir
simulator (Compositional) to model the reservoir performance. The
system has been designed so that ECLIPSE (and its model) resides
on the UNIX machine.
1.3.2.5 Mbal
Allows the Field Planning module to use the material balance
program Mbal (from Petroleum Experts) to model the reservoir
performance.
1.4 File Management
PIPESIM 2000 uses the following to store data;
• ASCII files
• Binary files
• Microsoft Access Database.
Input data (*.BPS, *.BPN, *.PGW, *.FPT,*.HSM)
Contains all the data that is necessary to run a model. This includes
data for; units, fluid composition, well IPR, system data, etc. The
support team requires these files when support queries are made.
Output data (*.OUT, *.SUM)
Contains program output data in different formats.
Transfer files (*.PLT, *.PLC, *.PWH, *.PBT, *.TNT, *.PST)
Files that transfer data from one PIPESIM 2000 module to another.
PVT table (*.PVT)
A file that contains a single stream composition and a table of fluid
properties for a given set of pressure and temperature values. This
file can (if required) be created by a commercial PVT package e.g.
Multiflash, Hysys, PVTSim, EQUI90, etc. or via the compositional
module in PIPESIM 2000.
Database files (*.MDB)
Microsoft Access Database file that contains;

30. 1-12 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
• Black Oil fluid data,
• ESP performance curves
• User defined pump and compressor curves
Units file (*.UMF)
Units files. Used to store user defined unit sets. These files can be
passed from user-to-user.
1.5 Security
Stand-alone (single PC) versions of PIPESIM 2000 are protected
from unauthorized use by means of a hardware security module
(generally referred to as a 'dongle' or 'bit lock'). Local Area Network
(LAN) versions are normally protected via License Manager software.
1.5.1 Stand-alone security
When the program executes the dongle must be attached to the
parallel port of the computer otherwise it will not run. The dongle
remains the property of Baker Jardine while in use by customers, and
are not replaceable if lost.
You can connect another device (or more Baker Jardine dongles) to
the parallel port while the dongle is still attached to it without affecting
the operation of the device or the dongle. Do this simply by plugging
the device into the back of the dongle. If you already have another
program protected by a similar dongle, they can both be plugged into
the port at the same time, and should not interfere with each other.
The dongle is quite robust, so no particular care need be taken in
handling it.
Users are able to view the Baker Jardine software modules licensed
on their dongles by using the Dongle Utility, BJA Dongle Utility. On
start-up of the utility, the attached dongle’s license details for the
various software modules are displayed. When renewing or
purchasing additional software licenses you will need to update the
licenses on your dongle(s) by receiving instructions from Baker
Jardine.
The dongles have an internal timing mechanism to enforce the
license periods. It is important NOT to set your PC’s clock into the
future and run PIPESIM 2000, as the dongle will prevent you from

31. Introduction 1-13
PIPESIM 2000
using PIPESIM 2000 after you have set your clock back. If you do
accidentally do this, contact Baker Jardine for information on how to
“reset” your dongle.
1.5.2 LAN Security
For LAN versions of PIPESIM 2000 the Sentinel License Manger
software from Rainbow Technology is used.
This system allows the number of concurrent users of the PIPESIM
2000 software to be monitored and controlled to insure that you don't
violate your license agreement.
The SentinelLM license server, installed on the LAN, can authorize,
meter and report PIPESIM 2000 usage. When PIPESIM 2000 is run,
it first makes a check to SentinelLM to verify that use is permitted by
the license agreement. If the user is authorized, then SentinelLM
gives PIPESIM 2000 permission to run. If permission is granted, this
process is invisible. If permission is denied, then you will be informed
and PIPESIM 2000 exited. Permission may be denied because all the
available PIPESIM 2000 licenses are in use, the license has expired,
or no license has been installed.
The LAN security system also has the following license management
capabilities,
• PIPESIM 2000 can be restricted to one or more computers
• A summary of current and historical PIPESIM 2000 usage can
be obtained
• A network administrator can impose local restrictions on the
usage of PIPESIM 2000. A certain number of licenses may be
reserved for particular departments or work groups.
• A network administrator can configure the license server to
report certain conditions such as approaching license
expiration.
A document," Sentinel License Manger; System Administrator's
Guide" can be down loaded from out web site.
1.6 New features
You are advised to review the additional notes' document supplied
with your version of the software for a complete list of new features.

32. 1-14 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
Our web site also provides detailed information on the latest version.
In addition, enhancements (service packs) can be download from the
site to fix minor bugs and enhancements.
1.7 Baker Jardine Support Services
Baker Jardine offer full technical support for PIPESIM 2000 from our
offices.
Center Tel Fax
London
Baker Jardine
9 Heathmans Road
Parsons Green
London SW6 4TJ
UK
+44 20 7371 5644 +44 20 7371 5182
Support@bjalondon.com
America
Baker Jardine Americas
Suite 440, 7500 San Felipe
Houston, TX 77063
USA
+1 713 334 2243 +1 713 334 2195
Support@bjahouston.com
Venezuela
Baker Jardine de Venezuela +58 61 922 346 +58 61 921 812
Bjvsptec@iamnet.com
Mexico
Baker Jardine de Mexicana +52 93 16 18 61 +52 93 16 48 56
Adelfo@compuserve.com
Canada
Baker Jardine
740, 600 6th Avenue S.W.
Calgary, T2P 0S5
Canada
+1 403 265 2696 +1 403 265 2646
Austin_James@atech.ca
To offer the best and fastest support our preferred method for
support services is via email.
In addition our web site offer a collect of frequently asked questions
(FAQ').

33. Introduction 1-15
PIPESIM 2000
1.8 What to do next
Depending upon your needs the following is recommended;
New users
• Familiarize yourself with the all PIPESIM 2000 modules, their
function and application.
• Work through the case studies for your particular area of interest
Existing users
• Read the new features section and the additional notes' document
to obtain an overview of new features.

34. 1-16 Introduction
PIPESIMPIPESIM 2 0 0 02 0 0 0
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35. Model Overview
PIPESIMPIPESIM 2000
2 MODEL OVERVIEW 2-1
2.1 Steps in building a model 2-1
2.2 Starting PIPESIM 2000 2-1
2.3 Units System 2-1
2.4 Fluid data 2-2
2.4.1 Black Oil 2-2
2.4.2 Compositional 2-4
2.4.3 Steam 2-5
2.5 Model components overview 2-5
2.5.1 Model & Component limitations 2-9
2.6 Flow correlation 2-10
2.7 Run an operation 2-10
2.8 Saving & Closing PIPESIM 2000 2-11
2.9 How to build models 2-11
2.9.1 Fluid calibration 2-11
2.9.2 Pipeline & facilities 2-12
2.9.3 Well Performance 2-15
2.9.4 Network Analysis 2-18
2.9.5 Production Optimization 2-20
2.9.6 Field Planning 2-20
2.9.7 Multi-lateral 2-21

36. Model Overview
PIPESIM 2000PIPESIM 2000
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37. Model Overview 2-1
PIPESIM 2000
2 Model Overview
2.1 Steps in building a model
The steps involved in building a PIPESIM 2000 model are slightly
different for each module but follow the same basic steps.
• Select units
• Set fluid data
• Calibrate data (optional)
• Define components in the model
• Well components (completion, tubing)
• Pipeline component
• Field equipment
• Set heat transfer options
• Select multiphase flow correlation
• Perform an operation
• Analyze the results
• Graphical
• Tabular
• Via schematic
2.2 Starting PIPESIM 2000
The PIPESIM 2000 GUI can be run from the start menu
<start/program files/Baker Jardine/PIPESIM 2000>.
2.3 Units System
The built in units system allows you the flexibility to select any
variable and define the unit of measurement to be used. Thus you
can use this feature to modify the units system to match reports or
data supplied by a service company or to simply customize the units
system to suit your own personal preferences.
Two non-customizable unit sets are provided;
• Engineering (oil field) and
• SI.
In addition the following customizable unit sets are supplied;
• Mexican
• Canadian S.I

38. 2-2 Model Overview
PIPESIM 2000PIPESIM 2000
Any number of customized unit sets can be created and saved (each
one to a different external data file) under a new name. These
customized files can be provided to other PIPESIM 2000 users.
The units system used for any particular model is saved with the
model data, thus allowing models to be moved easily.
Any unit set can be set as the default for new models or new
sessions of PIPESIM 2000.
2.4 Fluid data
One of the first things that you need to do before using PIPESIM
2000 is to decide what type of fluid system you are going to use.
PIPESIM 2000 can model the following fluid types
• Compositional
• Black Oil
• Gas
• Gas condensate
• Liquid
• Liquid & Gas
• Steam
The fluid model that you use will depend upon:
• Properties of the fluids in the system
• Flow rates and conditions (pressure & temperature) at which the
fluid(s) enter and leave the system.
• Available data, etc.
For a quick screening study where the accuracy of the physical
properties is not essential, we advise the user to use a Black oil fluid
model specification.
2.4.1 Black Oil
Black oil fluid modelling utilizes correlation models to simulate the key
PVT fluid properties of the oil/gas/water system. These empirical
correlation's treat the oil/gas system as a simple two component
system - unlike the more rigorous multi-component compositional
model methods. The hydrocarbon is treated simply as a liquid

39. Model Overview 2-3
PIPESIM 2000
component (if present) and a gas component related to stock tank
conditions. All that is needed for most applications is a minimum of
production data, oil gravity, gas gravity, solution gas/oil ratio and, if
water is also present in the system, the watercut.
Black oil fluid modelling is appropriate for use with a wide range of
applications and hydrocarbon fluid systems. In general, the basic
black oil correlations will provide reasonable accuracy in most PVT
fluid property evaluations over the range of pressures and
temperatures likely to be found in production or pipeline systems.
However, care should be taken when applying the black oil approach
to a highly volatile crude or a condensate where accurate modelling
of the gaseous light ends is required. In this case, the user should
consider the use of compositional modelling technique that describes
the fluid as a multi-component mixture.
In order to increase the accuracy of the basic black oil correlations for
modelling multiphase flow, PIPESIM 2000 provides the facility to
adjust salient values of a number of the most important PVT fluid
properties to match laboratory data.
These PVT fluid properties are considered the single most important
parameters affecting the accuracy of multi-phase flow calculations.
Calibration of these properties can greatly increase the accuracy of
the correlations over the range of pressures and temperatures for the
system being modelled.
This facility is optional, but the above calibrations will significantly
improve the accuracy of the predicted gas/liquid ratio, the flowing oil
density and the oil volume formation factor. If the calibration data is
omitted, however, PIPESIM 2000 will calibrate on the basis of oil and
gas gravity alone and thus, there will be a loss in accuracy. It should
be noted that the black oil calibration feature is only applicable to oil
fluid types, as it is not appropriate for a gas fluid type.
The following blackoil correlations are available:
• Solution gas and bubble point pressure: Lasater, Standing,
Vasquez and Beggs, or Glasø.

40. 2-4 Model Overview
PIPESIM 2000PIPESIM 2000
• Oil formation volume factor of saturated systems:-Standing,
Vasquez and Beggs, or Glasø.
• Oil formation volume factor of undersaturated systems:-
Vasquez and Beggs, or Glasø.
• Dead oil viscosity: Beggs and Robinson, Glasø, or Users data.
• Live oil viscosity of saturated systems: Chew and Connally or
Beggs and Robinson.
• Live oil viscosity of undersaturated systems: Vazquez and
Beggs, Kousel, or None.
• Viscosity of oil/water mixtures: Inversion, Volume Ratio, or
Woelflin.
• Gas viscosity:-Lee et al.
• Gas compressibility: Standing, or Hall and Yarborough.
2.4.2 Compositional
For compositional fluid modelling of hydrocarbon fluids and
associated gas and water components, PIPESIM 2000 uses a
seamless interface to a PVT modelling package.
Compositional fluid modelling is generally regarded as more
accurate, but also more expensive in terms of time and computer
resources than black oil modelling. It is justified for problems involving
volatile fluids needing rigorous heat transfer calculations. However
the black oil modelling approach can often give satisfactory results
with volatile fluids.
Oil systems contain in reality many thousands of pure components,
consisting of a spectrum of molecules with different carbon numbers
and large numbers of different isomers. It would be impossible to
model the behavior of such systems by explicitly defining the amount
of each of these molecules, both because of the excessive computing
power needed and the fact that laboratory reports could not possibly
supply all this information.
Since the alkane hydrocarbons are non-polar and therefore mutually
relatively ideal, lumping them together in the form of a number of
'pseudo-components' results in fairly accurate phase behavior and
physical property predictions.

41. Model Overview 2-5
PIPESIM 2000
Petroleum fractions are normally defined by splitting off sections of a
laboratory distillation of the C7+ mixture. Curves of boiling point,
density and molecular weight are produced from which the properties
of the individual pseudo-components may be derived.
Petroleum fractions are characterized by either;
• Measured Properties;
• boiling point (BP),
• specific gravity (SG) and
• molecular weight (MW). T
• Critical Property
• critical temperature (TC),
• critical pressure (PC),
• acentric factor (Omega) and
• specific gravity (SG).
Further details of the equations used, etc can be found in the
PIPESIM 2000 help system.
2.4.3 Steam - NOT available in version 1.30
For steam systems (production and injection) PIPESIM 2000 uses the
GPSA stream tables.
When modelling stream systems the pressure and quality are
required. If the quality is superheated (quality =100%) or sub-cooled
(quality=0%) then the temperature is also required.
2.5 Model components overview
A PIPESIM 2000 model is built (via the GUI) by adding components
(from the toolbox) to the model window.
Components are divided into 2 groups;
• Node type components
• Boundary nodes - Must be on the edge of the system and can
only have one connection either leaving (source) or entering
(sink).
• Internal nodes - Can not be on the edge of the system and can
have any number of connections.
• Linking type components - Joins 2 node type components

42. 2-6 Model Overview
PIPESIM 2000PIPESIM 2000
Node type components are connected by linking components and
thus must be added to the model first.
The components available depend upon the modules purchased.
Details on the inputs for each component can be found in the help
system.
A full list of components and their type is listed below.
Pipeline & facilities module
Component Type Description
Source Boundary
Node
The point where the fluid enters the
system.
Flowline Link A flowline to a point where it meets
another flowline (with different
characteristics) or another object.
Maybe horizontal or inclined and
surrounded by air, water or both;
insulated or bare
Riser Link A description of the riser (vertical or
near-vertical - up or down) to a point
where it meets another riser or another
object.
Pump Internal
Node
A single or multistage pump for the
pumping of liquids.
Multiphase
Booster
Node A multiphase booster.
Separator Internal
Node
Allows fluid separation to take place in
the model. It is a two-phase separator,
(i.e. gross liquids, water or gas).
The removed fluid can be re-injected
back into the network model via the
injection point component.
Compressor Internal
Node
A single or multistage centrifugal gas
compressor
Expander Internal
Node
An expander.

43. Model Overview 2-7
PIPESIM 2000
Heat exchanger Internal
Node
Allows a change in temperature and
pressure to be modelled
Choke Internal
Node
A device to restrict the flow of fluids.
Injection point Internal
Node
Allows a side stream (compositional
only) to be injected into the main
stream. The incoming pressure and
flowrate (along with the composition)
are required.
Multiplier/Adder Internal
Node
Changes the flowrate by the amount
specified.
Spot report Internal
Node
Allow key pieces of information to be
retrieved at any point (between links) in
the system. This component has no
effect on the temperature or pressure in
the system.
Keyword tool Internal
Node
Allows engine keywords to be inserted
into a model. A full list of the keywords
can be found in the Help system under
keyword reference.
Connector Link Joins to nodes without having any
effect on the calculations, i.e. a zero
length piece of pipe.
Well Performance module
Component Type Description
Vertical
completion
Boundary
Node
Describes the well IPR and the
reservoir static pressure for a vertical
completion. These are then used to
determine the bottom hole pressure.
Horizontal
completion
Boundary
Node
Describes the horizontal completion,
the IPR and the reservoir static
pressure. These are then used to
determine the bottom hole (heal)
pressure
Tubing Link Joins the reservoir top the surface. The
fluid can flow either through the tubing
or outside the tubing (inside the casing)
or both. The tubing may also have
down hole equipment installed.

44. 2-8 Model Overview
PIPESIM 2000PIPESIM 2000
down hole equipment installed.
Nodal analysis
point
Node The point in the system where the
(nodal) analysis is to be conducted.
The model is then broken into two
parts; inflow to the NA point and
outflow from the NA point.
Network module
Component Type Description
Production well Boundary
Node
Models the source as a production well.
The well is (normally) defined from the
sand face to the point where it joins
another object, i.e. well head, manifold,
etc.
Generic source Boundary
Node
The point where a fluid enters the
system. Can be used when a well is
modelled from the well head.
Injection well Boundary
Node
Models the sink as an injection well,
including tubing and completion.
Generic sink Boundary
Node
The point where the fluid leaves the
systems. A model may have any
number of sinks.
Node Node A point in the system where 1 or more
branches meets
Branch Link Connects 2 or more nodes, sources or
sinks. Any combination of flowline, riser
or pieces of equipment can be used to
describe a branch. When connected
between a well and a node the
resulting branch has no physical
meaning
Re-injection
node
Node Connects 3 branches;
1 - the incoming fluid stream (this
branch MUST contain a separator)
2 - the outlet stream
3 - the stream removed by the
separator. All the fluid removed from
the separator is re-injected. The re-
injected stream can be upstream or
downstream of the separator.

45. Model Overview 2-9
PIPESIM 2000
downstream of the separator.
2.5.1 Model & Component limitations
The following limitations;
General:
• Maximum number of components in a stream: 50
Pipeline & facilities
• Maximum number of sources: 1
• Maximum number of sinks: 1
• Maximum number pipe coatings: 4
• Maximum number of nodes for a pipeline or riser: 101
Well Performance
• Maximum number of completions: 10
• Maximum number of sinks 1
• Maximum number tubing coatings: 10
• Maximum number of nodes for a tubing: 100
• Maximum number of geothermal survey points: 100
• Maximum number of tubing strings:
• Detailed model: 20
• Simple model: 4
Network
• Maximum number of wells / branches: 512
• Maximum number of nodes: 512
• Maximum number of PVT files: 500
• Maximum number of compositions: 1,000
• Maximum number of Black Oil compositions: 1,024
• Maximum number of PQ data points: 30
Field Planning
• Maximum number of stored timesteps: 256
• Maximum number of auxiliary properties: 1,500
• Maximum number of Eclipse models: 1
• Maximum number of network models: 5
• Maximum number of events: 2,500

46. 2-10 Model Overview
PIPESIM 2000PIPESIM 2000
• Maximum number of schedule 'bean' lists: 99
• Maximum number of look-up tables: 500
• Maximum number of data lines in all look-up tables: 1500
• Maximum number of tank reservoirs: 50
Production Optimization (GOAL)
• Maximum number of wells/branches: 500
• Maximum number of nodes: 400
• Maximum number of sinks: 1
Multi-lateral (HoSim)
• Maximum number of multi-laterals: 500
2.6 Flow correlation
Flow correlations are used to determine the pressure drop and hold-
up in the system
Flow correlations are split in to the following section;
• Single phase
• Multiphase - vertical
• Multiphase - horizontal
A number of flow correlations have been proposed over the years.
In addition to the standard supplied flow correlations user's can
create and add their own multiphase flow correlation in to PIPESIM
2000 via the user DLL facility.
The linkages are documented in the user defined flow correlations
document which can be obtained from Baker Jardine or down loaded
from our web site.
2.7 Run an operation
Select the operation that is relevant to the model developed. The
simulation will commence and the post-processor can then be used
to analyze the results.

47. Model Overview 2-11
PIPESIM 2000
2.8 Saving & Closing PIPESIM 2000
When PIPESIM 2000 is closed all files (models) that have been
modified during the session are checked and an option to save any
that have changed is presented to the user.
2.9 How to build models
This section provides a brief overview of the steps involved in building
a model with each of the basic PIPESIM 2000 modules.
See the PIPESIM 2000 Help system " How do I…" section for full
details on setting up the basic models.
PIPESIM 2000 can build the following basic models;
• Pipeline and facilities
• Production well
• Single completion well
• Multiple completion well
• Horizontal completion well
• Injection well
• Sub-surface and surface Networks
• Gathering systems
• Looped systems
• Distribution systems
• Multi-lateral wells
• Production
• Injection
2.9.1 Fluid calibration
2.9.1.1 Black Oil
The following basic steps are required to calibrate the black oil
defined fluids;
• Select the units set of your preference
• Enter the basic fluid data
• Enter the Bubble Point data
• Enter the Advanced calibration data (optional)
• Run the operation.
• Save the model!

48. 2-12 Model Overview
PIPESIM 2000PIPESIM 2000
In a network model the calibration data is "mixed" at junctions to
provide average calibration data for the resulting stream.
2.9.1.2 Compositional
The following basic steps are required to calibrate the compositionally
defined fluids;
• Select the units set of your preference
• Enter the basic fluid data (library components, petroleum
fractions)
• Produce the phase envelop (for reference)
• Select the quantity to match to; Bubble Point or Dew point
• Enter the matching data
• Select viscosity matching options if applicable
• Enter the viscosity data
• Run the matching operation
• Update the composition
• Produce the new phase envelop
• Save the model!
2.9.2 Pipeline & facilities
The following basic steps are required to build a pipeline & facilities
model;
• Select the units set of your preference
• Add the necessary components to the model (source, flowline,
equipment, etc) and defined the necessary data.
• Define the fluid specification (black oil or compositional).
• Define the flow correlation to use.
• Save the model!
One the basic model has been developed a number of operations
can be performed or the model can be utilized in additional PIPESIM
2000 modules.
2.9.2.1 Correlation matching
The following basic steps are required to determine the most suitable
horizontal multiphase flow correlation;
• Build the pipeline & facilities model.
• Select the Correlation matching operation
• Determine the boundary condition to compute

49. Model Overview 2-13
PIPESIM 2000
• Select suitable Horizontal correlations
• Enter any known measured pressure and temperature values
• Run the operation.
• Save the model!
Insure that the most suitable correlation is then selected from the
horizontal flow correlation list for subsequent simulations.
2.9.2.2 Pressure/Temperature profile
The following basic steps are required to determine the pressure or
temperature profile along the system;
• Build the well performance model.
• Select the Pressure/Temperature profile operation
• Determine the boundary condition to compute
• Select any sensitivity parameters
• Enter the sensitivity parameters
• Run the operation
• Save the model!
2.9.2.3 Equipment/Flowline sizing (1 parameter)
The following basic steps are required to size a flowline/riser or a
piece of equipment;
• Build the pipeline and facilities model.
• Include the flowline/equipment/riser to be sized.
• Select the Pressure/Temperature profile operation
• Select the sensitivity parameter
• Enter the data for the sensitivity parameter
• Run the operation.
• Save the model!
2.9.2.4 Equipment/Flowline sizing (Multiple parameter)
The following basic steps are required to size a flowline/riser or a
piece of equipment;
• Build the pipeline and facilities model.
• Include the flowline/equipment/riser to be sized.
• Select the System Analysis operation
• Select the multiple sensitivity
• Select the x-axis and sensitivity parameters

50. 2-14 Model Overview
PIPESIM 2000PIPESIM 2000
• Enter the data for the sensitivity parameters
• Decide if the sensitivity parameters are permuted or change in
step.
• Run the operation.
• Save the model!
2.9.2.5 Multiphase booster design
The following basic steps are required to complete a multiphase
booster design;
• Build the pipeline and facilities (including the well if required)
model.
• Include the multiphase booster.
• Perform the analysis (nodal, PT profile, etc) with the booster
inactive.
• Invoke the generic Multiphase booster option and set the
booster parameters. Details on efficiency factors are supplied in
the help system.
• Re-run the analysis.
• Verify that multiphase booster van enhance production.
• Decide upon the Multiphase booster type required (Helico Axial
or Twin Screw).
• For twin screw boosters
• Select the generic twin screw module
• Enter the required data and re-run the analysis
• PIPESIM 2000 will automatically select the most suitable
size of the twin screw booster.
• Select the Twin screw booster module
• Select the nominal booster as recommend by the
previous operation
• Enter the data required data and re-run the analysis
• Select the vendor Twin screw module
• Enter the data required data and re-run the analysis
• For Helico Axial boosters
• Enter the required a data and re-run the analysis
• Save the model!

51. Model Overview 2-15
PIPESIM 2000
2.9.3 Well Performance
The following basic steps are required to build a well model (single or
multiple completion);
• Select the units set of your preference
• Determine the completion of the well
• Single
• Multiple
• Horizontal
• Add the necessary components to the model (completion,
tubing, etc) and defined the necessary data.
• Define the fluid specification
• Define the flow correlation to use.
• Save the model!
Once the basic model has been developed a number of operations
can be performed or the well model can be utilized in additional
PIPESIM 2000 modules.
2.9.3.1 Correlation matching
The following basic steps are required to determine the most suitable
vertical multiphase flow correlation;
• Build the well performance model.
• Select the Correlation matching operation
• Determine the boundary condition to compute
• Select suitable vertical correlations
• Enter any known measured down hole pressure and
temperature values
• Run the operation.
• Save the model!
Insure that the most suitable correlation is then selected from the
vertical flow correlation list for subsequent simulations.
2.9.3.2 Nodal analysis
The following basic steps are required to perform a nodal analysis;
• Build the well performance model.
• Determine the Nodal Analysis point and insert the NA point
object into the model (this is a node type object)
• Select the Nodal Analysis operation

52. 2-16 Model Overview
PIPESIM 2000PIPESIM 2000
• Determine the inflow and outflow parameters.
• Run the operation.
• Save the model!
2.9.3.3 Pressure/Temperature profile
The following basic steps are required to determine the pressure or
temperature profile along the system;
• Build the well performance model.
• Select the Pressure/Temperature profile operation
• Determine the boundary condition to compute
• Select any sensitivity parameters
• Enter the sensitivity parameters
• Run the operation
• Save the model!
2.9.3.4 Equipment/Tubing sizing (1 parameter)
The following basic steps are required to size tubing or a piece of
equipment;
• Build the well model.
• Include the tubing/equipment to be sized.
• Select the Pressure/Temperature profile operation
• Select the sensitivity parameter
• Enter the data for the sensitivity parameter
• Run the operation.
• Save the model!
2.9.3.5 Equipment/Tubing sizing (Multiple parameter)
The following basic steps are required to size tubing or a piece of
equipment;
• Build the pipeline and facilities model.
• Include the tubing/equipment to be sized.
• Select the System Analysis operation
• Select the multiple sensitivity
• Select the x-axis and sensitivity parameters
• Enter the data for the sensitivity parameters
• Decide if the sensitivity parameters are permuted or change in
step.
• Run the operation.

53. Model Overview 2-17
PIPESIM 2000
• Save the model!
2.9.3.6 Artificial Lift analysis
The following basic steps are required to analysis the effects of
artificial lift on a well;
• Build the well performance model.
• Insure that the gas lift or ESP lift depth has been set.
• Select the Artificial Lift operation
• Select the sensitivity parameters
• Run the operation
• Save the model!
2.9.3.7 Well performance curves for GOAL
The following basic steps are required to create well performance
curves for the Optimization module (GOAL);
• Build the well performance model.
• Insure that the gas lift or ESP lift depth has been set.
• Select the Artificial Lift operation
• Select the GOAL curve format
• Enter the required data
• Run the operation.
• Save the model!
The resulting data transfer files (*.PLT & *.PWH) are required by the
optimization model. These files must then be transferred (manually)
to the required optimization (GOAL) directory.
2.9.3.8 Reservoir Tables
The following basic steps are required to create reservoir look-up
tables;
• Build the well performance model.
• Select the reservoir tables operation
• Select the reservoir simulator
• Enter the required data
• Run the operation.
• Save the model!
The resulting ASCII file can then be used directly by the reservoir
simulator.

54. 2-18 Model Overview
PIPESIM 2000PIPESIM 2000
2.9.3.9 Horizontal completion length
The following basic steps are required to determine the optimal
horizontal completion length;
• Build the well (horizontal) performance model.
• Select the Horizontal completion length operation
• Enter the required data
• Run the operation.
• Save the model!
2.9.3.10 Gas Lift Rate v's Casing head pressure
The following basic steps are required to analysis the effects of gas
lift rate on the casing head pressure for a well;
• Build the well performance model.
• Insure that the gas lift depth and quantity has been set.
• Select the Gas Lift rate v's casing head pressure operation
• Select the sensitivity parameters
• Run the operation
• Save the model!
2.9.4 Network Analysis
2.9.4.1 Fluid properties
In a network model different fluid descriptions can not be used, i.e.
the model must be either black oil, compositional or steam.
Each source can have it's own fluid description or use shared data.
2.9.4.2 Boundary Conditions
In order to solve the network model the correct number of boundary
conditions must be entered. Boundary nodes are those that have only
one connecting branch, e.g. production well, injection well, source
and sink.
The number of boundary conditions that are required for a model is
known as the models Degrees of Freedom. This is computed by the
total number of boundary nodes, i.e. number of well (production and
injection) + number of sources + number of sinks.

55. Model Overview 2-19
PIPESIM 2000
For example a 3 production well system producing fluid to a single
delivery point has 4 degrees of freedom (3+1) regardless of the
network configuration between the well and the sink.
Each boundary can be specified in terms of;
• Pressure
• Flowrate
OR
• Pressure/Flowrate (PQ) curve.
To enable the system to be solved
1: the number of Pressure, flowrate or PQ specifications must
equal the degrees of freedom of the model.
2: At least 1 pressure must be specified
3: All each source (production well & source) the fluid
temperature must be set.
For example the above 3 well / 1 sink model could be specified as;
• Well 1: Reservoir pressure, reservoir temperature
• Well 2: Reservoir pressure, reservoir temperature
• Well 3: Reservoir pressure, reservoir temperature
• Sink: Delivery pressure
OR
• Well 1: Reservoir pressure, Flowrate, reservoir temperature
• Well 2: reservoir temperature
• Well 3: Reservoir pressure, reservoir temperature
• Sink: Delivery pressure
OR
• Well 1: Flowrate, reservoir temperature
• Well 2: Flowrate, reservoir temperature
• Well 3: Flowrate, reservoir temperature
• Sink: Delivery pressure
Etc.
2.9.4.3 Network model
The following basic steps are required to build a network model;
• Select the units set of your preference
• Develop the network model (wells and surface facilities). Pre-
built models of wells/flowline can be used.

56. 2-20 Model Overview
PIPESIM 2000PIPESIM 2000
• Set the fluid properties
• Set the boundary conditions
• Save the model!
2.9.5 Production Optimization
The following basic steps are required to build an optimization
(GOAL) model;
• Select the units set of your preference
• Develop the surface network model
• Set the outlet pressure
• Develop individual well models
• Create well performance curves for each well
• Save the model!
See the GOAL Used Guide for details on;
• building an optimization model
• Calibrating the surface network
• Calibrating the individual well models
• Optimizing the field
• Applying field constraints
2.9.6 Field Planning
The following basic steps are required to build an FPT model;
• Decide upon the reservoir description to use;
• Tanks
• Tables
• Reservoir simulator
• Set the name of the host UNIX workstation
• Material balance program
• Develop the network model (well and surface network) or
models.
• Link the wells to the reservoir description.
• Specify any flowrate constraints
• Define the time dependent events.
• Define the conditional based events.
• Select any auxiliary properties that are to be stored during the
simulation and analyzed in the post-processor.
• Set the convergence tolerance

57. Model Overview 2-21
PIPESIM 2000
• Save the model!
See the FPT Used Guide for an example of building a Field Planning
model.
2.9.7 Multi-lateral
The following basic steps are required to build a multi-lateral well
model;
• Select the units set of your preference
• Add the necessary components to the model (horizontal well
section, branch, etc) and defined the necessary data.
• Define the fluid specification (black oil or compositional).
• Define the flow correlation to use.
• Save the model!
See the HoSim Used Guide for an example of building a multi-lateral
well model.

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59. Fluid & Multiphase Modeling
PIPESIM 2000PIPESIM 2000
3 FLUID & MULTIPHASE FLOW MODELLING 3-1
3.1 Black Oil 3-1
3.1.1 Lasater 3-1
3.1.2 Standing 3-2
3.1.3 Vazques and Beggs 3-2
3.1.4 Glasø 3-3
3.1.5 Coning 3-4
3.1.6 Liquid Viscosity 3-5
3.1.7 Dead Oil Viscosity 3-5
3.1.8 Live Oil Viscosity 3-6
3.1.9 Undersaturated Oil Viscosity 3-7
3.1.10 Oil/Water Mixture Viscosity 3-8
3.1.11 Gas Viscosity 3-9
3.2 Compositional 3-9
3.2.1 EOS (Equations of State) 3-9
3.2.2 Viscosity model 3-10
3.2.3 BIP (Binary Interaction Parameter) Set 3-12
3.2.4 Hydrates 3-12
3.3 Pressure Drop Calculation 3-14
3.3.1 Flow regimes 3-15
3.3.2 Single Phase Flow Correlations 3-18
3.3.3 Vertical Multiphase Flow Correlations 3-19
3.3.4 Horizontal Multiphase Flow Correlations 3-24
3.4 References 3-29

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61. Fluid & Multiphase Modeling 3-1
PIPESIM 2000PIPESIM 2000
3 Fluid & Multiphase Flow Modelling
This section defines the fluid models and flow correlation modelled
available in PIPESIM 2000.
3.1 Black Oil
Fluid properties can be predicted by black-oil correlations that have
been developed by correlating gas/oil ratios for live crudes with
various properties, such as oil and gas gravities. The selected
correlation is used to predict the quantity of gas dissolved in the oil at
a particular pressure and temperature.
The black oil correlations have been developed specifically for crude
oil/gas/water systems and are therefore most useful in predicting the
phase behavior of crude oil well streams. When used in conjunction
with the calibration options, the black oil correlations can produce
accurate phase behavior data from a minimum of input data. They
are particularly convenient in gas lift studies where the effects of
varying GLR and water cut are under investigation. However, if the
accurate phase behavior prediction of light hydrocarbon systems is
important, it is recommended that the more rigorous compositional
models are employed.
3.1.1 Lasater
A correlation developed in 1958 from 158 experimental data points.
The data points spanned the following ranges:
pb (bubble point pressure): 48 to 5,780 psia
TR (reservoir temperature): 82 to 272 °F
g API (API gravity): 17.9 to 51.1 °API
g g (gas specific gravity): 0.574 to 1.223
Rsb (solution gas at bubble point pressure): 3 to 2,905 scf/STB
3.1.1.1 Bubble point pressure
Step 1: Calculate Mo (molecular weight of the stock tank oil)
For API <= 40: Mo = 630 - 10g API
For API > 40: Mo = 73,110(g API)
-1.562
Step 2: Calculate yg (mol fraction of gas)
yg = (Rsb/379.3)/(Rsb/379.3 + 350g o/Mo)
where g o = oil specific gravity
Step 3: Calculate the bubble point pressure factor (pbg g/TR)

62. 3-2 Fluid & Multiphase Modeling
PIPESIM 2000PIPESIM 2000
For yg <= 0.6: pbg g/TR = 0.679 exp(2.786yg) - 0.323
For yg > 0.6: pbg g/TR = 8.26yg
3.56
+ 1.95
Step 4: Calculate pb
pb = (pbg g/TR )(T/g g)
3.1.1.2 Solution gas
Rs = 132755 g o yg/(Mo(1 - yg))
3.1.2 Standing
Standing presented an equation to estimate bubble point pressures
greater than 1,000 psia. The correlation was based on 105
experimentally determined bubble point pressure of California oil
systems.
The data points spanned the following ranges:
pb (bubble point pressure): 130 to 7,000 psia
TR (reservoir temperature): 100 to 258 °F
gAPI (API gravity): 16.5 to 63.8 °API
g g (gas specific gravity): 0.59 to 0.95
Rsb (solution gas at bubble point pressure): 20 to 1,425 scf/STB
3.1.2.1 Bubble point pressure
Step 1: Calculate yg (mol fraction of gas)
yg = 0.00091TR - 0.0125g API
Step 2: Calculate pb
pb = 18(Rsb/g g)
0.83
x 10
yg
3.1.2.2 Solution gas
Rs = g g (p/(18 x 10
yg
))
1.204
3.1.2.3 Oil formation volume factor - saturated systems
Step 1: Calculate F (correlating factor)
F = Rs (g g /g o)
0.5
+ 1.25T
Step 2: Calculate Bo (oil formation volume factor in bbl/STB)
Bo = 0.972 + 0.000147F
1.175
3.1.3 Vazques and Beggs
Vasquez and Beggs used results from more than 600 oil systems to
develop empirical correlations for several oil properties including
bubble point pressure.

63. Fluid & Multiphase Modeling 3-3
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Approximately 6,000 measured data points were collected across the
following ranges:
pb (bubble point pressure): 50 to 5,250 psia
TR (reservoir temperature): 70 to 295 °F
g API (API gravity): 16 to 58 °API
g g (gas specific gravity): 0.56 to 1.18
Rsb (solution gas at bubble point pressure): 20 to 2,070 scf/STB
3.1.3.1 Bubble point pressure
pb = (Rsb/(C1g g exp(C3g API/( TR + 460))))
1/C2
where for
g API <= 30: C1 = 0.0362, C2 = 1.0937, C3 = 25.724
g API > 30: C1 = 0.0178, C2 = 1.187, C3 = 23.931
3.1.3.2 Solution gas
Rs = C1 g g p
C2
exp((C3 g API )/(T + 460))
where for
g API <= 30: C1 = 0.0362, C2 = 1.0937, C3 = 25.724
g API > 30: C1 = 0.0178, C2 = 1.187, C3 = 23.931
3.1.3.3 Oil formation volume factor - saturated systems
Bo = 1 + C1 Rs + C2 (T - 60)(g API/g gc) + C3 Rs (T - 60)(g API/g gc)
where for
g API <= 30: C1 = 4.677e-4, C2 = 1.751e-5, C3 = -1.811e-8
g API > 30: C1 = 4.67e-4, C2 = 1.1e-5, C3 = 1.337e-9
3.1.3.4 Oil formation volume factor - undersaturated systems
Bo = Bob exp(co (pb - p))
3.1.4 Glasø
Glasø developed PVT correlations from analysis of crude oil from the
following North Sea Fields:-
Ekofisk
Stratfjord
Forties
Valhall
COD
30/7-2A

64. 3-4 Fluid & Multiphase Modeling
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3.1.4.1 Bubble point pressure and solution gas
pb = f 1 [(Rs /g g )
0.816
(T
0.172
/g API
0.989
)]
3.1.4.2 Oil formation volume factor - saturated systems
Bob = f 2 [Rs (g g/g o)
0.526
+ 0.968T]
3.1.4.3 Oil formation volume factor - undersaturated systems
Bt = f 3 [Rs (T
0.5
/g g
0.3
) g o
A
p
-1.1089
]
Where
A = 2.9 x 10
-0.00027Rs
3.1.5 Coning
In order to simulate gas and/or water breakthrough from the reservoir,
flowrate dependent values of GOR and watercut may be entered.
In a homogeneous reservoir, analysis of the radial flow behavior of
reservoir fluids moving towards a producing well shows that the rate
dependent phenomenon of coning may be important.
The effect of increasing fluid velocity and energy loss in the vicinity of
a well leads to the local distortion of a gas-oil contact or a water-oil
contact. The gas and water in the vicinity of the producing wellbore
can therefore flow towards the perforation. The relative permeability
to oil in the pore spaces around the wellbore decreases as gas and
water saturation increase. The local saturations can be significantly
different from the bulk average saturations (at distances such as a
few hundred meters from the wellbore). The prediction of coning is
important since it leads to decisions regarding:
• Preferred initial completions
• Estimation of cone arrival time at a producing well
• Prediction of fluid production rates after cone arrival
• Design of preferred well spacing

65. Fluid & Multiphase Modeling 3-5
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3.1.6 Liquid Viscosity
There are four steps to calculating the liquid viscosity as follows:
1 Calculate the dead oil viscosity at atmospheric pressure and the
flowing fluid temperature. The methods available for calculating
dead oil viscosity are: Beggs and Robinson, Glasø, or Users
data.
2 Calculate the saturated live oil viscosity at the flowing fluid
pressure and temperature assuming that the oil is saturated with
dissolved gas. The methods available for calculating live oil
viscosity are: Chew and Connally or Beggs and Robinson.
3 Establish if the flowing pressure is above the bubble point
pressure for the flowing fluid temperature. If not, continue to step
4, otherwise calculate the undersaturated oil viscosity. The
methods available for calculating undersaturated oil viscosity are:
Vazquez and Beggs, Kousel, or None.
4 Determine the viscosity effects of water in the liquid phase. The
methods available for calculating the oil/water mixture viscosity
are: Inversion, Volume Ratio, or Woelflin.
3.1.7 Dead Oil Viscosity
The following Dead Oil Viscosity methods are available
• Beggs & Robinson
• Glasø
• Curve fit through user defined data

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3.1.7.1 Beggs and Robinson method
Beggs and Robinson used results from 600 oil systems to develop
relationships for dead and live oil viscosity. 460 dead oil observations
and 2,073 live oil observations were taken.
The range of data analysed was as follows:
p (pressure): 50 to 5,250 psia
T (temperature): 70 to 295 °F
g API (API gravity): 16 to 58 °API
Rsb (solution gas at bubble point pressure): 20 to 2,070 scf/STB
Dead oil viscosity is calculated as follows:
m OD = 10
x
- 1
where
x = yT
-1.163
y = 10
z
z = 3.0324 - 0.02023 gAPI
3.1.7.2 Glasø method
Dead oil viscosity is calculated as follows:
mOD = c(loggAPI)
d
where
c = 3.141(10
10
)T
-3.444
d = 10.313(logT) - 36.447
3.1.7.3 User's data method
A curve is fitted through the supplied data points of the following form:
Log(mOD) µ (1/T)
3.1.8 Live Oil Viscosity
The following live Oil Viscosity methods are available
• Chew and Connally
• Beggs and Robinson

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3.1.8.1 Chew and Connally
Chew and Connally used results from 457 oil systems to develop
relationships for live oil viscosity. The range of data analyzed was as
follows:-
p (pressure): 132 to 5,645 psia
T (temperature): 72 to 292 °F
Rsb (solution gas at bubble point pressure): 51 to 3,544 scf/STB
Live oil viscosity is calculated as follows:-
mOb = AmOD
B
where
A and B are given by the following table:
Rs (cu ft/bbl) A B
0 1.000 1.000
50 0.898 0.931
100 0.820 0.884
200 0.703 0.811
300 0.621 0.761
400 0.550 0.721
600 0.447 0.660
800 0.373 0.615
1,000 0.312 0.578
1,200 0.273 0.548
1,400 0.251 0.522
1,600 0.234 0.498
3.1.8.2 Beggs and Robinson
Live oil viscosity is calculated as follows:
mOb = AmOD
B
where
A = 10.715(Rs + 100)- 0.515
B = 5.44(Rs + 150)
- 0.338
3.1.9 Undersaturated Oil Viscosity
3.1.9.1 Vasquez and Beggs
Undersaturated oil viscosity is calculated as follows:-
m = mOb(p/pb)
m

68. 3-8 Fluid & Multiphase Modeling
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where
m = 2.6p
1.187
exp(-8.98x10
-5
p - 11.513)
For dead oils at high pressures the Vasquez and Beggs correaltion
overestimates the viscosity: Use Kousel.
3.1.9.2 Kousel method
Undersaturated oil viscosity is derived from the equation
Log(mp/ma) = p/1000(A + Bma
0.278
)
Where
A and B are parameters entered by the user.
Suggested values for A and B are 0.0239 and 0.01638 respectively.
m a is the viscosity of the oil at the same temperature and
atmospheric pressure.
3.1.9.3 No calculation
The undersaturated oil viscosity is assumed to be the same as the
saturated live oil viscosity at the same temperature and pressure.
3.1.10 Oil/Water Mixture Viscosity
3.1.10.1 Inversion method
The inversion method assumes that the continuous phase changes
from oil to water at a given watercut cutoff point. This means that, at a
watercut below or equal to the cut-off value, water bubbles are
carried by oil, and the mixture assumes the same viscosity as that of
the oil. At a watercut above the cut-off value, oil bubbles are carried
by water, and the mixture assumes the same viscosity as that of the
water.
3.1.10.2 Volume ratio method
Mixture viscosity is calculated as follows
mm = mOVo + mw Vw
where
mO = oil viscosity
Vo = volume fraction of oil
mw = water viscosity
Vw= volume fraction of water

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3.1.10.3 Woelflin method
The Woelflin option assumes that the continuous phase changes
from emulsion to water at a given watercut cutoff point. This means
that, at a watercut below or equal to the cut-off value, an emulsion
forms and the emulsion viscosity is given by the Woelflin equation for
emulsions. At a watercut above the cut-off value, oil bubbles are
carried by water, and the mixture assumes the same viscosity as that
of the water.
The Woelflin equation is as follows
mm = mO(1 + 0.0023 Vw
2.2
)
3.1.11 Gas Viscosity
3.1.11.1 Lee et al. Method
Gas viscosity is calculated as follows:
mg = Kexp(Xr
y
)
where
K = (7.77 + 0.0063M)T1.5
/(122.4 + 12.9M + T)
X = 2.57 + 1914.5/T + 0.0095M
Y = 1.11 + 0.04X
M is the gas molecular weight
r is the gas density
3.2 Compositional
3.2.1 EOS (Equations of State)
Equations of state describe the pressure, volume and temperature
behaviour of pure components and mixtures. Most thermodynamic
and transport properties are derived from the equation of state.
The following equations of state are available:-
• SRK (advanced and standard)
• PR (advanced and standard)
• SMIRK
3.2.1.1 Soave-Redlich-Kwong
The standard SRK equation is;
P = (NRT/(V - b)) + (a/(V(V + b)))

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The values of "a" and "b" in the above equations are derived from
functions of the pure component critical temperatures, pressures, and
acentric factors.
The advanced implementation of SRK contains additional non-
standard features. These include the ability to match stored values for
the liquid density (Peneloux correlation) and the saturated vapor
pressure and a choice of mixing rule.
3.2.1.2 Peng-Robinson
The standard PR equation is;
P = (NRT/(V - b)) + (a/(V2
+ 2bV - b2
))
The values of "a" and "b" in the above equations are derived from
functions of the pure component critical temperatures, pressures, and
acentric factors.
The advanced implementation of PR contains additional non-
standard features. These include the ability to match stored values for
the liquid density (Peneloux correlation) and the saturated vapor
pressure and a choice of mixing rule.
3.2.1.3 SMIRK
The Shell SPPTS package uses the SMIRK equation of state.
3.2.2 Viscosity model
The following methods are available to predict the liquid and gas
viscosity;
• Pederson
• LBC (Lohrenz-Bray-Clark)
These are not available when using SMIRK (SPPTS)
Preliminary testing has shown the Pedersen method to be the most
widely applicable and accurate for oil and gas viscosity predictions.
Both methods are based on the corresponding state theory.

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The choice of the equation of state has a large effect on the
viscosities predicted by both methods. The LBC method is more
sensitive to equation of state effects than the Pedersen method.
3.2.2.1 Lower Alkanes
Predicted liquid viscosities using LBC and Pedersen methods have
been compared to experimental data for Methane and Octane as a
function of both temperature and pressure and for Pentane as a
function of temperature. For both Methane and Pentane the
Pedersen method predictions show close agreement with
experimental data. For Octane, the Pedersen and LBC methods give
comparable results. For the aromatic compound, Ethyl Benzene, the
Pedersen method is not as good as the LBC method.
3.2.2.2 Higher Alkanes
The results for higher alkanes Eicosane and Triacontane are mixed:
the Pedersen method is adequate for Eicosane whereas the LBC
method is slightly better than Pedersen for Triacontane. For
Triacontane both LBC and the Pedersen methods are inadequate.
However, in the majority of cases the higher hydrocarbons should be
treated as petroleum fractions rather than as single named
components.
3.2.2.3 Petroleum Fractions
The LBC method describes viscosity as a function of the fluid critical
parameters, acentric factor and density. The LBC model is therefore
very sensitive to both density and the characterization of the
petroleum fractions.
3.2.2.4 Water
The Pedersen method suffers the same drawback as the LBC
method in that it is unable to predict the temperature dependence of
water, a polar molecule. To overcome this problem, the Pedersen
method has been modified especially for water so that it now
accurately models the viscosity of water in the liquid phase. This was
achieved by the introduction of a temperature-dependent correction
factor. However the prediction of the viscosity of the gas phase is
also affected, though in only a minor way.

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3.2.2.5 Methanol
Neither the LBC nor the Pederson method can deal with polar
components with the Pederson method slightly worse than the LBC
method. This is not surprising, as both methods were developed for
non-polar components and mixtures. The Pedersen method works
best with light alkanes and petroleum mixtures in the liquid phase. It
performs as well or better than the LBC method in nearly all
situations.
3.2.2.6 Emulsion
The following options are available for handing emulsions;
• Inversion method
• Volume ratio method
• Woelflin method
The methods are as described for Black Oil emulsions.
3.2.3 BIP (Binary Interaction Parameter) Set
Binary Interaction parameters (BIPs) are adjustable factors which Are
used to alter the predictions from a model until these reproduce as
closely as possible the experimental data.
BIPs apply between pairs of components. The SRK and PR EOS
(being cubic equations of state) require only a single BIP, kij, in the
model description. The closer the binary system to ideality the smaller
the size of kij, which will be zero for ideal systems. It is unlikely that
the value of kij will be greater than 1, although it is possible for it to be
negative.
3.2.4 Hydrates
Natural gas hydrates are solid ice-like compounds of water and light
components of natural gas. They form at temperatures above the ice
point and are therefore a serious concern in oil and gas processing
operations. The phase behavior of the systems involving hydrates
can be very complex because up to six phases must normally be
considered. The behavior is particularly complex if there is significant
mutual solubility between phases. The hydrate model uses a
modification of the RKS equation of state for the fluid phases plus
The van der Waals and Platteeuw model for the hydrate phases. The
model can explicitly represent all the effects of the presence of
inhibitors.