Manual de Simulador Pipe Phase

INTRODUCTION TOPIPEPHASE

Introduction to PIPEPHASE Workbook

The software described in this document is furnished under a license agreement and may be used only in accordance with the terms of that agreement. Information in this document is subject to change without notice. Simulation Sciences Inc. assumes no liability for any damage to any hardware or software component or any loss of data that may occur as a result of the use of the information contained in this document.

Copyright Notice Copyright © 2001 Simulation Sciences Inc. All Rights Reserved. No part of this publication may be copied and/or distributed without the express written permis-sion of Simulation Sciences Inc., 601 Valencia Ave., Brea, CA 92823-6346.

Trademarks PIPEPHASE, NETOPT, TACITE, and SIMSCI are registered marks and/or trademarks of Simulation Sciences Inc.

Windows, Excel, and MS-DOS are registered marks and/or trademarks of Microsoft Corporation.

All other products are trademarks or registered marks of their respective compa-nies.

Printed in the United States of America, July 2001.

Contents

Introduction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1

Exploring the PIPEPHASE Desktop . . . . . . . . . . . . . . . . . 5

Defining the Simulation . . . . . . . . . . . . . . . . . . . . . . . . . . 10

Setting the Input Units of Measure . . . . . . . . . . . . . . . . . . 22

Entering Thermodynamic or PVT Data . . . . . . . . . . . . . . 24

Specifying the Global Defaults. . . . . . . . . . . . . . . . . . . . . 31

Building the Flowsheet . . . . . . . . . . . . . . . . . . . . . . . . . . . 33

Entering Source and Sink Data. . . . . . . . . . . . . . . . . . . . . 36

Defining Links . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41

Setting up a Case Study . . . . . . . . . . . . . . . . . . . . . . . . . . 49

Working with Keyword Input Files. . . . . . . . . . . . . . . . . . 53

Running the Simulation . . . . . . . . . . . . . . . . . . . . . . . . . . 54

Viewing the Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64

Fluid Flow Basics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 71

Applying PIPEPHASE to Downhole Operations . . . . . . . 87

Executing a Sensitivity (or Nodal) Analysis. . . . . . . . . . . 98

Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 105

Introduction to PIPEPHASE i

torrta-orktely

s intonsi-ili-anas

plan-ank,

mic

and

Rs

AC-dedesen-

tovesam-temal

Introduction

PIPEPHASE is a steady-state multiphase fluid flow network simulaused for the rigorous modeling of oil and gas gathering and transpotion systems. PIPEPHASE provides integrated solutions to netwproblems. It can perform distinct analyses of individual nodes separaand it is also able to incorporate the parameters of interrelated nodethe total solution. The applications of PIPEPHASE range from the setivity analysis of key parameters in a single well, to a multi-year facties planning study for an entire field. This program also combines efficient multiphase network solution algorithm with modern oil and gproduction analysis techniques to create a unique field design and ning tool. This is coupled with an extensive physical property databand integrated with an intuitive Windows-based user interface.

CalculationEngine

PIPEPHASE technology includes:

■ Comprehensive physical properties databank and thermodynacapabilities

■ Fluid types, such as, blackoil, compositional, liquid, gas, steam, multiphase mixtures of gas and liquid

■ Link devices: pipes, tubing, compressors, pumps, separators, IP

■ Well analysis with inflow performance

■ Gas lift analysis

■ Pipeline sphering

■ Sensitivity (nodal) analysis

PIPEPHASE also comes with two add-on modules, NETOPT and TITE, which can be installed at the same time as PIPEPHASE proviyou have obtained the appropriate security. Contact your sales reprtative for more information.

NETOPTNETOPT provides you with optimization capabilities that allows youoptimize network performance by defining specific operating objectiwhile satisfying both physical and user-imposed constraints. For exple, you can use NETOPT to maximize the oil production from a sysof wells operating under injection-limited gaslift, or minimize capitcosts for a new pipeline system.

Introduction to PIPEPHASE 1

aignramink time-

e one

ver- cur-s aw-anwill forsingal

.

TACITEThe TACITE code, developed by IFP, Elf Aquitaine and TOTAL, iscompositional transient multiphase flow simulation tool, for the desand control of oil and gas production pipelines and wells. The progsimulates the transient behavior of a fluid flowing through a single-lflow system. The source flowrate and sink pressure are specified asdependent boundary conditions.

GraphicalUser

Interface

PIPEPHASE GUI features include:

■ A true 32-bit Windows-based application

■ Interactive data entry and execution

■ Generate graphs, tables, and charts; view in Microsoft Excel™

■ On-line help with hypertext jumps

■ And many more.

This comprehensive range of features enables your company to ussimulator for all phases of business.

PIPEPHASEEngine/GUI

Relationship

PIPEPHASE was originally designed with an easy-to-use keyword sion, where input information was entered through a text editor. Therently enhanced Graphical User Interface (GUI), however, providemore user-friendly and interactive environment for data input and flosheet construction. Although familiarity with the keyword structure cbe useful in executing and troubleshooting simulations, this class focus solely on the GUI for several reasons. The GUI prompts youthe necessary input data, making it easier for you to see what is misfrom a particular simulation. Furthermore, the GUI provides a visudescription of the process, giving you a better feel for the simulation

Figure 1:PIPEPHASE

ComponentsPIPEPHASE

Graphical User Interface

PIPEPHASE Graphical User

Interface

PIPEPHASEDatabase

PIPEPHASEDatabase

PFE TextEditor

PFE TextEditor

PIPEPHASECalculation

Module

PIPEPHASECalculation

Module

PIPEPHASEKeyword File

PIPEPHASEKeyword File

PIPEPHASERAS

PIPEPHASERAS

PIPEPHASEReport File

PIPEPHASEReport File

2 Introduction

lete

theles

nce, andntly,elp

Inc.IM-

pro-SCI'smi-EP-

entp-se

ived

opy

.

Where to Find Additional Help

Documents User manuals are shipped with your copy of PIPEPHASE. A compset of documents is provided on the CD in the form of .PDF files that aremost conveniently viewed using Adobe Acrobat Reader, supplied oninstallation CD. If you required additional manuals, contact your sarepresentative.

Online Help PIPEPHASE comes with online Help, a comprehensive online referetool that accesses information quickly. In Help, commands, featuresdata fields are explained in easy steps. Answers are available instaonline, while you work. You can access the electronic contents for Hby selecting Help/Contents from the menu bar.

TechnicalSupport

PIPEPHASE is backed by the full resources of Simulation Sciences(SIMSCI), a leader in the process simulation business since 1966. SSCI provides the most thorough service capabilities and advanced cess modeling technologies available to the process industries. SIMcomprehensive support around the world, allied with its training senars for every user level, is aimed solely at making your use of PIPHASE the most efficient and effective that it can be.

SIMSCI offers technical support for PIPEPHASE for all questions sby fax, E-mail or regular mail. In North America, call our hotline suport at 1-800-SIMSCI1. When contacting Technical Support, pleainclude the following in your correspondence:

■ Name and company, phone and fax numbers

■ Product version number

■ Problem description, including any error messages that you receand the steps necessary to duplicate the problem

■ If you are e-mailing your problem, please include an electronic cof the .INP or .PP0 and .PP1 files.

■ When calling in a request, please have this workbook available andbe near your computer to be able to walk through any difficulties


u

nt

ject

About This Workbook

This workbook complements SIMSCI's Introduction to PIPEPHASEtraining course. Since much of the course time is dedicated to hands-onexamples, you wil l not necessarily go through the document page bypage. The workbook does, however, follow the course sequence and yomay want to jot notes in the margin. We strongly recommend that youread this workbook from cover to cover once and then use it to refreshyour memory later on.

Conventions Before you begin this workbook, you should be aware of several conven-tions. These include:

■ Italicized text denotes menu items, dialog box names and fields, andlists. For example, File, Save As..., the Source Data dialog box, andComposition Defined.

■ Buttons within dialog boxes are represented as gray-fi lled boxeswith white overlaid text, such as , , and .

■ “...” Ellipses indicate items that, when selected, bring up a windoor dialog box, for example, and .

■ Text in < > brackets indicates keyboard strokes.

■ The , icon indicates a cautionary note or a useful tip.

SIMSCI has made great efforts to ensure that PIPEPHASE is compliawith Microsoft Windows. As a result, much of what follows will be veryfamiliar to experienced Windows users.

■ Click, Highlight or Select: Place the pointer on the item and press theleft mouse button.

■ Double-click: Same as click except you press the left mouse buttontwice with only a very short pause between clicks.

■ Open: To open a dialog box or object, place the pointer on the oband click or double-click the mouse.

■ Drag: Move the mouse while holding the left button down

OK Status Add ->

Modify... Enter Data...

, Note: Remember to save your work often!

4 Introduction

a-

Exploring the PIPEPHASE Desktop

The visual engineering of PIPEPHASE makes building a simulationeasy. Functional colors, menu-graphics and picture icons guide youevery step of the way. On-line references refresh your memory on equtions and guidelines. And if you encounter trouble, Help is availablewhen you need it.

LaunchingPIPEPHASE

To initiate a PIPEPHASE session:

➤ Click Start on the taskbar, select Programs and then SIMSCI.

➤ Click on PIPEPHASE.

➤ Click , then choose File from the menu bar.

The File menu is described below.

MainWindow

The PIPEPHASE main window, shown in Figure 2, is your primaryworkspace. This window forms the interface between you and thePIPEPHASE program. This is where you will build and run all your sim-ulations, as well as open files, save the current data, or exit the program.

You will use all the familiar Windows features such as toolbar buttons,menus, dialog boxes, and drop-down lists.

Table 1: File Menu OptionsOption Function

New Initialize a new simulation

Open Open an existing simulation

Import Keyword File Load a keyword input file into PIPEPHASE

Close Close the active simulation

Save/Save As Save the active simulation to a file with the same name, or to a new file

Copy Simulation Create a new simulation as a copy of an existing one

Delete Simulation Delete an existing simulation

Run Run the simulation

Remote Settings Run PIPEPHASE calculations from a UNIX machine

View Output File View the output file in the Programmer’s File Editor

View Keyword File View the input file in the Programmer’s File Editor

Print Print the flowsheet drawing or output report

Exit Close the active simulation and exit the program

OK


Figure 2:PIPEPHASE

Main Window

Menu Bar Directly below the title bar of the main PIPEPHASE window you willfind the main menu bar. It gives you easy access to the command menus.

Table 2: PIPEPHASE Main Window ComponentsComponent Description

Title Bar The window title contains the name of the current simulation and view.

Menu Bar All functionality can be accessed through the menus.

Toolbar Shortcut buttons for many commonly used PIPEPHASE operations are provided. These include data entry window buttons and viewing buttons.

Primary Workspace This is where you draw your flowsheet.

Scroll Bars The vertical and horizontal scroll bars enable you to move vertically and horizontally through a window.

Status Bar The bar below the toolbar that gives quick help on the highlighted button.

Control-menu Box The standard Windows control-menu in the top left corner can be used to move, resize or close the application window

Table 3: PIPEPHASE Menu BarMenu Main Functions

File File operations: open, close save, import, etc.

Edit Manipulate links and nodes on the flowsheet

View Specify what appears on the main window

General Add input data - all data can be entered from this menu

Special Features Enter case study and time-stepping data; access to a number of performance curves and program databases

Help Access the on-line help functions

6 Exploring the PIPEPHASE Desktop

-

Many of same commands are available through the buttons on the tool-bar.

Toolbar The toolbar appears just below the menu bar on the main PIPEPHASEwindow. Using the mouse, you can initiate many actions by clicking thebuttons on the toolbar.

Data EntryWindows

PIPEPHASE provides dialog boxes that allow you to enter data in a logical manner. Throughout this workbook, you wil l see examples of dataentry windows. Within these dialog boxes, there are many different typesof data entry devices including check boxes, radio buttons, drop-downlists, and buttons.

Table 4: PIPEPHASE Toolbar ButtonsButton Description Button Description

Create a new simulation

Define hydrates

Open an existing simulation

Select units of measurement

Import a keyword input file

Select the components

Save the active simulation

Select thermodynamic method or enter PVT data

Run the simulation and review the results

Set the calculation method

View the output file

Enter the global defaults

Print the output file or flowsheet

Define network optimization data

Add a source to the flowsheet

Zoom in on a selected area

Add a sink to the flowsheet

Zoom out

Add a junction to the flowsheet

Display the entire flowsheet in the main window

Add a calculator to the flowsheet Refresh the flowsheet drawing

Table 5: Data Entry Window ButtonsButton Description

All data are saved and the dialog box is closed.

All data entered or modified are lost when the dialog box closes.

Displays the online help for the dialog box.

OK

Cancel

Help


Color Cues PIPEPHASE uses color cues to inform you of the status of your simula-tion. The significance of the colors you will encounter while workingwith PIPEPHASE are summarized below.

Editing andViewing the

Flowsheet

You can use the options on the Edit menu to modify the placement ofobjects on your flowsheet diagram.

You can use the options on the View menu to modify the data displayedon your flowsheet diagram.

Table 6: Color Significance During Data EntryColor Significance

Red Required data is missing

Blue All necessary data has been entered

Green An item is selected

Gray Data field is not available to you

Table 7: Edit Menu OptionsOption Function

Copy Node... Copy an existing node to a new node at coordinates X, Y

Copy Link... Copy an existing link to a new link

Edit Node... Sort, edit, delete, and copy existing nodes or add a new node to the flowsheet

Edit Link... Sort, edit, delete, copy, or change the flow direction of existing links

Move Node... Move the highlighted node around the flowsheet using the arrow keys

Draw... Add text, a line, a rectangle, or an oval to the flowsheet.

Table 8: View Menu OptionsOption When the option has a checkmark beside it:

View Output View node results or link plots; you cannot make data entries or edits in this mode

Node Labels Node labels are shown on the PFD; for example, S001, D002

Link Labels Link names are shown on the PFD, for example, L001, L002

Show Pressures Defined pressures (not estimates) are displayed on the PFD

Show Temperatures Supplied temperatures for each source are displayed on the PFD

Show Rates Defined flowrates (not estimates) are displayed on the PFD

Ribbon Bar Toolbar is visible below the menu bar

8 Exploring the PIPEPHASE Desktop

intoin-

ft-

e

ta,

hetool-

Link DeviceData Window

The Link Device Data window, shown in Figure 3, is the workspace which you add and define your link data for each link on the main wdow. To open this window, double-click on any link on the flowsheet.

Figure 3:Link Device Window

This window is broken up into four sections. Starting from the top lehand-side, these include:

■ Access buttons—enter and exit link device view, and open onlinhelp.

■ Edit link functions—edit, delete, reverse, copy and paste functions.

■ Calculation data—enter link data, nodal analysis data, line sizing daor TACITE transient data.

■ Devices palette—use this toolbar to add devices to the active link; tdescription for each unit is provided in the status line above the bar, for example, Pipe.


s ofnd

lso

ree

ngle-E

e sim-ell

ign.ular

y toone israte,cifica-pes.

con-he-

enanal-

Defining the Simulation

This chapter describes the objectives, applications, and capabilitiePIPEPHASE. It introduces the concepts involved in pipeline, well, anetwork analysis and describes how PIPEPHASE tackles them. Thenumerous simulation and fluid types available in PIPEPHASE are adiscussed.

Applications The broad applications of PIPEPHASE can be categorized into thparts:

■ Single pipeline analysis

■ Wellbore analysis

■ Field wide studies

Single PipeAnalysis

PIPEPHASE is a sophisticated tool for the design and analysis of siphase and multiphase pipelines. The main features of PIPEPHASinvolve capacity calculations, condensate drop-out problems, CO2/Steam/N2 injection networks, and heated oil pipelines. The rigorousenergy balance and detailed heat transfer model enable the accuratulation of viscous fluids in insulated and/or heated oil pipelines as was steam injection systems.

Capacity calculations form the core of any preliminary process desPIPEPHASE allows you to specify the desired parameters in a particfield, and accurately calculates the operating conditions necessaraccommodate these values. For instance, as a simple example, if given a specified inlet and a desired outlet pressure at a given flow PIPEPHASE calculates the pump power needed to meet these spetions. You could also use line sizing to vary the diameter of the piused in order to provide an optimal estimate for the size of the pipes

Figure 4:Capacity Calculations

PIPEPHASE also accurately predicts retrograde condensation, or densate drop-out problems, in wet gas pipelines. The retrograde pnomena is graphically illustrated in Figure 5. Conventional techniquesthat employ extrapolation to predict the point of retrograde phenomare invariably incorrect. PIPEPHASE applies a point-by-point PVT a

CÙSYVYUTð?ed\Udð@bUccebU

@e]`ðCÙSYVYSQdY_^c

CÙSYVYUTð^\Udð@bUccebU

10 Defining the Simulation

ful

izet foreammalts in

ully thealpy.

inlet,

ysis, which has proven to be extremely accurate. This is especially usewhen exact solutions are desired.

Figure 5:Phase Envelope

Steam Injection NetworksIn steam injection networks, PIPEPHASE allows you to develop operat-ing conditions that will minimize heat loss in the network and optimenergy usage. Large networks require an optimal distribution of heamaximum energy efficiency. For instance, an even distribution of stinjection throughout the network may not necessarily be the optiarrangement. Such a configuration may exceed heating requiremensome wells and may fail to provide sufficient energy in others.

PIPEPHASE performs rigorous heat transfer calculations to fdescribe the energy requirements of each individual well, as well asnetwork as a whole. Because PIPEPHASE performs a rigorous enthbalance, it can be used for single component fluids other than steam

In the example shown in Figure 6, given 600 psia steam at the PIPEPHASE can calculate the flowing bottomhole pressure.

Figure 6:Steam Injection

Networks

@81C5ð5>F5<?@5ð@8!ð@81C5ð5>F5<?@5ð@8!ð@81C5ð5>F5<?@5ð@8!ð@81C5ð5>F5<?@5ð@8!ð

0

400

800

120

160

200

-150 -100 -50 0 50 100

DU]ÙbQdebUäð6DU]ÙbQdebUäð6DU]ÙbQdebUäð6DU]ÙbQdebUäð6

@bUccebUäð@C91

@bUccebUäð@C91

@bUccebUäð@C91

@bUccebUäð@C91

3bYdYSQ\ð@_Y^d

CQdebQdUTð<YaeYT

CQdebQdUTðFQ`_b

CQdebQdUTðFQ`_b!%ëð<Yaâ ! ëð<Yaâ %ëð<Yaâ

& ð`cYQðCdUQ]

@ð/

C_ebSU


de pipeunt,EP-

lenteci-nes,har-

iledlediondates,er-thlow-

is aa-viden be

vese, inn

out-

Heated Oil PipelinesFor heated oil pipelines, PIPEPHASE allows for the variation of noparameters (i.e., insulation thickness, heaters, pumps) to meet thespecifications. Viscosity characteristics are always taken into accoand the flow characteristics of the fluid can be analyzed exactly. PIPHASE can perform accurate calculations in both laminar and turbuflow regions, as well as analyze the transition region with equal prsion. In the event of sludge formation, especially in heated oil pipeliPIPEPHASE employs a sphering or pigging model to estimate slug cacteristics for the design of downstream slug catchers.

WellboreAnalysis

PIPEPHASE provides a comprehensive set of features for the detadesign of production or injection well systems. This includes detaireservoir inflow performance characterization, a choice of completmodels at the sandface, wellbore geometry variations to accommotypical production, injection or artificial lift (ESP or gaslift) operationand surface flowline and facilities models simulating most oil field opations. Almost all of the well-known mulitiphase correlations, boempirical as well as mechanistic, are available for a wide range of fing conditions and inclination angles.

Figure 7:Wellbore Analysis

The most common application of PIPEPHASE to wellbore problemsnodal analysis. PIPEPHASE is equipped with a sensitivity analysis feture, which is a generalized nodal analysis tool. This feature can prographical solutions to wellbore problems, where the solution node caany point along the production string, and the inflow and outflow curcan represent composite multiple parameter behavior. For instancmodeling a particular well, the inflow and outflow curves can be giveby the Productivity Index IPR (inflow) and the tubinghead pressure (flow). The intersection of these curves provides the solution.

��

��

@b_TeSdY_^ð6\eYTè_Y\ágQdUbáWQcçCebVQSU

BUcUbf_Yb

��


thisas aizen therfor-s the

ble.lso,he are the

l-ery

Performance AnalysisFigure 8 illustrates a graphical solution to wellbore calculations. In case, reservoir performance is given (flowing bottomhole pressure function of flow rate). The composite variable in this case is the s(inside diameter) of the pipes. These curves are superimposed ograph, and the intersection of these curves with the Reservoir Pemance curve indicates the solution for each case. The solution giveoperating conditions for the node to meet the desired specifications.

Figure 8:Wellbore Calculations- Varying Pipe Sizes

Figure 9 is analogous to the previous example with a different variaInstead of varying pipe sizes, you vary well-head pressure (WHP). Areservoir performance is represented by two curves, illustrating tdecline in the reservoir pressure with production. Similarly, solutionsindicated by the intersection of the two plots, and the solutions giveoperating conditions needed for the given specifications.

Figure 9:Wellbore Analysis -Varying Well-head

Pressure

PIPEPHASE also models artificial lift methods. The two methods avaiable to the program are continuous gas lift for enhanced fluid recovand electrical submersible pump analyses.

6\_gY^Wð2_dd_]X_\U

94ð-ð"ð!á"î@bUccebU

94ð-ð#î

94ð-ð#ð!á"î

94ð-ð$î

BUcUbf_Ybð@UbV_b]Q^SU

6\_gðBQdU

G8@ð-ð#

6\_gY^Wð2_dd_]X_\U

@bUccebU ðð

6\_gðBQdU

BUcUbf_Ybð@UbV_b]Q^SU

G8@ð-ð!

G8@ð-ð"


an fluidd it.as

er-

le of

oilrre-tion

oilrre-tion

ou oil

d beudyalson beare the

n be

Gas Lift AnalysisIn a gaslift analysis, separator gas available from the oil well or fromoutside source can be used to increase production. The productionis considered to be in the tubing and the lift gas in the annulus arounUsing PIPEPHASE, you can investigate the feasibility of injecting gfor continuous gaslift. PIPEPHASE has four gaslift options:

■ With specified oil production and lift gas rate, PIPEPHASE genates pressure profiles in the production and injection strings of thewell.

■ With specified tubinghead pressure, PIPEPHASE generates taboil production rate vs. specified lift gas rate.

■ With a specified range of gas injection valve locations for fixed production and lift gas injection rates, PIPEPHASE calculates cosponding production string pressure, and determines the injeclocation which is closest to the target outlet pressure.

■ With a specified range of gas injection valve locations for fixed production and lift gas injection rates, PIPEPHASE calculates cosponding injection string pressures and determines the locawhich is closest to the target outlet pressure.

Figure 10:Gas Lift Analysis

PIPEPHASE offers you great flexibility in cases of gaslift analysis. Ycan analyze the performance of wells currently on gaslift, maximizerecovery using new gaslift, and determine which gaslift valves shoulactivated for a specified production scheme. This allows you to steach production well in a field over the life of the reservoir. You can determine which wells are candidates for gaslift, how production caimproved with gaslift, and which gaslift rates and valve locations required. Once the performance of an individual well is refined usinggaslift options, the performance of an entire gathering system ca

BUcUbf_Ybð3_^TYdY_^c@-"! ð`cYWD-!("ð6

7Qcð<YVdðFQ\fU

7Qcð<YVdð7Qc@-)% ð`cYWD-! ð6äðA-/

DeRY^WðGU\\XUQTð@bUccebUð-ð!&%ð`cYW

Að/


ified

ofings-oilre

ti-

susasimu-

ons.s oilt ofEurate

lues

ough

del gasceheen-tionskedties

analyzed in the network mode with the injection depth and rate specfor each well.

The most common calculation in gas lift problems is the calculationthe optimum gas injection rate. Usually, you are given the followparameters: reservoir pressure, well-head pressure, formation garatio, and water cut. Injection pressure and gaslift valve locations ausually fixed, and from this information, you must determine the opmum lift gas injection rate, Q.

PIPEPHASE can generate plots of the liquid and oil production vergas injection rate, as shown in Figure 11, to indicate the optimum ginjection rate required (trial injection rates are used as input to this slation to generate the desired graph).

Figure 11:Finding the Optimum

Gas Injection Rate

PIPEPHASE also performs rigorous wellbore heat transfer calculatiThese are especially useful in steam injection networks with viscou(API < 10, or viscosity > 100 cP). As described previously, the objecsteam injection networks is to minimize heat loss, and PIPEPHAStakes into account all the necessary parameters to build an accmodel. PIPEPHASE allows user-defined input as well as default vafor pipe insulation, heat conduction, convection, heat transfer coeffi-cients, and radiation. It also accounts for time-dependent effects thrthe Ramey function.

Field WideSimulation

The network simulation capability in PIPEPHASE can be used to mothe interaction between the various elements of a complete oil orfield, including all of the wells, gathering and injection lines, surfafacilities, and contract delivery points. PIPEPHASE also allows tgrouping of production from the same zones for simulating time-depdent reservoir pressure decline, and changing well production condi(increasing GOR and water cut). These capabilities have been linwith the ability to simulate production contracts and changing facilito create a field planning tool.

A<A7ðè?`dY]e]ç

A<ðè=Qhâç

A7


wellt wellate,imi-SE

pro-line

tiontion forspec-.

udyeryuireer of

of ale, if

ts ofce ofiveimumxi-

In a field of interconnected wells, the parameters in each individual are interconnected. (i.e. changes in the pressure of well 1 may affec2). Consider Figure 12 where Well 2 has varying gas lift injection rand the resulting back pressure affects the performance of Well 1. Slarly, all of the surface facilities are also interdependent. PIPEPHAincorporates these effects in performing an overall field calculation.

Figure 12:Field Wide Simulation

Furthermore, PIPEPHASE is equipped with a new time-dependent duction planning capability. One such feature is the Reservoir Decoption, which describes the cumulative production volume calculabased on well grouping. PIPEPHASE provides a simple tank deplemodel for gas and condensate reservoirs. It also provides supportuser-specified reservoir pressure decline curves, as well as for user-ified decline in well characteristics (changing gas-oil ratio, water cut)

Another feature allows you to model changing facilities. The case stfeature simulates changing operation setpoints, facilities and delivcontracts over multiple time periods. For instance, the field may reqmore power (e.g. in pumps) with time, and increasing the horsepowthe pumps affects overall field performance and costs.

Regarding contracts, PIPEPHASE allows you to model the behaviorgiven field that is under specific contractual constraints. For exampthe field is given a maximum production rate Q which cannot beexceeded due to contractual agreements, the individual componenfield must be adjusted to meet the terms of contract. The performanthe field, however, will change with time. For instance, for the first fyears, compressor horsepower must be regulated because the maxfield operation exceeds Q. After five years, however, even with mamum power, field production does not exceed Q, and the necessaryadjustments must be made to meet production standards.

GU\\ð! GU\\ð"ègYdXðWQc\YVdç


one

ool-

this

ula-

to

g,or if

t

asesles

SimulatingNetworks inPIPEPHASE

The first step in creating a new simulation is to define the simulatitype and fluid type. If your fluid is compositional, you can also definthe phase of the fluid.

When creating a new simulation, by clicking the New button on the tbar or by selecting File/New from the menu bar, the Simulation Defini-tion dialog box will be opened automatically. If you need to access dialog box at any time, select General/Simulation Definition from themenu bar.

Figure 13:Simulation Definition

Dialog Box

Check the box beside Input Check Only when you want PIPEPHASE toperform a thorough check on your input before performing any calctions. If errors are found, it will not carry out the simulation.

SimulationType

The simulation type indicates which solution algorithm will be usedsolve the simulation. The options are:

■ Network Model

■ Gas Lift Analysis

■ PVT Table Generation

Select Network Model if the system you want to simulate is a gatherindistribution, or looped flowsheet system with one or more junctions, your system is a single link but you want PIPEPHASE to calculate thepressure at the source of a single link.

Select Gas Lift Analysis if you wish to to perform individual well gas lifanalyses. This option is for blackoil fluids only.

Select PVT Table Generation if you want PIPEPHASE to generate PVT data file for use in a subsequent run. Using PVT tables increasimulation speed by enabling PIPEPHASE to look up data from tabinstead of performing flash calculations.


e

orIPE-

calnsla-com-.

on- two-ngle-

P-gas,nt.nsity

ing,hod canorhe

Fluid Models A fluid model is non-compositional when it can be defined with averaggravities at stock tank conditions. A fluid model is compositional whenit can be defined in terms of its individual components either directlyvia an assay curve. There are seven types of fluid modeled in PPHASE:

■ Compositional

■ Black oil

■ Gas Condensate

■ Gas

■ Liquid

■ Steam

■ Compositional/Blackoil

The fluid type controls how the program is able to obtain the physiproperties necessary for pressure drop and heat transfer calculatio—either from the PIPEPHASE databank, from built-in empirical corretions, or from user-supplied input. Steam is a special case of a non-positional fluid, for which PIPEPHASE uses the GPSA steam tables

Non-Compositional ModelsA non-compositional fluid model must be defined as black oil, gas cdensate, liquid, gas, or steam. Black oil and gas condensate arephase, with one phase dominant. Gas and liquid fluid models are siphase. Steam can be single or two-phase.

When working with multi-phase non-compositional fluids in PIPEHASE, you must supply specific gravity (reference density) data for liquid, and water phases, even if you do not expect them all to be preseIn the case of single phase fluids, you need specify the reference deof that phase only.

PIPEPHASE employs empirical correlations (e.g. Vasquez, StandGlaso) to calculate certain fluid properties. You can define the metby which PIPEPHASE calculates these properties. For instance, youchoose Vazquez, Standing, or GLASO correlations for viscosity, Standing or Hall-Yarborough correlations for compressibility factor. Tdefault correlation depends upon the fluid being used.


s oftockd,

re-EP-

t oil

P-t.

ASEns.lackble

ses.E-

cham

s.

o

smf the

Blackoil Model

Black oil is a two-phase fluid model based on the reference gravitiethe two phases and the volumetric phase ratio (Gas-Oil Ratio) at stank conditions. You must supply specific gravity data for gas, liquiand water phases, even if you do not expect them all to be present.

Gas Condensate Model

Gas condensate is a multiphase non-compositional fluid with gas pdominating. All properties of gas condensate are calculated by PIPHASE from the specific gravity and built-in correlations. Gascondensate models are very useful in simulating the behavior of lighwith API’s greater than 45.

Single-Phase Liquid Model

All properties of a non-compositional liquid are calculated by PIPEHASE from the specific gravity and built-in correlations. You musdefine the liquid as water or hydrocarbon (oil), and supply its gravity

Single-Phase Gas Model

All properties of a non-compositional gas are calculated by PIPEPHfrom the specific gravity, which you specify, and built-in correlatioYou can also specify which correlation is to be used. Contrary to boil, you cannot adjust the Standing correlation to match any availalaboratory data.

Steam Model

Steam is a non-compositional fluid that is allowed to exist in two phaYou cannot override the steam table data contained within PIPPHASE’s data libraries. However, all pressure drop correlations whiare available to compositional fluids are also available to the stemodel.

Compositional ModelThere are three methods for defining components in PIPEPHASE:

■ Selecting individual components from the PIPEPHASE library.

■ Defining individual components as petroleum pseudocomponent

■ Defining an assay curve and having PIPEPHASE divide it intpetroleum cuts.

PIPEPHASE will then predict the fluid’s properties by applying theappropriate mixing rules to the pure component properties. UnlesPIPEPHASE is instructed otherwise, it will perform phase equilibriucalculations for the fluid and determine the quantity and properties oliquid and vapor phases.


of

po-per-m

ins adrop, or

ts, with

hys-om-for

E and You

oil,m-ms of

eumcter-l the

A compositional fluid can be defined in terms of any combination these options. You can have different compositions at each source.

Pure Library Components

The SIMSCI library contains over 2000 components. For all comnents, the databank contains data for all the fixed properties and temature-dependent properties necessary to carry out phase equilibriucalculations. For all common components, the databank also contafull set of transport properties necessary to carry out the pressure and heat transfer calculations. If you need to supplement the dataoverride the library data with your own, you can do so.

Petroleum Components

PIPEPHASE allows you to enter individual petroleum componenwhich are represented as cuts or sections of a hydrocarbon streamdefined average boiling points, specific gravities, and other thermopical properties. You can define individual components as petroleum cponents by specifying at least two of the following three properties each component:

■ Normal boiling point

■ Gravity

■ Molecular weight.

PIPEPHASE will predict the third property if you omit it. PIPEPHASuses industry-standard characterization methods to predict all fixedtemperature-dependent property data for each pseudocomponent.can select the method most suitable for your own mixture.

➤ Click in the Component Selection dialog box and enterthe data.

➤ You can provide names for the individual cuts, or have PIPEPHASEdefine names based on the cuts' NBPs.

Assay Data

A component breakdown for petroleum-based streams, such as crudeis difficult to obtain, because they contain thousands of distinct copounds. Usually these hydrocarbon streams are characterized in terlaboratory test data (also known as assay data). This typically includesdistillation data, gravity data, and an analysis of the low-boiling purcomponents (the lightends). PIPEPHASE derives a set of petrolecomponents from this assay data by using industry standard charaization techniques. These derived components are used to modestreams given by assay data.

Petroleum...


0),heedfine an be

ou data

pro-

ba-ata

s theilable

geas).d of

cifya-

be

If your fluid is defined by an assay curve (TBP, D86, D2287, or D116PIPEPHASE will divide it into a number of cuts. You can control tnumber of cuts and the ranges they cover. Each of the cuts is then treatas a pseudo-component, as described previously. You can also delightends analysis to go with the assay curve. The lightends cadefined using the pure library components database.

To construct the assay curve, along with the boiling point curve, ymust supply average density, and you can also supply density curveor molecular weight data.

From user-supplied data, PIPEPHASE uses a specified curve fittingcedure to best fit the assay data. An example is the SPLINE method, inwhich a cubic spline is fitted to all internal points and the normal probility distribution is used for extrapolation beyond the first and last dpoints. This method is also the default fitting method.

You should try to define the temperatures such that they encompasTBP ranges for all stream assay data. Several correlations are avafor calculating critical constants, molecular weights, and gravities.

PhaseDesignation

If you believe that the phase of your compositional fluid will not chanthroughout the simulation, you can specify that phase (liquid or gPIPEPHASE will bypass the flash calculations to increase the speeyour simulation.

You must be sure that the fluid remains in the phase which you spefor the entirety of the simulation, since any liquid dropout or vaporiztion which may occur in reality will be missed, and results will thenerroneous.


itseenetricimula-For

the

start

Setting the Input Units of Measure

Almost every item of data you will enter in PIPEPHASEwill have unof measure. For simplicity, units of measure in PIPEPHASE have barranged into four standard pre-defined sets: Petroleum, English, Mand SI. You select the set that nearest matches the needs of your stion and then override the pre-defined units for individual quantities. example, you can select the Metric Set and override the Celsius tempera-ture unit with Kelvin.

To change the default units of measure set for a simulation, clickUnits of Measure button on the toolbar or select General/Input Units ofMeasure to open the Input Dimensions dialog box. This dialog box (Fig-ure 14) automatically appears when you define a new simulation.

Figure 14:Input Dimensions

Dialog Box

By default, the standard Petroleum set is the global default used toeach simulation.

➤ To change the default set, select a set from the System list.

➤ Make any changes to individual units, as desired and click when finished.

OK

22 Setting the Input Units of Measure

ts

.

StandardSets

The units of measure in the standard sets are shown below.

Output Unitsof Measure

Normally, the output report is in the same units as the input set. How-ever, you can define a different set of units for the output. If you do wantoutput in a different set of units it is good practice to get it in the inputunit set as well, so that you can check the correctness of your input data.

➤ Select General/Output Units of Measur .

➤ Check the Use Output Units of Measurement box, and select the setfrom the System drop-down list.

You can override specif ic variables by selecting the appropriate unifrom each drop-down list.

By default, an additional report with the output dimensions is generatedIf desired, the output dimensions can replace the input dimensions bychecking the Replace Standard Output radio button in the OutputDimensions dialog box.

Table 9: Standard Units of MeasurePetroleum English Metric SI

Temperature °F °F °C K

Pressure psig psia bar kPa

Molar Rate lb-mol/hr lb-mol/hr kg-mol/hr kg-mol/hr

Weight Rate lb/hr lb/hr kg/hr kg/hr

Liquid Volume Rate bbl/hr ft3/hr m3/hr m3/hr

Gas Volume Rate 106 ft3/hr 106 ft3/hr 106 m3/hr 106 m3/hr

Default Basis liquid volume gas volume gas volume gas volume

Conductivity Btu/hr-ft-°F Btu/hr-ft-°F kcal/hr-m-°C W/m-K

Heat Transfer Coefficient Btu/hr-ft2-°F Btu/hr-ft2-°F kcal/hr-m2-°C kW/m2-K

Fine Length in in mm m

Coarse Length ft ft m m

Pipe Length ft ft m m

Water Density sp gr sp gr kg/m3 kg/m3

Oil Density API API kg/m3 kg/m3

Gas Density sp gr sp gr kg/m3 kg/m3

Power hp hp kW kW

Duty 106 Btu/hr 106 Btu/hr 106 kcal/hr 106 kJ/hr

Viscosity cP cP cP Pa-sec

Velocity mph ft/s km/hr m/s


s onosi- data

time,

hethe

antswillrding

andtw areturehen

Entering Thermodynamic or PVT Data

The thermodynamic or PVT data required for the simulation dependthe fluid type defined as the simulation definition. For any non-comptional simulation, you can enter up to 99 property sets. The requiredentry for each fluid type is described below.

When creating a new simulation, the PVT Data dialog box will beopened automatically. If you need to access this dialog box at any click the Thermodynamic Data button on the toolbar or select General/Thermodynamic Data... from the menu bar.

BlackoilModels

For blackoil or blackoil/compositional mixtures, you must enter tgravities (or densities) for each of the three potential phases of fluid—oil, gas and water. All other data are optional.

Figure 15:Blackoil/

Compositional PVTData Dialog Box

You can enter a mole percentage for any or all of the listed contamin(nitrogen, carbon dioxide and hydrogen sulfide). Entry of data here effect a change in the compressibility factor for the gas phase accoto built-in correlated curve relationships.

Regarding Antoine viscosity data, you can enter one temperatureone viscosity to define a constant viscosity of the dead oil, or enter points for regression onto a two-point Antoine curve. The viscositiesinterpolated and extrapolated on a log-scale for all other temperaconditions. If multiple sets of two-point viscosity data are supplied, tthe two temperature points must be identical for each set.

24 Entering Thermodynamic or PVT Data

EP-elyed by on

com-egas

For-orlaso

uez/

. Forally Katz,

seandil/

ties) are

ack-

ses,theellpec- a

orre-r thes, or

lso,

If laboratory data is available, you can adjust the properties that PIPHASE calculates from its built-in correlations so that they more closfit the measured data. Since the data adjusts the properties computthe Standing correlation, you must specify Standing for all propertiesthe Correlation list or dialog box.

You can define the method that PIPEPHASE uses to predict a non-positional compressibility factor. The available correlations are thStanding-Katz, Hall-Yarborough wet gas, and Hall-Yarborough dry methods.

You can also define the methods that PIPEPHASE uses to calculatemation Volume Factor (FVF) and Solution Gas Oil Ratio (SGOR). Fthe FVF, you can choose the TUFFP Vazquez/Beggs, Standing, or Gmethods. To calculate SGOR, you can define the TUFFP VazqBeggs, Lasater, Standing, or Glaso correlations.

There are numerous viscosity correlations available for each phaseoil, there are the TUFFP Vazquez/Beggs, Beal-Standing/Chew-Conand Glaso correlations. For the viscosity of gas, the Lee, et. al., andCarr, et. al. methods can be used.

If you want to specify a specific correlation for mixing, you can chooone of three methods: Volumetric averaging, API Procedure 14b, Woelflin (loose, medium, or tight). You can adjust the Woelflin OWater mixing correlations by entering your own data.

GasCondensate

and GasModels

As for the blackoil model, you must enter are the gravities (or densifor each of the three potential phases of the fluid, while all other dataoptional. Enter the contamination concentrations as you did for a bloil fluid.

You must supply specific gravity data for gas, liquid and water phaeven if you do not expect them all to be present. You can define amount of nitrogen, carbon dioxide, or hydrogen sulfide in the wwhich adjusts the compressibility factor calculations. You can also sify a gas specific heat ratio (cp/cv) to override the internal value set asdefault.

You can also specify which correlation is to be used. The available clations for gas viscosity are the Lee and the Katz-Carr methods. Foz-factor, you can use the Standing-Katz, the Hall-Yarborough wet gathe Hall-Yarborough dry gas model.

In the case of gas condensate models, you do not have a choice as towhich correlations are to be used for calculating fluid properties. A


cor-

cept

dinge theen-

al topro-s

ate

toe vis-nto-lect

osity

as opposed to black oil calculations, you cannot adjust the Standingrelation to match any available data.

Figure 16:Gas Condensate PVT

Data

The PVT dialog box for a single phase gas is similar to Figure 16 exthat the data entry field, Condensate, is not an option.

Single-Phase Liquid

Model

The liquid can be designated either as hydrocarbon or water. Depenon your selection, the appropriate correlations are used to calculatphysical properties. Hydrocarbon liquids are restricted to having a dsity less than pure water. If the liquid density is greater than or equ1.0 (specific gravity), the liquid must be defined as water. You must vide the gravity or density of the liquid. All of the physical propertiewill be calculated from the density using correlations.

You’ll want to define the heat capacity when it is important to calculthe heat transfer effects.

Figure 17:Single Phase Liquid

PVT Data

If a hydrocarbon contains viscous tars, the default correlation usedestimate the viscosity may not be accurate enough. In this case, thcosity can be set as a fixed value, or fit to a temperature-dependent Aine equation. Either select Fixed Viscosity and enter a value, or seAntoine and enter two temperatures and their corresponding viscvalues.


tede orn-

ed

ity.g,likevail-

dis-leva-

ter toalsoer-ature

on an

-is

You can supply liquid viscosity data to override the internally predicdata. You can do this by either defining the viscosity as a single valuas a two-point viscosity curve. Similarly, you can supply a single costant value for liquid specific heat to override the internally predictdata.

You can specify the correlation used to calculate oil or water viscosThe options for viscosity correlations are: for oil, Vazquez, Standinand GLASO; for water, Beal and ASME Steam tables. However, unblack oil, you cannot adjust the Standing correlation to match any aable laboratory data.

Steam Model Enter the gravity, or density, of the water to represent the amount ofsolved salt present in the water, which becomes important if large etion changes are present.

When using steam, you can specify the gravity of the condensed wabe more than 1.0 to take into account dissolved solids. You can specify steam quality if the steam is saturated. If the steam is supheated or the water is subcooled, you must specify both the temperand the quality.

Figure 18:Steam PVT Data

Note that the steam (or any single component fluid) model is based enthalpy balance.

Note: If two-point viscosity data is supplied for more than one property set, the temperature values must be the same. This required to calculate the proper mixture viscosity when the twfluids merge, for example at a junction node.


rela-mo-theody-thelsouid-

amic

ms.ide canher-API.eru-

CompositionalModel

For compositional models, PIPEPHASE can use a generalized cortion, an equation of state, or a liquid activity method to calculate therdynamic properties at the flowing conditions and hence to predict split between the liquid and vapor phases. The choice of the thermnamic property calculation method depends on the components in fluid and the prevailing temperatures and pressures. PIPEPHASE aprovides a number of methods that can rigorously calculate vapor-liqliquid equilibrium and solid-liquid equilibrium.

Generally you must select methods for calculating these thermodynproperties:

■ Equilibrium K-values

■ Enthalpies

■ Entropies

■ Densities.

In PIPEPHASE, thermodynamic methods are arranged into systeWhen you choose a thermodynamic system, PIPEPHASE will provdefault methods for each of these thermodynamic properties. Youoverride these defaults. For example, if the Soave-Redlich-Kwong tmodynamic system is selected, the default liquid density method is You can replace this with another method, for example, Lee-Keslshould you feel Lee-Kesler will predict the liquid densities more accrately for your simulation.

Figure 19:Thermodynamic

Methods forCompositional

Sources


fol-

qua-ata.

, orc-RS,

d foriedby af the

aines,

sure fluid.beper-

malunc- mix-

dic-

rmalheand

To cite a few method examples, for the calculation of K-values, the lowing methods can be used for heavy hydrocarbon systems:

■ Braun K10

■ Grayson-Streed

■ Peng-Robinson

■ Soave-Redlich-Kw

For some systems, notably close-boiling mixtures, the standard etions do not adequately reproduce experimental phase equilibria dYou can improve the predictability of many of the equations of stateliquid activity coefficient methods by inputting your own binary interation parameter values. For example, you can tune the PR, SRK, BWand LKP equations.

If you have water in a hydrocarbon system, you can select a methocalculating aqueous liquid and vapor enthalpies either by a simplifmethod which assumes that the steam is at its saturation point, or rigorous method which takes into account the degree of superheat ovapor, if any.

Energy considerations in pipelines must take into account three mfactors: (1) the energy transfer to the environment, (2) frictional forcand (3) expansion cooling within the pipe, also known as the Joule-Thompson effect. In the Joule-Thompson phenomena, as presdecreases, the gas expands and there is subsequent cooling of theIn the case of large pressure drops, large fluid expansion may observed, and the fluid temperature may drop below the ambient temature.

TransportMethods

The SIMSCI databank contains pure component data for the therconductivity, surface tension, and viscosity of liquids and vapors as ftions of temperature. You can choose to use these data and simpleing rules to predict the flowing properties of the fluid.

Alternatively you can choose to use the API Data Book property pretion methods and mixing rules for mixed hydrocarbons.

Some 60 of the bank components have data for viscosity and theconductivity from the GPA TRAPP program. If you choose to use tTRAPP data, all of your components must be TRAPP components you cannot have any pseudocomponents or assay data.


onsure

ase,bemain

ds isow-di-et. Tore is

In the case of oil and water mixing, you can use the same correlatiavailable to the black oil case: Volumetric averaging, API proced14B, and the three variations of the Woelflin emulsion procedure.

To override the mixture liquid viscosity predictions, you can supply two-point liquid viscosity curve for either the hydrocarbon liquid phathe water phase or the total liquid. A different viscosity curve may supplied for each source, however the temperature points must rethe same.

In most cases, a single set of thermodynamic and transport methoadequate for calculating properties of all sources. However, your flsheet may contain sources with widely varying compositions or contions such that they cannot be simulated accurately using just one saccount for this, you can define more than one set of methods (theno limit) and apply different sets to different sources.


op

ese

lessded,

lcu-nnuli.uid Thela-ce.SE.

cha-rills- and

l.

Specifying the Global Defaults

This chapter describes how you can set global defaults for pressure drmethods, thermal considerations, roughness, and transition Reynold’snumber. Click the Global Defaults button on the toolbar to set up thdefault methods and values. The Global Defaults dialog box appears(Figure 20). These settings will be used throughout the simulation unspecifically over-ridden. In this way, repetitive data entry can be avoiparticularly when entering device data.

Figure 20:Global Defaults Dialog

Box

FlowCorrelation

Defaults

You must specify the Pressure Drop flow correlation to be used to calate pressure drops along lengths of the pipes, risers, tubings, and aThe default is Moody. The correlations available depend on the fltype: gas, liquid, compositional, blackoil, gas condensate or steam.selected correlation will be used for all units of like type in the simution unless you specify a different correlation on an individual deviYou can also enter user-defined correlations supported by PIPEPHA

➤ Click to set the default flow code method.

PalmerCorrections

Palmer corrections are factors which can be used with any non-menistic pressure drop correlation except Orkiszewski and Beggs & BNo-Slip, in order to adjust for uphill and downhill multiphase flow presure drops. The defaults are those recommended for Beggs & BrillBeggs, Brill & Moody correlations: 0.924 for uphill, and 0.685 fordownhill.

➤ Click to set default values for Palmer uphiland downhill correction factors for pipes, tubing, risers, or annuli

Flow Correlations..

Palmer Corrections...


ess

tub-ion

res.

side. The the

foruli inturem-

l-

f-la-

ur-er

s forenled,

s a

evalu-

These data will be used for all units of like type in the simulation unlyou specify different data for an individual link device.

InsideDiameterDefaults

You can specify default sizes for each of the riser, pipe, annulus anding devices. These data will be used for all devices in the simulatunless you specify different data for individual devices.

➤ Click to set default values for actual onominal diameters and schedules for pipes and other flow devic

The inside diameter can be specified on the basis of the actual indiameter of the device or (except for annulus) as a nominal diameterrelationship between nominal and inside diameter is determined byschedule and is defined in the Flow Device Size database.

ThermalDefaults

PIPEPHASE allows you to select the heat transfer default methodcalculating heat transfer for all pipes, tubing devices, risers and annthe simulation. As well, you can enter the default ambient temperafor the medium surrounding all pipes, and the default geothermal teperature gradient for all well tubing heat transfer calculations.

➤ Click to select the default method for caculating heat transfer for all flow devices in the simulation.

➤ Click to enter default heat transfer coeficients for all pipes, tubing devices, risers and annuli in the simution.

➤ Click the appropriate button to set the defaults for the medium srounding the pipes in the simulation. You can set heat transfdefaults for soil, water, air, and pipe insulation.

MiscellaneousDefaults

PIPEPHASE also allows you to set the flow device inside roughnesall devices, flow efficiency, transitional Reynold’s number, and whthe Hazen-Williams equation for single phase liquids has been enabthe HW coefficient.

Use the flow efficiency parameter to adjust pressure drops. It employlinear relationship with the local flow rate in the flow device. Thisshould be used to match field data only when all other relevant flow vari-ables (such as roughness, heat transfer coefficient, etc.) have been ated for effect on pressure drop.

Enter the transitional Reynolds number which is used internally as thetransition point from the laminar to the turbulent flow regime.

Inside Diameter Defaults..

Heat Transfer Defaults...

Heat Transfer Coefficients...

32 Specifying the Global Defaults

foreci-t,gh

in theu-

dnks

cessbythe

-

isond thed

mple thework

Building the Flowsheet

The flowsheet you construct in PIPEPHASE acts as the blueprint your process. Each component in the flowsheet will require user-spfied data before the simulation is run. While building the flowsheePIPEPHASE will inform you of any missing or inconsistent data throumessage dialog boxes. The data entered in flowsheet construction GUI is automatically exported into a keyword file, upon which the simlation run is based.

FlowsheetTerminology

The flowsheet consists of nodes and links. Nodes are connected byLinks. Each link starts at a node and ends at another node.

A node can be a Source, a Sink, or a Junction. A source is a point atwhich fluid enters the piping system. A sink is a point at which fluileaves the piping system. A junction is a point where two or more limeet.

Each link consists of a series of flow devices: pipes, fittings, and proequipment and unit operations. The direction of flow is indicated arrows on the flowsheet. If the fluid flows in a direction opposite to arrows, then the results will indicate a negative flowrate.

Types ofNetworks

There are two basic types of networks—tree networks and looped networks.

Tree NetworksTree networks are those whichinvolve the distribution of a largeamount of fluid to a number ofdifferent sinks, or the gatheringof a particular fluid from a num-ber of sources. The latter is espe-cially common in offshore blackoil gathering systems.

When all sink flowrates (q) are fixed, and the source pressure P known, the network is called a spur network. In the case of the secfigure above, the sum of the flow rates of nodes B through H equalsflow rate at the source P (node A). All the flow rates are known, anfrom these values, you can find the pressure at junction H through sisingle link calculations. Since cumulative rates are known along withstarting pressure for every sub-branch of the network, the entire net


theusly.

EP-ork.heSE isthe

se,d con-leentsce-

inores

es, theg

can be solved by simply “marching” towards each sink. Therefore, incase of spur networks, different links need not be solved simultaneo

In some cases, only a few links in a network may be spur links. PIPHASE identifies these links and solves the remainder of the netwfirst, using the PBAL algorithm to perform a simultaneous solutionOnce it reaches this solution, PIPEPHASE continues to solve tremaining spur links. There may be some cases in which PIPEPHAable to solve the “main body” of the network, but may fail in solving spur links.

Looped NetworksPIPEPHASE solves networks iteratively. Whichever algorithm you uPIPEPHASE starts with an initial estimate of flowrates in all links anpressures at all nodes. It adjusts these values until it has reached averged solution within a predefined tolerance. Because of the compnature of some networks, PIPEPHASE allows you to make adjustmto a large number of parameters that it uses during the solution produre.

Networks which include loops fall into two basic categories -- thosewhich all link flow directions are known, and those in which one or mlink flow directions are unknown. The former networks are described asimple loops while the latter are known as complex loops.

In simple loops, you can instructPIPEPHASE not to attempt toreverse flows during the solutionprocedure. However, if youincorrectly define a loop linkflow direction, and then instructPIPEPHASE not to reverseflows during simulation, the network will fail to converge. In such casPIPEPHASE will produce an error message, and you can inspectiteration history to find which link is producing the error by identifyinthe link which has a near-zero flow.

Some network simulationsinclude more than one loop con-figuration, where one or more ofthe loops contains links in whichthe flow direction is not known.Such cases are known as com-plex loops.

C_ebSU

C_ebSU

CY^[

CY^[

//C_ebSU

34 Building the Flowsheet

ecialleast

port

rticu-nd alink

This is common in existing designs, and must be addressed in a spmanner. Problems are usually not found in looped networks until at one simulation has been run. If the problem has not converged, you cangenerate the full iteration output. You can then inspect this output reto diagnose the problem.

In some cases, PIPEPHASE may decide to reverse the flow in a palar link in a loop. By doing this, the solution path begins to diverge afinal solution is no longer achievable. Placing a check valve in that will prevent the flow reversal.


rce andwork,t-first

t by it

ureassifi-e

ons.

. Ifte thatro-

and theons or

thee,

Entering Source and Sink Data

The most simplest flowsheet in PIPEPHASE is comprised of a souconnected by a link to a junction or to a sink. The source, junction,sink names must be unique, 4-letter alphanumeric names. For a netthe first source name defaults to S001 and the source number is automaically incremented as new sources are created. Then similarly, the junction begins with J002, and the first sink begins with D003.

For a single link, you must specify two of the following variables:

■ source flowrate (which is also the sink flowrate),

■ source pressure, and

■ sink pressure.

Inactivating UnitsYou can inactivate any source, junction, or sink on the flowsheechecking the box in the appropriate unit dialog box thus removingfrom the calculations.

Sources PIPEPHASE requires the properties of the fluid to calculate pressdrops, heat transfer, and phase separation. There are two major clcations of fluid models: compositional and non-compositional. ThPIPEPHASE program supports all of the well known empirical methodsfor determining the properties of oil, water, gas, and oil-water emulsi

You must also define the total flowrate and pressure at the sourcethese values are to be set operating conditions, then you can indicathey are fixed values. If these are allowed to vary to meet specified pduction values, then they can be entered as estimated values. If the pres-sure is estimated, the inputted value will be used as an initial guessPIPEPHASE will calculate the correct source pressure. Note thatchoice of fixed or estimated may be limited by the boundary conditiof the simulation. Similarly, the source flowrate must be either fixedestimated (default).

You can reference a source to another defined source by selectingUse Reference Source radio button. You can then define that flowrattemperature and/or pressure will be copied from another source.

36 Entering Source and Sink Data

ratiopro-t topute

he pres-st beoled

re at

t forlpy,flow-therr by

ichrce.luid.

Non-Compositional SourcesBesides the source name, the enthalpy, pressure, flowrate, gas/oil and water cut are required data for blackoil sources. If you do not vide a value gas/oil ratio (GOR) or water cut, they will both be sezero. A temperature value is also required for PIPEPHASE to comenthalpy changes between nodes during calculations.

Figure 21:Black Oil Source

In addition to fluid composition and properties, you must specify tfluid enthalpy at the source. For steam sources, you must define thesure and quality of a saturated steam source. The temperature muspecified only if the steam is superheated ( quality 100%) or subco(quality 0%).

When working with downhole nodes, you can specify the temperatua node if it is available (e.g. reservoir temperature).

Compositional SourcesCompositional sources are used to introduce fluid into the flowsheethe compositional fluid type. Besides the source name, the enthapressure, flowrate and composition are required. The pressure and rate are the boundary conditions for the simulation and can be eifixed or estimated. Any parameter that is estimated will be solved foPIPEPHASE.

The PVT property set refers to the two-point viscosity PVT data whcan be input and made available to any compositional fluid souTherefore, if appropriate, select the set associated with the source f


nd

om-

em-e.

r forns

efine the00

re isotnet

out.enld two

. If alcu- deter-

Figure 22:Compositional Source

Component data can be entered in three ways:

■ Enter the actual source composition, comprised of the library apetroleum components.

■ Describe the source by distillation curve data rather than on a cponent-by-component basis.

■ Reference the source composition to another source; flowrate, tperature and/or pressure can also be copied from another sourc

The temperature is required for a multi-component source in ordePIPEPHASE to perform a flash calculation to ascertain fluid conditioat the source. For a source with only a single component, you can dthe two phase enthalpy by the quality or single phase enthalpy bytemperature. Liquid is defined by quality = 0 and vapor by quality = 1(default). Quality is entered as vapor mass percentage.

Junctions A junction is a point at which at least three links enter and exit. If thejust one link going in and one link coming out, then the junction is nnecessary and the link devices may be put on the same link. The flowrate in the junction is zero, since the flow in must equal the flow PIPEPHASE allows a maximum of twenty sources linked to a givjunction. If you want to attach more than twenty sources, you shouenter them in sets of twenty into two separate junctions, and link thejunctions together with a very short, large diameter pipe.

Besides the junction name, the junction pressure can be estimatedpressure estimate is not given for the junction, PIPEPHASE will calate an estimated pressure. This pressure estimate is then used to

��


forini-

on,

eewever,andicethe

dataonsused.

mine the flowrate estimates based on the estimated pressure dropeach link. Although specifying the junction pressure is optional, an tial estimate may prove useful in speeding up the solution.

You can enter the temperature of the rock formation at this junctiwhich is used when the junction is subsurface.

Sinks Sinks are used to remove fluid from the flowsheet. The sink nodrequires two parameters to be specified—pressure and flowrate. If thesare desired set points, then they can be entered as fixed values. Hoif they are to be calculated, you need to provide an initial estimate PIPEPHASE will calculate the final values. Again, note that the choof fixed or estimated may be limited by the boundary conditions of simulation.

Figure 23:Sink

The sink temperature is generally calculated and is not available forentry. However, the sink temperature is required for gas lift simulatiwhen option 4, locate gas lift valve to match desired casing head, is


d tow.

hich for-ined.rm.

eth-

ow-

rmtowith,ace-

ow-

etup

of per-

PIPEPHASE also provides you with two other units that you can adthe flowsheet—hydrates and the calculator. These are described belo

Hydrates The Hydrates unit predicts the pressure and temperature regime in wthe fluid at a node (source, sink, or junction) is vulnerable to hydratemation. Different ranges of temperature and pressure can be examCalculations assume the presence of free water for hydrates to foHydrate calculations are available only for compositional fluid types.

You can also study the effect of NaCl, methanol, ethylene glycol, di-ylene glycol and tri-ethylene glycol hydrate inhibitors.

You can associate a hydrate unit with any source, sink, or junction; hever, you cannot associate a hydrate unit with a link.

Calculator The calculator is a versatile utility module that allows you to perfoFORTRAN-like calculations on information from the flowsheet and transfer the results to other unit operations. The calculator interacts and is calculated along with other flowsheet modules. Therefore, plment is important for proper execution.

You can associate a calculator with any source, sink, or junction; hever, you cannot associate a calculator with a link.

The calculator dialog box has two sections: the upper section for s(assignment of unit parameters to be retrieved from the flowsheet, ini-tialization of constants, descriptive labeling of results, and sizingarrays); and the lower section for the procedure statements whichform the actual FORTRAN calculations.


e linkflow,link

urn,rame-shipori-ve

ndent Theusedshort

er to

t val-iiledula-

Defining Links

Recall that a link is defined as a connection between two nodes. Thcan consist of one or more devices, and can contain a number of equipment, and completion devices. Figure 24 shows a typical between a source and a sink.

Figure 24:Simple Link

Each link consists of a series of flow devices. Each flow device, in tis characterized by its structure, pressure drop, and heat transfer paters. A pipe, riser, annulus, tubing, and Inflow Performance Relationmodel are all flow devices. All but the latter have length, may be hzontal or vertical with an accompanying elevation change, and hadefined diameters.

Each flow device usually undergoes a pressure drop, which is depeupon the flow codes, roughness, and flow efficiency of each device.flow code defines which pressure drop and holdup method is to be for the calculations. The roughness is the pipe inside roughness in length units. Flow efficiency is given as a percentage. This parameter isrecommended only when other parameters have been varied in ordmatch field data.

Heat transfer parameters can also be user-specified or left to defaulues. The ambient temperature may or may not have a vertical gradent.The default overall heat transfer coefficient, U, is set to 1. More detaheat transfer parameters, such as conductivity of surroundings, instion, etc., are available if the you want to enter these values as well.

?Ù^ãX_\Uð3_]`\UdY_^

#îðDeRY^W 3X_[U

@e]`

&îð@YÙ CY^[CY^[CY^[CY^[

C_ebSUC_ebSUC_ebSUC_ebSU

CU`QbQd_b


ed).t tem- also

theate

pres-et bur-t by

Heat

nd-

nly.ambi-atedient

pe

er in

Pipe Pipes are flow devices through which fluid flows from one point toanother. Pipes can have any orientation (horizontal, vertical, or inclinThe elevation change is defined on a relative basis, and the ambienperature is dependent upon the medium: air, water, or soil. Pipes canbe insulated or left bare.

The mandatory data for a pipe device includename, length and diameter. The optional datainclude elevation change, roughness, heattransfer and pressure drop method.

For most systems, the total pressure dropis dominated by frictional forces. The fric-tion factor is determined by the fluid velocity, the pipe roughness andmultiphase flow pattern. The fluid velocity is constrained by the flowrand the inside diameter of the pipe.

The heat transfer from the pipe is calculated at the same time as thesure drop. The heat transfer can either be turned off (isothermal), san overall heat transfer coefficient or calculated from the specified sroundings. The pipe, insulation and ambient conditions can all be seselecting the appropriate heat transfer option.

Initial default values for the Pipe Inside Diameter, Pipe Roughness, Transfer and Pressure Drop Method can all be set through the GlobalDefaults dialog box, which can be accessed by clicking the correspoing button on the toolbar:

Riser Risers are vertical or near-vertical with flow in an upward direction oElevation is measured in an absolute basis, and there is usually an ent temperature gradient with varying elevation. Heat loss is simulusing an overall heat transfer coefficient between the fluid and ambconditions.

To specify a downcomer, you can use a piwith a negative elevation change. For oil orgas well applications, tubing should beused.

Like the pipe, initial default values for theInside Diameter, Roughness, Heat Transfand Pressure Drop Method can all be setthe Global Defaults dialog box.

<U^WdX

5\UfQdY_^ð3XQ^WU

5\UfQd Y_^3XQ^WU

<U^WdX

42 Defining Links

ion-ured inwriteela-

s-liq-ase,y bevice.

Gas-ese

are

n.

d iseach

res-ases., the on

Tubing andAnnulus

Tubing and annuli have vertical orinclined flow. Wireline length is definedas the length from the surface to the pipeend. Depth is the actual vertical depthtaken from the surface. Heat loss for tub-ing and annuli is simulated using an over-all heat transfer coefficient andgeothermal gradient.

Initial default values for the Inside Diame-ter, Roughness, Heat Transfer, and Pres-sure Drop Method can all be set in theGlobal Defaults dialog box.

ReservoirInflow

PerformanceRelationship

(IPR)

The Inflow Performance Relationship (IPR) device models the relatship between flowrate and reservoir pressure draw-down or pressdrop at the sand face in a well. Several IPR models are suppliePIPEPHASE. You can select from five standard models or you can your own subroutine and use it to model the inflow performance rtionship.

The Productivity Index (PI) model is used for single-phase liquid sytems. The Vogel coefficient model is more suitable for multiphase, uid-dominated systems, while the gas flow model is best for multiphgas-dominated systems. Alternatively, user-defined IPR models malinked to PIPEPHASE and data for them entered through the IPR de

You can enter tables of reservoir pressure, cumulative production, Oil Ratio, Condensate-Gas Ratio, Water Cut and Water-Gas ratio. Thare used in timestepping to simulate reservoir decline with time.

You can enter curves that correlate reservoir pressure or cumulative pro-duction with flowing bottomhole pressure and flowrate. These data then regressed onto one of the standard models.

For an IPR with a gas basis, you can specify a drawdown formulatio

The Flow Well Pressure, Pwf, curves in Figure 25 are user-suppliecurves generated from a reservoir simulator. Each individual curvebased on the current reservoir conditions. The time-dependency of curve is based on the Reservoir Pressure, Pr, or the Cumulative Produc-tion, Np. With increasing Reservoir Pressure and decreasing Well Psure, the pressure gradient increases, and the production rate increSince cumulative production varies inversely as Reservoir Pressureopposite trend is observed for the dependence of production rateCumulative Production.

4U`dX

��

<U^WdX


or

ed

s:

he

Figure 25:Flow Well Pressure

Curves

The Linear Productivity Index equation shown above is valid only fsingle-phase flow above Boiling Point Pressure (BPP). Qo denotes theproduction rate, and PI the productivity index. This equation is derivfrom the pseudo-steady state equation from Darcy’s Law.

(1)

Darcy’s Law applied to an oil well in the center of a reservoir is given a

(2)

For gas wells, it is expressed as:

(3)

where:

k = effective permeability

h = thickness

Bo = oil formation volume factor

µg = viscosity

x = shape factor

S = skin factor

D = non-Darcy flow constant

It is important to specify the basis for the Productivity Index model. Tdefault basis in PIPEPHASE is oil.

?B

3e]â@b_T^äð> @

BUcâ@bUccebUäð@b

@b_TeSdY_^ðBQdUäðA

6\_gY^WðGU\\ð@bUccebUäð@

gV

Qo PI Pr Pwf–( )⋅=

Qo Ckh Pr Pwf–( )

Boµo xln 0.75– S+( )---------------------------------------------------⋅=

Qo Ckh Pr

2Pwf

2–( )

µgTrZ xln 0.75– S DQ+ +( )----------------------------------------------------------------------⋅=

44 Defining Links

as-

n:

t datahe

ile

s to

Solution Gas-Drive ReservoirThe Linear PI model is not valid for flow below the bubble point, inwhich multi-phase flow may occur. This is the case with Solution GDrive Reservoirs. The IPR curve varies with cumulative production.Vogel (1968) modeled this variation by deriving the following equatio

(4)

Above the bubble point:

(5)

where Qb is Qo at the bubble point.

Figure 26:Inflow Performance

Curves; Vogel’s CurveBelow Bubble Point

Fetkovich’s Gas Flow EquationThe Fetkovich equation (1975) is derived from the radial flow equation,and is expressed as:

(6)

This equation can be expressed graphically by taking three well-tespoints and plotting them on a logarithmic scale, as shown above. Tresulting line will have a slope n, where 0.5 < n < 1.0, and the intercept islog Cp. The greater values of the slope n indicate laminar flow, whsmaller values indicate turbulent flow.

The Forsheimer (Laminar-Inertial-Turbulent) equation is analogouthe Fetkovich equation.

(7)

Plotting (Pr2-Pwf

2)/Qg will yield a line of slope B and intercept A.

Qo

Qmax------------ 1.0 0.2

Pwf

Pr--------

– 0.8Pwf

Pr--------

2–=

PI1.8 Qmax Qb–( )

Pb--------------------------------------=

A_áA]Qh

@gV@b

>@ðáð>

A _

@gV > @ð-ð

@bY

Qg Cp Pr2

Pwf2

–( )n

=

Pr2

Pwf2–( ) AQg BQg

2+=


tal

and arfo-rme-

d theionslinear

Figure 27:Three-PointIsochronal

Test for Gas FlowCoefficients

Horizontal WellsTypically, one observes 3-10 times productivity increase in horizonwells. The key simulation issues in these cases are:

■ IPR segmentation for increasing velocity

■ Velocity gradient component of pressure drop

■ Coning

BottomholeCompletions

Bottomhole completion describes the interface between a reservoir well. There are two types of completion: gravel packed and open perated. The pressure drop through a completion is calculated from peability and other data you input.

PIPEPHASE uses the Jones model for gravel-packed completion anMcLeod model for open-perforated completions. The McLeod equatare based on radial flow, while the Jones equations are based on flow.

Figure 28:Completion Models

\_WðA 7

\_Wðè@b"ðãð@gV" ç

h

h

h

C\_Ùð-ð^

9^dUbSU`dð-ð\_Wð3 @

=S<U_Tð?Ù^ã@UbV_bQdUTð3_]`\UdY_^=S<U_Tð?Ù^ã@UbV_bQdUTð3_]`\UdY_^=S<U_Tð?Ù^ã@UbV_bQdUTð3_]`\UdY_^=S<U_Tð?Ù^ã@UbV_bQdUTð3_]`\UdY_^ :_Ûcð7bQfU\ã@QS[UTð3_]`\UdY_^ð=_TU\:_Ûcð7bQfU\ã@QS[UTð3_]`\UdY_^ð=_TU\:_Ûcð7bQfU\ã@QS[UTð3_]`\UdY_^ð=_TU\:_Ûcð7bQfU\ã@QS[UTð3_]`\UdY_^ð=_TU\

3U^dUb\YÛ

@UbVðTYQ]UdUb

TbY\\ðX_\UðbQTYec

deRY^W

cQ^TðcSbUU^

de^Û\ð\U^WdX

��@UbVðTYQ]UdUb

@UÛdbQdY_^ðTU`dX

3becXUTðj_Û

SQcY^W

SU]U^d

46 Defining Links

ave

liquidluids.d onevs.

p

sedm

sure,ssor

canusedunit, the

Youutletify-

ulti-den-ust beom-

lems

aointtream,sure. its.

ngeul in

EquipmentDevices

This section describes link devices available in PIPEPHASE that hnot yet been described in this chapter.

Pumps are equipment devices used to increase the pressure in a line. Pump devices are not available for steam or single-phase gas fThe mandatory data for a pump device includes the pump name anof the following: power, outlet pressure, or pump curve (flowrate head). The optional data for a pump device include adiabatic efficiencynumber of stages, maximum pressure and maximum power. Pumdevices should only be used for incompressible fluids.

If the fluid is compressible, then the compressor unit should be uinstead. You can also set limiting conditions in the form of maximupower and maximum pressure (discharge). To specify suction presyou must use the multi-stage compressor. The multi-stage compredescribes a single or multi-stage, multi-train compressor station. It model the effect of intercoolers and scrubbers. This unit cannot be for steam systems. If you specify the suction (inlet) pressure for this a special subnetworking algorithm is invoked. This algorithm sizescompressor power requirements.

A heater/cooler simulates the addition or removal of heat to a fluid. must specify pressure drop and either: total heater/cooler duty or otemperature. You may also set limiting conditions (optional) by specing a maximum duty and/or a minimum/maximum temperature.

A separator removes a defined portion of a selected phase from a mphase stream. It can separate vapor, liquid, liquid water and/or consate. The fluid that is removed is lost unless it is reinjected. You mspecify either the flowrate or percentage of the required phase toremoved. This device does not operate with steam, and is valid for cpositional fluids, black oil and condensate problems. The latter probcan be treated by selecting a qualifier for a particular effluent phase.

The injection device is used for introducing an injection stream fromlateral source or re-introducing a stream from a separator to a pdownstream. Equipment devices cannot be used on the separated sbut you can flash the stream to the desired temperature and presThis device is only used for compositional fluids in single links, andcan also be used for compositional fluids from separators in network

A check valve prevents flow reversal in a given link. You must specify acheck valve diameter when implementing this device. You can chathe check valve discharge coefficient. This device is especially usefnetwork calculations.


, toan

oilired

-ssureange cal- as

intro-ncethisizes the

aseeam or

gradi-

ct or thentu-let,

it oneasttwo willre fit-

SEance

pplyaturetivity datahe

The gas lift valve injects a gas stream into the production tubingenhance fluid recovery. You must specify gas flowrate, and you cchange gas solubility in oil. This device can be used only for blackfluids, and gaslift problems. A separate liftgas PVT data set is requin order to properly describe the gas used.

A regulator is used to fix the pressure in the link immediately downstream from it if the upstream pressure is greater. If the stream preis lower than the regulator pressure, then the regulator does not chthe downstream pressure. This device is especially useful in networkculations. The regulator unit allows you to specify suction pressurewell.

A choke restricts flowrate and creates a pressure drop. This device duces a discontinuity into the defined network structure. The balabetween the parts of the network upstream and downstream of device is solved by PIPEPHASE’s subnetworking algorithm, which sthe choke. You must specify the choke diameter, and you can varychoke discharge coefficient, as well as the heat capacity ratio.

An electric submersible pump is an equipment device used to increthe pressure in a liquid line. Pump devices are not available for stfluids. You must provide one of the following: power, outlet pressurepump curve plus motor horsepower, auxiliary power, head degradation,minimum submergence, casing head pressure, or vertical pressure ent.

Orifices, nozzles and venturimeters are fitting devices used to restrito measure the flowrate through the pipe. If being used to restrictflowrate, the pressure drop across an individual orifice, nozzle or verimeter may be large. You must supply the inside diameter of the intype of orifice and the orifice diameter.

Pipe tees are fitting devices used to merge two pipes into one or splpipe into two directions. To be consistent, the tee should be the ldevice in a link going to a junction The junction node should have other links either entering or exiting. Any other arrangement of a teebe modeled as if the third end of the tee is capped off. Pipe bends ating devices used to change the direction of the flow.

DP-DT devices simulate equipment for which no standard PIPEPHAmodel exists. These devices are typically used to model the performof specially designed valves and fittings. For these devices, you sudata relating the fluid flowrate, the pressure change and the temperchange in tabular form. These devices can model Wellhead Producaccurately. If a wellhead flowrate versus pressure graph is available,from the well test or from the simulation can be used to eliminate twellbore from the problem.

48 Defining Links

tud-n.s beenen no based

ipleom-on-

r thevingom

or onula-

riginal 10

nput,highme.

n theudieseu cann exe-

rame-

ce,e

t the

Setting up a Case Study

The Case Study option provides the facility to perform parametric sies and to print multiple problem solutions in a single computer ruCase studies are always performed after the base case problem hasolved. If the base case problem cannot be solved for any reason, thcase studies are performed. Each case study analysis is performedon the cumulative changes to the flowsheet up to that time.

Case studies are an efficient means of obtaining solutions for multscenarios to a given problem, and result in large savings in both cputer time and cost. For problems requiring iterative solutions, the cverged results of the last solution are used as the starting values fonext run. This can result in large computer time savings in runs invollarge networks, where it typically takes several iterations to move frthe initial pressure estimates to the final converged solution.

There is no limit on the number of parameters varied per case study the total number of case studies that can be in a given run. The cumtive changes up to a given case study run may be erased and the obase case restored at any time. PIPEPHASE allows you to performcases and 10 changes per case.

Since the case studies are performed sequentially in the order you iit is best to make changes in an orderly manner, proceeding from values to low values or low values to high values, but not in randoorder. This enhances convergence and minimizes total computer tim

EnteringCase Study

Data

You can enter case study data before you run the base case. Wheprogram runs, the base case will be executed first and the case stwill be executed afterwards. Alternatively, you can run the base casfirst, then enter case study data and execute the case studies. Yoopen an already solved flowsheet, add case study data to it and thecute the case studies.

You must specify which parameters are to be changed. For each pater you must supply the:

■ Change Variable Names—select a source node, sink node, link deviconstraint, or network convergence parameter on which the casstudy is based.

■ Data Source—set data to a specified value or have a calculator sevalues for you.


gedr in

emetereci-

gedvice

in theainseters

sure,. Thepe of

■ Parameter—list box displays all the parameters that can be chanfor that particular item. These are explained in greater detail latethis chapter.

■ Change Variable To—the value for the parameter being changed.

Figure 29:Example Case Study

Parameter

Change Types You can make changes in three different ways.

Global Changes—You can change one parameter in the entire problusing a global command. You do this by supplying the type of paramyou want to change, its old value, and the new value. Only those spfied parameters with that old value will then be changed.

Individual Changes—Source, sink, and device parameters can be chanindividually. You must specify a name for each source, sink, or dewhere a parameter change is desired.

Cumulative Changes—When performing case studies, you must keep mind that any variable changes you input are cumulative. That is,variable you change in the first case run (after the base case) remchanged for the next run, unless you specify that base case paramare to be restored.

Variables Source and Sink VariablesWhen performing case studies on sources, you can vary the prestemperature, or flow rate at the source, regardless of fluid propertiesnumber of additional variable parameters is dependent upon the tyfluid you are working with.

50 Setting up a Case Study

o-Oilon-

r/gas

e ofow-ilitydyx.

arere

uip-g,

ess,esedis-

bingking

lingns,e nots.

e ores and

e and

est orkov-

When working with compositional fluids, you can also vary the compsition of the source stream. In cases of black oil studies, the Gas/Ratio (GOR) and Water Cut parameters can be changed. For Gas Cdensate fluids, you can vary the condensate/gas ratio or the wateratio. For steam, you can change the quality.

Although there are few variables one can vary in the sink, these arprime importance in the design of production fields. The desired flrate (production) at the sink often determines the efficiency or feasibof a given design. Thus, the flow rate is one of the allowable case stuvariables for the sink, as well as the pressure and the injectivity inde

Pipe VariablesIn many wells, the inlet (reservoir) and outlet (wellhead) parametersusually desired or fixed values, and the equipment linking the two asubject to adjustments to meet specific production goals. Such eqment includes the connections in the system, such as pipes, tubinannuli, and risers.

PIPEPHASE can vary the inner diameter (nominal or actual), roughnheat transfer coefficient U, and/or the pressure drop for each of thconnection devices. Additional parameters can be varied for each tinct component. For pipes, you can vary the length, the elevationchange, and or the ambient temperature of the surroundings. For tuand annuli, you can also vary the temperature gradient. When worwith an annulus, you can also change the outer diameter.

Device VariablesVariation of device variables is especially useful when you are modean existing system. It would be impractical to change the connectiosuch as the pipes or tubing, and so if performance specifications arbeing met, the easiest parameters to vary are found in these device

For pumps and compressor, you can change the power, pressure, andefficiency. You can also vary the number of stages (i.e. single stagmultistage compressor/pump), and certain parameters such as curvefficiencies can be varied for different stages.

In heat exchange networks, you can vary the duty, outlet temperaturpressure drops of any heaters or coolers present.

In links, when working with Inflow Performance Relationship devic(IPRs) you can vary the Productivity Index (PI), and/or the coefficienthe exponent in the corresponding IPR model (e.g. coefficient in Fetich gas deliverability model, exponent in the Vogel equation).


sethisd

t file.ase.

Executingthe Case

Study

Click the Run button to execute the simulation. By default, the BaCase and all case study cycles will be executed. You can restrict using the Execution Options list option in Case Study Parameters anResults dialog box.

A Case Summary report is always produced at the end of the outpuIt shows the node pressures, temperatures, and flowrates for each c

52 Setting up a Case Study


Working with Keyword Input Files

Keyword input files (.INP) are free format ASCII text files that define aPIPEPHASE simulation using specific commands known as keywords.You can import and run keyword files within the graphical user interface.Keyword files play many important roles in PIPEPHASE:

■ They provide an alternate interface with the PIPEPHASE calcula-tional module.

■ They allow you to maintain compatibility with simulations that wererun with earlier versions of PIPEPHASE.

■ If you need help with a simulation, you can send your keyword fileto SIMSCI for technical support.

■ They provide a compact means of storing simulation input.

■ If you have several similar flowsheets to run, you can create the firstsimulation within the GUI and then modify its keyword file for eachscenario.

You can import existing keyword files into the GUI using the Import...option from the File menu.

Keyword files are easy to read and understand and data are entered in thefollowing order:

GENERAL DATA

COMPONENT DATA

NETWORK DATA

THERMODYNAMIC DATA

PVT DATA

STRUCTURE DATA

UNIT OPERATIONS DATA

CASE STUDY DATA

e ofle-lationn

lanceonsr. Aswndous

e:

ated

in a

tesolu-rk

ngries.ction

s.

het-. The out

Running the Simulation

The PIPEPHASE solution algorithm can be used to solve any typpipeline network, from complex, multiphase looped systems to singphase gas transmission lines. This chapter describes network calcumethods, techniques for achieving better convergence, and the ruoptions available in PIPEPHASE.

Internally, PIPEPHASE generates a set of material and pressure baequations from the input data, and proceeds to solve these equatisimultaneously using a Newton-Raphson scheme and a matrix solvewill be seen in the following section, almost any combination of floand pressure node conditions can be solved, which gives you tremeflexibility in solving a wide variety of problems.

To assist in setting up networks and to follow good simulation practic

■ Each boundary node should have one fixed value and one estimvalue.

■ At least one boundary node pressure must be fixed.

Pressure Balance MethodThe methodology for determining the pressure and flow distribution pipeline network is based on a pressure balance (PBAL) solution algo-rithm.

From a network flow balance, the PBAL algorithm first identifies the setof starting link flows which is the minimum set of link flow rates thacompletely define the network flow distribution. Spur links, which arflowrate-specified isolated sections that do not affect the rest of the tion, are identified and solved, independently of the general netwosolution. The primary variables for the solution matrix are the startilink flowrates and all unknown pressure values at source boundaPressure imbalances are computed at all fixed pressure sink junnode boundaries, as well as at nodes with two or more incoming flow

Mass Balance MethodThe mass balance (MBAL) solution method is used to provide PBAL wita good initial estimate of the flow and pressure distribution in the nwork. This method may also be selected for single phase networksalgorithm is based on the principle that the sum of all flows into (andof) all nodes in a network must equal zero in steady-state.

54 Running the Simulation

ASElcu-

res-stress

eanges

bal-oming

allsuidl heat

ngeor

solu- the ares at

icesThise

ature,ub-nt of

d ver-r the

CalculationMethods

To perform pressure drop and heat transfer calculations, PIPEPHdivides each flow device into calculation segments. The segment calation takes into account frictional, elevational, and accelerational psure drop components. Frictional pressure drop is due to the shear between pipe wall and fluid. Elevation pressure drop is a result of theconversion of fluid potential energy into hydrostatic pressure and thaccelerational pressure drop is the gain or loss in pressure due to chin velocity of the fluid.

In addition to the pressure balance of the pipe segment, an energyance is also performed. There must be a balance between energy cinto the segment and energy leaving it. Energy can enter or leave withthe fluid or through the flow device walls. The transfer through the wis governed by the temperature difference between the average flflowing temperature and the ambient temperature and by the overaltransfer coefficient.

ForwardTraverse

The calculation segment and pressure drop and temperature chaequations are the heart of PIPEPHASE’s calculational capability. Fflow devices, the calculation segments are strung together and the tion procedure is sequential. Calculation begins at the inlet whereconditions are known. The heat and momentum balance equationssolved, in an iterative fashion for this first segment and the conditionthe other end are found. These calculated conditions become the knownconditions for the inlet to the next segment. Calculations progresssequentially until the end of the device is reached. Further flow devare calculated in the same way until the end of the link is reached. calculational method is a forward traverse method, which means that thcalculation proceeds in the direction of the flow.

CalculationSegment

PIPEPHASE works in segments to determine the pressure, temperhold-up, and flow pattern distribution in all flow devices: pipe, riser, ting string or annulus. A segment is the smallest calculation incremea larger length of pipe, as shown in Figure 30.

Figure 30:Pipe Segment

Separate segment sizes can be specified for all horizontal (pipe) antical (tubing, annulus, riser) flow devices, either as segment length onumber of segments per device, through the Network Calculation Meth-

8UQdðdbQ^cVUbðdXb_eWX

ðgQ\\c6\eYTðêð8UQdð?ed@?edäD?ed

6\eYTðêð8UQdð9^

@9^äD9^ð1^W\U@1fWäD1fW


ula-seodels

E the

t theent

ub-esults

tub-

ssuresicalsureASEuter

ula-tion

ods dialog box. These options should be considered prior to any simtion involving significant changes in fluid density. Almost all multiphaand single-phase gas applications, as well as single-phase liquid mwith sharp thermal gradients fall under this classification.

A flow device may be internally divided automatically by PIPEPHASinto several compositional segments based on a maximum limit toenthalpy change per segment. This includes pipes, risers, or tubing.

A shorter segment size will increase the accuracy of the simulation aexpense of computation time. If you are unsure of an optimal segmsize, the simulation should be run first with default segmenting. In ssequent runs, you should adjust segment sizes on the basis of the rof the prior simulations until the optimal point is defined.

SolutionAlgorithm

Figure 31 outlines the segment calculation procedure for every pipe,ing, annulus, and riser for compositional and steam systems.

Figure 31:PIPEPHASE Solution

Algorithm

This procedure is iterative, and it requires average conditions of preand temperature in order to calculate the phase equilibria and phyproperties of the system. These values are then used for the presdrop and energy balance calculations. To achieve this, PIPEPHemploys an inner loop for the convergence on pressure, and an oloop for enthalpy convergence.

For black oil or single-phase fluids where there are no enthalpy calctions, the segment calculation procedure reduces to a single iteraloop.

CD1BD

79F5>ð@!äD!ä8!ä4<ä]5CD9=1D5ð∆Dðêð∆@

Dð-ðD!ðåð∆Dá"31<3E<1D5#∆85CDEC9>7ð851Dð21<1

@ð-ð@!ðåð∆@á"

31<3ð6<E94ð@B?@Câ31<3ð∆@5CD

_∆@5CD#0#∆@_?#ε3

∆@ð-ð∆@5CD

>?

Y^Ûbð\__`

@"ð-ð@!ðåð∆@5CDD"ð-ðD!ðå#∆D

31<3E<1D5ð8"∆8ð-ð8"ðãð8!

_∆85CDð0#∆8_?#ε8∆D-∆D∆8á∆8?<4∆@-∆@5CD

>?

_edUbð\__`

I5C

CD?@


, andion.

ty

s allsure

rticu- and

suchtedexted,over-ther.

red,t of thisria,

h iss cor-

todi-

eleady

Line Sizing For single links, PIPEPHASE can calculate the sizes of pipes, riserstubing to meet either a pressure drop or a maximum velocity criterYou can select from three options:

■ One flow device with fixed source and sink pressures.

■ Multiple flow devices with fixed source pressure and maximumvelocity specification.

■ Multiple flow devices with sink pressure and maximum velocispecification.

With a fixed source pressure and sink pressure, PIPEPHASE sizeflow devices to the same diameter. With a fixed source or sink presand maximum velocity, PIPEPHASE sizes each device separately.

You can select all flow devices to be sized or you can select only palar ones for sizing. You can also supply a set of maximum velocitiesa corresponding set of diameters or slip densities.

During the sizing run, PIPEPHASE checks to see if a device size is that a maximum velocity is not exceeded. If this specified or calculamaximum velocity is exceeded, then PIPEPHASE will select the nhigher line size. Recall that if a range of line sizes is not specifiPIPEPHASE defaults to the schedule 40 inside diameters. You can ride this list by specifying your own preferred line sizes. Note that line sizing option does not result in a decrease of the device diamete

The maximum velocity can be based on one of two criteria. If desiyou can enter a set of maximum velocities corresponding to a seinside diameters or densities (economic velocity). If you do not enterdata, PIPEPHASE will use the erosional maximum velocity criteVEM, as shown below.

Tabular Data Default (8)

You can change the value of the erosional velocity constant, whic100 above. You can also enter values for the two-phase slip densitieresponding to the set of maximum velocities.

Sphering(Pigging)

Sphering of a wet gas pipelines is a common operating practiceimprove the flow efficiency of the pipeline. PIPEPHASE uses a mofied form of the Barua-modified-McDonald-Baker (MB) pigging modto simulate the sphering process. The MB model is a successive ststate model. Normal two-phase flow is represented in Figure 32.

VMAX f ρf( ) 100

ρf

---------= =


r theine - slugumesr the

uid usedcula-e it

bse-nsn.

theignch-

surepec-of 2suresults. The

Figure 32:Normal Two-Phase

Flow (Stratified)

The pig is launched after steady state flow has been reached. Aftepig has been launched four distinct zones of flow occurs in the pipelthe re-established two phase flow zone, the gas flow zone, the liquidflow zone and the undisturbed two-phase flow zone. The model assthat the inlet flow rate remains constant at the steady state rate aftepig has been launched.

Figure 33:Two-Phase PipelineFlow with Spheres

PIPEPHASE predicts the pressure profile, length of each zone and theposition of the sphere as a function of time. In addition, when the liqslug reaches the end of the pipeline a special slug delivery model isto model the slug delivery when the liquid slug accelerates. Next caltion continues after slug delivery is completed to calculate the timtakes for steady state flow to be re-established in the pipeline.

The first sphere must be launched at the inlet of the first pipe. Suquent pigs may be launched from downstream pig launching statiowhen the upstream pig(s) reach the downstream pig launching statio

To model the pigging process the pig diameter must be specified infirst pipe. To specify downstream pig launching stations, specify the pdiameter for the corresponding pipe. The program interprets the lauing station to be the inlet of the pipe.

Setting theCalculationTolerances

For networks that require iterative calculations, you can set the presconvergence tolerance for the solution. For instance, if you do not sify a tolerance pressure value, PIPEPHASE allows for a tolerance psi. It will then perform the required iterations until it reaches a presthat is within 2 psi of the desired value. Setting tighter tolerances rein more accurate solutions, at the expense of more calculation time

6\_g

6\_g

BUãUcdQR\YcXUTDg_ã@XQcUð6\_g

<YaeYTðC\eWðJ_Û E^TYcdebRUTðDg_ã@XQcUð6\_gðJ_Û


re. If set aould

ase,ckosi-e for

r-orks

par-rlym-ms

ntiveing

ding

ofon,l have, as in, ify toates

two

ng

flot in

tolerance should commonly range between 0.5 to 5 psi for pressuyou anticipate a large drop in pressure, then it may be appropriate tohigher tolerance. Conversely, for small pressure gradients, you shset a tighter tolerance value.

PIPEPHASE allows you to specify tolerances for other parameters,well. When using the MBAL method, you can specify the flow tolerancwith the units depending on the fluid type (bbl/day for liquid and blaoil, MM ft 3/day for gas and gas condensate, and MM lb/hr for comptional fluids and steam). You can also specify temperature tolerancMBAL networks.

For PBAL network solution methods, in addition to the pressure toleance, you can also specify the rate to improve convergence in netwwith chokes in critical flow.

GettingBetter

Convergence

The best way to ensure that PIPEPHASE calculations converge for aticular network is to make sure that the problem is structured propebefore running the simulation. The following are a few general recomendations on how to set-up networks to avoid the majority of probleduring the solution procedures. These recommendations are prevemeasures rather than actual troubleshooting guides for non-convergsimulations. Such simulations may require greater attention, depenon the severity of the error.

1. If you specify fluid flowing from a node of low pressure to another larger pressure, PIPEPHASE will not be able to calculate a solutiunless it reverses the flow. There are cases where the sink node wila greater pressure than the source node after a solution is reachedthe case of a pump in a single link. Also, in cases of downhill flowsgravitational forces are dominant, the flow may be a direction contrarthe pressure gradient. Generally, you should supply pressure estimonly at nodes where a value can be confidently predicted.

2. Every internal node (junction) must have at least one outflowing link andat least one inflowing link. The junction node should only be used in circumstances:

■ The network structure dictates that one or more links are joinitogether or splitting apart.

■ You require the generation of a phase envelope or two-phase map or flash report (compositional runs only) at a particular pointhe network which is not described by any other node.


twoe theile

etri-

nce.een

et-

itw, itnc-

k. Inave

ink, asmy”ear-

con-sult-

c-d.

3. There are no other reasons for using junction nodes other than thepreviously given. Adding unnecessary nodes only serves to increassize of the matrix and so increase computing time. Therefore, whthere is a tendency for neatness in input by splitting long links intosmaller links using junctions, you should bear in mind the possible dmental effect on the simulation solution procedure.

Thus, reducing the number of junctions results in quicker convergeIn the figure shown below, two extra junctions (unnecessary) have btaken out while still retaining all the flow devices.

4. The first two primary guidelines for good simulation practice when sting up any network simulation in PIPEPHASE are:

■ There should be only one link to a sink node.

■ There should be only one link from a source node.

In the preceding discussion about junctions, we noted how usefulwould be to eliminate superfluous nodes. In the case depicted belowould seem that we are contradicting this principle by adding two jutions to the already existing design. However, the two guidelines givenabove take precedence over the number of junctions in the networother words, it is preferable to have more junctions rather than to hmore than one link coming from a source or going into a node.

In some cases, two or more links can be attached to a source or a sshown below. To overcome this limitation, you can construct a “dumpipe to connect the source to a junction. This pipe should have a nzero pressure drop (short length, large diameter). Similarly, you cannect a “dummy” pipe to the sink. PIPEPHASE can then solve the reing network.

Note: Outside of their uses that have been previously indicated, juntions must be viewed as simulation devices only, and shoulnot be confused with any physical representation of the plant

2UddUb

CX_bdð@YÙ<QbWUð94

CX_bdð@YÙ<QbWUð94


pre-ntos thatri-

heseouowlves. of

im-

n it

on

an, and

5. Some solution paths may oscillate widely due to flow reversals. To vent flow reversal in specific links, you can implement a regulator ithe network. Regulators can be used as zero-pressure drop deviceforce flow in a specific direction. For instance, if a certain link is expeencing multiple flow reversals, you can use a regulator to stabilize toscillations. In the case of flow reversal in interconnected links, yshould use the check valve only in the link that causes the first flreversal. Generally, you should avoid the excessive use of check vaIf all the link flow directions are known, however, you can select theNoFlow Reversal option instead of specifying a check valve in every linkthe network.

If solution path oscillates widely due to flow reversals:

■ Use No Flow Reversal option if flow direction in every link is known

■ Use Check Valves in key links if direction is not known in every link

■ Use Flow Rate Damping

Run Options You can run a PIPEPHASE simulation in several ways:

■ Interactively—run and solve the active simulation.

■ Run Other—launch other user applications from the PIPEPHASE sulation environment.

■ Run Remote—allows you to create a simulation on your PC and ruon a remote UNIX machine.

InteractiveRun

Capabilities

To run your PIPEPHASE simulation interactively, click the Run button the toolbar, or select File/Run from the menu bar. The Run Simulationand View Results dialog box appears. From this dialog box, you ccheck simulation data, run simulations, stop and restart simulationslink to the Results Access System (RAS) programs.


ordn

n a

n a

ce.

o-sys-nt in

ta.

Figure 34:Run Simulation andView Results Dialog

Box

The following options can be selected for running a simulation:

Solve Network—solves the problem as a steady state solution. A keywinput file (.INP) is first written and the batch execution is initiated. If ainput file already exists, you are asked if it should be overwritten.

Nodal Analysis—performs detailed engineering analysis of nodes withisingle link.

Line Sizing—performs detailed engineering analysis of line sizing withisingle link.

Create Keyword File—generates a keyword file from the designated sour

Run Keyword File—runs the selected keyword file.

Component Lumping—generates the binary components from the compnent lumping data. This option appears for compositional transient tems only. The component lumping operation can be run at any poithe modeling as long as components have been defined. [TACITE only]

Transient Simulation—solves the system using transient simulation da[TACITE only]

Report options will be discussed in the next chapter.


nsn-

to the

ifica-be

and a

e

youfea-

ote

Run Other The Run Other option allows you to to launch other user applicatiofrom the PIPEPHASE simulation environment. This is useful for runing additional engineering applications such as the POPOHZN horizon-tal well model developed by JNOC. To access other applications:

➤ Click within the Run Simulation and View Results dia-log box.

➤ Select to configure the application. This allows you name the application and specify the commands used to invokeapplication.

➤ Use to find an executable application.

The configuration also supports additional commands such as spection of the initialization file. For example, the RAS application could configured as follows:

Application Title: Results AccessApplication Run File G:\SIMSCI\PPHASE\GUI\WINRAS.EXEApplication Argument List: /i=G:\SIMSCI\PPHASE\USER\PIPEPHASE.INI

Run Remote PIPEPHASE gives you the ability to create a simulation on your PC run it on a remote UNIX machine. When you install PIPEPHASE,batch file named XXREMOTE.BAT will be added to your GUI directory,typically \PIPEPHASE\GUI. This file will allow you to access the remotbatch capabilities of PIPEPHASE, assuming that you have the PIPEP-HASE calculation engine on a networked UNIX machine. Normally, should not need to modify this file. In order to use the Run Remote ture, you must define the settings for your configuration.

➤ Select File/Remote Settings from the menu bar.

➤ Check the Run Calculations on Remote Computer box to enable thisoption.

➤ Check the Minimize Screen During Execution box to have the pro-gram run in the background.

You must supply the following information:

■ The operating system local on your PC.

■ The host name, user ID, and user files directory path for your remhost machine.

➤ Select either the TELNET or RSH option for communicating with theremote host.

➤ For the TELNET option, you must also supply a user password.

Run Other...

Properties...

Browse...


and

grate

and

nsnkectly

or

ng

lot

Viewing the Results

In addition to the standard output report format, you can generate view plots, tables, and flowsheet diagrams from PIPEPHASE. Thischapter describes how to view these simulation results through the flow-sheet, output file, and the Results Access System, and how to intethem into accurate, professional reports.

InteractiveOutput

You can interactively view summary results for sources, junctions, sinks in two ways:

■ Select View Output from the menu bar, and make your selectiofrom the View menu. According to your selection, the node and lilabels, pressures, temperatures, and flowrates are displayed diron the flowsheet.

■ In the View Output mode, double-click on a source, junction, sink. The temperature, pressure, and total liquid flowrate (oil +water) for that node is displayed, as shown below.

You can interactively view summary results for links by double-clickion the link when the program is in the View Output mode. The Link PlotSelection dialog box appears. PIPEPHASE provides you with four ptypes.

Note: To view these plots, select Device Detail as Part, and Plots asPart under Print Options from the General menu before run-ning the simulation.

64 Viewing the Results

r

For example, the Pressure versus Distance plot is shown below.

Figure 35:Pressure vs. Distance

Plot

OutputReport

You can examine most of your simulation results through the outputreport (.OUT) file. PIPEPHASE contains a wide variety of report optionsfor customizing your output format. In the Print Options dialog box, youcan choose, amongst other things, which portions of the input data youwould like reported. The default print options are given in Table 10below.

The output report for your simulation is automatically generated afterthe simulation has converged. To view the output report, select OutputReport from the Report list box in the Run Simulation and View Resultsdialog box, and click . The report is opened in the Programme’s

Table 10: Default Print OptionsPrint Option Default Setting

RAS Database None

Input Reprint Full

Device Detail Summary

Device Style Both

Property Data None

Plots None

Flash Report Full

Link Slug Report* None

Iteration Printout Off

Connectivity Plot On

Flow Regime Map Off

Optimization Printout Control Part

* Item is activated only when Device Detail is set to Part or Full.

View


irec-

s run.ionnlyrorsself,her will

ut-y. By

f this

toaryro-

d to each

nd

ients in

ted

File Editor, provided by PIPEPHASE. PIPEPHASE appends the .OUTextension to your file name and saves the output file in the same dtory that you saved your simulation files. The default directory is C:\SIM-SCI\PPHASE\USER.

The output from a PIPEPHASE simulation is in three main sectionwhich correspond to the three phases of the PIPEPHASE simulationThese are the input check and input data reprint; intermediate soluthistory and output; and the final results output. PIPEPHASE will ocontinue from one section to the next if no errors are detected. If erare found, either in the input data or during the solution procedure itself explanatory messages will be printed and the simulation will eitterminate or, in the case of a solution procedure error, PIPEPHASEtry to resolve the problem and continue with the simulation.

A reprint of your keyword input data file is always created for each oput file. PIPEPHASE cross-checks the data for logic and consistencdefault, it also prints out the full set of input data which shows all thedefault values used, as well as the user-supplied data. All, or part, ofull input data reprint can be suppressed if desired via the Print Optionsdialog box.

During solution of a network, PIPEPHASE iterates until it convergeswithin the tolerance you set, or that which is set by default. A summof any errors or warnings encountered during that iteration will be pduced at the end of each iteration. The iteration option can be userequest additional printout which shows flowrates and pressures atiteration of the solution path. This can be particularly useful if you haveinadvertently given conflicting specifications in the problem setup athe program has failed to resolve the inconsistencies.

If well test data have been specified, the inflow performance coefficis calculated before the solution calculations and the report appearthe intermediate output.

The solution output is made up of a number of sections, as indicabelow:

■ Flash Report ■ Results Summary

■ Separator Report ■ Link Device Detail Report

■ Link Summary ■ Link Property Detail Report

■ Node Summary ■ Slug Report

■ Device Summary ■ Case Summary

■ Structure Data Summary ■ Sensitivity Analysis

■ Velocity Summary ■ Sphering Report


nal tem-hase

la-s fortric

ratehe

te is For a

eviceeyion

flu-

inles, dis- all

ate a

ysisview

n

Flash Report A flash report is produced by default for each node in a compositiorun unless property tables are being used. This report contains theperature, pressure, composition, flowrate, and properties for each ppresent at each node.

Link Summary The link summary is produced by default for all PIPEPHASE simutions and shows the flowrates, pressure, temperature, and holdupeach link in a tabular format. The flowrates displayed are the volumerates at actual flowing conditions for each phase. A negative flowindicates that the fluid flow is opposite to the way it is drawn on tflowsheet.

Node Summary The node summary is produced by default and shows the flowrates, pres-sure, and temperature at each node in a tabular format. The flowrashown for each phase, but the flow basis depends on the fluid type.single-phase liquid or gas, standard volumetric rates are shown. For acompositional fluid, weight flowrates and gravity are also given.

DeviceSummary

The device summary is produced by default and summarizes each d(pipe, fitting, or item of process equipment) in the order in which thwere defined in the link. The table in the report shows the correlatused, inside diameter, length, elevation change, liquid holdup, and theoutlet temperature, pressure and liquid fraction. For compositional ids, a phase envelope and its data points are shown. The Taitel-DuklerFlow Regime map is produced for two-phase flow.

ResultsAccessSystem

The Results Access System (RAS) is a post-processing featurePIPEPHASE that allows you to configure and view text reports, taband plots of transient results data. RAS provides multiple formats toplay the data in an effort to satisfy the range of available software tousers.

To prepare data for RAS, your run must contain the command to credatabase in order to use the RAS. This command is found in the PrintOptions dialog box. The database is not required for Sensitivity Analand Gas Lift simulations as the RAS produces customized plots to these results.

To run the Results Access System:

➤ After the simulation has converged, click ithe Run Simulation and View Results dialog box.

➤ To activate this dialog box, select File/New to create a new RASdatabase.

➤ Select your file with extension .RAS.

Results Access System


lts

ithn. As

caseble,.

l

ta.

Figure 36 shows the PIPEPHASE RAS dialog box.

Figure 36:Results Access

System

From the General menu, your options are:

Output Format Changes—change the output units of measure of all resufor the current simulation.

Report Options—allows you to choose the plotter used to graph data.

Tables Tables display results numerically, in a sorted or grouped manner wappropriate headings. They are viewed in a spreadsheet applicatiominimum of one plot definition is required. PIPEPHASE RAS allowyou to plot inlet/outlet data or all segments data for either the base or the optimized case. The table is organized by device, link or variaas you desire. Table title is optional and will be defaulted if left blank

The options within the X-Variable list box are Total Length, HorizontaLength, Device Length, Pressure, and Temperature.

➤ To create a table, click for Table Options from theSIMSCI PIPEPHASE RAS dialog box (Figure 36). The RAS TableOptions dialog box appears.

➤ Define the table type and the data to be tabulated.

➤ Click to specify the table variables from selections in the RASTable Data Options dialog box.

Table data options depend on the simulation type and device link da

➤ Make your Device and Variable selections from the list boxes andclick when complete.

View/Edit...

Add

Add Selection


base

entf the

n mul-at the of

alare

Figure 37:Table Data Options

Dialog Box

➤ When you’ve added all your selections, click to return to theRAS Table Options dialog box.

➤ Click to display the table.

Figure 38 shows an example of a table created in RAS. Both the case and case study are shown for both devices in the link.

Figure 38:RAS Table

Plots PIPEPHASE allows you to view multiple user-selectable dependvariables on the same plot. You can analyze data along the length opipeline for the base case or any other case in the case study. Whetiple segments are defined, there is an option to plot the segments actual location along the pipe, or plot all points with a starting lengthzero. This option is recommended for comparing device data.

➤ To create a plot, click for Plot Options from the SIM-SCI PIPEPHASE RAS dialog box (Figure 36). The RAS Plot Optionsdialog box appears.

The options within the X-Variable list box are Total Length, HorizontLength, Device Length, Pressure, and Temperature. Plot labels optional and will be defaulted if left blank.

➤ Define the data to be plotted and enter label names.

Done

View

View/Edit...


type

d

he

ng a

otw-otmat, etc.,

➤ Click to specify the plot variables from selections in the RASPlot Data Options dialog box.

Note that this dialog box is essential identical to the Table Data Optionsdialog box (Figure 37). Plot data options depend on the simulation and device link data.

➤ Make your Device and Y-Variable selection from the list boxes anclick when complete.

➤ When you’ve added all your selections, click to return to tRAS Plot Options dialog box.

➤ Click to display the plot.

Figure 39 shows an example of a plot of the temperature profile aloheavy crude pipeline.

Figure 39:RAS Plot

Plot ViewerYou have a choice of viewing these plots in either the SIMSCI PlotViewer or Microsoft Excel 5.0/7.0 Plotter. Plotting graphs in the PlViewer is convenient in saving CPU time and conserving RAM. Hoever, you cannot edit the format or display of the graph in this PlViewer. If you want to edit the presentation of the graph, such as forthe axes labels, change the legend, or use different fonts for the titleyou should use Microsoft Excel.

Add

Add Selection

Done

View


es-ichsingle forme

on-cal theff-lky

oreepa-

outfore,

ugh

qua-n twormo-n inpipe

om-ed

ysric-

,

Fluid Flow Basics

When one encounters the complexity of multiphase fluid flow, the qution arises as to why it would not be simpler to design systems whseparated phases at or close to the source, thereby encouraging phase flow throughout the network. This would eliminate the needthe complex calculations that multiphase flow demands, saving tifrom both a design and maintenance perspective. So, why bother withmultiphase flow at all?

The answer lies in the practical and economical concerns in the cstruction of piping networks. Multiphase flow is especially economiin an offshore environment. Building large separation equipment atwellhead would be difficult and expensive, due to the high cost of oshore platform space. Another concern regards safety issues. Buequipment offshore introduces greater fire hazards and requires mmaintenance. Furthermore, it is easier to build and maintain a few srators in one site than to support a number of separators spreadacross a large field. The most practical and economical design, therewould be to take the multiphase fluid at the source, transport it thropipes to the onshore facility, and perform the separations onshore.

Single-Phase Flow

The theoretical basis for fluid flow equations is the general energy etion, which expresses the balance or conservation of energy betweepoints in a system. The energy equation can be modified, using thedynamic principles, to form a pressure gradient equation, as showequation (9). This equation describes the pressure variation in a inclined at some angle θ to the horizontal.

(9)

The elevation change component is applicable to compressible or incpressible, steady state or transient flow, in both vertical and inclinflow. It is zero for horizontal flow only. For downward flow, sin θ is neg-ative, and the pressure increases in the direction of the flow.

The friction loss term applies to any flow at any pipe angle. It alwacauses a pressure drop in the direction of the flow. In laminar flow, ftion losses are linearly proportional to fluid velocity. In turbulent flowthese losses are proportional to vn, where 1.7 ≤ n ≤ 2. The friction factor,

dPdL-------

dPdL-------

elevation

dPdL-------

friction

dPdL-------

acceleration

+ +=

dPdL-------

ggc-----ρ θsin

fρν2

2gcd-----------

ρνgc------

dνdL------+ +=


and

For ofity.

ticf the

ey-ces vis-flow andy ar-

ce of fela-

e toapo-

wo-ly isrs b

ionsject

f, in the frictional losses term, is a function of the Reynolds numberpipe roughness.

The acceleration term is zero for constant area, incompressible flow. any flow condition in which a velocity change occurs, as in the casecompressible flow, pressure drops in the direction of increasing veloc

FrictionFactor

The friction factor, f, is a ratio of the pipe wall shear stress to the kineenergy per unit volume. It is a function of the absolute roughness opipe divided by the inside diameter. It is also dependent upon the Rnolds number, which is the ratio of inertial forces to the viscous foracting on the fluid. When the Reynolds number is small (Re < 3000)cous forces are dominant, and the flow is said to be in the laminar region. Higher Reynolds numbers indicate dominant inertial forces,this region is called turbulent flow. Laminar flow is characterized bparabolic velocity profile, while a flat velocity profile is observed in tubulent flow.

(10)

Figure 40:Single-Phase Flow

Several correlations have been developed expressing the dependenupon the ε/d ratio and Reynolds number. One commonly used corrtion for the single phase friction factor is the Moody diagram.

MultiphaseFlow

In the past (and in some cases, even today), it was common practicuse the simplistic correlations used for single-phase flow, and to extrlate them to describe multiphase flow. If pure liquid flow had some givenflow characteristics, and pure gas flow had another, then logically, tphase flow should be a composite of these two flow regimes. Not onthis not the case, but the pressure drop between the two cases diffeat least one order of magnitude. As we shall see, the simple definitthat we have applied to parameters such as the friction factor, are subto more rigorous analysis in the case of multiphase flow.

f functionεd--- Re,

where Re = ρνd

µ----------,=

BUð,ð#

<Q]Y^Qbð6\_g<Q]Y^Qbð6\_g<Q]Y^Qbð6\_g<Q]Y^Qbð6\_g

@QbQR_\YSð@b_VY\U

BUð.ð#

DebRe\U^dð6\_gDebRe\U^dð6\_gDebRe\U^dð6\_gDebRe\U^dð6\_g

6\Qdð@b_VY\U

72 Fluid Flow Basics

fluid

is

otiesn cal-xingpre-ouldg to

ow,

flowtion

ent

or issinginingup or

inoulde).

Pressure Drop The pressure gradient function given in equation (9) applies for any in any steady state, one dimensional flow, in which friction (f), density(ρ), and velocity (v) can be defined. The definition of these variableswhat causes most of the difficulty in describing two-phase flow.

The calculation of pressure gradients requires values for certain flconditions, such as velocity and fluid properties. These fluid properinclude density, viscosity, and in some cases, surface tension. Wheculating these values for multiphase flow, one encounters certain mirules and definitions unique to this application. Before adapting the viously derived pressure gradient for multiphase conditions, one shdefine and analyze some of the more important properties pertaininmultiphase flow.

Equation (10) below is of an identical form as that for single phase flbut one should note that the subscript m (for multiphase) denotes thatthese parameters are not set values, but can be dependent on theconditions. In particular, they are dependent on the relative distribuof the gas and liquid phases.

(11)

Liquid Holdup Liquid holdup is defined as the ratio of the volume of a pipe segmoccupied by liquid to the volume of the pipe segment. That is,

(12)

where V = Vg + VL and A = Ag + AL.

The value of HL varies from zero, for single-phase gas flow, to one, fall liquid flow. The most common method of measuring liquid holdupdone by isolating a segment of a flow stream between two quick-clovalves, and then measuring the amount of liquid trapped. The remaspace is occupied by gas, and this space is referred to as gas holdgas void fraction. This is denoted by Hg and is related to HL by:

Hg = 1 - HL

No-Slip Liquid HoldupNo-slip liquid holdup is defined as the ratio of the volume of the liquida pipe segment divided by the volume of the pipe segment which wexist if the gas and liquid traveled at the same velocity (no-slippag

dPdL-------

dPdL-------

elevation

dPdL-------

friction

dPdL-------

acceleration

+ +=

dPdL-------

ggc-----ρm φsin

fmρmνm2

2gcd-------------------

ρmνm

gc-------------

dνm

dL---------+ +=

��LA

GAHL

volume of liquid in a pipe segmenvolume of pipe segment

----------------------------------------------------------------------------------AL

AL Ag+------------------= =


by

ly.

s an

hanes moreere-

rceard

e is

This ratio is calculated from the measured gas and liquid flowratesthe equation:

(13)

where qL and qg denote the in-situ liquid and gas flow rates, respective

Note that the liquid holdup HL is not equal to the no-slip liquid holdupHLNS.

To illustrate the difference between liquid holdup and no-slip liquidholdup, consider the example given in Figure 41. These two casesdescribe two-phase fluid flow along a pipe. The first case describeuphill flow, while the second case indicates downward flow.

Figure 41:Liquid Holdup

Dependency onElevation

In the case of uphill and horizontal flow, the gas flows more quickly tthe liquid. This is due to the greater influence of gravitational forcupon the liquid than the gas. Also, the less dense gas phase is muchbuoyant, or lighter, than the liquid, and flows upward more easily. Thfore, since Vg (velocity of gas) is greater than VL (velocity of the liquid),then from the previous equations describing HL and HLNS, we can seethat HL > HLNS. Mathematically,

(14)

In the case of downhill flow, gravitational forces exert a greater foupon the liquid than the gas, and therefore, the liquid is pulled downwat a greater velocity than the gas (due to greater liquid density). SincVL> Vg in this case, the same equation applies, but the inequality reversed:

HL ≤ HLNS

HLNS

qL

qL qg+-----------------=

��

f7f<

VL ≥ VG

HL ≤ HLNS

Uphill Downhill��

f<f7

VL < VG

HL > HLNS

HL

AL

AL Ag+------------------ HLNS

qL

qL qg+-----------------> >

ALVL

ALVL AgVg+( )-------------------------------------= =


a- flo the

se town in

xist-sems

eob- Theher

d.

ic

pecte inn,

HorizontalFlow Patterns

Whenever two fluids with different physical properties flow simultneously in a pipe, a wide range of possible flow regimes exists. Thepattern of a given system refers to the distribution of each phase inpipe relative to the other phase(s). Numerous studies have given ristandard names given to particular patterns, some of which are shoFigures 42 through 44.

Many pressure loss correlations rely heavily on a knowledge of the eing flow patterns in a given pipe. The description of these flow patternis what distinguishes the engineer’s approach to multiphase problfrom other perspectives. To clarify this point, examine the following:

■ From a mathematical perspective, the introduction of another phasin a fluid flow problem introduces three new equations into the prlem (mass balance, energy balance, and pressure gradient).interdependence of these equations along with those of the otphase brings much complexity to the problem.

■ From a design perspective, the new phase gives rise to another com-plication: flow patterns. From the acceptable flow patterns illustratein these figures, one has another parameter to define the system

■ From a physicist’s perspective, the second phase modifies the sonwave propagation of the system. Sound travels faster through a liq-uid medium than in a gaseous medium, and so one would exsound to travel in a two-phase medium at a speed somewherbetween the liquid and gas systems. Contrary to this expectatio

Figure 42:Segregated Flow

Figure 43:Distributed Flow

Figure 44:Intermittent Flow

GQfi

CdbQdYVYUT

=Ycd 2eRR\U

C\eW@\eW

1^ê\Qb


ase

dealy ofict,

n tom-ori-theuidu-

f three Thend isires inible

se the too

dif-

erfi-akenlina-eTheters,

ented

sound actually travels an order of magnitude slower in two-phsystems than in either liquid or gas mediums.

■ Finally, from an engineering perspective, the addition of an extraphase gives rise to flow patterns, of which the slug flow pattern,illustrated in Figure 44, is the most troublesome and complex to with. In single phase flow, the goal was to maximize the capacitthe flow system. In multiphase flow, the goal invariably is to predminimize or even eliminate slug flow.

The prediction of flow patterns for horizontal flow is more difficult thafor vertical flow. In horizontal flow, the phases tend to separate duedifferences in density, causing a form of stratified flow to be very comon. When a pipe is inclined at some angle other than vertical or hzontal, the flow patterns take other forms. For inclined upward flow, pattern is almost always slug or mist. The effect of gravity on the liqprecludes stratification. For inclined downward flow the pattern is usally stratified or annular.

Flow RegimeCorrelations

Recall that the general pressure gradient equation was composed oterms: an elevation term, a frictional term, and an acceleration term.elevation term depends on the density of the two-phase mixture ausually calculated using a liquid holdup value. The friction term requthe evaluation of a two-phase friction factor (recall Moody diagramsingle phase calculations). The acceleration term is usually negligunless dealing with cases of high flow velocities.

The correlations that have been developed for predicting two-phaflowing pressure gradients differ in the manner they use to calculatethree individual pressure gradient components. The correlations arenumerous to describe in detail, so it will suffice to point out the main ferences between the multiphase and single phase correlations.

Multiphase correlations are based on mixture velocities (sum of supcial velocities, rather than actual velocities). Flow patterns must be tinto account, and these are functions of the superficial velocities, inction angle, and fluid physical properties. Liquid holdup must also bknown to calculate the corresponding density and viscosity values. friction factor is dependent upon all these aforementioned parameand the choice of which correlation to use to evaluate f depends on thedemands of the simulation or calculation. These equations are presbelow:

Superficial Velocities ,

Liquid Holdup

vSL

qL

A-----= vSG

qG

A------=

ρm HLρL 1 HL–( )ρG+=

µm HLµL 1 HL–( )µG+=


dtern vichaneane

am-

0.55ap,

eslug

ones.all the

Mandhane Flow Regime MapThe relative distribution of gas and liquid in pipes is known as flow pat-tern or flow regime. In 1972, G. W. Govier and K. Aziz demonstratethat the importance of relative volumes of each phase on flow patsuggests that logical coordinates for a simple flow pattern map areSGand vSL, the superficial velocities (as opposed to earlier work, whused mass flux rates as coordinate axes). In 1974, J.M. Mandhextended the work of Govier and Aziz and constructed the MandhHorizontal Flow Pattern Map, which is shown in Figure 45.

Figure 45:Mandhane Flow

Regime Map

To illustrate the use of the Mandhane map, consider the following exple: given the following data for a wet gas pipeline, calculate the flowregime:

Gas flowrate = qg = 18.0 ft3/sec

Liquid flowrate = qL = 0.77 ft3/sec

Pipe diameter = 16.0 in. = 1.33 ft

Calculating the superficial velocities yields values of 12.9 ft/sec and ft/sec for the gas and the liquid, respectively. Using the Mandhane mwe see that this falls within the slug flow region. In fact, many of thproblems encountered in industry reveal pipelines that flow in the flow regime.

The work of Mandhane is restricted to horizontal pipes, but in commpractice, it is almost impossible to get a completely horizontal pipelinIn most, if not all, cases, slight inclinations will occur, and even smchanges in inclination angle (<1°) can cause dramatic changes inflow regime.

GQfi

C\eW=Ycd

2eRR\U

CdbQdYVYUT

!â â! â !

" â

â!

! â ! #

!â 1^ê\Qb

fC<

fC7


ne

rs for ished to

w

andichedw on

tivea-

Taitel-Dukler-Barnea Flow Regime MapIn 1976, Y. Taitel and A. Dukler extended the Mandhane study toaccount for variations in pipe inclination. The Taitel-Dukler Map is aexcellent model which gives a mechanistic analysis of flow regimboundaries for horizontal and near-horizontal flow. (Barnea lateextended this analysis to the range of inclination angles.) The basithis model is that the most common flow regime for horizontal flowstratified liquid. To consider other flow regimes, they examined tmechanism by which a change from stratified flow could be expecteoccur.

Figure 46:Taitel-Dukler Flow

Regime Map

Taitel and Dukler presented criteria for the following changes of floregimes:

■ Stratified to Intermittent

■ Stratified to Annular

■ Intermittent to Dispersed Bubble

■ Stratified Smooth to Stratified Wavy

■ Annular to Intermittent or Dispersed Bubble

They used this criteria to predict the flow regime for both horizontal near-horizontal flow. They did not state an inclination angle at whtheir flow regime boundaries are no longer valid. They superimpostheir criteria upon the existing Mandhane map to generate the floregime shown in Figure 46, which shows the effect of inclinationtransition boundaries.

The Taitel-Dukler results reaffirmed the observation that slight posiinclination angles promote slug formation and slight negative inclin

!â

â!

â !

! â

'%â

â! !â ! â ) â ! â

9^dUb]YddU^d

1^ê\Qb

CdbQdYVYUTGQfiCdbQdYVYUTð

C]__dX

2eRR\i

f C<ðèVdácUSç

fC7ðèVdácUSç


w as

diesof asiddict

nti-

mes

moveepipe

ghformble

-

tions promote stratification. Their studies revealed that angles as lo±1° cause significant changes.

Duns and Ros Flow Regime MapThe work of Duns and Ros is an example of the more rigorous stuinvolving vertical multiphase flow. They considered the contribution both slip and flow regimes, eliminating common simplifications suchthe no-slip condition. They developed correlations to predict liquholdup and friction factor, and they also developed methods to prewhich defined flow regime exists at a given point.

Figure 47:Duns and Ros Flow

Regime Map

The flow regimes are defined as functions of the dimensionless quaties Ngv (Gas Velocity number) and NLv (Liquid Velocity Number).These are shown in Figure 47 above. There are four main flow regiwhich may occur in a vertical pipe.

Region 1: Bubble Flow Region. The pipe is almost completely filled with liq-uid and the free gas phase is present in small bubbles. The bubblesat different velocities and except for density, have little effect on thpressure gradient. The liquid phase is always in contact with the wall.

Region 2: Slug Flow Region. The gas phase is more pronounced. Althouthe liquid phase is still continuous, the gas bubbles coalesce and plugs or slugs which almost fill the pipe cross section. The gas bubvelocity is greater than that of the liquid. The liquid in the film maymove downward at low velocities. Both the gas and the liquid have significant effects on the pressure gradient.

��

��

��

��

!

! ! ! ã!

!

! "

><F

2eRR\U6\_g

@\eW6\_g

C\eWð6\_gð

BUWY_^ð9BUWY_^ð9BUWY_^ð9BUWY_^ð9


6b_dXð6\_gð


DbQ^cYdY_^

DbQ^cYdY_^

DbQ^cYdY_^

DbQ^cYdY_^

=Ycdð6\_g

! ã! ! " ! #

>7F


theatedsure

nu- beough

ing

d aris-low.

tedle,ig-

wces

aylor

Region 3: Mist Flow Region. The gas phase is continuous and the bulk of liquid is entrained as droplets in the gas phase. The pipe wall is cowith a liquid film, but the gas phase predominantly controls the presgradient.

Transition Region. The change from a continuous liquid phase to a contious gas phase occurs. The gas bubbles may join and liquid mayentrained in the bubbles. The gas phase effects are predominant, thliquid effects are also significant.

Ansari Flow Pattern MapThe Ansari correlation is also available in PIPEPHASE for modelupward two-phase flow. In 1988, A.M. Ansari developed a comprehen-sive model composed of a sub-model for flow-pattern prediction anset of independent mechanistic models for predicting flow charactetics such as holdup and pressure drop in bubble, slug, and annular f

The first step in this analysis is the development or prediction of flopatterns. Based on the work of Barnea, Taitel, et.al., Ansari predicdifferent flow patterns by defining transition boundaries among bubbslug, and annular flows. This Ansari Flow Pattern Map is shown in Fure 48.

Figure 48:Ansari Flow Pattern

Map

Boundary A shows the transition from Bubble to Dispersed Bubble flowhich occurs at high liquid rates. In this transition, turbulent forbreak large gas bubbles down into small ones.

Boundary B shows the transition from Bubble to Slug flow, which ischaracterized by the coalescence of small gas bubbles into large Tbubbles.

! !

CeÙbVYSYQ\ð<YaeYTðFU\_SYdiðè]ácç

CeÙbVYSYQ\ð7QcðFU\_SYdi

13

2

44

2QbÛQDbQ^cYdY_^

2eRR\i

4YcÙbcUTð2eRR\U

C\eWð?bð3Xeb^ 1^ê\Qb

! ã! ! "

!

! ã!

!

! "


ch any

seg

king

ble,ot

rablyon-ulti-n fac-erde-w,ram-flow-tionuidnsed to

e.lid

emsw andaitel-n of

sesissuretionnt is

easesus-

Boundary C is the transition that occurs at high gas velocities, in whithe dispersed bubble flow is dominated by turbulence that preventsagglomeration.

Boundary D, the transition to annular flow, is based on the gas-phavelocity required to prevent the entrained liquid droplets from fallinback into the gas stream. Barnea modified this transition point by tainto account the effect of liquid film thickness.

The second step is the development of physical models for the flowbehavior in each flow pattern. This results in distinct models for bubslug, and annular flow. Due to the complexity of churn flow, it is nmodeled separately, but is treated as part of slug flow.

AddressingProblemsUnique to

MultiphaseFlow

The approach one takes towards a multiphase problem is considedifferent from that taken for a single-phase system. Although both ccern the solution or evaluation of the pressure drop equation, the mphase problem involves parameters that are not only dependent upotors absent in single-phase calculations (i.e. holdup), but are also intpendent with each other. Many correlations for multiphase flotherefore, demand a simultaneous or iterative solution for certain paeters. For instance, many equations used for predicting two-phase ing pressure losses can be solved explicitly for a two-phase fricfactor. However, the resulting equations are usually a function of liqholdup. Therefore, a valid comparison of friction factor correlatiowould rely on using data for which measured holdup data, as oppospredicted values, were available.

These correlations themselves are dependent upon the flow regimMany correlations for pressure drop and/or liquid holdup are only vafor specific regimes. Use of the Mandhane map for horizontal systprovides an accurate tool for “placing” a particular system in a floregime. However, the Mandhane map is restricted to horizontal flow,when inclinations are present, as they almost always are, then the TDukler-Barnea Flow regime map provides a more accurate descriptiothe system.

PhenomenaUnique to

MultiphaseFlow

Heading Phenomena in Vertical Upward FlowIn single-phase vertical upward flow, the pressure gradient increawith increasing flowrate, as expected. A different phenomena observed for two-phase flow. To understand this, recall that the presgradient expression has three components: an elevation term, a fricterm, and an acceleration term. At low flowrates, the pressure gradiedictated by the elevation term. In this region, the pressure drop decrwith increasing flow rate. The flow is unstable at this level, and in ind


g

ture

point-e gra-

iffer-is nollyn-

loc-wnd Liq-nyntlyng to

try, one may observe sporadic, irregular fluid flow (i.e., alternatinbetween no flow to sudden spurts of fluid flow).

Figure 49:Modeling Vertical

Upward Flow

When more gas is present, the elevation component is not as significanand the friction component begins to predominate. With lower pressdrops, the amount of gas in the pipe increases, and at a particular (indicated by the minimum of the U-shaped curve in Figure 49) frictional forces dominate, and one observes an increase in the pressurdient with increasing flow rate. This is the stable region of flow.

This phenomena is unique to two-phase flow because of the large dence between liquid and gas densities. In single-phase flow, there critical point at which the density of the system changes dramaticawith lower pressure or higher flowrate. Density remains roughly costant. When two-phases are present, however, one reaches a “critical”flowrate at which density, and consequently elevation, factors are over-ridden by frictional forces, giving rise to this phenomena.

Terrain-Induced SluggingThis phenomena is very common when liquid flows at a very slow veity in a downward direction, then has to climb after a certain point. Loliquid velocity makes it very difficult for the fluid to ascend the pipe, athus, liquid tends to settle down at the valley between the two pipes.uid builds up until the flow space is completely occupied, blocking agas from passing through. At this point, pressure builds up constauntil it is large enough to actually force the liquid to flow upwards alothe pipe. This type of flow falls in the slug flow regime, and gives risethe term, “terrain induced slugging.”

ðaèWQcç

∆@

E^cdQR\Uð6\_g

CdQR\Uð6\_g

Dg_ã@XQcUð6\_g

5\UfQdY_^ðT_]Y^QdUT

6bYSdY_^ð4_]Y^QdUT

∆@U\UfQdY_^

∆@VbYSdY_^

......

.....

..

..

..

. . .... .

....

....

.

..... ......... .

. .

... .... .. ....

...... . ..

...... ..................... ..

........ . .


lent

ever,giblee flow

s are

nttals.

andrties,ium,.

tings

heatr-

ient,er

nlcula-ed toature

-statepo-led

fu-

thehe

Small Pressure Recovery in Downward Stratified FlowsGravitational forces predominate downward stratified flows. In singliquid-phase downward flow, one measures a distinct pressure gradiebetween the inlet and outlet of a pipe. In the presence of gas, howthis pressure recovery decreases significantly, due to gravity’s neglieffect on the gas. Using gas phase models in these cases models thregime better, and in doing so, the calculated pressure recoveriemuch lower than those expected for liquid systems.

Flow PatternsAs demonstrated in the Taitel-Dukler-Barnea map, flow patterns arestrongly influenced by pipe inclination. This is especially significabecause one almost always has slight inclination in even horizonpipes. Angles of 1° can produce dramatic differences in flow regime

HeatTransfer

Calculations

PIPEPHASE performs an energy balance on pipes, risers, tubing,annuli. The heat transfer depends on the fluid temperature, propeand flowrate, the temperature and properties of the surrounding medand the heat transfer coefficient between the fluid and the mediumPIPEPHASE does not model heat transfer to the surroundings for fitand equipment devices.

For non-compositional gas or liquid fluid models, you can suppress transfer calculations for individual flow devices, by specifying isothemal calculations in the general gata list.

PIPEPHASE uses a default value for the overall heat transfer coefficU, of 1.0 BTU/hr-ft2°F. You can also specify different U values eithglobally or for individual components.

For a pipe or tubing, you can supply an overall coefficient or you carequest detailed heat transfer calculations. Detailed heat transfer cations are invoked when you input any one of the parameters requircarry out the calculations. You also supply data for ambient temperand geothermal gradient.

The resistance to heat transfer in wellbores consists of a steadycomponent (resistance from tubing to wellbore) and a transient comnent (resistance from wellbore to rock). The transient effect is modeby the Ramey FTD function, which is an analytical solution to the difsivity equation for a homogeneous medium.

For partially buried pipes, PIPEPHASE uses a modified form of Neher formulation to account for heat transfer in the buried part. TNeher formulation applies to totally buried pipes.


then

n andand thenvi-nd byaysP-iedov- loss.g itbi-arly

ousndions,

tureloss,e

/hr- tovid-

yer” sur-om-

PIPEPHASE uses the Churchill correlation to model heat transfer indifferent flow conditions in a pipe—laminar, turbulent, and the transitioregion between laminar and turbulent flow

For many pipelines, a balance must be reached between the retentioaddition of heat. Heavy crudes usually have such high viscosities sensitive temperature-viscosity functions that it is important to keepflowing temperature as high as possible. Waterflood lines in cold eronments must be kept above the freezing point. Liquid dropout ahydrate formation in gas and gas/condensate lines can be limitedmaintaining or increasing the flowing temperature. There are two wof doing this—insulate the line or install heaters along the line. PIPEHASE allows up to five layers of insulation for pipes, with user-specifor default conductivities. For onshore pipelines, burying the line or cering it with earth is sometimes an effective means of retarding heatFor offshore pipelines, burying the pipe prevents damage by protectinfrom anchors or offshore construction material. Generally, some comnation of heaters, insulation, and burial constitutes an optimum or neoptimum operation. Arctic environments usually disallow the burialoption because of damage to the permafrost layer.

If the compositional fluid model is used, PIPEPHASE performs rigorheat transfer calculations while taking into account compression aexpansion heating effects as well. In the case of downhole applicatyou can also input a temperature gradient.

TemperatureCalculations

Heat flow through pipes is characterized as:

(15)

(16)

PIPEPHASE calculates heat loss in pipes to determine the temperachanges. Equation 15 shows the basic function for calculating heat Q, over a segment of length L. Tf and TA are the temperatures of thfluid and ambient medium, respectively. The pipe diameter is given by d,and U represents the overall heat transfer coefficient.

For pipes in PIPEPHASE, the U-value defaults to a value of 1.0 BTUft2°F, unless you specify otherwise in the input. PIPEPHASE is ablerigorously calculate the U-value, and also allows you to override indiual heat transfer coefficients, if desired.

Figure 50 shows a cross-section of a pipe, including each “lathrough which heat must pass to be transferred from the fluid to theroundings, or vice-versa. These layers have an overall resistance cprised of the sum of the resistances of the individual layers.

Q uπd Tf TA–( )L=

U1

Resistances∑-----------------------------------=


rall

nal

talaturere-,loc- theat isence theasesbient

Figure 50:Insulation Layers

The U-value for a pipe is calculated from equation (16) above. Overesistance is given by:

Σ Resistances = Rinside, film, + Rpipe + Rinsulation + Rsurr + Rinside + Rout-

side + Rrad

The last three terms, additional resistance inside the pipe, additioresistance outside the pipe, and radiation, are optional entries.

LargeElevational

Changes

The phenomena previously described must be restricted to horizonflow. When you impose large elevation changes in pipes, the temperprofile of the fluid takes on a different form than those shown in the pceding graphs. When fluid flows downward, as shown in Figure 51heating effects occur due to the change in elevation (higher fluid veity, and therefore, higher kinetic energy). Due to this heating effect,fluid temperature actually approaches an asymptotic temperature thgreater than the ambient temperature. Note the pronounced differbetween this case and the Joule-Thomson effect. In horizontal flow,fluid temperature drops below the ambient temperature, but in the cof large elevation, the fluid temperature does not even reach the amvalue.

Figure 51:Large Elevational

Changes

@YÙðGQ\\

9^cYTUð6Y\]Cebb_e^TY^Wcð

èc_Y\äðQYbäð_bðgQdUbç9^ce\QdY_^

Resistance Due T

RInside, Film Boundary layer on the inside of the pipe

RPipe Material from which the pipe is made

RInsulation Insulation (up to five concentric layers)

RSurr Surroundings (soil, air, water)

RInside An additional fluid resistance inside the pipe (user-defined)

ROutside An additional ambient fluid resistance on the outside of the pipe (user-defined)

RRad Radiation

∆ z

φ

<<<<


om-tem-d bsi-

byeat-

ature

ropsrig-rong

ions

on,nges

es.thathaseper-

he fric- toosi-

PIPEPHASE performs more rigorous enthalpy calculations for the cpositional model (to satisfy the enthalpy balance), and the resulting perature profile for this case more accurately simulates that producea non-compositional model. A graphical comparison of the compotional and non-compositional model are shown in Figure 52.

Figure 52:Rigorous Heat

Transfer

Gas lines coming down mountains often exhibit the behavior shownthe compositional model in Figure 52. This model incorporates the hing effects due to the change in elevation. Note that the fluid temperdoes not drop to the level of the ambient temperature.

In the case of the non-compositional model, the fluid temperature ddown to the ambient value. This illustrates that by employing more orous heat transfer calculations, severe design errors, such as wpipeline sizing, can be avoided.

Effects ofTemperature

The importance of the effect of temperature on all system calculatcannot be overstated. Since temperature can have profound effects onfluid properties, phase split, pressure drop/holdup, hydrate formatiwax deposition, and flow pattern (among other parameters), any chain temperature need to be modeled as accurately as possible.

Of primary importance is the effect of temperature on fluid propertiThese properties influence most, if not all, of the major calculations PIPEPHASE performs. Since temperature affects the gas-liquid psplit, pressure drop and holdup calculations are very sensitive to temature gradients. This determines the flow regime (flow pattern) of tsystem, upon which the pressure drop calculations are based (i.e.,tion factor correlations). PIPEPHASE also has a built-in correlationdetermine the point and the type of hydrate formation with the comptional model.

>_^ã3_]`_cYdY_^Q\ð6\eYT

3_]`_cYdY_^Q\ð6\eYT

4YcdQ^SU

D1]RYU^dðDU]ÙbQdebU

:_e\UãDX_]`c_^ðS__\Y^W


ns:

o-

snds

ensur- onASE

mn

the

ces

pro-ureell-llySucht isumers-

ingints suf-ted

Applying PIPEPHASE to Downhole Operations

PIPEPHASE’s downhole capabilities include the following applicatio

■ Gas Lift Analysis

■ Electrical Submersible Pump (ESP)

■ Time Dependent Production Planning

Gas lift analysis is used to investigate the effects of lift gas on well prduction. Another common method of artificial lift is the electrical sub-mersible pump (ESP). These pumps improve the productivity of wellwith flow rates ranging from a few hundred barrels to tens of thousaof barrels per day.

Production planning involves the time-dependent interaction betwethe producing formation(s), and all of the wells, gathering lines, and face facilities in an oil or gas field, and the impact of this interactionthe overall development strategy of the operating company. PIPEPHsupplies this capability through its time-stepping feature.

Gas LiftAnalysis

Problem—The bottom hole pressure is too low to support the fluid coluin the well.

Remedy—Reduce the density of the fluid column by injecting gas into tubing.

Dilemma—Gas injection creates additional back pressure which reduproduction rate.

Reservoir pressure decreases gradually once a field is brought intoduction. Often there arise situations where the reservoir pressbecomes so low that it is insufficient for the well fluids to reach the whead. In these cases, the pressure in the tubing must be artificiaboosted, or lifted, to enable the reservoir fluids to reach the surface. procedures can be performed by using artificial lift methods. Gas lifone of the more common artificial lift methods used in the petroleindustry. Other methods include sucker rod pumping, electric submible pumps, and plunger/chamber lift, to name a few.

In gas lift, the object is to introduce gas near the bottom of the tubstring. This injected gas “lightens” the fluid between the injection poand the wellhead. Thus, the available bottom hole pressure becomeficient to lift this column of aerated fluid to the top. Gas can be injec


ft).nca-

owng.sual),

ween thethevalve gas open-ed topth.s isne-

continuously (continuous gas lift) or in spurts (intermittent gas liPIPEPHASE allows you to model a continuous gas lift analysis, iwhich you can specify the fluid properties of the gas, specify valve lotions, as well as other parameters.

Figure 53 shows a typical gas lift installation where gas is injected da packed annulus and oil and gas are produced through the tubinAlthough the reverse case is sometimes possible (though very unuit is not presently supported by PIPEPHASE.

Figure 53:Gas Lift

In this case, we assume that the static fluid level is somewhere betthe topmost valve and the wellhead. Once gas is injected throughannulus, the topmost valve is designed to open first. This “lightens” fluid above the topmost valve, causing a reduced pressure on the second from the top. The second valve then opens, injecting moreinto the tubing. This process repeats as more and more valves keeping. Once a lower valve opens, the upper valves are normally designclose. You will see that the gaslift effects generally increase with deOnly the bottom most valve allows gas passage into the tubing. Thicalled the operating valve. The valves above this one merely help ibringing the well into production (i.e. unloading the well). They artherefore called unloading valves. In steady-state operation, PIPEPHASE can calculate the depth of the operating valve.

Designing aGas LiftSystem

The main problems faced by the engineer in gaslift design include:

■ How much gas should be injected?

■ At what depth should gas be injected?

■ What is the casing head pressure limit?

@G8

9^ZUSdY_^ð4U`dXð

# ðVdâ

" ðVdâ

! ðVdâ

?ÙbQdY^Wð7Qcð<YVdðFQ\fU

E^\_QTY^Wð7Qcð<YVdðFQ\fUc

3QcY^Wð8UQTð@bUccð9^ZUSdY_^ðBQdUcðaY^Z

@38@

88 Applying PIPEPHASE to Downhole Operations

re-g one by

ys-ob-

fluid

asASEr the

illper-pth the is

■ What is the wellhead pressure required for target flowrate?

■ What is the depth of the operating valve?

There are four options in PIPEPHASE for gaslift analysis:

■ Generate the pressure profile for afixed oil production and lift gas rate.

■ Generate a table of oil production ver-sus lift gas rate for fixed pressures.

■ Locate the gas injection valve to matchrequired tubing head pressure.

■ Locate the gas injection valve to matchrequired casing head pressure.

This dialog box appears as part of the simulation definition, and thefore you must enter data into one of these options before continuinto the next dialog box. You can access these options again anytimselecting Special Features/Gas Lift... from the menu bar.

Gaslift analysis is limited to single link, black oil, continuous gaslift stems. You must follow certain basic rules when setting up gaslift prlems, such as:

1. PVT data sets must be available for both the produced reservoirand the injected gas.

2. The production string is automatically named PROD and the gasinjection string (annulus) is named GASL.

3. Gas injection rates are user-specified.

Option 1 Pressure ProfileIn Option 1, Pressure Profile, the casing-head pressure and the lift-ginjection rate are fixed. Given values for these parameters, PIPEPHcalculates the pressure profiles in both the annulus and the tubing focorresponding production rate.

When specifying a gaslift calculation with this option, PIPEPHASE wprompt you to enter values for the lift gas injection pressure and temature at the casing head, lift gas injection rate, and the vertical defrom the well head to the lift gas injection valve. You can also enterpercent of soluble lift gas which dissolves in the well fluid. This valuedefaulted to 100%, and generally should not change.


the

m-

bot-

re

ilures,ptionu

ume canluid

thelight-ever, highrate,

Figure 54:Option 1: Pressure

Profile

Since you know the injection rate along the well depth, obtaining annulus pressure profile is relatively simple. Pressure profile calcula-tions in the tubing are done as follows:

1. As oil rate is fixed (calculated from the injection rate), the bottohole flowing pressure is known, then

2. Use formation GOR to calculate the pressure gradient from the tomhole to the operating valve,

3. Use total GOR (formation = injection) to calculate the pressutraverse from the operating valve to the wellhead.

Option 2 Injection PerformanceIn Option 2, Injection Performance, PIPEPHASE generates a table of oproduction versus lift gas rate, given fixed values for wellhead pressvalve depth and the casing-head pressure. When selecting gaslift o2, PIPEPHASE will ask you to further specify the injection rates. Yocan specify up to nine lift gas injection rates in standard gas volunits, and all entries must be greater than zero. As in option 1, youalso enter a value for the percent solubility of the lift gas in the well f(generally 100%).

For each gas injection rate, there will be an oil flow rate that satisfiessystem constraints. At lower gas injection rates, increasing the rate ens the well fluid and therefore causes a production increase. Howat higher injection rates, the frictional losses in the tubing may be sothat this trend is reversed. There is, therefore, an optimal injection as shown in Figure 56.

6YhUTðBQdUð6_bðBUcUbf_Ybð6\eYT

6YhUTðBQdUðQ^Tð@bUccebUðV_bð<YVdð7Qc

6YhUTð7á<ðFQ\fUð4U`dX


esulthertiony the

es-pthses,heepthpec-ures.

Figure 55:Option 2: Injection

Performance

Figure 56:Example Gas

Injection Curve

Note that continuously increasing lift gas rate does not necessarily rin increased production rate. When frictional forces dominate, higinjection rates actually decrease production. The optimal gas injecrate and the corresponding oil production achievable are indicated barrows.

Option 3 Valve Location - Fixed Tubing Head Pressure (THP)When you select gaslift option 3, Valve Location - Fixed TH, PIPEP-HASE will prompt you to specify lift gas injection temperature and prsure at the casing head, injection rate, and up to eight vertical defrom well head to lift gas injection valves. From these specified valuPIPEPHASE will then locate the gas injection valve to match trequired tubing head pressure. Figure 57 shows a plot of injection dversus the production string outlet pressure, which you must also sify. Note that greater injection depths process higher wellhead press

6YhUTðGU\\XUQT@bUccebU

BQ^WUð_Vð6YhUTð<YVdð7QcðBQdUc

6YhUTð7á<ðFQ\fU4U`dX

<YVdð7QcðBQdU

@b_TeSdY_^ðBQdU


refor-l toionp too,ich

the

Figure 57:Option 3: Valve

Location -Fixed THP

Option 4 Valve Location - Fixed Casing Head Pressure (CHP)Option 4, Valve Location - Fixed CH, generates a casing head pressuversus gas injection depth curve. PIPEPHASE models valve permance by using the orifice gas pressure drop equation. Identicaoption 3, PIPEPHASE prompts you to enter values for lift gas injecttemperature and pressure at the casing head, injection rate, and ueight vertical depths from well head to lift gas injection valves. Alsyou can enter the percent solubility of the lift gas in the well fluid, whis generally 100%.

Figure 58:Option 4: Valve

Location -Fixed CHP

Gaslift option 4 allows you three additional entries:

1. Orifice inside diameters corresponding to the gas-lift injectionvalves.

2. Inside diameters of tubing above gaslift valves corresponding togas-lift injection valves.

3. Orifice coefficients corresponding to the gas-lift injection valves.

BQ^WUð_Vð6YhUTFQ\fUð4U`dXc

6YhUTðBQdUðQ^Tð@bUccebU6_bð<YVdð7Qcð

6YhUTðBUcUbf_Ybð@bUccebUäð@9äðQ^Tð6\_gbQdU

GU\\XUQTð@bUccebU

4U`dX

BQ^WUð_Vð6YhUTFQ\fUð4U`dXc

6_bð<YVdð7Qcð

6YhUTðBUcUbf_Ybð@bUccebUäð@9äðQ^Tð6\_gbQdU

6YhUTðBQdUðQ^Tð@bUccebU


s ofan-quentfor-

eP-

ElectricalSubmersiblePump (ESP)

Electrical Submersible Pumps(ESP’s) are applicable to a widerange of operating conditions: deepformations, high viscosity fluids,directionally-drilled wells, etc. Theprimary limiting factor in the effi-cient operation of an ESP is theamount of associated free gas pro-duced. Free gas (as opposed to gasin solution), which in limited quan-tities actually improves operation(by increasing overall fluid buoy-ancy), also progressively degradesperformance due to cavitation, ulti-mately creating a gas lock, at whichpoint the pump ceases operation. Tprevent such performance degrada-tion, free gas is frequently (par-tially) separated downhole, and re-introduced into the productionstream downstream of the chok(venting to the atmosphere not being permitted in most areas).

The ESP model in PIPEPHASE simulates a downhole pump in termits effects on the hydraulics of the well-bore. This includes logic to hdle specific features such as gas separation at the inlet (and subsere-injection at the surface), and the effect of viscosity on pump permance.

Clicking the ESP button in the Link Device Data window brings up theElectrical Submersible Pump dialog box, shown in Figure 59. This is thoriginal Pump dialog box with an additional button for the entry of ESspecific data.

Figure 59:Electrical

Submersible PumpDialog Box


andiately data, andfac-nce thewn-

andp OD

ch ofpower

telytime lifeectedThisHASEf the

cificmections of

rvoirn-

There are two categories of data entry under the Electrical SubmersiblePump dialog box. The first category is for data specific to the pump, the second for data specific to a downhole separator located immedupstream of the pump (to reduce the gas ingestion). Pump-specificinclude auxiliary power, submergence depth, casing head pressurethe vertical pressure gradient. A check box for the Riling correction tor is provided for viscosity-related corrections to the pump performacurves. The Head Degradation Curve (maximum of 5 points) allowsspecification of degradation as a function of gas fraction. When a dohole separator exists, you are prompted for the separator name,either the gas ingestion percent (GIP) rate for the pump, or the pumand casing ID, to calculate the GIP internally.

Under the Electrical Submersible Pump Curve dialog box, you have achoice of entering up to ten data points or the three constants in eathe quadratic equations representing the head, efficiency and horsein terms of the in situ volumetric flow rate.

Time-Stepping

ProductionPlanning

Although PIPEPHASE is a steady-state simulator, it can accuramodel well behavior over an extended period of time. Typically, the period of analysis extends from a few years to the entire producingof the field. For such periods, a quasi-steady-state approach is expto be an adequate representation of the time-dependent problem. approach can be achieved through successive steady-state PIPEPsimulations, each representing a time-step in the operating history ofield.

The main components of the time-stepping analysis are:

■ Well Grouping

■ Reservoir Depletion

■ Facilities Planning

Well Grouping Each of the well completion zones in a gathering network from a speformation or reservoir. The decline in the reservoir pressure with tiand the changes in the characteristics of the fluid produced are a funof the total fluid volume produced form the reservoir. For the purposethese claculations, a well completion is associated with a resegroup. A reservoir group includes all of the producing zones that cotribute to its depletion.


y aacity

hesester

eatureple-me.and the

des

e in

ified

oralues the

ReservoirDepletion

The depletion of a reservoir over the life of a field is represented bdecline in average reservoir pressure that affects the production capof the associated wells. Additionally, with time, the composition of tproduct fluid changes. For most reservoirs, the gas-oil ratio increawith time; for a reservoir with an active water drive, the produced wacut increases as the water table creeps up. The reservoir depletion fwill predict the average decline in reservoir pressure for all the comtions in the reservoir as a function of the cumulative produced voluIn addition, at the end of every time step, it will update the water cut GOR in each associated completion zone as simplified functions ofcumulative production rate (or reservoir pressure).

Figure 60:Reservoir Pressure

Over Time

In PIPEPHASE, the user-specified data for reservoir depletion incluthe initial cumulative production rate (Qcum) and the basis for Qcum cal-culations. The default value for initial Qcum is zero (virgin field) and thedefault calculation basis is oil (or gas for a gas field).

At every time step, PIPEPHASE calculates Qcum by adding productionfrom all the grouped wells. PIPEPHASE also calculates the changthe average pressure, ∆Pr, average, for the reservoir. It is important to notethat the initial value of the reservoir is taken to be the value you specin the Source dialog box. Subsequent values of Pr are calculated from∆Pr, average. This is a different case from the time-step calculations ffluid characteristics, water cut and GOR. In these cases, the initial vare taken from the initial IPR curves rather than those specified inSource dialog box.

@b

ASe]


e the

uponssure

oe.e forep-ve.than

R)en-urve

WellDepletion

Production RateThe reservoir pressure declines by an amount calculated from thgrouped wells. This affects the IPR equation or the tabular data forIPR, since the reservoir pressure, Pr, is the common variable in most IPRequations. Figure 61 illustrates the dependence of production rate wellhead pressure and reservoir pressure. As the reservoir predeclines, so does cumulative production.

Figure 61:Wellhead Pressure as

a Function ofProduction Rate

Fluid CharacteristicsFor an active water drive reservoir, the water cut, fw, will increase signif-icantly with increasing production. The data for the fw decline curve canbe input in the IPR Decline Data dialog box. However, you must alsspecify an initial value for fw in the input dialog box for the Source nodTherefore, an ambiguity may exist between the IPR calculated valuinitial f w and that entered into the source data. To resolve any discrancy, PIPEPHASE will use the value calculated from the IPR curThis data is well specific, and therefore, gives a more reliable value that input into the source node, which may be an average value.

Figure 62:Water Cut and GOR

as a Function ofProduction Rate

Similarly, for a Solution Gas Drive Reservoir, the Gas:Oil Ratio (GOvaries with increasing production. To properly model this time-depdent variation, PIPEPHASE uses the values from the IPR decline c

@gVègU\\XUQTð`bUccebUç

A_

@b

Vg_b7?B

ASe]

Vg

7?B


itial

cify case toer

ysi-

otfore,F),

d byeliv-is

(if you have supplied these). Otherwise, PIPEPHASE uses the inGOR value you’ve specified in the Source node.

In cases of enhanced oil recovery, PIPEPHASE allows you to speadditional parameters to more accurately model the system. In theof pressure maintenance in an oil field, an additional well is usedinject fluid (for example, water), into the reservoir to prevent or hindthe decline of reservoir pressure. The cumulative production thenbecomes a function of the amount of fluid being injected and the phcal properties of that fluid.

(17)

injection well production well

If water is injected into an oil reservoir, a given volume of water will nhave the same pressure as an equivalent volume of oil. TherePIPEPHASE allows you to enter a Formation Volume Factor (FVwhich takes into account the fluid properties. The FVF is representeB in the equation above. PIPEPHASE also allows you to specify a derability basis for the calculations. The default basis is oil, and this indicated by the Bo in the denominator within the summation above.

Qcum Qcum initial,Bw

Bo------

Qi∆t Qi∆t

i 1=

N

∑+

i 1=

N

∑–=


thesys-

vity

intm

the

ureink

Executing a Sensitivity (or Nodal) Analysis

Sensitivity or Nodal analysis allows you to graphically represent flow and pressure behavior of wells, pipelines and other single link tems when input parameter(s) are varied over a range of values. The sin-gle link option must be chosen to activate nodal analysis/sensitianalysis.

Dividing theLink

The link is divided into two sections at any point on the link. This pois called the Solution Node which you can specify. The section upstreaof the solution node is called the Inflow Section. The section downstreamof the solution node is called the Outflow Section. Figure 63 shows thesolution node at the wellhead. The well is in the inflow section and surface flow line is in the outflow section.

Figure 63:Dividing the Link

Concept

The Inflow Performance curve is the plot of the solution node pressPSN as the flow rate is varied in the Outflow section keeping the spressure constant. Note that PSN increases with flow rate.

Figure 64:Performance Curves

AAAA@!

GU\\

C_\edY_^ð>_TU

6\_gð<YÛ

@"

A

@c^

@"ð6YhUT hh

hh

h

@c^

A

@!ð6YhUThh

hh

h

98 Executing a Sensitivity (or Nodal) Analysis

des the

ndolu-

ane. Af anr out-er-

ion for

Forsia is P

(Pry

ingm to

For the given link with a fixed source and sink pressure the solution nopressure calculated in the inflow section must have the same value asolution node pressure from the outflow section.

Figure 65:Inflow and Outflow

Definitions

Graphically this is represented by the intersection of the the Inflow aOutflow performance curves. The intersection point represents the stion node pressure and the flow rate that you will get for the link.

Figure 66:Inflow and Outflow

Performance Curves

A family of Inflow curves can be generated for a range of values ofInflow parameter. In this case, the parameter is the source pressurfamily of Outflow curves can be generated for a range of values oOutflow parameter. In this case, the chosen parameter is the sink olet pressure. When the families of Inflow and Outflow Curves are ovlaid on the same plot we get the plot shown in Figure 67.

When a pair of inflow and outflow curves intersect each intersectpoint represents the operating flow rate and solution node pressurethe link for the values of the parameters each curve represents.example, Q1 is the flow rate in the link if the source pressure is 600 pand the sink pressure is 100 psia. The pressure at the solution node1.

The nodal analysis plot concisely represents the system behavior SNand Q) of the link when the Inflow and Outflow (plot) parameters vaover a range of values. This information would be useful for predictsystem behavior or in making decisions on how to control the systeobtain the desired behavior.

A

@9@5ðí" @"

@9@5ðí!

@!

@>

9^V\_g

>_TU?edV\_g

A

@C>h

hhhh

hh

hh @"ð6YhUT

?ÙbQdY^Wð@_Y^dð_VðdXUð"ð@YÙðCicdU]

@!ð6YhUT


eachaland

to 5sec- theay be

eterslled angetersmpound

ies.ame then be

Figure 67:Demonstrating the

Relevance ofIntersections of

Performance Curves

Terminology Sensitivity ParametersWhen generating a nodal plot you have to select one parameter forfamily of Inflow and Outflow curves ( Sensitivity parameter). Typicchoices of a parameter could be the reservoir pressure for Inflow flow line ID for Outflow.

You can select up to 5 values for each parameter. This implies up Inflow and 5 Outflow curves may be generated. Up to 5*5 = 25 intertion points may be obtained. The chosen parameters must be frombase case input data. To generate the curves, up to 10 flowrates mspecified.

Compound ParameterTypically, we choose one parameter. In PIPEPHASE, several paramcan be compounded into one parameter. Such a parameter is cacompound paramete. A compound parameter may be the ID of a tubiand its corresponding roughness. It may be a combination of paramfrom different devices. For example, one set of values of the pupower, pipe ID and heater duty can be compounded as one compparameter value.

In PIPEPHASE the available parameters are divided into 7 categorCompounding can be done only with parameters belonging to the scategory. The only exception to this is the source data category andIPR data which belongs to the structure data category. IPR data cacompounded with source data.

AAAA

@@@@C>C>C>C>

@_edð-ð! â ð`cYQ @_edð-ð" â ð`cYQ@_edð-ð! â ð`cYQ

@Y^ð-ð$ @Y^ð-ð% @Y^ð-ð&


ofers

istheOut-

aty bem-ou

Out-nd

delue

Out-rame- oftion

ame-

thaties 6 acts

Single LinkCalculations

A solution node can be specified by one of 3 ways:

■ Specify the device name. The solution node will be placed at the inlet the device. If it is the first device in the link, the source parametwill belong to the Inflow section.

■ Specify the Source name. The solution node will be at the source. In thcase no Inflow section (and data) can exist. Similarly, specify Sink name. The solution node will be at the sink. In this case no flow section (and data) can exist.

■ Specify Bottom or Sink. In this case the solution node will be located the outlet of the last device in the link. The Sink parameters main the Outflow section. Note that when you select the Inflow paraeters the parameter must belong to the Inflow section. When yselect the Outflow parameters the parameter must belong to theflow section. It is a common mistake to mix up the flow section athe choice of parameter.

The structure data input requirements include:

■ The source and sink pressures must be specified.

■ The source flow rate must be estimated.

Additional plots generated in PIPEPHASE include the solution notemperature as a function of flow rate for each Inflow parameter vaand the sink temperature for each Outflow parameter.

To generate a nodal analysis plot you must select an Inflow and an flow parameter and the range of values you want to use for each pater. All the parameters are divided into 7 categories. Compoundingparameters is allowed within each data category only with the excepof source/sink parameters and corresponding new IPR Device parters. These two sets of parameters may be compounded even though thebelong to different categories.

Category 4 above refers to the non-compositional source propertiescan be defined for Sensitivity Analysis. The Lateral Source (categorand 7) refers to a subsidiary feed, such as an injection device, whichas an additional source to the Main source.


NodalAnalysis

Output

Nodal Analysis output consists of the following:

■ The Nodal Pressure plot—displays the solution node pressure versusflow rate curve for each value of the sensitivity Infl ow and Outflowparameter. The plot data is included.

■ The Nodal Temperature plot—displays the solution node temperature ver-sus flow rate curve for each Inflow parameter value and the sinktemperature versus flow rate for each Outflow parameter value. Theplot data is included.

■ If completions exist in the simulation, a family of completion pres-sure drop versus flow rate is plotted for each Inflow parameter if thecompletion is in the Inflow section or Outflow parameter if the com-pletion occurs in the Outflow section. The plot data is included.

■ The intersection points are reported in the output report.

Figure 68 shows a typical nodal pressure plot. The Inflow parameter issource pressure and the Outflow parameter is pipe ID Increasing sourcepressure increases flow rate and increasing pipe ID increases flow rate.

Table 11: Available ParametersCategor Device Available Parameters

Source Pres, PI, Vogel, Coeff, Exp

Sink Pres, II, Coeff, Exp

Structure Completion Shots, Perforation Diameter, Penetration Depth, Tunnel

Pipe ID, Rough, U, Floweff

Tubing ID, Rough, U, Floweff

Riser ID, Rough, U, Floweff

Annulus ID, Annulus, OD Tube, Rough, U, Floweff

Choke ID, Coeff

Compressor Stages, Power, Pres, Eff

Pump Stages, Power, Pres, Eff

Heater Duty, Tout, DP

Cooler Duty, Tout, DP

Separator Percent, Rate

Injection Temp, Pres

Sales Rate

Glvalve Rate, Dissolve

IPR RVAL

PVT GOR, WCUT, CGR, WGR, Quality

Main Source Compositional Composition

Lateral Source Compositional Composition

Lateral Source Rate, Temp, Pres


mbi-

om-

ple andthercon-

e

ionrob-n.

quip-each of to of

eralThisich.

The nodal plot helps to decide what source pressure and pipe ID conations would be feasible for a desired throughput.

Figure 68:Nodal Pressure Plot

FeaturesUnique to the

PIPEPHASE

PIPEPHASE offers many nodal analysis technical features not cmonly found in standard nodal analysis packages. The compositionalcapability with the extensive SIMSCI component library is one examof these features. This allows rigorous simulation of phase behaviorheat transfer that is not possible with black oil type approaches. Ofluids that can be used include steam, black oil, liquid, gas and gas densate models.

PIPEPHASE solves the total energy balance equations. This enables thcalculation of both pressure and temperature profiles in the link. Also,you have the option of conveniently defining the location of the solutnode. The best choice of the solution node location changes from plem to problem and where field data may be available for compariso

As you have seen earlier, you can use all standard PIPEPHASE ement devices in the sensitivity analysis. A number of parameters for device are available for you to vary, in order to fully study the effectsspecific parameters on the overall system performance. In additiondevices which affect pressure drop, PIPEPHASE allows the studytemperature change devices (heater/cooler capacity).

The option of combining, or compounding, parameters together is apractical feature which can save considerable simulation time. Sevsensitivity variables can change in unison like a single parameter. feature also allows you to organize the sensitivity analysis more, whis especially useful when working with a large number of parameters

@bUccebUðèRQbç

6\_gðBQdUðè]#áXbç

#â%ðY â̂ðTYQ

$ðY â̂ðTYQ

#( ðRQb

#$ ðRQb

#" ðRQb


nye

isut a

E-rs, effi-

PIPEPHASE Sensitivity Analysis is structured such that virtually aoilfield production/injection problem or any pipeline problem can banalyzed. The fluid composition itself can be changed. You can performa gaslift analysis using the black oil model using the gaslift analysoption. But the Sensitivity Analysis feature also allows you to carry ocompositional gaslift analysis by using the Injection device.

Finally, the nodal analysis can be done in conjunction with PIPPHASE’s Case Study option. This allows you to vary other parameteindependent of the nodal analysis parameters. This enables you tociently generate an unlimited number of plots in one simulation run.


Index

A

Algorithm, solution 56

Annulus 43

Ansari flow regime map 80Antoine viscosity data 24

Applicationsfield wide simulation 15single pipe analysis 10wellbore analysis 12

Artificial liftapplications 12gas lift method 14

Assay data 20

B

Blackoil modelfluid type 19PVT data 24

Bottomhole completions 46

Bottomhole pressurecalculating 11

C

Calculation methodsalgorithm 56convergence 59forward traverse 55line sizing 57mass balance method 54pressure balance method 54, 59rules 54segments 55tolerances 58

Calculator 40

Case studychange types 50change variable names 49cumulative changes 50entering data 49functionality 49global changes 50individual changes 50

limitations 49parameter 50running a 52variables 50

Change types 50

Change variable names 49

Check valve 47Choke 48

Color cues 8

Component lumping 62Components

defining 19entering data 38generating from assay data 20library 20lightends data 21petroleum 20

Compositional fluid modeloptions 19phase type 21source 37thermodynamic data 28transport methods 29

Compound parameter 100Compressor 47

Contaminants 24, 25

Convergence, ways to obtain 59Correlations

flow 31flow regime 76fluid properties 18mixing 25oil, water 27pressure loss 75viscosity 25

Cumulative changes, case study 50

D

Data entry windows 7

DefaultsSee Global defaults

Device summary 67Distributed flow 75

Downhole operations

electrical submersible pump 93gas lift analysis 87time-stepping analysis 94

Downward stratified flow 83

DP-DT device 48

Duns and Ros flow regime map 79

E

Edit menu 8

Electrical submersible pump (ESP)applications 93curve data 94data requirements 93

Elevational changeseffect on temperature 85

F

Fetkovich’s gas flow equation 45Field wide simulation

applications 15reservoir decline 16

File menu 5

Flash report 67Flow correlation defaults 31

Flow efficiency parameter 32

Flow patternshorizontal 75vertical 79

Flow regime correlations 76

Flow regime mapsAnsari 80Duns and Ros 79Mandhane 77Taitel-Dukler-Barnea 78

Flowsheetediting 8junction 38links 41network types 33sink 39source 36terminology 33viewing 8


Fluid characteristics, reservoir 96Fluid models

blackoil 19compositional 19gas condensate 19non-compositional 18single-phase gas 19single-phase liquid 19steam model 19

Forsheimer equation 45

Forward traverse calculation method 55

Friction factor 72

G

Gas condensate modelfluid type 19PVT data 25

Gas lift analysisdesigning in PIPEPHASE 88injection performance 90modeling 14modeling options 89optimum gas injection rate 15PIPEPHASE options 14pressure profile 89simulation type 17typical installation 88valve device 48valve location - fixed CHP 92valve location - fixed THP 91

Gas modelfluid type 19PVT data 25

Global changes, case study 50

Global defaultsflow correlations 31flow efficiency parameter 32HW coefficient 32inside diameter 32Palmer corrections 31thermal 32transitional Reynolds number 32

H

Heat transfer calculations 11, 15defaults 32effects of temperature 86insulation layers 84large elevational changes 85methods 55

overall U-value 41, 83performing 83pipe 42temperature 84

Heated oil pipelines 12

Heater/cooler 47

Helpdocuments 3online 3technical support 3

Holdup, liquid 73Horizontal flow patterns

distributed flow 75intermittent flow 75segregated flow 75

HW coefficient 32

Hydrates 40

I

Individual changes, case study 50Inflow Performance Relationship (IPR)

Fetkovich’s gas flow equation 45modeling 43Productivity Index (PI) model 43solution gas-drive reservoir 45

Injection device 47

Injection performance, option 2 90

Input units of measureSee Units of measure

Inside diameter defaults 32

Insulation 84

Interactive output 64Interactive run capabilities 61

Interconnected wells 16

Intermittent flow 75

J

Jones gravel-packed completion 46Junction

data requirements 38inactivating 36

K

Keyword input filecreating 62data entry order 53importing 5

reprint in output file 66running 62

L

Laminar flow 72

Library components 20Lightends 21

Line sizingentering data 9maximum velocity 57options 57running 62

Linkannulus 43bottomhole completions 46check valve 47choke 48compressor 47definition 41dividing the 98DP-DT 48gas lift valve 48heater/cooler 47injection device 47IPR 43multi-stage compressor 47pipe 42pumps 47regulator 48riser 42separator 47summary 67tubing 43

Link Device Data windowfeatures 9opening 9

Liquid holdupdefining 73no-slip 73

Liquid modelfluid type 19PVT data 26

Looped networks 34

M

Main windowcolor cues 8components 6data entry windows 7menu bar 6

106 Index

opening Link Device Data window 9toolbar 7workspace 5

Mandhane flow regime map 77

Maps, flow regimeAnsari 80Duns and Ros 79Mandhane 77Taitel-Dukler-Barnea 78

Mass balance method 54

McLeod open-perforated completion 46Menu

edit 8file 5view 8

Menu bar 6

Multiphase flowdownward stratified flow 83horizontal flow patterns 75liquid holdup 73modeling 72pressure drop 73problems unique to 81sphering (pigging) 58terrain-induced slugging 82vertical flow patterns 79vertical upward flow 81

Multi-stage compressor 47

N

NETOPT 1Network model 17

Networkslooped 34running 62tree 33types 33

New file 5Nodal analysis

application 98calculations 101compound parameter 100dividing the link 98entering data 9features unique to PIPEPHASE 103inflow/outflow curves 98output 102running 62sensitivity parameters 100terminology 100wellbore applications 12

Node summary 67Non-compositional fluid models

define 18source requirements 37

No-slip liquid holdup 73

O

Online help 3

Optimization 1

Optimum gas injection rate 15Output

link profiles 64nodal analysis 102node and link labels 64node simulation results 64

Output format changes 68

Output reportsections 66See Also Reportunits of measure 23

Overall heat transfer coefficient 41, 83

P

Palmer corrections 31Parameters

case study 50compound 100sensitivity 100

Performance curves 98

Petroleum components 20Phase envelope 10

Phase type 21

Pipelines, heated 12PIPEPHASE

applications 10components 2GUI 2launching 5main window 5NETOPT add-on 1simulating networks in 17TACITE add-on 2technology 1window components 6

Pipes 42

Plot viewer 70

Plotscreating in RAS 69

inflow/outflow parameters 102link profiles 64nodal temperature 102pressure vs. distance 65print options 64production vs. gas injection rate 15RAS example 70

Pressure balance method 54, 59

Pressure drop function 73

Pressure loss correlations 75

Pressure profile, option 1 89Print options 64

Production rate 96

Pumps 47PVT data

blackoil model 24condensate gas 25gas fluids 25liquid model 26steam model 27

PVT table generation 17

Q

Quality 37

R

Reference source 36

Regulator 48

Reportdevice summary 67flash 67link summary 67options 68summary 67

Reservoir decline option 16

Reservoir depletion 95

Reservoir performance curve 13Reservoir pressure 96

Reservoir, solution gas-drive 45

Resultslink profiles 64nodal analysis 102node 64

Results Access System (RAS)output format 68plot viewer 70plots 69report options 68


running 67tables 68

Retrograde condensation 10

Reynolds numberlaminar and turbulent flow 72transitional 32

Risers 42Run options

interactively 61run other 63run remote 63

S

Save 5Segments, calculation 55

Segregated flow 75

Sensitivity analysisSee Nodal analysis

Sensitivity parameters 100

Separator 47

Simulationchanging the UOM 22copying and deleting 5creating a new 5defining 17editing 8printing 5running 5saving a 5viewing 8

Simulation typegas lift analysis 17network 17PVT table generation 17

Single pipe analysiscapacity calculations 10heated oil pipelines 12phase envelope 10steam injection networks 11

Single-phase flowacceleration term 72elevation change 71friction loss 71modeling 71

Single-phase gas model 19Single-phase liquid model 19

Sinkinactivating 36requirements 39

Slugging, terrain-induced 82

Solution algorithm 56Source

compositional fluid 37data requirements 36entering component data 38estimated values 36fixed values 36inactivating 36non-compositional 37reference 36temperature requirement 37, 38

Spheringmodeling 57

Start PIPEPHASE 5

Steam injection networks 11Steam model

fluid type 19PVT data 27

T

Tablescreating 68example 69

TACITE 2component lumpring 62entering transient data 9running 62

Taitel-Dukler-Barnea map 78

Technical referenceflow regime correlations 76friction factor 72horizontal flow patterns 75multiphase flow 72multiphase phenomena 81single-phase flow 71vertical flow patterns 79

Technical support 3

Temperature calculations 84

Terrain-induced slugging 82Thermal defaults 32

Thermodynamic datahandling water 29method applications 29options 28pre-defined methods 28transport methods 29

Time-stepping analysiscomponents 94reservoir depletion 95well depletion 96well grouping 94

Tolerances 58Toolbar 7

Transitional Reynolds number 32

Transport methods 29Tree networks 33

Tubing 43

Turbulent flow 72

U

Units of measureoutput 23pre-defined sets 22standard sets 23

UNIX, running PIPEPHASE on 63

V

Valve locationfixed CHP, option 4 92fixed THP, option 3 91

Variables, case studydevice 51pipe 51source and sink 50

Vertical flow patterns 79

Vertical upward flow 81

View menu 8Viscosity correlations 25

W

Water cut 96Water, thermo for handling 29

Well depletionfluid characteristics 96production rate 96

Wellbore analysisgraphical solution 13heat transfer calculations 15nodal analysis 12overview 12varying pipe sizes 13varying well-head pressure 13

Wellsgrouping 94horizontal 46interconnected 16

Workbook conventions 4

108 Index

Contents

Black Oil Pipeline. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1

Black Oil Flowline with Devices . . . . . . . . . . . . . . . . . . . . 6

Compositional Pipeline. . . . . . . . . . . . . . . . . . . . . . . . . . . 11

Gas Well . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18

Case Study of Black Oil Pipeline . . . . . . . . . . . . . . . . . . . 22

Heavy Crude Pipeline . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27

Pipeline Sphering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33

Looped Black Oil Network. . . . . . . . . . . . . . . . . . . . . . . . 37

Black Oil Gathering System . . . . . . . . . . . . . . . . . . . . . . . 40

Two Well Gas Lift Analysis . . . . . . . . . . . . . . . . . . . . . . . 44

Steam Injection Well. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 49

Forecasting Well Production . . . . . . . . . . . . . . . . . . . . . . . 55

Three-Year Decline Model . . . . . . . . . . . . . . . . . . . . . . . . 59

Ridge Pipeline. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66

Appendix - Keyword Input Files . . . . . . . . . . . . . . . . . . . 73

All diameters in the example problems are in actual mea-surement unless otherwise stated.

Introduction to PIPEPHASE i

Black Oil Pipeline

#### TASK Black oil flows through a pipeline with an inner diameter of 10 inchesand a pipe roughness of 0.002 inches. The pipeline drops 1,000 feet overits 20,000 foot length. The fluid properties at the source are listed inTable 1.

Figure 1:Black Oil Pipeline

Part A Create a new simulation BLKOIL. The SOURCE pressure is 1000 psig andthe SINK pressure is 500 psig. Use 100000 bbl/day as the initial flowrateestimate for both the source and the sink.

For these conditions, what is the oil flowrate?

What is the water flowrate?

Part B In a second run, keep the source pressure at 1000 psig, but use a fixedflowrate of 100,000 bbl/day of oil. As for initial sink estimates, use100,000 bbl/day for flowrate and 500 psig for pressure. Note that forblackoil problems, the source flowrate is based on the oil flowrate, notthe total flowrate.

What will the sink pressure be?

2\QS[ð?Y\2\QS[ð?Y\2\QS[ð?Y\2\QS[ð?Y\

! ðVd! ðVd! ðVd! ðVd

" ä ðVd

" ä ðVd

" ä ðVd

" ä ðVd

Table 1: Source Fluid PropertiesProperty Value

Oil, API 30

Gas, specific gravity 0.75

Water, specific gravity 1.05

Temperature 120°F

Gas/Oil ratio 200 ft3/bbl

Water Cut 10%


or

-

r by

e

by

the.

n

@@@@ SOLUTION

Part A Begin by launching PIPEPHASE (double-click the PIPEPHASE iconselect PIPEPHASE from the SIMSCI folder on the Start menu).

Step 1 Create a New Simulation

➤ Select New from the File menu or click the New button on the toolbar. The New File dialog box appears.

➤ Name the simulation BLKOIL and click to save your data.

Step 2 Enter Simulation DescriptionThe Simulation Description dialog box appears.

➤ Enter the Problem, Site, and User information along with the prob-lem description in this dialog box.

These entries are optional and you can access this dialog box lateselecting Simulation Description from the General menu.

➤ Click to save your data and exit this dialog box.

Step 3 Enter the Simulation Definition and Input DimensionsThe Simulation Definition dialog box appears. Network Model is thdefault Simulation Type and Blackoil is the default Fluid Type, which areappropriate for this problem. Later, you can access this dialog box selecting Simulation Definition from the General menu.

➤ Click to accept the default definitions.

The Input Dimensions dialog box appears, showing Petroleum as default dimension set. These defaults are acceptable for this problem

➤ Click to accept the default dimensions.

You can access this dialog box later by selecting Input Units of Measurfrom the General menu, or by clicking the Input Dimensions button othe toolbar.

Step 4 Enter PVT DataThe Fluid Property Data dialog box appears.

➤ Click to enter the Blackoil fluid properties in the BlackoilPVT Data dialog box.

➤ Fill in the Oil API Gravit , and the Gas and Water specific sravitydata.

OK

OK

OK

OK

New...

2 Black Oil Pipeline

et.

en

re indi-

and,the

-

al-

ink

➤ Click to save entries. Click again to exit to the flowshe

You can make edits to the PVT data at any time by selecting PVT Datafrom the General menu or by clicking the PVT button on the toolbar.

Step 5 Build the Flowsheet

➤ Build the flowsheet by clicking the source toolbar button and thclicking again to position the unit on the flowsheet.

➤ Do the same for the sink unit.

➤ Select the source unit by clicking on the icon once. A red squaappears on the node and the border of the node turns green tocate that the node has been selected.

➤ Connect the source and sink units by clicking inside this square while holding the mouse button down, drag the cursor towards sink and release.

Step 6 Enter Unit Data

Source Data

➤ Double-click the SOURCE unit on the flowsheet to open the Black OilSource dialog box.

➤ Fill in the Pressure, Temperature, GOR, and Water Cut data fromTable 1.

➤ Enter an initial estimate for the oil flowrate. By default, the OilFlowrate Estimated radio button is activated, indicating that PIPEPHASE will calculate this flowrate.

➤ Click to save the data and close the dialog box.

Sink Data

➤ Double-click on the SINK unit to open the Sink dialog box.

➤ Enter the SINK pressure data. Again, by default the flowrate Esti-mated radio button is activated, indicating that PIPEPHASE will cculate this flowrate.

➤ Enter an initial estimate for the oil flowrate at the SINK.

Step 7 Enter Link Data

➤ Double-click on the LINK between the two units to open up the LinkDevice Data window.

➤ Click on the PIPE button in the device palette to add a pipe to the land to open the Pipe dialog box for that pipe.

OK OK

OK


-

nesn thet- fornoted

ar.

te is

t file

thatou-

e).

➤ Enter the Length, Elevation Change, Inside Diameter, and PipeRoughness data from Table 1.

➤ When complete, click to save the entries and return to the LinkDevice Data window.

➤ Click to save the LINK device data and return to the main flowsheet.

Step 8 Run the Simulation and View the ResultsWhen data entry is complete, the borders of all the icons and link lion the flowsheet turn blue. The outlines of the entered device icons iLink Device Data window turn blue as well. Any selected item is oulined in green rather than blue. To determine if the data is completethat item, click on an empty region of the flowsheet. If the data is complete, the outline will turn red instead of blue. If any item is outlinin red, double-click on it to enter the remaining data.

➤ Select Run from the File menu or click the Run button on the toolbThe Run Simulation and View Results dialog box appears.

➤ Click to solve the network.

➤ To check your results, select Output File from the Report drop-downlist in the View Reports section of the dialog box and click .

From the Node Summary, you can see that the standard oil flowra107,571 bbl/day and the standard water flowrate is 11,952 bbl/day.

To return to the flowsheet, close the editor. To access the outpuagain, select View Output File from the File menu or click the View Out-put File button on the toolbar.

➤ To view the node output on the flowsheet, select View Output fromthe View menu, and double-click on a unit.

The temperature, pressure, and total liquid flowrate (oil + water) for node in Blackoil type simulations is displayed. For example, if you dble-click on the SINK, the dialog box shown in Figure 2 appears.

, Note: Elevation Change is positive for uphill flow and negative fordownhill flow.

OK

OK

Run

View

, Note: Your results may vary slightly due to the initial estimates andthe specified convergence tolerances (± 2 psi for the pressur

4 Black Oil Pipeline

elect

lect

:

e

ecalcu-

Figure 2:Sink Summary on

Flowsheet

To view Pressure vs. Distance or Temperature vs. Distance plots, sDevice Detail as Part, and Plots as Part under Print Options from theGeneral menu before running the simulation. After convergence seView Output from the View menu or double-click on the LINK . Choosethe plot by clicking on one of the buttons in the Link Plot Selection dia-log box that appears.

Part B Under the File menu, choose Save As and save this problem as BLKOILB.To find the SINK pressure with a fixed SOURCE oil flowrate of 100,000bbl/day and a 1,000 psig SOURCE pressure, perform the following tasks

➤ Select the View Output option from the View menu to return to theedit input mode.

➤ Double-click on the SOURCE, activate the Fixed radio button for thoil flowrate, and enter a value of 100,000 bbl/day.

➤ Double-click on the SINK, activate the Estimated radio button for thpressure, and enter a value of 500 psig, so that the pressure is lated by PIPEPHASE.

➤ Rerun the simulation and view your results.

From the Node Summary, you will find that the SINK pressure is nowcalculated to be 678 psig.


ith 8e-

l

Black Oil Flowline with Devices

#### TASK The flowrate through an oil well is controlled using a choke at the well-head. For a 1 inch diameter choke, the desired wellhead pressure is 200psig. Because the reservoir is unconsolidated sandstone, a gravel-packedcompletion has been used.

Figure 3:Oil Well

The upper portion of the tubing string is 2.441 inches in diameter. Thelower portion is 1.995 inches in diameter. The reservoir pressure is 3,000psig and the reservoir temperature is 190°F. The temperature gradient inthe earth at this location is 2°F/100 feet. Assume an average overall heattransfer coefficient (U) of 10.0 Btu/hr-ft2-°F.

The gravel-packed completion has a perforated zone 30 feet long, wshots/foot. The expected size of the perforations is 0.39 inches in diamter and 3 inches deep. Table 2 gives the properties of the reservoir fluid.

Part A Create a new simulation named OILFLW. Use 500 bbl/day as the initiaflowrate estimate for both the source and the sink.

For these conditions, what is the oil flowrate?

#% ðVd#% ðVd#% ðVd#% ðVd#" ðVd#" ðVd#" ðVd#" ðVd

## ðVd## ðVd## ðVd## ðVd

$% ðVd$% ðVd$% ðVd$% ðVd

Table 2: Reservoir Fluid PropertiesProperty Value

Oil, API 35



Gas/Oil ratio 300 ft3/bbl

Water Cut 20%

6 Black Oil Flowline with Devices

tral into iseterease

w-

e

ro-

Part B A pipeline is proposed to transport the oil from the wellhead to a censtorage tank. First, all of the gas phase is separated for re-injectionthe reservoir to maintain the pressure. A pump (efficiency = 85%)used to raise the fluid pressure to 700 psig. The 2.441 inch diampipeline to the storage tank is 15,000 feet long with an elevation incrof 200 feet.

Figure 4:Transportation

Pipeline

As for initial sink estimates, use the value calculated in Part A for florate and supply 200 psig for the sink pressure.

How much gas is being removed at the wellhead?

What is the required horsepower of the pump?

What will the sink pressure be?

@@@@ SOLUTION

Part A Create a new simulation by selecting New from the File menu and namethe simulation OILFLW.

Step 1 Enter Simulation Description

➤ Enter a description in the Simulation Description dialog box.

Step 2 Define the Simulation and Input DimensionsIn the Simulation Definition dialog box, keep Network Model as thSimulation Type and Blackoil as the Fluid Type.

In the Input Dimensions dialog box, keep the units of measure as Petleum.

Step 3 Enter PVT DataThe Fluid Property Data dialog box appears next.

➤ Click New to open the Blackoil PVT Data dialog box.

➤ Supply the Oil API Gravit , and the Gas and Water specific gravitydata and click .

!%ä ðVd!%ä ðVd!%ä ðVd!%ä ðVd

6b_]6b_]6b_]6b_]GU\\XUQTGU\\XUQTGU\\XUQTGU\\XUQT

" ðVd" ðVd" ðVd" ðVd" ð`cYW" ð`cYW" ð`cYW" ð`cYW

OK


th a

-

te

-

esacerst.

e


➤ Add a source and a sink to the flowsheet. Connect the two wilink.


Source Data

➤ Double-click on the SOURCE unit on the flowsheet to open up theBlack Oil Source dialog box.

➤ Using the data provided in Table 2, fill in the fields for source Pres-sure, Temperature, GOR, and Water Cut.

By default, the Oil Flowrate Estimated radio button is activated, indicating that PIPEPHASE will calculate this flowrate.

➤ Provide an initial estimate for the oil flowrate at the SOURCE.

Sink Data

➤ Double-click on the SINK icon to open up the Sink dialog box.

➤ Enter the SINK pressure. Again, by default the flowrate Estimatedradio button is activated indicating that PIPEPHASE will calculathe flowrate.

➤ Enter an initial estimate for the oil flowrate. By default, the OilFlowrate Estimated radio button is activated, indicating that PIPEPHASE will calculate this flowrate.


➤ Double-click on the LINK to open up the Link Device Data window.

➤ Click on the GRAVEL PACKED COMPLETION button. The GravelPacked Completion dialog box appears.

➤ Enter the Perforation Interval, Shot Density, Tunnel Length, and Per-foration Diameter data.

For a LINK with multiple sections, the order in which you list the devicis critical. You must enter the section of tubing farthest from the surffirst. In this case, the bottom section of the tubing string is entered fi

, Note: No information is given to relate the reservoir conditions to thflowing conditions. If a Productivity Index (PI) or any otherInflow Performance Relationship, IPR, information was given,then P and T at the SOURCE would be the reservoir P and T.With no IPR data, they are the flowing bottomhole pressureand temperature.


,500

dient

eth is

-

esble-d link

r.

-

➤ Click on the TUBING button. The Tubing dialog box appears.

➤ Enter the Measured Wireline Depth, True Vertical Depth, and InsideDiameter data into the appropriate fields.

For the lower section, the measured wireline depth is 8,000 feet (= 4+ 3,500); and the true vertical depth is 6,500 feet (= 3,200 + 3,300).

➤ Change the Heat Transfer Method from Default to U-Value. Enterthe average overall heat transfer coefficient and temperature gradata.

➤ To enter the upper section of the tubing string, click the TUBING but-ton again. Another Tubing dialog box for the second TUBING devicein the link appears.

➤ Enter the Measured Wireline Depth, True Vertical Depth, and InsideDiameter data of the TUBING section next to the source. This timthe measured wireline depth is 3,500 ft, and the true vertical dep3,200 ft. Make the necessary changes to the Thermal CalculationsArea.

➤ Add a choke device by clicking the CHOKE button and enter theChoke Diameter.

➤ Click to save the LINK device data and return to the main flowsheet.

Step 7 Run the Simulation and View the ResultsWhen the data is complete, the outlines of all the icons and link linturn blue on the flowsheet. If there is an item with a red outline, douclick on it to enter the remaining data. Remember selected icons anlines are green so you must click away from the flowsheet to see its truestatus.

➤ Select Run from the File menu or click the Run button on the toolbaThe Run Simulation and View Results dialog box appears.


➤ To check your results, select Output File from the Report drop-downlist in the View Reports section of the dialog box and click .

, Note: Remember that the Measured Wireline Depth of tubing is thetotal length starting from the surface to the bottom of that tubing string, and the True Vertical Depth is the depth from thesurface to the bottom of that tubing string.

OK

Run

View


te isstan-

t file

r

. gas.

From the Node Summary, you can see that the standard oil flowra2,471 bbl/day, the standard water flowrate is 618 bbl/day, and the dard gas flowrate is 0.7412 MM ft3/day.

To return to the flowsheet, close the editor. To access the outpuagain, select View Output File from the File menu or click the View Out-put File button on the toolbar.

Save your simulation before starting Part B.

Part B Under the File menu, choose Save As and save this problem as OILFLWB.To find the SINK pressure for a fixed SOURCE oil flowrate of 2,471 bbl/day, perform the following tasks:

➤ In the Black Oil Source dialog box, click the Fixed radio button forthe oil flowrate and enter a value 2,471.

➤ In the Sink dialog box, click the Estimated radio button for the SINK

pressure. Enter an initial estimate for the oil flowrate.

➤ In the Link Device Data window, click once on the CHOKE device sothat the additional devices are added after it. Add the SEPARATOR,PUMP, and PIPE devices to the LINK and input the supplied data foeach.

➤ Change the Device Detail to Part or Full in the Print Options dialogbox, accessed by selecting Print Options from the General menu.

➤ Rerun the program and view your results.

From the Node Summary, you can see that the SINK pressure is 163 psigFrom the Link Device Detail Report, you can see that the amount ofremoved is 0.670 MM ft3/day and the required pump power is 32.2 hp


r and

Compositional Pipeline

#### TASK A 24-inch diameter pipeline transports crude oil 200 kilometers, over anelevation increase of 400 meters. The desired sink pressure is 10 bathe ambient temperature is 20°C.

Figure 5:Crude Oil Pipeline

Use 500,000 kg/hr as the initial flowrate estimate for both the source andthe sink.

Part A Use metric dimensions for everything except the fine length, which is ininches. Set the Print Options for link plots to Full. Table 3 gives the com-position and conditions of the source fluid. Table 4 gives data for thehigher-boiling components.

3beTUð?Y\3beTUð?Y\3beTUð?Y\3beTUð?Y\

$ ð]$ ð]$ ð]$ ð]

" ð[]" ð[]" ð[]" ð[]

Table 3: Source Composition and ConditionsComponent Mole % Component Mole %

H2S 5.4 NC5 2.9

C1 2.0 NC6 4.1

C2 14.3 C78 8.5

C3 16.3 C910 4.0

IC4 2.9 C11+ 20.0

NC4 8.6 C20+ 7.9

IC5 3.1

Pressure 74 bar

Temperature 74°C

Table 4: Petroleum Component PropertiesPetroleum Component

Molecular Weight

Density (kg/m3)

Boiling Point (°C)

C78 109 748

C910 137 795

C11+ 207 944

C20+ 354 1036 547


tion

e

is

What is the flowrate?

Do the fluid conditions cross the phase envelope?

Does the fluid temperature drop below the ambient?

How much time did the calculations take?

Part B Generate a PVT table for the flash calculations and run the simulaagain.

What is the gas gravity?

What is the oil gravity?

What is the oil flowrate?

What is the gas/oil flowrate ratio?


Part C Convert the simulation to a black oil fluid and run it again.

What is the oil flowrate?


@@@@ SOLUTION Create a new simulation by selecting New from the File menu and namethe simulation CPIPE.

Part A

Step 1 Define the Simulation and Input Dimensions

➤ In the Simulation Definition dialog box, keep Network Model as thSimulation Type.

➤ Select Compositional as the Fluid Type.

➤ In the Input Dimensions dialog box, select Metric from the Systemdrop-down list.

➤ Change the Fine Length units to inches, since the tubing diametergiven in inches.

➤ Change the Default Basis to Weight.

12 Compositional Pipeline

e

he

um

th a

d

e

Step 2 Enter Component Data

➤ In the Component Data dialog box, click in the LibraryComponents area to bring up the Library Component Data dialogbox.

Under the Component Family List, Standard Production Set is thdefault. The components from H2S to NC6 are listed in the SpecificComponents Available for Selection section.

➤ Select the library components listed in Table 3, and then click t to place them in the Add these Library Compo-

nents to the Component List box. Alternatively, you can double-clickon the components to add them into this list immediately.

➤ Clicking saves this list and returns you to the Component Datadialog box.

➤ Click in the Petroleum Fractions area, enter the petrolecomponents listed in Table 4, and click to save the entries.

You can access the Component Data dialog box later by clicking on theComponent Data button on the toolbar




Source Data

➤ Double-click on the SOURCE unit and enter the temperature anpressure. Provide an estimate for flowrate.

➤ Click in the Composition field and enter thecomposition of the previously selected components. Choose Savefrom the Worksheet menu.

Sink Data

➤ Double-click on the SINK and enter a Fixed value for the SINK pres-sure. The Estimated radio button for the flowrate is selected bydefault.

➤ Enter an initial estimate for the oil flowrate at the SINK.

, Note: If you change the basis after you enter the flowrate data, thflowrate value is not converted to the corresponding value inthe new units, only the units are changed.

Add...

Add Components

OK

Add... OK

Define Composition


es

,910

w-

evel-

ck-

Step 5 Enter Link DataDouble-click on the LINK to open up the Link Device Data window.

➤ Click on the PIPE button and enter the Length, Elevation Change,and Inside Diameter data.

➤ Select the U-Value method from the Heat Transfer drop-down listand enter the Ambient Temperature in the activated field. This over-ides the global default.

Step 6 Run the Simulation and View the ResultsWhen the data is complete, the outlines of all the icons and link linturn blue. A red outline indicates incomplete data entry.

➤ Select Run from the File menu or click the Run button. The Run Sim-ulation and View Results dialog box appears.


➤ To check your results, select Output File from the Report drop-downlist and click .

From the Node Summary, you can see that the total flowrate is 1,180kg/hr.

➤ To view the NODE results and the LINK plots, select View Outputfrom the View menu.

➤ Double-click on a NODE to see its pressure, temperature, and florate.

➤ Double-click on the LINK to bring up the Link Plot Selection dialogbox and click .

The temperature plot in Figure 6 shows that the fluid temperature neverdrops below the ambient temperature. Since the gas phase is just doping, the Joule-Thompson effect is weak.

, Tip: Make sure to select Full for Device Detail, Plots and RASDatabase options (select Print Options under the Generalmenu) so that you can generate a Phase Envelope plot by cliing in the Results Access System (RAS). Special Plots...

Run

View

Temperature vs. Distance


S).

ct to

Figure 6:Temperature vs.

Distance Plot

➤ Click within the Run Simulation andView Results dialog box to access the Results Access System (RA

➤ To activate the PIPEPHASE RAS dialog box, select File/New to cre-ate a new RAS database. Select CPIPE.ras (Figure 7).

Figure 7:PIPEPHASE RAS

Dialog Box

➤ Click .

➤ Check the Phase Envelope box and click to display thephase envelope (Figure 8).

This also shows the fluid state through the pipe's length with respethe phase envelope.

Run Results Access System

Special Plots...

View Plot


king

.

resnd 5-

bout

er-

Figure 8:Phase Envelope

Save your simulation before starting Part B.

Part B Generate a PVT table to speed up the flash calculations. Before maany changes, save the file as CPIPEB. Make the following changes:

➤ Select the PVT Data from the General menu or click the PVT Databutton on the toolbar.

➤ Click and check the box next to Click the button to enter the data.

➤ Enter the Source Name and a range of pressures and temperatuthat spans the expected range. A reasonable range is 5-75°C a75 bar with 10 degree and 10 bar increments respectively.

➤ Run the simulation.

Runs using the PVT table to interpolate the physical properties are a5-6 times faster than using the flash calculations.

From the Node Summary section of the output report, the fluid propties to simulate a black oil are:

Gas specific gravity = 1.47

Oil specific gravity = 0.88

Gas/Oil Flowrate Ratio = 97 m3/ m3

Oil Flowrate = 1083 m3/hr

Edit... Generate PVT Table...


si-e the

-

yy of

nal

rop-

forosi-

Part C Convert the simulation to a blackoil fluid to see how this non-compotional approach affects the results. Before making any changes, savfile by selecting Save As from the File menu. Name the new simulationCPIPEC. Make the following changes:

➤ Change the simulation type to Blackoil by selecting Simulation Defi-nition from the General menu.

➤ Change the Gas Densit, Oil Density, and Water Density units to spe-cific gravity (sp gr) by selecting Input Units of Measure from theGeneral menu or by clicking the Input Dimensions toolbar button.

➤ Select PVT Data from the General menu, or click the PVT Data button on the toolbar. Click in the Fluid Property Data dialogbox. In the Blackoil PVT Data dialog box, enter the specific gravitof the gas and oil calculated in Part B, and set the specific gravitwater to “1”.

➤ Double-click on the SOURCE, enter the Gas/Oil Ratio calculated inPart B, and select the Property Set number as “1” from the drop-down list. Enter “0” for the water cut.

➤ Rerun the program, and compare the results of the compositioand the non-compositional solutions.

You will find that the black oil flowrate is now 620 m3/hr, significantlylower than the compositional oil flowrate of 1,083 m3/hr. This change iscaused by the different representations used for the fluid physical perties.

The non-compositional run took 3 seconds, compared to 4 secondsthe PVT table calculation/interpolation, and 15 seconds for the comptional flash. These values will vary depending upon CPU speed.

, Note: Use PVT table generation when no SEPARATOR or INJECTION

(from a SEPARATOR) devices exist in the LINK or when allSOURCEs have the same composition. The composition of thefluid must remain the same throughout the system.

New...


n

r

run

Gas Well

#### TASK A gas well is drilled in two stages: vertically for 1,067 meters, and theat an angle for 935 meters (another 610 meters deep).

Figure 9:Gas Well

The tubing string is 2.441 inches in diameter. Use metric dimensions foeverything except the fine length. Table 5 gives the composition andsource conditions of the inlet gas.

Provide initial sink estimates: pressure= 50 bar, flowrate= 100,000 kg/hr.

Part A What is the pressure drop to the surface?

What is the specific gravity of the gas?

Part B Convert the simulation to a non-compositional single-phase gas andit again.

What is the pressure drop to the surface now?

What is the actual flowrate at the source?

! &'ð]! &'ð]! &'ð]! &'ð]

)#%ð])#%ð])#%ð])#%ð]

&! ð]&! ð]&! ð]&! ð]

Table 5: Source Composition and ConditionsComponent Mole %

Methane 80%

Ethane 15%

Propane 5%

Pressure 74 bar

Temperature 74°C

Flowrate 0.01 MM m3/hr (STP)

18 Gas Well

e

lt

nent

e

@@@@ SOLUTION Create a new problem by selecting New from the File menu. Name thesimulation GWELL.

Part A

Step 1 Define the Simulation and Input Dimensions

➤ In the Simulation Definition dialog box, keep Network Model as thSimulation Type and choose Compositional as the Fluid Type.

➤ In the Input Dimensions dialog box, select Metric from the Systemdrop-down list.

➤ Change the Default Basis from Moles to Gas Volume.

➤ Change the Fine Length units to inches, since the TUBING diameteris given in inches.

Note the warning that SINK flowrates must be specified in Weight unitsfor compositional fluids.

Step 2 Enter Component Data

➤ In the Component Data dialog box, click in the LibraryComponents field to open the Library Component Data dialog box.

Under the Component Family List, Standard Production Set is the defauand the components of this set are listed in the Specific ComponentsAvailable for Selection section.

➤ Highlight components C1, C2, and C3 and click to add them to the Component List.

You can access the library components again by clicking the CompoSelection button.


➤ Add a source and a sink to the flowsheet and connect.


Source Data

➤ Double-click on the SOURCE and enter the Temperature and Pressuredata. When entering the flowrate, first select the Fixed radio button.

, Note: If you change the basis after you enter the flowrate data, thflowrate value is not converted to the corresponding value inthe new units, only the units are changed.

Add...

Add Components


-

l

es

rs (=10).

eline

g

➤ Click and enter the composition for the previously selected components from Table 5. Select Save from theWorksheet menu when complete.

Sink Data

➤ Double-click on the SINK to enter the Sink dialog box.

➤ Check the Estimated button for the pressure and provide an initiaestimate. By default, the Estimated button for the flowrate is acti-vated, indicating that PIPEPHASE will calculate this value.

➤ Supply an initial estimate for the gas flowrate.


➤ Double-click on the LINK to open up the Link Device Data window.

For a LINK with multiple devices, the order in which you list the devicis critical. You must enter the section of tubing next to the SOURCE first.In this case, the deviated section of the tubing string is entered first.

➤ Click on the TUBING button and enter the Measured Wireline Depth,True Vertical Depth, and Inside Diameter data.

For the deviated section, the measured wireline depth is 2,002 mete1,067 + 935); and the true vertical depth is 1,677 meters (= 1,067 + 6

➤ To enter the vertical section of the tubing string, click the TUBING

button again and enter the data for this segment (measured wirdepth is 1,067 m; true vertical depth is also 1,067 m).

Define Composition...

, Note: Because no Inflow Performance Relationship, IPR, informationis given to relate the reservoir conditions to the flowing condi-tions, the SOURCE P and T are the flowing bottomhole pressureand temperature. If an IPR was given, the SOURCE P and Twould be the reservoir P and T.

, Note: Remember that the Measured Wireline Depth of tubing is thetotal length starting from the well head, and the True VerticalDepth is the depth from the well head to the start of that tubinsection.

20 Gas Well

.

bar

e

,

it

-

nal

nal

ow

ck-

Step 6 Run the Simulation and View the Results



➤ To check your results, select Output File from the Report drop-downlist in the View Reports section of the dialog box and click

The Link Summary shows the pressure drop to the surface is 54.9and the actual flowrate at the SOURCE is 0.000148 MM m3/hr. The spe-cific gravity of the gas is found in the Node Summary section of threport. You should get a value of 0.68.

➤ To view the NODE results and the LINK plots, select View Outputfrom the View menu and double-click on a NODE to see its PressureTemperature, and Flowrate.

Part B Convert the problem to a non-compositional single-phase gas, runagain and note how this affects the results. Before making any changes,save the file by selecting Save As from the File menu. Name the nesimulation GWELLB. If necessary, select View Output from the Viewmenu to return to edit input mode. Make the following changes:

➤ Change the simulation type to Gas by selecting Simulation Defini-tion from the General menu.

➤ Change the gas density units to specific gravity by selecting InputUnits of Measurement from the General menu or by clicking theInput Dimensions button on the toolbar.

➤ Select PVT Data from the General menu, or click the PVT Data button on the toolbar. Click in the Fluid Property Data dialogbox and enter the specific gravity of the gas from the compositiorun. Double-click on the SOURCE and set the PVT Property Set num-ber to "1".

➤ Rerun the simulation and compare the results of the compositioand the non-compositional solutions.

From the Link Summary, you should find that the pressure drop is n60.1 bar. The actual flowrate at the source is 0.000146 MM m3/hr.

, Tip: Make sure to select Full for Device Detail, Plots and RASDatabase options (select Print Options under the Generalmenu) so that you can generate a Phase Envelope plot by cliing in the Results Access System (RAS). Special Plots...

Run

View

New...


,

ram-

Case Study of Black Oil Pipeline

#### TASK Starting with the Black Oil Pipeline simulation, Part B as the Base Caserun six cases to study the effects of the following parameters on the pres-sure drop:

■ Inside diameter

■ Elevation change

■ Pipe roughness

■ Heat transfer coeff icient

■ Flowrate at source

■ Pressure drop correlation

Use the Restore Base Case option in each case to set the changed paeters back to the original values.

Provide initial estimates for the sink: Pressure = 500 psig, Flowrate =100,000 bbl/day.

Fill in Table 6 and answer the following questions. In the original BlackOil Pipeline problem, Part B, the pressure drop was 323 psig.

Which three parameters have the largest effect on the pressure drop?

Which two parameters have the smallest effect on the pressure drop?

Table 6: Case Study DataCase Study Parameter From Value To Value Pressure Drop

Source-SinkDifference From Base Case

Inside diameter 10 11

Elevation change -1,000 -1,100

Pipe roughness 0.002 0.0022

Heat transfer coefficient 1 1.1

Total rate at source (oil basis) 100,000 110,000

Pressure drop correlation BBM DE

22 Case Study of Black Oil Pipeline

pres-

es

@@@@ SOLUTION

Step 1 Copy a Simulation and Open

➤ Select Copy Simulation from the File menu and copy the simulationBLKOILB to BLKOILCS.

➤ Select Open from the File menu and choose BLKOILCS file. This isthe Base Case.

Step 2 Enter Case Study Information

➤ Select Case Study from the Special Features menu to open the CaseStudy dialog box.

➤ Click the check box for Perform Case Study Calculations to activatethis option.

Case One

➤ Click in the Case Study dialog box to open the Case StudyChanges dialog box.

➤ Provide a description different from CASE STUDY 01 to differentiatebetween cases (optional).

➤ Click to open up the Define Case Study Parameter dialogbox.

Because you are studying the effects of the six parameters on the sure drop, you must enter each change under a new case.

➤ For the first case, select the link L001 from the Link Name list.

You can select Pipe from the Device Type drop-down list to limit theDevice Name list on the following line to include the Pipe device namonly.

➤ From the drop-down lists, select the Device Name, Parameter, andsupply a value for the Inside Diameter in the data field labeled To:

● Link Name L001

● Device Type Pipe

● Device Name E001

● Parameter Inside Diameter

● To (the new ID value) 11

The completed dialog box for case one is shown below in Figure 10.

Add...

Add...


re- to

Figure 10:Case Study

Parameters for Case 1

➤ Click to save the Define Case Study Parameter dialog box toreturn to the Case Study Changes dialog box.

Figure 11:Case Study Changes

for Case 1

➤ Click to return to Case Study dialog box.

The Case Study Changes and the Define Case Study Parameter dialogboxes can be reopened by clicking .

Case Two

➤ Click to enter the second case.

➤ Check Restore Base Case to reset the parameters changed in the pvious case back to the original values (i.e., the pipe ID is reset10").

OK

OK

Edit...

Add...


ure,

has

ose

d isse 1

rrela-

to

➤ Click to open up a new Define Case Study Parameter dialogbox and enter the new parameters for link L001:

● Link Name L001

● Device Type Pipe


● Parameter Elevation Change

● To (the new value) -1,100

Case Three through Six

➤ Complete the remaining cases 3 to 6 following a similar procedentering the case data provided in Table 6.

The Case Study dialog box appears as Figure 12 when all six casesbeen entered.

Figure 12:Completed Case

Study Dialog Box

➤ Upon the completion of the case study entries, click to clthe Case Study dialog box.


➤ Select Run from the File menu, or click the Run button. The RunSimulation and View Results dialog box appears.


The Case Study Summary appears at the end of the output file anreproduced in Figure 13. From the simulation, you can see that Ca(inside diameter), Case 5 (flowrate), and Case 6 (pressure drop co

Add...

, Note: Remember to click on the Restore Base Case box to returnthe original Base Case values prior to each case.

OK

Run


tion) show the largest change in pressure drop, ∆(∆p) = 347 psi, -245 psiand -274 psi, respectively. The heat transfer coefficient and the piperoughness have the smallest effect in this simulation.

Figure 13: CaseStudy Summar BASE CASE

PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 1000.0 120.0 99999.90 SINK 677.6 117.4 -99999.90 CASE STUDY 01 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 1000.0 120.0 99999.90 SINK 1024.0 117.2 -99999.90 CASE STUDY 02 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 1000.0 120.0 99999.90 SINK 738.3 117.4 -99999.90 CASE STUDY 03 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 1000.0 120.0 99999.90 SINK 666.8 117.4 -99999.90 CASE STUDY 04 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 1000.0 120.0 99999.90 SINK 677.7 117.2 -99999.90 CASE STUDY 05 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 1000.0 120.0 110000.00 SINK 432.7 117.6 -110000.00 CASE STUDY 06 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 1000.0 120.0 99999.90 SINK 403.6 117.4 -99999.90


f 300 bar-

nd

Heavy Crude Pipeline

#### TASK A 24-inch diameter oil pipeline is planned for an offshore platform in aremote arctic site for transportation to an inland facility. The oil is ahighly viscous heavy crude, 20 API, with a temperature-dependent vis-cosity indicated in Table 7. The crude temperature at the platform is110°F and the ocean temperature remains at about 35°F throughout theyear. The design parameters for the pipeline are a source pressure opsig, a sink pressure of 150 psig, and a capacity of at least 80,000rels/day.

Pipe 2 is buried on the ocean floor and Pipe 3 is buried on dry land. Bothare at a depth of 3 feet. Use a thermal conductivity of 0.3 BTU/hrft°F fordry soil and 1.2 BTU/hrft°F for wet soil.

Determine how the seasonal variations in air temperature affect the pipe-line's flow capacity. In the summer, air temperatures can reach 50°F, ain the winter temperatures are as low as 5°F. Also evaluate the pipelinefor an air temperature of 30°F.

Figure 14:Heavy Crude Pipeline

Use 1.0 for the specific gravity of water.

Use 80,000 bbl/day as the initial flowrate estimate for both the sourceand the sink.

Table 7: Crude Viscosity DataTemperature (°F) Viscosity (cp)

70 370

120 50


i-uld

Part A Perform case studies on the pipeline at the ambient air temperatures indcated in Table 8. The ambient temperatures for Pipes 1 and 2 shoremain at 35°F. Use the Results Access System (RAS) to make a plotshowing a temperature profile for each of the cases.

Part B Specify 2 inches of insulation (conductivity = 0.015 Btu/hr-ft-°F) onPipe 3 and repeat the run. Make a similar plot showing a temperatureprofile for each of the cases.

Does the winter flowrate improve?

@@@@ SOLUTION Create a new problem by selecting New from the File menu. Name thesimulation HCRUDE.

Step 1 Define the Simulation and Input DimensionsThe Simulation Type is Network Model and the Fluid Type is Liquid.Since all of the PIPE inside diameters are 24 inches, you can save sometime by changing the Global Default Pipe ID to 24 inches. Similarly, youmay want to change the default Ambient Temperature to 35°F. Set Maxi-mun Iteration to 150 and de-check Hausen Method.

Step 2 Build the Flowsheet and Enter Unit Data

➤ Add a source and a sink to the flowsheet. Connect the two with alink.

➤ Enter the pipeline into the Link Device Data window.

Remember to supply the thermal conductivities for Pipes 2 and 3. Theambient temperature for Pipes 1 and 2 is 35°F for all cases. For the basecase run, start with the summer ambient air temperature, 50°F, for Pipe 3and estimate the source flowrate at 80,000 bbl/day.

Table 8: Effect of Air Temperature on FlowrateCase Ambient

Temperature (°F)Flowrate, bbl/day

Base Case 50

Case #1 30

Case #2 5

, Note: Simulation convergence is often dependent upon the segmentlength used during the calculations. In this case, select Calcu-lation Methods from the General menu and select Manual Seg-mentation from the Segmentation drop-down list.

28 Heavy Crude Pipeline

e

Step 3 Enter Case Study Problem

➤ Select Case Study from the Special Features menu and check thePerform Case Study Calculations box in the Case Study dialog box.

➤ Click to enter a case.

➤ Check Restore Base Case to reset all the parameters changed in thprevious Case Study back to the original values (i.e., the pipe ID isreset to 10 inches).

➤ Click to open up a new Define Case Study Parameter dialogbox and enter the Case Study parameter provided in Table 8.

➤ Repeat the steps above for the second case.

➤ Upon the completion of the case study entries, click to closethe Case Study dialog box.

Step 4 Run the Simulation and View the ResultsBefore you run the simulation, enable the Results Access System (RAS)by selecting Print Options from the General menu and select Full fromthe RAS Database drop-down list. Also select Part from the DeviceDetail drop-down list, which increases the amount of reporting in theoutput file.



Find the Case Study Summary at the end of the output fil e. Table 9shows the results.

As you can see, the flowrate drops drastically during the winter. The lowtemperature causes a large increase in viscosity, which in turn causes alower flowrate between the (constant pressure) SOURCE and SINK. Thelower flowrate means more heat loss, which leads to higher viscosity,etc. The result is a flowrate that can be very sensitive to ambient temper-ature.

Table 10 shows the results for the same Case Study set but with twoinches of insulation with a conductivity of 0.015 Btu/(hr-ft-°F) on Pipe3. The winter flowrate has increased significantly, and the insulation is

Add...

Add...

OK

Table 9: Effect of Air Temperature on FlowrateCase Ambient

Temperature (°F)Flowrate bbl/day

Base Case 50 92,771

Case #1 30 81,990

Case #2 5 3,250

Run


probably a wise investment. To perform a more complete analysis, youcan investigate insulating the other pipes, different insulation thick-nesses, the use of heaters, etc. With economic data, you can choose thebest scenario.

Step 5 Generate Results Access System PlotsThe PIPEPHASE Results Access System (RAS) allows you to graphi-cally display your simulation results. To generate plots in the RAS, youmust set RAS Database to Full in the Print Options under the Generalmenu before you run the simulation.

➤ To access this system, click within the RunSimulation and View Results dialog box.

➤ Select New from the File menu to create a new RAS database.

➤ Choose HCRUDE.ras and click . The PIPEPHASE RAS dialogbox appears (Figure 15).

Figure 15:PIPEPHASE RAS

Dialog Box

➤ Click .

In this exercise, you want to plot the temperature for each case study ona single graph. Leave the x-variable as Total Length.

Table 10: Results with 2 Inches of Insulation on Pipe 3Case Ambient

Temperature (°F)Flowratebbl/day

Base Case 50 101,155

Case #1 30 96,969

Case #2 5 90,755


OK

View/Edit...


m

-

y and

➤ To select the Y-axis variables, click and select L001 frothe Link Name list.

➤ Check the box next to All Devices in the Link and select Temperature from the State Variable list. The complete RAS Plot DataOptions dialog box for the Base Case is shown in Figure 16.

Figure 16:RAS Plot Data

Options

➤ Click .

➤ Add the other case study plots by changing the Case Study entrclicking .

➤ When complete, click .

The RAS Plot Options dialog box should have three entries—one for thebase case and one for each case study, as shown in Figure 17.

Figure 17:RAS Plot Options

Dialog Box

➤ Click to create the graph shown in Figure 18.

Add...

Add Selection

Add Selection

Done

View


owneretrans-

The results for the run with two inches of insulation on Pipe 3 are shin Figure 19. The discontinuities in the slope of the curves occur whthe different pipes meet. The steeper the curve, the higher the heat fer rate.

Figure 18:Plot of Temperature

Versus Length

Figure 19:Plot of Temperature

Versus Length. Pipe 3has 2" of Insulation


ture,

ill be

Pipeline Sphering

#### TASK A cross-country pipeline, which carries a two-phase natural gas mixis currently operating at its maximum capacity. The pressure at the endof the pipeline will become too low if the flowrate is increased and soadditional compression wil l be required. Sphering, or pigging, is to beperformed in order to increase the throughput of the line. Spheres wlaunched at the beginning of the line and at two intermediate pointsalong the line as shown in Figure 20.

Your job is to determine the quantity of liquid that will be removed fromthe pipeline in order to size the slug catcher.

Figure 20:Sphering Pipeline

Table 11 gives the composition and conditions of the source fluid. Table12 provides data for the higher-boiling components.

<!<" <# <$

<(

<&

<%<'

( ð94ð`YÙµ !"³ð94ðð`YÙ

C`XUbUð<Qe^SXY^WðCdQdY_^cðQ^TðC`XUbUð4YQ]UdUb

4ð-ð(µ

4ð-ð(â!µ4ð-ð!"â!µ

Table 11: Source Composition and ConditionsComponent Mole % Component Mole %

C1 88.61 NC5 1.67

C2 3.15 NC6 1.11

C3 2.69 PETRO1 0.55

NC4 2.04 PETRO2 0.18

Pressure 350 psia

Temperature 120°F

Gas Flowrate 0.7667 MM ft3/hr

Table 12: : Petroleum Component PropertiesPetroleum Component

Density (API)

Boiling Point (°F)

PETRO1 45 350

PETRO2 38 480


The pipe devices are summarized in Table 13. The pipe heat transfercoefficient is 0.8 Btu/hr ft2°F. The ambient temperature is 65°F.

For initial sink estimates, use 1 lb/hr for flowrate and 10 psia for pres-sure.

How much liquid must be removed from the pipeline?

How long does it take for the slug to reach the end of the pipe?

How long does it take to re-establish steady-state?

@@@@ SOLUTION Create a new simulation named SPHERE and enter a simulation descrip-tion.

Step 1 Define the Model

➤ Keep Network Model as the Simulation Type and select Composi-tional as the Fluid Type.

➤ In the Input Dimensions dialog box, select English as the systemunits of measure.

Step 2 Enter Component and Thermodynamic Data

➤ In the Component Data dialog box, click and select thelibrary components listed in Table 11.

➤ Click in the Petroleum Fractions area, enter the petroleumcomponents data from Table 12, and click to save the entries.

➤ Click the PVT Data button on the toolbar. In the Fluid Property Datadialog box, click and change the Water Enthalpy to Super-heated.

Table 13: Piping SegmentsPipe Length (ft) Elevation Change (ft)

L1 4224 0

L2 6336 154

L3 8448 -69

L4 3696 100

L5 6336 120

L6 264 -10

L7 2640 58

L8 9504 -118

Add...

Add... OK

Edit...

34 Pipeline Sphering

th a

.

r.

longlumein-er the

Step 3 Define the Simulation Defaults

➤ Enter the desired global defaults for the Ambient Temperature, PipeID, and Pipe Heat Transfer Coefficient data by clicking the GlobalDefaults button on the toolbar.

Step 4 Change the Calculation Options

➤ Select Calculation Methods from the General menu or click the Cal-culation Methods button from the toolbar.

➤ Check the box next to Sphering Analysis.

Step 5 Build the Flowsheet and Enter Unit and Link Data


➤ Enter the SOURCE and SINK data.

➤ Add eight PIPEs to the LINK and enter the data provided in Table 13

Remember to input the Sphere Inside Diameter for pipes L1, L3, and L6.

Step 6 Run the Simulation and View the ResultsBefore you run the simulation, select Print Options from the Generalmenu and set Device Detail to Part and Plots to Full. Also, check the Tai-tel Dukler Flow Pattern Map box to generate flow data.




From the Sphering Report, you can see that the slug is 2,723.6 ft when it reaches the end of the pipe. Calculating by hand, the slug vois 2,137.9 ft3 (12 in. ID) which is delivered in 181.7 sec (just over 3 mutes). Steady state flow is re-established 31,092 sec (8.6 hours) aftsphere is launched.

The latter parts of the Sphering Report is shown below.

Run

View


Figure 21:Slug Zone Report ----------------SLUG ZONE------------------

SLUG SLUG SLUG SLUG EDGE PRESS: EDGE TIME VELO: LENGTH PRESS: DROP DISTANCE (SECS) (FPS) (FT) (PSIA) (PSIA) (FT) ------- ------- --------- ------- ------- --------- 1606.9 13.94 2445.6 252.2 21.0 38520.6 1625.4 13.86 2444.5 254.0 20.8 38662.8 1643.8 13.86 2473.0 253.6 21.0 38936.4 1662.3 13.87 2501.4 253.2 21.2 39210.3 1680.8 13.87 2530.2 252.9 21.5 39484.6 1699.3 13.87 2559.0 252.5 21.7 39759.3 1717.7 13.88 2588.0 252.2 21.9 40034.3 1736.2 13.88 2617.1 252.0 22.0 40309.6 1754.7 13.88 2646.3 251.8 22.1 40585.3 1773.1 13.81 2648.2 253.5 21.8 40728.9 1791.6 13.81 2677.6 253.3 21.9 41003.4 1810.1 13.81 2707.1 253.1 22.0 41278.2 1819.3 13.82 2721.8 253.0 22.0 41415.6 1820.5 13.82 2723.6 253.0 22.0 41432.8

Figure 22:Delivery Report SLUG DELIVERY

------------- PRESS: SLUG SPHERE BEHIND TIME VELOCITY VELOCITY SPHERE (SECS) (FPS) (FPS) (PSIA) ------- -------- -------- ------- 9.8 13.87 13.87 274.6 19.7 13.87 13.87 273.5 29.5 13.90 13.90 272.4 39.3 13.96 13.96 271.6 49.1 13.98 13.98 270.6 58.8 14.02 14.02 269.4 68.5 14.09 14.09 268.6 78.2 14.16 14.16 267.6 87.8 14.21 14.21 266.5 97.3 14.27 14.27 265.5 106.9 14.33 14.33 264.4 116.4 14.39 14.39 263.3 125.8 14.44 14.44 262.1 135.3 14.51 14.51 261.0 144.6 14.57 14.57 259.8 154.0 14.63 14.63 258.6 163.3 14.70 14.70 257.4 172.5 14.77 14.77 256.1 181.7 14.84 14.84 254.8

36 Pipeline Sphering

Looped Black Oil Network

#### TASK A black oil gathering and distribution facility is shown below. Oil is col-lected from four different fields and transported to two terminal points(B and C). This system consists of loops and cross-over lines.

Figure 23:Flowsheet for Looped

Black Oil Network

Three of the four source flowrates are known by field measurements,while the remaining source and both terminals have known pressures.

You are required to determine the unknown boundary flows and pres-sures, along with the flow distribution in the loops and crossovers. Findthe individual delivery rates for the two terminal points and locate anypotential bottlenecks in the system.

To locate bottlenecks, calculate the pressure drop per pipe length foreach link. A large value indicates high frictional losses which could bealleviated by either increasing the pipe diameter or by adding a second,parallel pipeline. All pipes are 12 inches in inside diameter

: : : :

:!:!:!:!

:$:$:$:$

:":":":"

:%:%:%:% 3333

:&:&:&:& 2222

:#:#:#:#

1!1!1!1!

1 1 1 1

1"1"1"1"

1#1#1#1#

! ä ðVd! ä ðVd! ä ðVd! ä ðVd

# ä ðVd# ä ðVd# ä ðVd# ä ðVd

!(ä ðVd!(ä ðVd!(ä ðVd!(ä ðVd#"ä ðVd#"ä ðVd#"ä ðVd#"ä ðVd

% ä ðVd% ä ðVd% ä ðVd% ä ðVd

# ä ðVd# ä ðVd# ä ðVd# ä ðVd

#%ä ðVd#%ä ðVd#%ä ðVd#%ä ðVd

#ä% ðVd#ä% ðVd#ä% ðVd#ä% ðVd

"ä% ðVd"ä% ðVd"ä% ðVd"ä% ðVd

#%ä ðVd#%ä ðVd#%ä ðVd#%ä ðVd



!! ð`cYW!! ð`cYW!! ð`cYW!! ð`cYW

!"%ð`cYW!"%ð`cYW!"%ð`cYW!"%ð`cYW

!ä ðVd!ä ðVd!ä ðVd!ä ðVd

!ä ðVd!ä ðVd!ä ðVd!ä ðVd

Table 14: Fluid PropertiesOil, specific gravity 0.54




inks.

Source data is provided below in Table 16. Italicized numbers corre-spond to initial estimates for unmeasured values.

As for sink initial estimates, use 20,000 BPD for first sink and 40,000BPD for second.

What is the direction of flow between junctions J2 and J4? between J5and J6? between J0 and J1?

(Remember that a positive flowrate indicates that the flow is in the direc-tion the link is drawn and negative flow indicates that the flow is in theopposite direction.)

@@@@ SOLUTION Create a new simulation LOOPNET and enter a simulation description.

Step 7 Enter Simulation DefaultsUse the defaults: Network Model as the Simulation Type , and Blackoil asthe Fluid Type.

➤ Leave the input dimensions as Petroleum, but change the Oil Densityunits from API to specific gravity.

➤ Supply the Oil, Gas, and Water specific gravity data in the BlackoilPVT Data dialog box.

➤ Click the Global Defaults button on the toolbar to open the GlobalDefaults dialog box and change the default PIPE inside diameter to12 inches, and the default PIPE heat transfer coeff icient to 2 BTU/hrft2°F.


➤ Add four sources, seven junctions, and two sinks to the flowsheet.Using Figure 23, reposition as needed and add the appropriate l

Table 15: Heat Transfer DataAmbient Temperature, F 80

Overall U-coefficient, Btu/hr-ft2-F 2

Table 16: Source DataName Gas/Oil Ratio

ft3/bblFlowrateBPD

TemperatureºF

Pressurepsig

A0 400 10,000 120 395

A1 300 10,000 110 300

A2 100 15,500 110 250

A3 230 20,000 120 200

38 Looped Black Oil Network

,

e

pres-

ts.

r.

toisest.01

lick-ler-

as,c-

You can hold down the <Shift> key to drop multiple units at a timereleasing the <Shift> key prior to dropping the last unit.

Step 9 Enter Unit and Link Data

➤ Fill in the data for each SOURCE in turn. Provide initial estimates forunmeasured flowrates and/or pressures.

➤ Enter the data for the SINKs, providing estimates where needed.

➤ Double-click on each LINK in turn, and enter the relevant devicdata.

Step 10 Change the Print OptionsTo locate bottlenecks, you need to get the components of the total sure gradient for each link.

➤ Select Print Options from the General menu, and select Full for theDevice Detail report option list to get the Pressure Gradient repor




➤ To view the results, select Output File from the Report drop-downlist in the View Reports section of the dialog box and click .

Check the flowrate directions. You will find that the flow is from J0 J1, from J4 to J2 and from J6 to J5. The flowrate into terminal C 121,430 bbl/day and into terminal B it is 71,306 bbl/day. The highpressure drop per pipe length is for the link between A0 and J0 at 0psi/ft (see the Velocity Summary in the Output Report).

You can change the solution tolerances and algorithm options by cing on the Calculation Methods button on the toolbar. Tighten the toance for pressure and rerun the network. Did your answers change?

, Note: PIPEPHASE allows a maximum of twenty sources linked to given junction. If you want to attach more than twenty sourceyou should enter them in sets of twenty into two separate juntions, and link two junctions together with a very short, largediameter pipe.

Run

View


Black Oil Gathering System

#### TASK A black oil gathering system is shown in Figure 24. There are six wellsleading to an offshore platform, which then has a pipeline to an onshorefacility.

Figure 24:Black Oil Gathering

System

Given the following data in Tables 17 through 19, find the total flow offluid arriving at the onshore terminal (SINK “ONSH”).

!!!!""""

####

$$$$%%%%

&&&&

@<1D@<1D@<1D@<1D ?>C8?>C8?>C8?>C8

<!<!<!<!<"<"<"<"

<#<#<#<#

<$<$<$<$ <%<%<%<%<&<&<&<&

Table 17: Fluid PropertiesWells 1-3 Wells 4-6

Oil, API 30 Oil, API 33

Gas, specific gravity 0.60 Gas, specific gravity 0.63

Water, specific gravity 1.01 Water, specific gravity 1.03

Table 18: Source and Sink DataNode Pressure

(psig)Temperature (°F)

GOR (ft3/bbl)

WCUT (%)

Source 1 2,500 185 700 15

Source 2 2,500 185 750 5

Source 3 2,530 185 500 20

Source 4 2,370 195 700 12

Source 5 2,704 190 600 25

Source 6 2,690 187 700 15

ONSH 160

40 Black Oil Gathering System

Table 19: Link DataLink Device Prod. Index

(bbl/day/psi)Length or Wireline Depth (ft)

Inner Diameter (in)

Vertical Depth (ft)

Elevation Change (ft)

L1 IPR 5

Tubing 3,000 2.441 2,500

Choke 1.000

Pipe 1,500 4.000 47

Riser 500 4.000 470

Pipe 30 4.000

L2 IPR 6

Tubing 3,500 2.441 3,500

Choke 1.000

Pipe 1,800 4.000 -70

Riser 500 4.000 490

Pipe 50 4.000

L3 IPR 4.5

Tubing 3,800 2.992 3,700

Choke 1.000

Pipe 2,800 4.000 -70

Riser 500 4.000 490

Pipe 50 4.000

L4 IPR 8

Tubing 4,500 2.992 4,300

Choke 1.000

Pipe 2,700 4.000 -40

Riser 550 4.000 490

Pipe 20 4.000

L5 IPR 5

Tubing 4,200 2.992 4,100

Choke 1.000

Pipe 2,900 4.000 -10

Riser 600 4.000 490

Pipe 20 4.000

L6 IPR 10

Tubing 3,900 2.992 3,900

Choke 1.000

Pipe 3,700 4.000 -10

Riser 600 4.000 490

Pipe 20 4.000

PLAT/ONSH

Pipe 490 16.000

Pipe 211,200 16.000 300

Pipe 5,280 16.000 190

Pipe 10,560 16.000


and

-

s 4-

et.riate

re of

es.

res-

y

Use 1,000 bbl/day as the initial flowrate estimate for each source 6,000 bbl/day for the sink.

@@@@ SOLUTION Create a new simulation named BOGS and enter a simulation description.

Step 1 Define the ModelUse the defaults: Network Model as the Simulation Type and Blackoil asthe Fluid Type.

➤ Enter the Blackoil PVT data through the Fluid Property Data dialogbox. Create two property sets, one for wells 1-3 and one for well6 from the data in Table 1.

➤ Enter the desired global defaults for the LINK data using the GlobalDefaults button on the toolbar.


➤ Add six sources, one junction, and a single sink to the flowsheUsing Figure 24, reposition as needed and connect the appropunits.

You can create LINK s in two different ways:

■ Select the first unit and use the cursor to connect the small squathe first unit to the small square of the second unit.

■ With no icon selected (i.e., no icon has green outline), select EditLink from the Edit menu. Click and select the From andTo node names from the drop-down list of the corresponding nod

➤ Fill in the data for each SOURCE and the SINK from the data in Table18. Provide initial estimates for unmeasured flowrates and/or psures.

➤ For each LINK , enter the appropriate data for the LINK devices givenin Table 19 (i.e. IPR, TUBIN , CHOKE, PIPE, and RISER).

Add Link

Tip: A quick way to add multiple links to the flowsheet is to firstadd link L1 and complete the required devices for this link.Then highlight link L1 and select Copy Link from the Editmenu. Copy this link to links L2 through L6. Then change onlthe parameters that differ.

42 Black Oil Gathering System

r.

e

lick-teners




➤ To view the individual node results, select View Output from theView menu and double-click on the sink. The total flowrate to thsink is 27,643 bbl/day and the temperature is 81.0°F.

You can change the solution tolerances and algorithm options by cing on the Network Calculation Methods button on the toolbar. Tighthe tolerance for pressure and rerun the network. Did your answchange?

Run


-

t

ca-

Two Well Gas Lift Analysis

#### TASK For a single well on gas lift, the increased back-pressure from the injection gas affects other wells that share a common flowline. If any of theother wells are also on gas lift, it in turn contributes to an overall increasein back pressure. As such, a single-well gas lif t analysis performed inisolation will over-predict production. The actual optimal injection ratewill be influenced by the interacting wells, and will be lower than thatpredicted by single-well analysis. The problem therefore is to determinethe amount of gas to allocate to each of the wells under of gas lift inorder to maximize the total production rate from the field. In PIPE-PHASE, this is determined by executing a case study.

A 1500 ft, 4-inch flowline connects two wells to a separator operating a250 psi. Gas lift is applied to both wells. Perform an analysis to deter-mine the maximum production from the two wells.

Given the data in Tables 20 and 21, determine the optimal lift gas allotion between the two wells, based on the available gas being limited to 4MM ft 3/day, to achieve the maximum oil production.

Table 20: Fluid PropertiesBlackoil PVT Data

Oil, API 30



Lift Gas Data

Specific gravity 0.8

Table 21: Source DataUnit Pressure

(psig)Temperature (°F)

GOR (ft3/bbl)

WCUT (%)

S001 2499 180 108 0

S002 2505 181 102 10.5

44 Two Well Gas Lift Analysis

For Pipe, use nominal diameter = 4", schedule 40. For Tubing, use nom-inal diameter = 4", schedule TB01. Use a U-value of 1 Btu/hr ft2°F forboth. The ambient temperature is 65°F.

Use 5,000 bbl/day as the initial flowrate estimate for each source and10,000 bbl/day as the initial estimate for the sink.

What is the maximum production from the two wells?

@@@@ SOLUTION Create a new simulation named GASLIFT and enter a simulation descrip-tion.


Use the default Petroleum units of measure set.

➤ Enter the Blackoil PVT data through the Fluid Property Data dialogbox.

➤ Enter the desired global defaults for the LINK device data by clickingthe Global Defaults button on the toolbar


➤ Add two sources, a junction, and a single sink to the flowsheet.

➤ Fill in the data for each SOURCE and SINK in turn. Provide initialestimates for unmeasured flowrates.

Table 22: Link DataLink Device Productivity

Index (bbl/day/psi)

Length or Wireline Depth (ft)

True Vertical Depth (ft)

Existing Lift Gas Flowrate (MM ft3/day)

L1 IPR 25.5

Tubing 8,010 8,010

Gas Valve 0.5

Tubing 6,810 6,810

Pipe 231

L2 IPR 22.1

Tubing 8,111 8,111

Gas Valve 3.5

Tubing 6,445 6,445

Pipe 103

L3 Pipe 1,500


snet-

me

from 0.5.

r.

n

➤ Enter the LINK device data provided in Table 22.

➤ Click the PVT Data toolbar button to reopen the Fluid Property Datadialog box.

➤ Click and enter the specific gravity. This option wanot available earlier since a gas lift valve was not yet part of the work.

Step 3 Enter Case Study DataFor each case, supply two parameters, one for each well.

➤ Select Case Study from the Special Features menu.

➤ Check the Perform Case Study Calculations box and click .

➤ Click and from the drop-down lists, supply the followingfor the first case.

● Link Name L001

● Device Type Gas Lift Valv


● Parameter Rate

● Change To 1.0

➤ Click again to supply the second parameter for the sacase (the Link Name is L002; the Device Name is E008). Change therate to 3.0.

For the five remaining cases, increase the rate to gas lift valve E0031.5 to 3.5 while decreasing the rate to gas lift valve E008 from 2.5 toUse increments of 0.5 MMSCFD.

Step 4 Run the Simulation and View the ResultsBefore you run the simulation, select Print Options from the Generalmenu and set the Input Reprint, Property Data, Flash Report options toNone and RAS Database to Full.

➤ Select Run from the File menu or click the Run button on the toolba



Lift Gas Data

Add...

Add...

Add...

Note: A quick way to add multiple cases is to use the Copy functioin the Case Study dialog box.

Run

View


and.80

From the Case Summary, the optimal solution is 3883.76 BPD 3056.03 BPD for sources 1 and 2 respectively (for a total of 6939BPD), at a gas injection rate of 2.0 MMSCFD for each well.

Figure 25:Case Summary BASE CASE

PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2499.0 180.0 1479.03 S002 2505.0 181.0 3883.92 D004 250.0 160.3 -5362.95 CASE STUDY 01 - 1/3 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2499.0 180.0 2611.54 S002 2505.0 181.0 3650.82 D004 250.0 161.6 -6262.36 CASE STUDY 02 - 1.5/2.5 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2499.0 180.0 3346.47 S002 2505.0 181.0 3387.39 D004 250.0 162.2 -6733.86 CASE STUDY 03 - 2/2 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2499.0 180.0 3883.76 S002 2505.0 181.0 3056.03 D004 250.0 162.3 -6939.80 CASE STUDY 04 - 2.5/1.5 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2499.0 180.0 4281.03 S002 2505.0 181.0 2611.38 D004 250.0 162.0 -6892.40 CASE STUDY 05 - 3/1 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2499.0 180.0 4576.59 S002 2505.0 181.0 1983.79 D004 250.0 160.9 -6560.37 CASE STUDY 06 - 3.5/0.5 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2499.0 180.0 4818.88 S002 2505.0 181.0 1068.75 D004 250.0 159.2 -5887.63


6.

e- 2.0

cisete is

Plotting the sink data in Excel produces the graph shown in Figure 2

Figure 26:Oil Production as a

Function of CaseNumber

Figure 26 shows that the maximum oil production does occur somwhere close to the conditions of case 3, when the gas lift flowrate isMMSCFD. Additional runs can be executed to determine more preoperating conditions. Also, cases where the combined gas lift flowraless than 4.0 MMSCFD should also be examined.

5000

5250

5500

5750

6000

6250

6500

6750

7000

0 1 2 3 4 5 6

Case Number

Tot

al O

il P

rodu

ctio

n (B

PD

)


Steam Injection Well

#### TASK Steam is continuously injected from a boiler through a flowline, into awell as shown in Figure 27. The injected steam enhances the mobility ofthe reservoir fluid and improves the production in an adjacent well. Sys-tem details are given in Tables 23-26.

Figure 27:Steam Injection Well @YÙðè! ðVdç

DeRY^Wè" ðVdç2_Y\Ub

CdUQ]!% ð`cYWaeQ\Ydi*ð))ë

9@BBUcUbf_Yb" ð`cYW! ¡6

Table 23: Link DataLink Device Nominal

Diameter (in)Schedule Thickness

(in)

Pipe 4 40 0.125

Tubing 3.5 TB01

Table 24: Pipe Insulation DataThickness 0.1 in

Conductivity 0.01 BTU/hr-ft-°F

Table 25: Heat Transfer DataAmbient Surface Temperature 80°F

Wind Velocity 10 mph

Earth Conductivity 0.8 BTU/hr-ft-°F

Table 26: Wellbore DataWellbore Diameter 8.5 in

Casing OD 6.0 in

Casing thickness 0.125 in


umesi

and

nto

ick of

ff (i.e.

m) issure

-

u

d-

The annulus between the tubing and casing is filled with brine (assdefault “liquid” properties). The injectivity has a value of 10 lb/hr/p(model as an IPR).

Use 1,000 lb/hr as the initial flowrate estimate for both the source the sink.

Part A Calculate the quality, temperature and rate of fluid being injected ithe reservoir.

Part B What is the effect of burying the flowline 36" below the surface?

Restore the base case, then re-insulate the flowline with 0.125" thinsulation of thermal conductivity 0.1 Btu/hr-ft-F. What is the effectthis?

Restore the base case. Drain the brine from the annulus and seal oair filled annulus). What is the improvement?

Part C The results of the previous runs indicate that only hot water (no steabeing injected to the reservoir. What changes would you make to ensome steam is injected?

@@@@ SOLUTION

Part A Create a new simulation named STMINJ and enter a simulation description.


➤ Define this problem as a Network Model, with Steam as the FluidType.

➤ Enter the Water specific gravity (spgr = 1.001).


➤ Add a source and a sink to the flowsheet. Connect the two units.

➤ Enter the SOURCE and SINK data from Figure 27. Make sure yocheck the Injection Well box in the Sink Data Entry dialog box.

➤ Double-click on the LINK . Add a PIPE to the LINK and enter the cor-responding data. Select Pipe in Air from the Heat Transfer drop-down list, and click to enter the corresponing data from Tables 24 and 25.

Heat Transfer Data...

50 Steam Injection Well

t

r.

.

hose

intos so

e in

➤ Add a TUBING device following the PIPE and enter its data. SelecDetailed from the Thermal Calculations Heat Transfer list and entera Temperature Gradient of 1°F/100 ft.

➤ Click and enter a Production Time of 100days and change the Annular Medium to Liquid.

➤ Add an IPR device following the TUBING. Change the DeliverabilityBasis to Weight and enter the Productivity Index.




➤ To view the results, select Output File from the Report drop-downlist in the View Reports section of the dialog box and click

➤ Scroll through the Node Summary and compare your results to tin Figure 28.

As you can see, only hot water (steam quality=0) is being injected the well. In the remaining runs, you will try to reduce the heat lossethat some steam is actually injected.

Part B

Step 4 Bury the PipeBefore making any changes, save the file by selecting Save As from theFile menu. Name the new simulation STMINJB.

➤ Double-click on the LINK and double-click on the PIPE.

➤ Select Buried Pipe from the Heat Transfer drop-down list. Click and enter the Buried Depth of the PIPE.

➤ Run the simulation and compare your Node Summary to the onFigure 29.


Run

View

Figure 28:Node Summary for

Part A

NODE SUMMARY STEAM TOTAL NODE PRES. QUAL. RATE TEMP. (PSIG) (LBHR) (F) ---- ------- ------ -------- ------- S001 1500.0 * 0.99 1423. 597.5 D002 2000.0 * 0.00 -1423. 245.8 * INDICATES KNOWN PRESSURE OR FLOW



the

duc-

30.

jec-dy

31.

Burying the pipe actually lowered the downhole temperature anddecreased the steam (water) flowrate. Clearly we should not burypipe to improve the steam quality.

Step 5 Add Insulation to the Base CaseOpen the file named STMINJ and save it as STMINJC.

➤ Change the insulation thickness to 0.125 in. and the thermal contivity to 0.1 Btu/hr-ft-°F in the Pipe Detailed Heat Transfer Datadialog box.

➤ Run the simulation and compare your Node Summary to Figure

Although the steam temperature increased, it is still a liquid at the intion site. The simulation shows that insulating the pipe will not remethe problem.

Step 6 Change the Tubing Conditions of the Base CaseOpen the file named STMINJ and save it as STMINJD.

➤ Double-click on the TUBING device. Click and select Gas from the Annular Medium drop-down list.

➤ Run the simulation and compare your Node Summary to Figure


Part B

NODE SUMMARY STEAM TOTAL NODE PRES. QUAL. RATE TEMP. (PSIG) (LBHR) (F) ---- ------- ------ -------- ------- S001 1500.0 * 0.99 1159. 597.5 D002 2000.0 * 0.00 -1159. 217.0


Part C




Part D



le

eingreser-

the

least head. at

se),

pearsure

tingight

saythan

Removing the brine gives only a slight improvement in the downhosteam temperature. The steam quality is still zero.

Part C

Step 7 Change the Source Conditions of the Base CaseDespite our best efforts to reduce heat losses, we have not succeeded ininjecting steam into this well. This is because saturated steam is bproduced at a temperature lower than the saturation temperature at voir conditions. The only reason you have flow from the low pressuresource to the high pressure sink is due to the head of liquid water intubing.

To drive a gas into the well, we expect the source pressure to be atas high as the sink pressure, since a column of gas has a negligibleWith this in mind, we will examine increasing the boiler pressure toleast 2000 psig.

Open the file named STMINJ and save it as STMINJE.

➤ Perform a Case Study with boiler pressures at 1,500 (base ca2,000, 2,200, 2,400, 2600, 2800, and 3,000 psig.

Figure 32 shows a condensed version of the Node Summary that apin the Output file. As you would expect, increasing the boiler pressincreases the downhole steam quality. It also demands higher power andhence higher costs. It is your job to balance these additional operacosts with the benefits obtained by steam injection. From here you mwant to explore the effect of operating at an intermediate pressure, 2,200 psig, and adding insulation. This might be more cost effective simply running the boiler at 2,600 psig.



Part C

BASE CASE STEAM TOTAL NODE PRES. QUAL. RATE TEMP. (PSIG) (LBHR) (F) ---- ------- ------ -------- ------- S001 1500.0 * 0.99 1423. 597.5 D002 2000.0 * 0.00 -1423. 245.8 * INDICATES KNOWN PRESSURE OR FLOW

CASE NO. 1 STEAM TOTAL NODE PRES. QUAL. RATE TEMP. (PSIG) (LBHR) (F) ---- ------- ------ -------- ------- S001 2000.0 * 0.99 3291. 636.6 D002 2000.0 * 0.00 -3291. 567.4

CASE NO. 2

STEAM TOTAL NODE PRES. QUAL. RATE TEMP. (PSIG) (LBHR) (F) ---- ------- ------ -------- ------- S001 2200.0 * 0.99 4443. 650.2 D002 2000.0 * 0.02 -4443. 636.4






the

Forecasting Well Production

#### TASK The oil field shown in Figure 33 is being evaluated for possible introduc-tion into an existing crude oil gathering network. The Planning Depart-ment has asked you for an indication of the contribution from this fieldduring its first year of production.

Figure 33:Oil Field

The well source data is given below and the well head pressure is fixed at50 psig. From economic considerations, production may be achievedusing either 3" or 4" tubing. The well is expected to have a productivityindex (PI) of 2.4 bbl/day/psi, although experience has shown that for afield of this nature, a PI as high as 4.8 is possible.

Determine the effects of changing the tubing diameter and PI on amount of oil retrieved. Also, calculate the amount of oil collected afterthe first year of production using the optimum well configuration.

! ðVd

%" ðVd

$ ðVd

#" ðVd# ðVd

Table 27: Heat Transfer DataAmbient Temperature,°F 50

Overall U-coefficient, Btu/hr-ft2°F 0.74

Table 28: Fluid PropertiesOil, API 34




d
Use 3,000 bbl/day as the initial flowrate estimate for both the source anthe sink.
@@@@ SOLUTION Create a new simulation named FORECAST and supply a simulationdescription.


➤ Enter the Blackoil PVT data.

➤ Enter the desired global defaults for the Ambient Temperature andthe TUBING data using the Global Defaults button on the toolbar.


➤ Add a source and a sink to the flowsheet. Connect the two units.


➤ For the LINK data, enter the IPR device first. Select the ProductivityIndex option from the IPR Model drop-down list and click

to enter a PI value of 2.4 bbl/day/psig.

➤ For the three TUBING devices, enter the length and depth for eachsection. Remember, the TUBING farthest from the well head must beentered first.

Step 3 Enter Case Study Data

➤ Select Case Study from the Special Features menu.

➤ Check the Perform Case Study Calculations box and click .Click to enter the Define Case Study Parameter dialog box.

Case One

➤ Using Figure 34 as a guide, enter data to change the TUBING insidediameter from 3" to 4" for all links.

Table 29: Well Source DataTemperature, °F 150

Pressure, psig 4500

Gas/oil ratio, ft3/bbl 40

Water Cut, % 20

IPR Model Data

Add... Add...

56 Forecasting Well Production

ualme-

Figure 34:Parameters Dialog

Box for the First Case

➤ Check the Restore Base Case Solution box in the Case StudyChanges dialog box.

Case Two

➤ Using Figure 35 as a guide, enter data to perform an individchange to the IPR device, with the Productivity Index as the parater.

Figure 35:Parameters Dialog

Box for the SecondCase

➤ Check the Restore Base Case Solution box in the Case StudyChanges dialog box.


ulta-this

bothnge

case

ar.

sethe

duce

Case Three

For the third case, change both parameters of the oil reservoir simneously. You must consider both global and individual changes for case. You can accomplish this in either of two ways:

■ You can restore the simulation to the Base Case and then varyparameters in the third case. This is done by adding the chaparameters within the same Case Study Changes dialog box, or

■ You can choose not to check the Restore Base Case Solution box andchange the parameter that was not already varied in the second(tubing ID).




➤ To view the results, select Output File from the Report drop-downlist and click .

At the end of the output report, you will find a summary of the castudy results as shown below in Figure 36. As you might expect, highest flowrate is achieved when the TUBIN inside diameter is set to 4and the PI is at 4.8. Under these circumstances, the well would pro6,599.4 bbl/day or 2.41x106 bbl/yr.

Run

View

Figure 36:Case Study Summar BASE CASE

PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 4500.0 150.0 3249.59 SINK 50.0 141.8 -3249.59 CASE 01 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 4500.0 150.0 3547.88 SINK 50.0 140.1 -3547.88 CASE 02 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 4500.0 150.0 5284.97 SINK 50.0 144.9 -5284.97 CASE 03 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- SORS 4500.0 150.0 6599.40 SINK 50.0 144.5 -6599.40

58 Forecasting Well Production

l.

Three-Year Decline Model

#### TASK Two wells, producing from a single reservoir, flow into a manifoldwhich has a pipeline connection to a processing facility. The productionin this system is to be analyzed based on a three year decline mode

Figure 37:Two Well System

from a SingleReservoir

Use the Results Access System to plot the pressure traverses for the welllinks as a function of time. Also tabulate and plot the individual well oilflowrates and the total oil fl ow rates as a function of time for three years.

GU\\ð! GU\\ð"

BUcUbf_Yb

@b_SUccY^W6QSY\Ydi:e^SdY_^

Table 30: Reservoir Decline DataCumulative Oil Production (bbl)

Average Reservoir Pressure (psig)

0 2602

10,000,000 2431

20,000,000 2296

30,000,000 2011

40,000,000 1958

50,000,000 1834

Table 31: IPR Decline DataReservoir Well 1 Well 2Pressure (psig) GOR(ft3/bbl) WCUT(%) GOR(ft3/bbl) WCUT(%)

2602 450 10.1 455 11.1

2431 477 10.3 481 11.1

2296 492 10.8 506 11.5

2011 513 11.0 530 11.8

1834 550 11.8 562 12.5


Table 32: Fluid PropertiesWell 1 Well 2

Oil, API 35.2 Oil, API 35.4

Gas, specific gravity 0.704 Gas, specific gravity 0.710

Water, specific gravity 1.010 Water, specific gravity 1.012

Table 33: Source and Sink DataSource Pressure

(psig)Abandonment Pressure (psig)

Temperature (°F)

GOR (ft3/bbl)

WCUT (%)

Well 1 2,602 1,200 105 450 10.1

Well 2 2,598 1,200 125 455 11.1

Sink 300

Table 34: Link Device DataLink Device PI

(bbl/day/psi)Length (ft) Nominal

Diameter (in)True Vertical Depth (ft)

Elevation Change (ft)

L1 IPR 30

Tubing 1,500 2.875 1,450

Choke 2.000

Pipe 201 4.000 -5

L2 IPR 25

Tubing 1,631 2.875 1515

Choke 2.000

L3 Pipe 4,070 4.000 207

, Note: Tubing and Pipe diameters are nominal. The actual insidediameters are as follows: for a 4 in. pipe (schedule 40), theactual inside diameter is 4.028 in; for 2.875 in. (API) tubing,the actual inside diameter is 2.441 in.

60 Three-Year Decline Model

ce,

nect.

n

Figure 38:Reservoir Decline

Curve

Use 7,000 bbl/day as the initial flowrate estimate for the first sour11,000 bbl/day for the second, and 20,000 bbl/day for the sink.

@@@@ SOLUTION Create a new simulation named TDPRODPL and enter a simulationdescription.


➤ Enter Black Oil PVT data for each set.


➤ Add two sources, a junction, and a sink to the flowsheet and con

➤ Enter SOURCE and SINK data.

Step 3 Enter Reservoir Data

➤ Select Reservoir Database from the Special Features menu to openthe Reservoir Database dialog box.

➤ Click to enter the reservoir decline data.

➤ Set the Production Basis as the Oil and Water Standard Volume fromthe drop-down list. The Cumulative Production is 0 for a new field.

➤ Click to input the Reservoir Decline Curve data.

➤ Fill in the first reservoir pressure and the cumulative productiodata.

➤ Click Add After on the menu bar to add the second set of data.

!%

!'

!)

"!

"#

"%

"'

! " # $ %

3e]e\QdYfUð@b_TeSdY_^3e]e\QdYfUð@b_TeSdY_^3e]e\QdYfUð@b_TeSdY_^3e]e\QdYfUð@b_TeSdY_^ðè==ðRR\çðè==ðRR\çðè==ðRR\çðè==ðRR\ç

@bUccebUðè`cYWç

@bUccebUðè`cYWç

@bUccebUðè`cYWç

@bUccebUðè`cYWç

New...

Enter Data...


he

b

the

r the

-

ng.

u

ar.

ut

➤ Once completed, select Save from the Worksheet menu to save andexit the worksheet.


➤ Double-click on the Link L1 to open the Link Device Data window.

➤ Add an IPR device and enter the PI value.

➤ Click to open the related dialog box. Select tGroup Decline Model from the Production Decline drop-down list.Select RC01 as the Reservoir Group from the drop-down list. Fill inthe Reservoir abandonment pressure. Select Reservoir Pressure forthe Decline basis, and fill in the given data. Close the dialog boxclicking .

➤ You can now select the remaining devices in the link and enter length, depth, or elevation change and diameter data for these TUB-

ING, CHOKE and PIPE devices.

➤ Following the same procedure as in L1, enter the link devices folinks L2 and L3.

Step 5 Enter Time Stepping Data

➤ Select Time Stepping from the Special Features menu.

➤ Check the box to activate the time stepping calculations.

➤ Check the box for Production Decline and click the associated button.

Time data is 365, 730, and 1,096 days for 3 years production planni

Step 6 Run the Simulation and View the ResultsTo create the file necessary to run the RAS, the RAS Database of Fulloption in the Print Options dialog box must first be selected before yorun the simulation.



➤ To view the results, select Output File from the Report drop-downlist and click .

Figure 39 shows the Time Stepping Summary in the output report.

IPR Decline Data

OK

, Note: Pressure decline is specific to the reservoir; GOR and water cchanges are specific for each well.

Run

View


temr the

s-

is as

Step 7 Generate Results Access System PlotsYou can plot the studied cases on a single plot to see how the syspressure traverse is affected by the reservoir pressure decline oveyears (Part A). You can also plot how the oil production drops in eachwell individually or in different links, by using the Results Access Sytem (RAS) (Part B).

➤ After the simulation is run, click within theRun Simulation and View Results dialog box.

➤ To activate the PIPEPHASE RAS dialog box, select New from theFile menu to create a new RAS database and choose TDPRODPL.ras.

Plotting Graphs with the SIMSCI Plot Viewer

➤ Click for the Plot Report option.

➤ Fill in the title and axis labels as desired. You can leave the x-axthe Total Length.

Figure 39:Time Stepping

Summary

TIME = 0.00 DAYS PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2602.0 105.0 9298.83 S002 2598.0 125.0 8389.54 J004 1220.1 114.4 0.00 D003 300.0 113.3 -17688.37 TIME = 365.00 DAYS PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2478.5 105.0 8677.06 S002 2474.5 125.0 7848.13 J004 1156.4 114.3 0.00 D003 300.0 113.2 -16525.19 TIME = 730.00 DAYS PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2377.4 105.0 8184.93 S002 2373.4 125.0 7409.61 J004 1106.2 114.3 0.00 D003 300.0 113.2 -15594.54 TIME = 1096.00 DAYS PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F BBL/DAY ---- -------- ----------- --------- S001 2285.3 105.0 7757.84 S002 2281.3 125.0 7025.51 J004 1062.0 114.3 0.00 D003 300.0 113.1 -14783.35


View/Edit...


sure

and

rates

rt A

➤ Click . The RAS Plot Data Options dialog box appears.

➤ Select the Link as L001, check the All Devices in the Link box to seethe change from the reservoir to the manifold, and select Presfrom the State Variable list and click .

➤ Add the other time step plots by changing the Case Study entryclicking .

➤ After all four time step plots are added, click .

➤ Click to generate the plot.

Compare how the pressure changes in the system as the productionchange over the years. The graph is shown in Figure 40.

Figure 40:Plot of Pressure as a

Function of TotalLength in Link L001

Plotting Graphs in Microsoft Excel

The Plot Viewer is the default option to view the plots. HoweverMicrosoft Excel is also available. Follow a similar procedure as in Pato define this plot.

➤ Select Setup Options from the General menu in the PIPEPHASERAS dialog box.

➤ Choose the Excel 5.0/7.0 Plotter radio button and click .

➤ Select New from the Plot Report list and click .

➤ Change the X-axis to Time.

Add...

Add Selection

Add Selection

Done

View

OK

View/Edit...


the of

tated

➤ Click and select the Oil. Std. Volumetric Flow Rate from Hydraulic Variable drop-down list, then add the selection for eachthe three links.

➤ To view the plots, click . This will open up Excel for the plo(Figure 41). The raw data is also transferred into Excel and is locon the second sheet named RAS Raw Data.

Figure 41:Plot of Individual Well

and Total OilFlowrates as a

Function of Time

Add...

View


e toure

per-ator

for

Ridge Pipeline

#### TASK A new well is planned for a reservoir that lies under a steep ridge. Duthe location of the reservoir, the well will be deviated as shown in Fig42. The production of the well will be routed to a gas-oil separator oating at 100 psig, by way of a constant diameter flowline. This separis located on the other side of the ridge. The flowline may be built overthe ridge, or around it, as illustrated in Figure 43.

Figure 42:Well Geometry

Figure 43:Topographical Layout

Table 35 gives the Measured Wireline Depth and True Vertical Depththe well, which corresponds with Figure 42.

1

2

3

( ðVdâ

$ ðVdâ

&% ðVdâ

% ðVdâ

!% ðVdâ

"% ðVdâ

#! ðVdâ "' ðVdâ

5\UfQdY_^

! % ðVdâ ("%ðVdâ ! '%ðVdâ!) ðVdâ

GU\\ðCYdUè5\UfQdY_ ð̂-ð ç

CU`QbQd_bè5\UfQdY_ ð̂-ð ç

66 Ridge Pipeline

d
Use 2,500 bbl/day as the initial flowrate estimate for both the source anthe sink.
Part A Design the well and flowline to maximize total production. Use theBeggs-Brill (with Moody Friction Factor) flow correlation (BBM),Standing physical property correlations, and the information given inTables 36 through 39.

Table 35: Tubing MeasurementsLocation Measured Wireline

Depth (ft)True Vertical Depth (ft)

A 800 800

B 4500 4000

C 7500 6500

Table 36: Fluid PropertiesOil 20 API

Gas 0.79 sp.gr

Water 1.01 sp.gr

Table 37: Heat Transfer DataAmbient Temperature 65°F

Geothermal Gradient 2.08 °F/100 ft

Table 38: Reservoir DataTemperature 200°F

Pressure 2,950 psig

Gas/oil ratio 475 ft3/bbl

Water Cut 0 %

Estimated PI 1.7 bbl/day/psi

Table 39: Link DataTubing Nominal ID 4.00 in.

Tubing roughness (absolute) 0.0003 in.

Tubing Heat Transfer 2.2 BTU/hr-ft2-°F

Pipe Nominal ID 6.00 in.

Pipe roughness (absolute) 0.0005 in.

Pipe Heat Transfer 3.0 BTU/hr-ft2-°F


-

Which design maximizes production, building the flowline over theridge or around it?

What is the oil flowrate for the optimum design?

Part B After the well is drilled, a fluid analysis yields the data in Table 40.

At the reservoir temperature of 200°F, the bubble point pressure is 2,110psi, viscosity is 0.7 cp, and compressibility above bubble point pressureis 0.00002 vol/vol/psi. The water cut remains at 0%.

Using the optimum design, found in Part A, what is the flowrate with theadjusted Standing data?

Part C A portable separator test conducted at the wellhead yields the data inTable 41.

Recalculate the flowrate using this additional data.

What is the actual PI?

What is the actual tubing heat transfer coefficient?

@@@@ SOLUTION

Part A Create a new simulation named RIDGE and enter a simulation description.


➤ Enter Blackoil PVT data. To use the Standing correlation for physi-cal properties, click in the Fluid Property Data

Table 40: Fluid Analysis DataProperty Bubble Point Medium Pressure Low Pressure

Pressure (psi) 2,110 1,200 200

Solution GOR (SCF/bbl) 400 280 38

Formation Volume Factor (bbl/STB) 1.298 1.206 1.079

Table 41: Well Test DataOil Rate 2,500 bbl/day

Wellhead Pressure 140 psig

Wellhead Temperature 160°F

Correlations Data

68 Ridge Pipeline

th a

7

he

e

900, 3:n =

irdr

r.

dialog box. Select Standing from the drop-down list for GOR, OilFV , Z-factor, and Oil Viscosit .

➤ Enter the desired global defaults for the Ambient Temperature, Geo-thermal Gradient, and the TUBING and PIPE data using the GlobalDefaults button on the toolbar.




➤ For the LINK data, enter the IPR device first. Select ProductivityIndex from the IPR Model drop-down list. Enter a PI value of 1.bbl/day/psig.

➤ For the three TUBING devices, enter the length and depth for eacsection. Remember, the TUBING farthest from the well head must bentered first.

You will have to build two separate flowsheets to simulate the flowlinover the ridge, and the flowline around the ridge.

➤ First, to simulate the flowline over the ridge, add four PIPEs to theLINK and enter data as shown in Figure 43 (Pipe 1: length = 1,elevation = 0 ft; Pipe 2: length = 1,050, elevation = 250 ft; Pipelength = 825, elevation = -250 ft; Pipe 4: length = 1,075, elevatio0 ft).

➤ Use the Mukherjee-Brill (MB) pressure drop correlation for the thPIPE in the link. This correlation provides an accurate model fodownhill flow.

➤ Save the flowsheet before proceeding.




➤ Find the total standard oil flowrate into the SINK. You can find thisvalue in the Output Report, or you can select View Output from theEdit menu and double-click on the sink.

Step 4 Modify the Flowsheet for Flow Around Ridge

➤ Double-click on the LINK and delete the four PIPEs.

Run


=se

aay. of

tolineave

ted

vari-

➤ Add two PIPEs and enter the data from Figure 43 (P1: length3,100, elevation = 50 ft; P2: length = 2,700, elevation = -50 ft). Uthe MB correlation for the downhill PIPE.

➤ Save this flowsheet as RIDGE2.


➤ Run the simulation again.

The results show that building the pipeline around the ridge yieldsmore favorable result, with a standard oil flowrate of 2,398.7 bbl/dBuilding the pipeline over the ridge results in a standard oil flowrate2,361.9 bbl/day.

Part B For the second part of the problem, you are provided with fluid dataimprove the accuracy of your model. Use the optimum design (pipearound the ridge) for parts B and C. Before making any changes, sthe file as RIDGEB.

Step 6 Adjust Standing Data

➤ Select PVT Data from the General menu.

➤ Select Property Set 1, and click .

➤ Check the box beside and click the associabutton.

➤ Use the data provided in Table 40 to adjust the corresponding ables. The resulting dialog box is shown in Figure 44.

Figure 44:Adjust Standing Data

Dialog Box

Edit...

Adjust Standing Data

70 Ridge Pipeline

he the 20 andingstedons

the

-



The flowrate with the adjusted Standing data is 2,378.3 bbl/day. Tadjusted Standing correlation provides a more accurate model forsystem. Although the difference is small, this discrepancy of aboutbbl/day can compound itself over the course of a year, resulting inannual discrepancy of approximately 7,300 bbl. Generally, the StanCorrelation is not used for oil with API greater than 15, unless adjudata is available. If no such data is provided, the Vasquez correlatimay yield more accurate results.

Part C Open the file named RIDGE2 and before making any changes save file as RIDGEC.

Step 8 Add Well Test Data

➤ Double-click on the SOURCE node.

➤ Activate the Well Test Data radio button, then click on the corresponding button.

➤ Enter the data from Table 41 as shown in Figure 45.

Figure 45:Well Test Data Dialog

Box

➤ Delete the IPR device from the LINK . This enables PIPEPHASE tocalculate the actual PI value from the well test data provided.


ns-

the

e is

on-tion a

inac-ti-thattive.h the

, and


➤ To obtain a detailed report for the link devices (including heat trafer coefficients), select Device Detail = Part from the Print Optionsdialog box.


➤ Scroll through the Output Report to find the calculated values forProductivity Index and the heat transfer coefficient for the TUBING.

The standard oil flowrate is 2,519.3 bbl/day. The calculated PI valu1.802, and the heat transfer coefficient of the TUBIN is 1.923 BTU/hr-ft2°F. These results are shown in Figure 46.

The discrepancy between the estimated and actual PI values demstrates the importance of providing accurate estimates for a simulamodel. By providing an initial estimate of 1.7 for the PI, we providevalue that is too low to properly simulate actual conditions.

It is important to note that this problem only considered productivitycoming up with an optimum design for the pipeline. In reality, other ftors have to be considered before deciding on which design is truly opmal. For instance, a rigorous cost: benefit analysis may show building the pipeline over the ridge may be a more favorable alternaThis may be the case if the labor and material costs associated witpipe far outweigh the profits of greater productivity. This analysis wouldrequire additional data such as the cost per unit volume of the pipelabor costs for building over or around the ridge.

Figure 46:Ou tputReport for IPR INFLOW PERFORMANCE CALCULATION RESULTS

-------------------------------------- WELL NAME L001 IPR TYPE PI TEST DATA TEST 1 FLOW RATE 2500.0(BPD) GOR 475.0(CFBBL) OUTLET PRESSURE 140.0(PSIG) OUTLET TEMPERATURE 160.0(F) CALCULATED RESULTS FLOWING BOTTOMHOLE PRESS 1562.7(PSIG) HEAT TRANSFER COEFFICIENT 1.923(BTU/HRFT2F) IPR COEFFICIENTS (CALCULATED) PRODUCTIVITY INDEX (PI) 1.802(BPDPSI)

72 Ridge Pipeline

Appendix - Keyword Input Files

Black Oil Pipeline

Part ATITLE DIMENSION RATE(LV)=BPDCALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL , DEVICE=PART , PLOT=PART SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=30, GRAV(GAS,SPGR)=0.75, * GRAV(WATER,SPGR)=1.05$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1000, TEMP=120, * RATE(ESTI)=1.0000e+005, GOR=200, WCUT=10, XCORD=38, YCORD=202$SINK NAME=D002, PRES=500, RATE(ESTI)=1.000e+005, * XCORD=732, YCORD=200$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=20000, ECHG=-1000, ID=10, ROUGH(IN)=2.000e-003,* U=1$END

Part BTITLEDIMENSION RATE(LV)=BPD CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL, DEVICE=PART , PLOT=PARTSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=30, GRAV(GAS,SPGR)=0.75, * GRAV(WATER,SPGR)=1.05$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1000, TEMP=120, * RATE=1.0000e+005, GOR=200, WCUT=10, XCORD=38, YCORD=202$SINK NAME=D002, PRES(ESTI)=500, RATE(ESTI)=1.000e+005, * XCORD=732, YCORD=200$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=20000, ECHG=-1000, ID=10, ROUGH(IN)=2.000e-003,* U=1$END


Black Oil Flowline with Devices

Part ATITLEDIMENSION RATE(LV)=BPD CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULLSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=35, GRAV(GAS,SPGR)=0.71, * GRAV(WATER,SPGR)=1.02$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=3000, TEMP=190,* RATE(ESTI)=500, GOR=300, WCUT=20, XCORD=155, YCORD=-1$SINK NAME=D002, PRES=200, RATE(ESTI)=500, XCORD=813, YCORD=-1$LINK NAME=L001, FROM=S001, TO=D002COMPLETION NAME=E001, JONES, TUNNEL=3, PERFD=0.39, SHOTS=8, LENGTH=30TUBING NAME=E002, LENGTH=8000, DEPTH=6500, ID=1.995, U=10, TGRAD=2TUBING NAME=E003, LENGTH=3500, DEPTH=3200, ID=2.441, U=10, TGRAD=2CHOKE NAME=E004, ID=1$END

Part BTITLEDIMENSION RATE(LV)=BPDCALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL , DEVICE=PART SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=35, GRAV(GAS,SPGR)=0.71, * GRAV(WATER,SPGR)=1.02$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=3000, TEMP=190, RATE=2531, * GOR=300, WCUT=20, XCORD=50, YCORD=333$SINK NAME=D002, PRES(ESTI)=200, RATE(ESTI)=2531, XCORD=736, YCORD=327$LINK NAME=L001, FROM=S001, TO=D002COMPLETION NAME=E001, JONES, TUNNEL=3, PERFD=0.39, SHOTS=8, LENGTH=30TUBING NAME=E002, LENGTH=8000, DEPTH=6500, ID=1.995, U=10, TGRAD=2TUBING NAME=E003, LENGTH=3500, DEPTH=3200, ID=2.441, U=10, TGRAD=2CHOKE NAME=E004, ID=1SEPARATOR NAME=E005, PERCENT(GAS)=100PUMP NAME=E006, PRES=700, EFF=85PIPE NAME=E007, LENGTH=15000, ECHG=200, ID=2.441, U=1$END

74 Appendix - Keyword Input Files

Compositional Pipeline

Part ATITLE DIMENSION Metric, LENGTH=M,INCALCULATION NETWORK, PVTRUN, Compositional, PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL , DEVICE=PART , PLOT=FULL , DATABASE=FULL SEGMENT AUTO=ON, DLHORIZ(M)=609.6, DLVERT(M)=152.4$COMPONENT DATALIBID 1, H2S / 2, C1 / 3, C2 / 4, C3 / 5, IC4 / 6, NC4 / 7, IC5 / * 8, NC5 / 9, NC6PETRO(KGM3) 10, C78, 109.000, 748.000 / 11, C910, 137.000, 795.000 / * 12, C11+, 207.000, 944.000 / 13, C20+, 354.000, 1036.000, 547.000$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$THERMODYNAMIC DATAMETHOD SET=SET01 , SYSTEM=SRK , ENTHALPY=SRK , DENSITY(V)=SRK $PVT PROPERTY DATASET SETNO=1, SET=SET01 $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, PRES=74, TEMP=74, * RATE(ESTI,W)=5.0000e+005, XCORD=132, YCORD=246, * COMP(M)=1, 5.4 / 2, 2 / 3, 14.3 / 4, 16.3 / 5, 2.9 / 6, 8.6 / * 7, 3.1 / 8, 2.9 / 9, 4.1 / 10, 8.5 / 11, 4 / 12, 20 / 13, 7.9$SINK NAME=D002, PRES=10, RATE(ESTI)=5.000e+005, XCORD=684, YCORD=241$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=2.000e+005, ECHG=400, ID=24, U=4.8824, TAMB=20$END

Part BTITLE DIMENSION Metric, LENGTH=M,INCALCULATION NETWORK, Compositional, PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL , DEVICE=FULL , PLOT=FULL , DATABASE=FULL SEGMENT AUTO=ON, DLHORIZ(M)=609.6, DLVERT(M)=152.4$COMPONENT DATALIBID 1, H2S / 2, C1 / 3, C2 / 4, C3 / 5, IC4 / 6, NC4 / 7, IC5 / * 8, NC5 / 9, NC6PETRO(KGM3) 10, C78, 109.000, 748.000 / 11, C910, 137.000, 795.000 / * 12, C11+, 207.000, 944.000 / 13, C20+, 354.000, 1036.000, 547.000$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$THERMODYNAMIC DATAMETHOD SET=SET01 , SYSTEM=SRK , ENTHALPY=SRK , DENSITY(V)=SRK $PVT PROPERTY DATAGENERATE SETNO=1, SOURCE=S001, TEMP=5, DT=10, NT=8, PRES=5, DP=10, NP=8SET SETNO=1, SET=SET01 $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, PRES=74, TEMP=74, * RATE(ESTI,W)=5.0000e+005, XCORD=30, YCORD=142, * COMP(M)=1, 5.4 / 2, 2 / 3, 14.3 / 4, 16.3 / 5, 2.9 / 6, 8.6 / * 7, 3.1 / 8, 2.9 / 9, 4.1 / 10, 8.5 / 11, 4 / 12, 20 / 13, 7.9$SINK NAME=D002, PRES=10, RATE(ESTI)=5.000e+005, XCORD=647, YCORD=176$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=2.000e+005, ECHG=400, ID=24, U=4.8824, TAMB=20$END


Part CTITLE DIMENSION Metric , RATE(LV)=CMHR , LENGTH=M,IN, DENSITY=SPGR CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL , DEVICE=PART , PLOT=FULL , DATABASE=FULL SEGMENT AUTO=ON, DLHORIZ(M)=609.6, DLVERT(M)=152.4$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,SPGR)=0.88, GRAV(GAS,SPGR)=1.47, *GRAV(WATER,SPGR)=1$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=74, TEMP=74,* RATE(ESTI)=5.0000e+005, GOR=97, WCUT=0, XCORD=132, YCORD=246$SINK NAME=D002, PRES=10, RATE(ESTI)=5.000e+005, XCORD=684, YCORD=241$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=2.000e+005, ECHG=400, ID=24, U=4.8824, TAMB=20$END

Gas Well

Part ATITLE DIMENSION Metric , LENGTH=M,INCALCULATION NETWORK, Compositional, PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL, DEVICE=PART , PLOT=FULL, DATABASE=FULLSEGMENT AUTO=ON, DLHORIZ(M)=609.6, DLVERT(M)=152.4$COMPONENT DATALIBID 1, C1 / 2, C2 / 3, C3$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$THERMODYNAMIC DATAMETHOD SET=SET01 , SYSTEM=SRK , ENTHALPY=SRK , DENSITY(V)=SRK

PVT PROPERTY DATASET SETNO=1, SET=SET01 $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, PRES=74, TEMP=74, RATE(GV)=0.01, * XCORD=-62, YCORD=188, COMP(M)=1, 80 / 2, 15 / 3, 5$SINK NAME=D002, PRES(ESTI)=50, RATE(ESTI)=10000, XCORD=526, YCORD=191$LINK NAME=L001, FROM=S001, TO=D002TUBING NAME=E001, LENGTH=2002, DEPTH=1677, ID=2.441, U=4.882TUBING NAME=E002, LENGTH=1067, DEPTH=1067, ID=2.441, U=4.882$END

Part BTITLE DIMENSION Metric , RATE(GV)=CMHR , LENGTH=M,INCALCULATION NETWORK, Gas , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL, DEVICE=PART , PLOT=FULL, DATABASE=FULLSEGMENT AUTO=ON, DLHORIZ(M)=609.6, DLVERT(M)=152.4$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(SPGR)=0.68, CPRATIO=1.3$


STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=74, TEMP=74, RATE=0.01, * XCORD=-62, YCORD=188$SINK NAME=D002, PRES(ESTI)=50, RATE(ESTI)=10000, XCORD=526, YCORD=191$LINK NAME=L001, FROM=S001, TO=D002TUBING NAME=E001, LENGTH=2002, DEPTH=1677, ID=2.441, U=4.882TUBING NAME=E002, LENGTH=1067, DEPTH=1067, ID=2.441, U=4.882$END

Case Study of Black Oil PipelineTITLE DIMENSION RATE(LV)=BPDCALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL , DEVICE=PART , PLOT=PART SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=30, GRAV(GAS,SPGR)=0.75, * GRAV(WATER,SPGR)=1.05$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1000, TEMP=120, * RATE=1.0000e+005, GOR=200, WCUT=10, XCORD=38, YCORD=202$SINK NAME=D002, PRES(ESTI)=500, RATE(ESTI)=1.000e+005, XCORD=732,* YCORD=200$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=20000, ECHG=-1000, ID=10, * ROUGH(IN)=2.000e-003, U=1$CASE STUDY DATADESCRIPTION Case 01 RESTOREPARAMETER PIPE=E001, VARIABLE=ID, VALUE=11$CASE STUDY DATADESCRIPTION Case 02 RESTOREPARAMETER PIPE=E001, VARIABLE=ECHG, VALUE=-1100$CASE STUDY DATADESCRIPTION Case 03RESTOREPARAMETER PIPE=E001, VARIABLE=ROUG, VALUE=2.200e-003$CASE STUDY DATADESCRIPTION Case 04 RESTOREPARAMETER PIPE=E001, VARIABLE=U, VALUE=1.1$CASE STUDY DATADESCRIPTION Case 05 RESTOREPARAMETER SOURCE=S001, VARIABLE=RATE(LV), VALUE=1.100e+005$CASE STUDY DATADESCRIPTION Case 06 RESTOREPARAMETER PIPE=E001, VARIABLE=FCOD, FCODE=DE$END


Heavy Crude Pipeline

Part ATITLE DIMENSION RATE(LV)=BPDCALCULATION NETWORK, Liquid , PRANDTLDEFAULT IDPIPE=24, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065, * TAMBIENT=35PRINT INPUT=FULL , DEVICE=PART , DATABASE=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(LIQUID, API)=20, VISC=70, 370/ 120, 50$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=300, TEMP=110,* RATE(ESTI)=80000, XCORD=-99, YCORD=408$SINK NAME=D002, PRES=150, RATE(ESTI)=80000, XCORD=691, YCORD=411$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=1000, ECHG=-1000, WATERPIPE NAME=E002, LENGTH=50000, ECHG=1000, SOIL, CONSOIL=1.2, BDTOP=36PIPE NAME=E003, LENGTH=3.000e+005, SOIL, CONSOIL=0.3, BDTOP=36, TAMB=50$CASE STUDY DATADESCRIPTION Case 01 PARAMETER PIPE=E003, VARIABLE=TAMB, VALUE=30$CASE STUDY DATADESCRIPTION Case 02 PARAMETER PIPE=E003, VARIABLE=TAMB, VALUE=5$END

Part BTITLE DIMENSION RATE(LV)=BPDCALCULATION NETWORK, Liquid , PRANDTLDEFAULT IDPIPE=24, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065, * TAMBIENT=35PRINT INPUT=FULL , DEVICE=PART , DATABASE=FULL SEGMENT AUTO=OFF, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(LIQUID, API)=20, VISC=70, 370/ 120, 50$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=300, TEMP=110,* RATE(ESTI)=80000, XCORD=-99, YCORD=408$SINK NAME=D002, PRES=150, RATE(ESTI)=80000, XCORD=691, YCORD=411$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=1000, ECHG=-1000, WATERPIPE NAME=E002, LENGTH=50000, ECHG=1000, SOIL, CONSOIL=1.2, BDTOP=36PIPE NAME=E003, LENGTH=3.000e+005, SOIL, CONSOIL=0.3, BDTOP=36, * THKINS=2, 0, 0, 0, 0, CONINS=0.015, 0.015, 0.015, 0.015, 0.015, * TAMB=50$CASE STUDY DATADESCRIPTION Case 01 PARAMETER PIPE=E003, VARIABLE=TAMB, VALUE=30$CASE STUDY DATADESCRIPTION Case 02 PARAMETER PIPE=E003, VARIABLE=TAMB, VALUE=5$END


Pipeline SpheringTITLE DIMENSION EnglishCALCULATION NETWORK, Compositional, PRANDTL, SPHERINGDEFAULT IDPIPE=8, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065, * TAMBIENT=65, UPIPE=0.8, UTUBING=1, URISER=1, UANNULUS=1PRINT INPUT=FULL , DEVICE=PART , PLOT=FULL , MAP=TAITEL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$COMPONENT DATALIBID 1, C1 / 2, C2 / 3, C3 / 4, NC4 / 5, NC5 / 6, NC6PETRO(API) 7, PETRO1, , 45.000, 350.000 / 8, PETRO2, , 38.000, 480.000$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$THERMODYNAMIC DATAMETHOD SET=SET01 , SYSTEM=SRK , ENTHALPY=SRK , DENSITY(V)=SRK WATER PROPERTY=Super $PVT PROPERTY DATASET SETNO=1, SET=SET01 $STRUCTURE DATASOURCE NAME=S001, PRIORITY=0, SETNO=1, SET=SET01, PRES=350, TEMP=120, * RATE(GV)=0.7667, XCORD=192, YCORD=272, COMP(M)=1, 88.61 / 2, 3.15 / * 3, 2.69 / 4, 2.04 / 5, 1.67 / 6, 1.11 / 7, 0.55 / 8, 0.18$SINK NAME=D002, PRES(ESTI)=10, RATE(ESTI)=1, XCORD=887, YCORD=279$LINK NAME=L001, FROM=S001, TO=D002, PRINTPIPE NAME=E001, LENGTH=4224, IDSPHERE=8, ID=8, U=0.8PIPE NAME=E002, LENGTH=6336, ECHG=154, ID=8, U=0.8PIPE NAME=E003, LENGTH=8448, ECHG=-69, IDSPHERE=8.1, ID=8, U=0.8PIPE NAME=E004, LENGTH=3696, ECHG=100, ID=8, U=0.8PIPE NAME=E005, LENGTH=6336, ECHG=120, ID=8, U=0.8PIPE NAME=E006, LENGTH=264, ECHG=-10, IDSPHERE=12.1, ID=12, U=0.8PIPE NAME=E007, LENGTH=2640, ECHG=58, ID=12, U=0.8PIPE NAME=E008, LENGTH=9504, ECHG=-118, ID=12, U=0.8$END

Looped Black Oil NetworkTITLE DIMENSION RATE(LV)=BPD , DENSITY=SPGR CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=12, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065,* UPIPE=2, UTUBING=1, URISER=1, UANNULUS=1PRINT INPUT=FULL, DEVICE=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,SPGR)=0.54, GRAV(GAS,SPGR)=0.765, * GRAV(WATER,SPGR)=1$STRUCTURE DATASOURCE NAME=A0 , PRIORITY=0, SETNO=1, PRES=395, TEMP=120,* RATE(ESTI)=10000, GOR=400, WCUT=0, XCORD=78, YCORD=884$SOURCE NAME=A1 , PRIORITY=0, SETNO=1, PRES(ESTI)=300, TEMP=110,* RATE=10000, GOR=300, WCUT=0, XCORD=33, YCORD=317$SOURCE NAME=A2 , PRIORITY=0, SETNO=1, PRES(ESTI)=250, TEMP=110,* RATE=15500, GOR=100, WCUT=0, XCORD=511, YCORD=-94$SOURCE NAME=A3 , PRIORITY=0, SETNO=1, PRES(ESTI)=200, TEMP=120,* RATE=20000, GOR=230, WCUT=0, XCORD=827, YCORD=938$SINK NAME=B , PRES=125, RATE(ESTI)=20000, XCORD=1430, YCORD=579SINK NAME=C , PRES=110, RATE(ESTI)=40000, XCORD=1444, YCORD=287$JUNCTION NAME=J0 , XCORD=212, YCORD=705JUNCTION NAME=J1 , XCORD=287, YCORD=420JUNCTION NAME=J2 , XCORD=595, YCORD=133JUNCTION NAME=J3 , XCORD=889, YCORD=751JUNCTION NAME=J4 , XCORD=598, YCORD=676


JUNCTION NAME=J5 , XCORD=1101, YCORD=313JUNCTION NAME=J6 , XCORD=1115, YCORD=596$LINK NAME=L001, FROM=J0 , TO=J1 PIPE NAME=E002, LENGTH=35000, U=2$LINK NAME=L002, FROM=J1 , TO=J2 PIPE NAME=E004, LENGTH=30000, U=2$LINK NAME=L003, FROM=J0 , TO=J4 PIPE NAME=E005, LENGTH=32000, U=2$LINK NAME=L004, FROM=J4 , TO=J2 PIPE NAME=E006, LENGTH=50000, U=2$LINK NAME=L005, FROM=J4 , TO=J3 PIPE NAME=E008, LENGTH=18000, U=2$LINK NAME=L006, FROM=J3 , TO=J6 PIPE NAME=E011, LENGTH=10000, U=2$LINK NAME=L007, FROM=J2 , TO=J5 PIPE NAME=E010, LENGTH=35000, U=2$LINK NAME=L008, FROM=J6 , TO=J5 PIPE NAME=E012, LENGTH=30000, U=2$LINK NAME=L009, FROM=J6 , TO=B PIPE NAME=E013, LENGTH=100, U=2$LINK NAME=L010, FROM=J5 , TO=C PIPE NAME=E014, LENGTH=100, U=2$LINK NAME=L011, FROM=A0 , TO=J0 PIPE NAME=E001, LENGTH=3500, U=2$LINK NAME=L012, FROM=A1 , TO=J1 PIPE NAME=E003, LENGTH=1000, U=2$LINK NAME=L013, FROM=A2 , TO=J2 PIPE NAME=E007, LENGTH=2500, U=2$LINK NAME=L014, FROM=A3 , TO=J3 PIPE NAME=E009, LENGTH=1000, U=2$END

Black Oil Gathering SystemTITLE DIMENSION RATE(LV)=BPD CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4, IDTUBING=4, IDRISER=4, IDANNULUS=6.065PRINT INPUT=FULLSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=30, GRAV(GAS,SPGR)=0.6, GRAV(WATER,SPGR)=1.01SET SETNO=2, GRAV(OIL,API)=33, GRAV(GAS,SPGR)=0.63,GRAV(WATER,SPGR)=1.03$STRUCTURE DATA$SOURCE NAME=1 , PRIORITY=0, SETNO=1, PRES=2500, TEMP=185,* RATE(ESTI)=1000, GOR=700, WCUT=15, XCORD=490, YCORD=-151$SOURCE NAME=2 , PRIORITY=0, SETNO=1, PRES=2500, TEMP=185,* RATE(ESTI)=1000, GOR=750, WCUT=5, XCORD=238, YCORD=-19$SOURCE NAME=3 , PRIORITY=0, SETNO=1, PRES=2530, TEMP=185, * RATE(ESTI)=1000, GOR=500, WCUT=20, XCORD=122, YCORD=207$SOURCE NAME=4 , PRIORITY=0, SETNO=2, PRES=2370, TEMP=195,* RATE(ESTI)=1000, GOR=700, WCUT=12, XCORD=238, YCORD=451$SOURCE NAME=5 , PRIORITY=0, SETNO=2, PRES=2704, TEMP=190,* RATE(ESTI)=1000, GOR=600, WCUT=25, XCORD=512, YCORD=522$SOURCE NAME=6 , PRIORITY=0, SETNO=2, PRES=2690, TEMP=187,*


RATE(ESTI)=1000, GOR=700, WCUT=15, XCORD=767, YCORD=423$SINK NAME=ONSH, PRES=160, RATE(ESTI)=6000, XCORD=1358, YCORD=186$JUNCTION NAME=PLAT, XCORD=532, YCORD=212$LINK NAME=L001, FROM=1 , TO=PLATIPR NAME=E001, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 5 / OPEN,1 / UPTIME,1TUBING NAME=E002, LENGTH=3000, DEPTH=2500, ID=2.441, U=1CHOKE NAME=E003, ID=1PIPE NAME=E004, LENGTH=1500, ECHG=47, U=1RISER NAME=E005, LENGTH=500, ELEV=470, U=1PIPE NAME=E006, LENGTH=30, U=1$LINK NAME=L002, FROM=2 , TO=PLATIPR NAME=E007, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 6 / OPEN,1 / UPTIME,1TUBING NAME=E008, LENGTH=3500, DEPTH=3500, ID=2.441, U=1CHOKE NAME=E009, ID=1PIPE NAME=E010, LENGTH=1800, ECHG=-70, U=1RISER NAME=E011, LENGTH=500, ELEV=490, U=1PIPE NAME=E012, LENGTH=50, U=1$LINK NAME=L003, FROM=3 , TO=PLATIPR NAME=E013, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 4.5 / OPEN,1 / UPTIME,1TUBING NAME=E014, LENGTH=3800, DEPTH=3700, ID=2.992, U=1CHOKE NAME=E015, ID=1PIPE NAME=E016, LENGTH=2800, ECHG=-70, U=1RISER NAME=E017, LENGTH=500, ELEV=490, U=1PIPE NAME=E018, LENGTH=50, U=1$LINK NAME=L004, FROM=4 , TO=PLATIPR NAME=E019, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 8 / OPEN,1 / UPTIME,1TUBING NAME=E020, LENGTH=4500, DEPTH=4300, ID=2.992, U=1CHOKE NAME=E021, ID=1PIPE NAME=E022, LENGTH=2700, ECHG=-40, U=1RISER NAME=E023, LENGTH=550, ELEV=490, U=1PIPE NAME=E024, LENGTH=20, U=1$LINK NAME=L005, FROM=5 , TO=PLATIPR NAME=E025, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 5 / OPEN,1 / UPTIME,1TUBING NAME=E026, LENGTH=4200, DEPTH=4100, ID=2.992, U=1CHOKE NAME=E027, ID=1PIPE NAME=E028, LENGTH=2900, ECHG=-10, U=1RISER NAME=E029, LENGTH=600, ELEV=490, U=1PIPE NAME=E030, LENGTH=20, U=1$LINK NAME=L006, FROM=6 , TO=PLATIPR NAME=E031, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 10 / OPEN,1 / UPTIME,1TUBING NAME=E032, LENGTH=3900, DEPTH=3900, ID=2.992, U=1CHOKE NAME=E033, ID=1PIPE NAME=E034, LENGTH=3700, ECHG=-10, U=1RISER NAME=E035, LENGTH=600, ELEV=490, U=1PIPE NAME=E036, LENGTH=20, U=1$LINK NAME=L007, FROM=PLAT, TO=ONSHPIPE NAME=E037, LENGTH=490, ID=16, U=1PIPE NAME=E038, LENGTH=2.112e+005, ECHG=300, ID=16, U=1PIPE NAME=E039, LENGTH=5280, ECHG=190, ID=16, U=1PIPE NAME=E040, LENGTH=10560, ID=16, U=1$END

Two Well Gas Lift AnalysisTITLEDIMENSION RATE(LV)=BPD CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT NOMD=4, SCHE= 40, NOMT=4, SCHT=TB01, NOMR=4, SCHR= 40, * IDANNULUS=6.065, TAMBIENT=65, UPIPE=1, UTUBING=1, URISER=1, UANNULUS=1PRINT INPUT=FULLSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=30, GRAV(GAS,SPGR)=0.75,* GRAV(WATER,SPGR)=1.002LIFTGAS GRAV(GAS,SPGR)=0.8$STRUCTURE DATA


$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=2499, TEMP=180,* RATE(ESTI)=6000, GOR=108, WCUT=0, XCORD=-190, YCORD=-12$SOURCE NAME=S002, PRIORITY=0, SETNO=1, PRES=2505, TEMP=181,* RATE(ESTI)=6000, GOR=102, WCUT=10.5, XCORD=-120, YCORD=644$SINK NAME=D004, PRES=250, RATE(ESTI)=10000, XCORD=818, YCORD=284$JUNCTION NAME=J003, XCORD=269, YCORD=260$LINK NAME=L001, FROM=S001, TO=J003IPR NAME=E001, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 25.5 / OPEN,1 / UPTIME,1TUBING NAME=E002, LENGTH=8010, DEPTH=8010, U=1GLVALVE NAME=E003, RATE=1.5TUBING NAME=E004, LENGTH=6810, DEPTH=6810, U=1PIPE NAME=E005, LENGTH=231, U=1$LINK NAME=L002, FROM=S002, TO=J003IPR NAME=E006, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 22.1 / OPEN,1 / UPTIME,1TUBING NAME=E007, LENGTH=8111, DEPTH=8111, U=1GLVALVE NAME=E008, RATE=1.5TUBING NAME=E009, LENGTH=6445, DEPTH=6445, U=1PIPE NAME=E010, LENGTH=103, U=1$LINK NAME=L003, FROM=J003, TO=D004PIPE NAME=E011, LENGTH=1500, U=1$CASE STUDY DATADESCRIPTION Case 01 - 2.0 MM ft3/day RESTOREPARAMETER GLVALVE=E003, VARIABLE=RATE, VALUE=2PARAMETER GLVALVE=E008, VARIABLE=RATE, VALUE=2$CASE STUDY DATADESCRIPTION Case 02 - 2.5 MM ft3/day RESTOREPARAMETER GLVALVE=E003, VARIABLE=RATE, VALUE=2.5PARAMETER GLVALVE=E008, VARIABLE=RATE, VALUE=2.5$CASE STUDY DATADESCRIPTION Case 03 - 3.0 MM ft3/day RESTOREPARAMETER GLVALVE=E003, VARIABLE=RATE, VALUE=3PARAMETER GLVALVE=E008, VARIABLE=RATE, VALUE=3$CASE STUDY DATADESCRIPTION Case 04 - 3.5 MM ft3/day RESTOREPARAMETER GLVALVE=E003, VARIABLE=RATE, VALUE=3.5PARAMETER GLVALVE=E008, VARIABLE=RATE, VALUE=3.5$CASE STUDY DATADESCRIPTION Case 05 - 4.0 MM ft3/day RESTOREPARAMETER GLVALVE=E003, VARIABLE=RATE, VALUE=4PARAMETER GLVALVE=E008, VARIABLE=RATE, VALUE=4$CASE STUDY DATADESCRIPTION Case 06 - 4.5 MM ft3/day RESTOREPARAMETER GLVALVE=E003, VARIABLE=RATE, VALUE=4.5PARAMETER GLVALVE=E008, VARIABLE=RATE, VALUE=4.5$CASE STUDY DATADESCRIPTION Case 07 - 5.0 MM ft3/day RESTOREPARAMETER GLVALVE=E003, VARIABLE=RATE, VALUE=5PARAMETER GLVALVE=E008, VARIABLE=RATE, VALUE=5$END


Steam Injection Well

Part ATITLE DIMENSION RATE(W)=LBHRCALCULATION NETWORK, Steam , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(WATER,SPGR)=1.001CORRELATION WPROP=Super $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1500, RATE(ESTI)=1000, * QUALITY=99, XCORD=25, YCORD=163$SINK NAME=D002, PRES=2000, RATE(ESTI)=1000, INJECT, XCORD=641, YCORD=159$$LINK NAME=L001, FROM=S001, TO=D002, PRINTPIPE NAME=E001, LENGTH=1000, NOMD=4, SCHED= 40, AIR, VELOCITY=10, * THKPIPE=0.125, THKINS=0.1, 0, 0, 0, 0, CONINS=0.01, 0.015, 0.015, * 0.015, 0.015, TAMB=80TUBING NAME=E002, LENGTH=2000, DEPTH=2000, NOMD=3.5, SCHED=TB01,* HOLEID=8.5, TIME=100, DIFFUSIVITY=0.96, TGRAD=1, MEDIUM=3, 5, * IDCASING=5.75, ODTUBING=3.5, ODCASING=6, EMIS=0, 0, EMOS=0, 0, * CPAN=0.46, 0, CONANN=0.12083, 0.5, CONCAS=25, 25, BETANN=0, 0, * VISANN=0.22, 0, DENANN(LBFT3)=62.4, 0, VELANN=0, 0, CONEARTH=0.8IPR NAME=E003, TYPE=PI, IVAL=BASIS, 5, RVAL=PI, 10 / UPTIME,1$END

Part BTITLE DIMENSION RATE(W)=LBHRCALCULATION NETWORK, Steam , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(WATER,SPGR)=1.001CORRELATION WPROP=Super $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1500, RATE(ESTI)=1000, * QUALITY=99, XCORD=25, YCORD=163$SINK NAME=D002, PRES=2000, RATE(ESTI)=1000, INJECT, XCORD=641, YCORD=159$LINK NAME=L001, FROM=S001, TO=D002, PRINTPIPE NAME=E001, LENGTH=1000, NOMD=4, SCHED= 40, SOIL, BDTOP=36, * THKPIPE=0.125, THKINS=0.125, 0, 0, 0, 0, CONINS=0.1, 0.015, 0.015, * 0.015, 0.015, TAMB=80TUBING NAME=E002, LENGTH=2000, DEPTH=2000, NOMD=3.5, SCHED=TB01,* HOLEID=8.5, TIME=100, DIFFUSIVITY=0.96, TGRAD=1, MEDIUM=3, 5, * IDCASING=5.75, ODTUBING=3.5, ODCASING=6, EMIS=0, 0, EMOS=0, 0, * CPAN=0.46, 0, CONANN=0.12083, 0.5, CONCAS=25, 25, BETANN=0, 0, * VISANN=0.22, 0, DENANN(LBFT3)=62.4, 0, VELANN=0, 0, CONEARTH=0.8IPR NAME=E003, TYPE=PI, IVAL=BASIS, 5, RVAL=PI, 10 / UPTIME,1$END


Part CTITLE DIMENSION RATE(W)=LBHR CALCULATION NETWORK, Steam , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULLSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(WATER,SPGR)=1.001CORRELATION WPROP=Super $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1500, RATE(ESTI)=1000, * QUALITY=99, XCORD=-82, YCORD=163$SINK NAME=D002, PRES=2000, RATE(ESTI)=1000, INJECT, XCORD=641, YCORD=159$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=1000, NOMD=4, SCHED= 40, AIR, VELOCITY=10, * THKPIPE=0.125, THKINS=0.125, 0, 0, 0, 0, CONINS=0.1, 0.015, 0.015, * 0.015, 0.015, TAMB=80TUBING NAME=E002, LENGTH=2000, DEPTH=2000, NOMD=3.5, SCHED=TB01,* HOLEID=8.5, TIME=100, DIFFUSIVITY=0.96, TGRAD=1, MEDIUM=3, 5, * IDCASING=5.75, ODTUBING=3.5, ODCASING=6, EMIS=0, 0, EMOS=0, 0, * CPAN=0.46, 0, CONANN=0.12083, 0.5, CONCAS=25, 25, BETANN=0, 0, * VISANN=0.22, 0, DENANN(LBFT3)=62.4, 0, VELANN=0, 0, CONEARTH=0.8IPR NAME=E003, TYPE=PI, IVAL=BASIS, 5, RVAL=PI, 10 / UPTIME,1$END

Part DTITLE DIMENSION RATE(W)=LBHRCALCULATION NETWORK, Steam , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(WATER,SPGR)=1.001CORRELATION WPROP=Super $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1500, RATE(ESTI)=1000, * QUALITY=99, XCORD=25, YCORD=163$SINK NAME=D002, PRES=2000, RATE(ESTI)=1000, INJECT, XCORD=641, YCORD=159$LINK NAME=L001, FROM=S001, TO=D002, PRINTPIPE NAME=E001, LENGTH=1000, NOMD=4, SCHED= 40, AIR, VELOCITY=10, * THKPIPE=0.125, THKINS=0.1, 0, 0, 0, 0, CONINS=0.01, 0.015, 0.015, * 0.015, 0.015, TAMB=80TUBING NAME=E002, LENGTH=2000, DEPTH=2000, NOMD=3.5, SCHED=TB01,* HOLEID=8.5, TIME=100, DIFFUSIVITY=0.96, TGRAD=1, MEDIUM=1, 5, * IDCASING=5.75, ODTUBING=3.5, ODCASING=6, EMIS=0, 0, EMOS=0, 0, * CPAN=0.25, 0, CONANN=0.01875, 0.5, CONCAS=25, 25, BETANN=1.410e-003, 0,* VISANN=0.0223, 0, DENANN(LBFT3)=0.0559, 0, VELANN=0, 0, CONEARTH=0.8IPR NAME=E003, TYPE=PI, IVAL=BASIS, 5, RVAL=PI, 10 / UPTIME,1$END


Part ETITLE DIMENSION RATE(W)=LBHRCALCULATION NETWORK, Steam , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(WATER,SPGR)=1.001CORRELATION WPROP=Super $STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=1500, RATE(ESTI)=1000, * QUALITY=99, XCORD=-82, YCORD=163$SINK NAME=D002, PRES=2000, RATE(ESTI)=1000, INJECT, XCORD=641, YCORD=159$LINK NAME=L001, FROM=S001, TO=D002PIPE NAME=E001, LENGTH=1000, NOMD=4, SCHED= 40, AIR, VELOCITY=10, * THKPIPE=0.125, THKINS=0.1, 0, 0, 0, 0, CONINS=0.01, 0.015, 0.015, * 0.015, 0.015, TAMB=80TUBING NAME=E002, LENGTH=2000, DEPTH=2000, NOMD=3.5, SCHED=TB01,* HOLEID=8.5, TIME=100, DIFFUSIVITY=0.96, TGRAD=1, MEDIUM=1, 5, * IDCASING=5.75, ODTUBING=3.5, ODCASING=6, EMIS=0, 0, EMOS=0, 0, * CPAN=0.25, 0, CONANN=0.01875, 0.5, CONCAS=25, 25, BETANN=1.410e-003, 0,* VISANN=0.0223, 0, DENANN(LBFT3)=0.0559, 0, VELANN=0, 0, CONEARTH=0.8IPR NAME=E003, TYPE=PI, IVAL=BASIS, 5, RVAL=PI, 10 / UPTIME,1$CASE STUDY DATADESCRIPTION Case Study 01 PARAMETER SOURCE=S001, VARIABLE=PRES, VALUE=2000$CASE STUDY DATADESCRIPTION Case Study 02 PARAMETER SOURCE=S001, VARIABLE=PRES, VALUE=2200$CASE STUDY DATADESCRIPTION Case Study 03 PARAMETER SOURCE=S001, VARIABLE=PRES, VALUE=2400$CASE STUDY DATADESCRIPTION Case Study 04 PARAMETER SOURCE=S001, VARIABLE=PRES, VALUE=2600$END

Forecasting Well ProductionTITLE DIMENSION RATE(LV)=BPDCALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=3, IDRISER=4.026, IDANNULUS=6.065, * TAMBIENT=50, UPIPE=1, UTUBING=0.74, URISER=1, UANNULUS=1PRINT INPUT=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=34, GRAV(GAS,SPGR)=0.84,GRAV(WATER,SPGR)=1.04$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=4500, TEMP=150,* RATE(ESTI)=3000, GOR=40, WCUT=20, XCORD=338, YCORD=868$SINK NAME=D002, PRES=50, RATE(ESTI)=3000, XCORD=484, YCORD=125$LINK NAME=L001, FROM=S001, TO=D002IPR NAME=E001, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 2.4 / OPEN,1 / UPTIME,1TUBING NAME=E002, LENGTH=9400, DEPTH=8000, U=0.74TUBING NAME=E003, LENGTH=6200, DEPTH=5000, U=0.74TUBING NAME=E004, LENGTH=1000, DEPTH=1000, U=0.74$


CASE STUDY DATADESCRIPTION Case 01 PARAMETER TUBING=ALL, VARIABLE=ID, GLOBAL, OLD=3, VALUE=4$CASE STUDY DATADESCRIPTION Case 02 RESTOREPARAMETER IPR=E001, VARIABLE=PI, VALUE=4.8$CASE STUDY DATADESCRIPTION Case 03 PARAMETER TUBING=ALL, VARIABLE=ID, GLOBAL, OLD=3, VALUE=4PARAMETER IPR=E001, VARIABLE=PI, VALUE=4.8$END

Three-Year Decline ModelTITLE DIMENSION RATE(LV)=BPDCALCULATION NETWORK, Blackoil , PRANDTLDEFAULT IDPIPE=4.026, IDTUBING=4.026, IDRISER=4.026, IDANNULUS=6.065PRINT INPUT=FULL , DATABASE=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=35.2, GRAV(GAS,SPGR)=0.704, * GRAV(WATER,SPGR)=1.01SET SETNO=2, GRAV(OIL,API)=35.4, GRAV(GAS,SPGR)=0.71, * GRAV(WATER,SPGR)=1.012$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=2602, TEMP=105,* RATE(ESTI)=7000, GOR=450, WCUT=10.1, XCORD=115, YCORD=856$SOURCE NAME=S002, PRIORITY=0, SETNO=2, PRES=2598, TEMP=125, * RATE(ESTI)=11000, GOR=455, WCUT=11.1, XCORD=621, YCORD=876$SINK NAME=D004, PRES=300, RATE(ESTI)=20000, XCORD=1101, YCORD=248$JUNCTION NAME=J003, XCORD=404, YCORD=253$LINK NAME=L001, FROM=S001, TO=J003IPR NAME=E002, TYPE=PI, GROUP=RC01, IVAL=BASIS, 3, RVAL=PI, 30 / * PRES1, 2602 / PRES2, 2431 / PRES3, 2296 / PRES4, 2011 / PRES5, 1834 / * GOR1, 450 / GOR2, 477 / GOR3, 492 / GOR4, 513 / GOR5, 550 / * WCUT1, 10.1 / WCUT2, 10.3 / WCUT3, 10.8 / WCUT4, 11 / WCUT5, 11.8 / * ABANDON, 1200 / OPEN,1 / UPTIME,1 / QLCUM, 0, ARRAY=PPRES, 2602, 2431, * 2296, 2011, 1958, 1834 / AQLCUM, 0, 1.000e+007, 2.000e+007, 3.000e+007,* 4.000e+007, 5.000e+007TUBING NAME=E003, LENGTH=1500, DEPTH=1450, NOMD=2.875, SCHED=TB01, U=1CHOKE NAME=E004, ID=2PIPE NAME=E005, LENGTH=201, ECHG=-5, NOMD=4, SCHED= 40, U=1$LINK NAME=L002, FROM=S002, TO=J003IPR NAME=E006, TYPE=PI, GROUP=RC01, IVAL=BASIS, 3, RVAL=PI, 25 / * PRES1, 2602 / PRES2, 2431 / PRES3, 2296 / PRES4, 2011 / PRES5, 1834 / * GOR1, 455 / GOR2, 481 / GOR3, 506 / GOR4, 530 / GOR5, 562 / * WCUT1, 11.1 / WCUT2, 11.1 / WCUT3, 11.5 / WCUT4, 11.8 / WCUT5, 12.5 / * ABANDON, 1200 / OPEN,1 / UPTIME,1TUBING NAME=E007, LENGTH=1631, DEPTH=1515, NOMD=2.875, SCHED=TB01, U=1CHOKE NAME=E008, ID=2$LINK NAME=L003, FROM=J003, TO=D004PIPE NAME=E001, LENGTH=4070, ECHG=207, NOMD=4, SCHED= 40, U=1$TIMESTEPPINGCHANGE TIME=365, 730, 1096$END


Ridge Pipeline

Part A

Flow over RidgeTITLE DIMENSION RATE(LV)=BPD CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT NOMD=6, SCHE= 40, NOMT=4, SCHT=TB01, IDRISER=4.026, * IDANNULUS=6.065, TAMBIENT=65, TGRAD=2.08, UPIPE=3, UTUBING=2.2, * URISER=1, UANNULUS=1PRINT INPUT=FULLSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=20, GRAV(GAS,SPGR)=0.79,* GRAV(WATER,SPGR)=1.01CORRELATION VISC(OIL)=Standing, SGOR=Standing, FVF=Standing$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=2950, TEMP=200, * RATE(ESTI)=2500, GOR=475, WCUT=0, XCORD=50, YCORD=182$SINK NAME=D002, PRES=100, RATE(ESTI)=2500, XCORD=932, YCORD=184$LINK NAME=L001, FROM=S001, TO=D002IPR NAME=E001, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 1.7 / OPEN,1 / UPTIME,1TUBING NAME=E002, LENGTH=7500, DEPTH=6500, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E003, LENGTH=4500, DEPTH=4000, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E004, LENGTH=800, DEPTH=800, ROUGH(IN)=3.000e-004, U=2.2PIPE NAME=E005, LENGTH=1900, ROUGH(IN)=5.000e-004, U=3PIPE NAME=E006, LENGTH=1050, ECHG=250, ROUGH(IN)=5.000e-004, U=3PIPE NAME=E007, LENGTH=825, ECHG=-250, ROUGH(IN)=5.000e-004, U=3, FCODE=MB PIPE NAME=E008, LENGTH=1075, ROUGH(IN)=5.000e-004, U=3$END

Flow Around RidgeTITLE DIMENSION RATE(LV)=BPD CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT NOMD=6, SCHE= 40, NOMT=4, SCHT=TB01, IDRISER=4.026, * IDANNULUS=6.065, TAMBIENT=65, TGRAD=2.08, UPIPE=3, UTUBING=2.2, * URISER=1, UANNULUS=1PRINT INPUT=FULLSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=20, GRAV(GAS,SPGR)=0.79,GRAV(WATER,SPGR)=1.01CORRELATION VISC(OIL)=Standing, SGOR=Standing, FVF=Standing$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=2950, TEMP=200,* RATE(ESTI)=2500, GOR=475, WCUT=0, XCORD=50, YCORD=182$SINK NAME=D002, PRES=100, RATE(ESTI)=2500, XCORD=932, YCORD=184$LINK NAME=L001, FROM=S001, TO=D002IPR NAME=E001, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 1.7 / OPEN,1 / UPTIME,1TUBING NAME=E002, LENGTH=7500, DEPTH=6500, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E003, LENGTH=4500, DEPTH=4000, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E004, LENGTH=800, DEPTH=800, ROUGH(IN)=3.000e-004, U=2.2PIPE NAME=E005, LENGTH=3100, ECHG=50, ROUGH(IN)=5.000e-004, U=3PIPE NAME=E006, LENGTH=2700, ECHG=-50, ROUGH(IN)=5.000e-004, U=3, FCODE=MB $END


Part BTITLE DIMENSION RATE(LV)=BPD CALCULATION NETWORK, Blackoil , PRANDTLDEFAULT NOMD=6, SCHE= 40, NOMT=4, SCHT=TB01, IDRISER=4.026, * IDANNULUS=6.065, TAMBIENT=65, TGRAD=2.08, UPIPE=3, UTUBING=2.2, * URISER=1, UANNULUS=1PRINT INPUT=FULLSEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=20, GRAV(GAS,SPGR)=0.79,GRAV(WATER,SPGR)=1.01ADJUST TRES=200, VISC=0.7, COMP=2.0000e-005, PRES=2110, 1200, 200, * FVF=1.298, 1.206, 1.079, SGOR=400, 280, 38CORRELATION VISC(OIL)=Standing, SGOR=Standing, FVF=Standing$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=2950, TEMP=200, * RATE(ESTI)=2500, GOR=475, WCUT=0, XCORD=50, YCORD=182$SINK NAME=D002, PRES=100, RATE(ESTI)=2500, XCORD=932, YCORD=184$$LINK NAME=L001, FROM=S001, TO=D002IPR NAME=E001, TYPE=PI, IVAL=BASIS, 3, RVAL=PI, 1.7 / OPEN,1 / UPTIME,1TUBING NAME=E002, LENGTH=7500, DEPTH=6500, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E003, LENGTH=4500, DEPTH=4000, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E004, LENGTH=800, DEPTH=800, ROUGH(IN)=3.000e-004, U=2.2PIPE NAME=E005, LENGTH=3100, ECHG=50, ROUGH(IN)=5.000e-004, U=3PIPE NAME=E006, LENGTH=2700, ECHG=-50, ROUGH(IN)=5.000e-004, U=3, * FCODE=MB $END

Part CTITLE DIMENSION RATE(LV)=BPDCALCULATION SINGLE, Blackoil , PRANDTL$DEFAULT NOMD=6, SCHE= 40, NOMT=4, SCHT=TB01, IDRISER=4.026, * IDANNULUS=6.065, TAMBIENT=65, TGRAD=2.08, UPIPE=3, UTUBING=2.2, * URISER=1, UANNULUS=1PRINT INPUT=FULL, DEVICE=FULL SEGMENT AUTO=ON, DLHORIZ(FT)=2000, DLVERT(FT)=500$NETWORK DATASOLUTION PBALANCE, FLOWAL=2, STEP=1$PVT PROPERTY DATASET SETNO=1, GRAV(OIL,API)=20, GRAV(GAS,SPGR)=0.79,GRAV(WATER,SPGR)=1.01CORRELATION VISC(OIL)=Standing, SGOR=Standing, FVF=Standing$STRUCTURE DATA$SOURCE NAME=S001, PRIORITY=0, SETNO=1, PRES=2950, TEMP=200, * RATE(ESTI)=2500, GOR=475, WCUT=0, XCORD=50, YCORD=182WTEST NAME=E004, PI , RESP=2950, TEMP=160, PRES=140, RATE=2500, * GOR=475, WCUT=0$SINK NAME=D002, PRES=100, RATE(ESTI)=2500, XCORD=932, YCORD=184$LINK NAME=L001, FROM=S001, TO=D002TUBING NAME=E002, LENGTH=7500, DEPTH=6500, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E003, LENGTH=4500, DEPTH=4000, ROUGH(IN)=3.000e-004, U=2.2TUBING NAME=E004, LENGTH=800, DEPTH=800, ROUGH(IN)=3.000e-004, U=2.2PIPE NAME=E005, LENGTH=3100, ECHG=50, ROUGH(IN)=5.000e-004, U=3PIPE NAME=E006, LENGTH=2700, ECHG=-50, ROUGH(IN)=5.000e-004, U=3, * FCODE=MB $END


Date post:	06-Mar-2015
Category:	Documents
Upload:	hernan-montero
View:	3,179 times
Download:	14 times